final copy of new mwd manual

Approved By Director

Document & Revision No. JIN-DD-MWD-INDUCTION.MANUAL-01

Reviewed By GM

Date of issue August 2011

Prepared by Base Coordinator

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Title MWD/DD-INDUCTION.MANUAL

DIRECTIONAL DRILLING

INDUCTION MANUAL



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DIRECTIONAL DRILLING

INDUCTION MANUAL-01

Issue/Revision : JIN-DD-MWD.IND.MANUAL-01

Compiled By

Kamlesh Unadkat / Vaishali Sali Base Coordinator

Reviewed By

Umesh Thakur / Satish Jawanjal GM (Directional Drilling)

Approved By

Dr. I N Chatterjee Director



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Table of Contents 1. Introduction to Jindal 7

2. Oil exploration & drilling 10

2.1 Forming oil 10 2.2 Locating Oil 11 2.3 Oil Drilling Preparation 12 2.4 Oil Rig Systems 14 2.5 Testing For Oil 19

3. Directional Drilling 21

3.1 Applications of Directional Drilling 21 3.1.1 Sidetracking 21 3.1.2 Inaccessible Locations 21 3.1.3 Salt Dome Drilling 22 3.1.4 Offshore Multiwell Drilling 23 3.2 Types of Directional Wells 23 3.2.1 “L” profile (Build and Hold) 24 3.2.2 “S” Type Well 24 3.2.3 “J” Type Well 25 3.2.4 Horizontal Well 25 3.3 Geometry of A Directional well 25

4. Drilling of Directional Well 28

4.1 Bottom Hole Assembly 29 4.2 Sizes of BHA Component 30 4.3 Parts of A BHA 30 4.3.1 Drill bit 30 4.3.2 Steerable Downhole Mud Motor 32 4.3.3 Float Sub 36 4.3.4 UBHO (Universal Bore Hole Orienting subs) 37 4.3.5 NMDC (Non Magnetic Drill Collar) 38

4.3.6 Heavy Weight Drill Pipes 38 4.3.7 Drill Collars 39 4.3.8 Stabilizers 39 4.3.9 Crossovers 40



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5. Measurement 42

5.1 Inclination/ Azimuth/ Measured Depth 42 5.2 True North and Magnetic North 43 5.3 Earth’s Magnetic Field 44 5.4 Earth’s Magnetic Components 44

6. MWD 46

6.1 Introduction 46 6.2 What Is MWD? 46 6.3 Mud Pulse Telemetry 46 6.4 MWD Principles 48

6.4.1 Positive Mud Pulse Telemetry 48 6.4.2 Negative Mud Pulse Telemetry 48 6.4.3 Continuous Wave Telemetry 48 6.4.4 Electromagnetic Telemetry 48

6.5 MWD TOOL Components 51

6.5.1 Dummy Switch 51 6.5.2 Centralizer 51 6.5.3 Electronics Module 52 6.5.4 Gamma Tool 53 6.5.5 Battery 55 6.5.6 Pulsar Driver System 56 6.5.7 Stringer Assembly 57

6.6 MWD STRING 58 6.6.1 Gamma Job 58 6.6.2 Non-Gamma Job 58

6.7 Placing MWD tool in the BHA 60 6.8 KINTEC PIN CONNECTIONS 62 6.9 Working of MWD tool 62 6.10 MWD Tool Retrieval Equipment 64 6.11 TOOLFACE 65 6.12 Fluidic Vortex 66 6.13 Azimuth Correction Technique 67 6.14 Basic Hydraulics 69

6.14.1 System Pressure 69 6.14.2 Annular Velocity 70



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6.14.3 Pressure Pulses 71 6.14.4 Drilling Fluid 71

6.15 Factors Affecting the Mud Pulse 72 6.16 Reliability 72

7. Tensor MWD Battery Manual 74 7.1 Procedure for Leaking or Vented Batteries 76 7.2 Procedure for Hot Batteries 77 7.3 Procedure for Exploding Batteries 77 7.4 Procedure for Lithium Fire 78 7.5 Lithium Battery Safety 78 7.6 Storage and Disposal Tips 80 7.7 Handling and Inspection Guidelines 81 7.8 Handling during Product Assembly 82

8. QMWD-SAP System 84

8.1 System Description 84 8.2 Toolface Offset Procedures 87 8.3 Summary of the Features Of Qmwd V 01.30 90 8.4 Summary of Features of Qmwdpc V 01.20 92 8.5 Summary of New Features in Qmwd V02.02 95

9. TRU-VU User Guide 97

9.1 Tru Vu Data Wise System Setup 97 9.2 Printing Plots 103 9.3 Calibration 112 9.4 Miscellaneous Notes 114 9.5 Tru-Vu Renewal Procedure 115

10. Drill Well User Guide 117

10.1 Configuration 117 10.2 Loading Parameters From A Device 120 10.3 Xxtalk Utility 120 10.4 Drillwell Main Screen 122 10.5 Tools Screen 125 10.6 Depth Tracking Setup 126 10.7 TFO Procedure 126 10.8 Wits Setup 128



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11. Ring Out Test Sheet 145

12. Poppet Orifice Chart 147



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1. INTRODUCTION

This is the official “Jindal Drilling MWD Training Guide.” This manual is designed

to help novice and seasoned oilfield worker make the transition into becoming an

MWD Engineer specializing in the use of probe based positive pulse telemetry

MWD system.

This manual is intended to be used with your in-field training to give you the best

possible chance for success.

The only dumb question is the one you didn’t ask and should have. By not asking

a question you may inadvertently miss an important point that could cause

trouble in field and cost thousands of dollars.

Guide to Safety

You must take adequate precautions before you start working on any operations.

A health and safety introduction will be conducted before you can go to any rig

sites.

You’ll be shown current handling and cleaning methods for all equipment that

your job requires you to use.

Ensure your equipment is in good working order to prevent accidents from

happening.



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In case of an accident, report it to management immediately.

PERSONAL PROTECTIVE EQUIPMENT When working on an oil rig, appropriate attire, coverall is required. Any

clothing underneath the coverall should be fire retardant or at very least

breathable and slow burning.

The uniform should be clean and in good repair when you go to a job site. You should look professional when at any jobsite.

For safety reasons your hair must be cut short. If you have longer hair it must be

tied back or put in a pony tail and you should come clean shaven for work.

MWD uniforms consist of:

Fire retardant coveralls

CSA approved Hard hat

CSA approved steel toed Boots

Hearing protection

Gloves

TAKE PRIDE IN YOUR WORK AND WHERE YOU WORK! You are responsible for maintaining your equipment.



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Ensure all tools and equipment is clean and in good working order, ensure your

toolboxes have adequate supplies to complete a job professionally – all the time.

Please keep any living/work area clean for yourselves and your co-workers.

Ensure you clean up any shacks properly before leaving a job site.

Work Smart – Work Safe MWD ENGINEER RESPONSIBILITIES

The MWD Engineer must know how a rig operates as the rig operations

affect the working of the MWD tool. In this knowing the BHA( bottom hole

assembly) in hole is a must.

An MWD Engineer must know how the different components of an MWD

string operate and how they contribute to drilling.

An MWD Engineer must reduce the problems and downtime.

An MWD Engineer must always remember that they are representing their

company in front of the client hence proper behavior is expected of the

operator always in their shift.



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2. Oil exploration & Drilling 2.1 Forming oil Oil comes from organic matter that died and sank into the sand at the bottom of

the sea.

Over the years, the organisms decayed in the sedimentary layers. In these

layers, there was little or no oxygen present so microorganisms broke the

remains into carbon-rich compounds that formed organic layers which formed

the source rock. As new sedimentary layers were deposited, they exerted intense

pressure and heat on the source rock. The heat and pressure distilled the

organic material into crude oil and natural gas. The oil flowed from the source

rock and accumulated in thicker, more porous limestone or sandstone,

called reservoir rock. Oil and natural gas in the reservoir rocks got trapped

between layers of impermeable rock, or cap rock.

The different types of trap systems are:

Structural traps

Folds - Horizontal movements press inward and move the rock layers upward

into a fold.

Faults - The layers of rock crack, and one side shifts upward or downward.



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Stratigraphic traps Pinch out - A layer of impermeable rock is squeezed upward into the reservoir

rock.

2.2 Locating Oil

Searching for oil over water using seismology

Whether employed directly by an oil company or under contract from a private

firm, geologists are the ones responsible for finding oil. Their task is to find the

right conditions for an oil trap -- the right source rock, reservoir rock and

entrapment. Modern oil geologists also examine surface rocks and terrain, with

the additional help of satellite images. However, they also use a variety of other



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methods to find oil. They can use sensitive gravity meters to measure tiny

changes in the Earth's gravitational field that could indicate flowing oil, as well as

sensitive magnetometers to measure tiny changes in the Earth's magnetic field

caused by flowing oil. They can detect the smell of hydrocarbons using sensitive

electronic noses called sniffers. Finally, and most commonly, they

use seismology, creating shock waves that pass through hidden rock layers and

interpreting the waves that are reflected back to the surface.

In seismic surveys, a shock wave is created by the following:

Compressed-air gun - shoots pulses of air into the water (for exploration

over water)

Thumper truck - slams heavy plates into the ground (for exploration over

land)

Explosives - detonated after being drilled into the ground (for exploration

over land) or thrown overboard (for exploration over water)

The shock waves travel beneath the surface of the Earth and are reflected back

by the various rock layers. The reflections travel at different speeds depending

upon the type or density of rock layers through which they must pass. Sensitive

microphones or vibration detectors detect the reflections of the shock waves --

hydrophones over water, seismometers over land. Seismologists interpret the

readings for signs of oil and gas traps.

Once geologists find a prospective oil strike, they mark the location

using GPS coordinates on land or by marker buoys on water.



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2.3 Oil Drilling Preparation

Once the site has been selected, scientists survey the area to determine its

boundaries, and conduct environmental impact studies if necessary. The oil

company may need lease agreements, titles and right-of way accesses before

drilling the land. For off-shore sites, legal jurisdiction must be determined.After

the legal issues are settled, the crew goes about preparing the land:

1. The land must be cleared and leveled, and access roads may be built.

2. Because water is used in drilling, there must be a source of water nearby.

If there is no natural source, the crew drills a water well.

3. The crew digs a reserve pit, which is used to dispose of rock cuttings and

drilling mud during the drilling process, and lines it with plastic to protect

the environment. If the site is an ecologically sensitive area, such as a

marsh or wilderness, then the cuttings and mud must be disposed of

offsite -- trucked away instead of placed in a pit.

Once the land has been prepared, the crew digs several holes to make way for

the rig and the main hole. A rectangular pit called a cellar is dug around the

location of the actual drilling hole. The cellar provides a work space around the

hole for the workers and drilling accessories. The crew then begins drilling the

main hole, often with a small drill truck rather than the main rig. The first part of

the hole is larger and shallower than the main portion, and is lined with a large-

diameter conductor pipe. The crew digs additional holes off to the side to

temporarily store equipment -- when these holes are finished, the rig equipment

can be brought in and set up.



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Depending upon the remoteness of the drill site and its access, it may be

necessary to bring in equipment by truck, helicopter or barge. Some rigs are built

on ships or barges for work on inland water where there is no foundation to

support a rig (as in marshes or lakes).

In the next section, we'll look at the major systems of an oil rig.

2.4 Oil Rig Systems

PARTS OF A RIG

No diagram can ever explain a drilling rig completely unless you don’t see

one for yourself but in trying to familiarize you with the different parts here is a rig

schematic.

Parts of the rig are shown in the next page.



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One can divide the rig into three major sections:

a) Power system

Large diesel engines - burn diesel-fuel oil to provide the main source of

power

Electrical generators - powered by the diesel engines to provide

electrical power b) Mechanical system - driven by electric motors



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Hoisting system - used for lifting heavy loads; consists of a mechanical

winch (draw works) with a large steel cable spool, a block-and-tackle

pulley and a receiving storage reel for the cable.

Turntable - part of the drilling apparatus

c) Rotating equipment - used for rotary drilling

Swivel - large handle that holds the weight of the drill string; allows the

string to rotate and makes a pressure-tight seal on the hole

Kelly - four- or six-sided pipe that transfers rotary motion to the turntable

and drill string

Turntable or rotary table - drives the rotating motion using power from

electric motors

Drill string - consists of drill pipe (connected sections of about 30 feet (10

meters) and drill collars (DC) and heavy weight drill pipes (HWDP)

(larger diameter, heavier pipe that fits around the drill pipe and places

weight on the drill bit which helps in drilling)

Drill bit - end of the drill that actually cuts up the rock; comes in many

shapes and materials (tungsten carbide steel, diamond) that are

specialized for various drilling tasks and rock formations.

A few other parts are:

Derrick - support structure that holds the drilling apparatus; tall enough to

allow new sections of drill pipe to be added to the drilling apparatus as

drilling progresses



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CIRCULATORY SYSTEM

The mud pump is like the heart of the rig whereas the mud is like the blood that

flow through the system. Pumps drilling mud (mixture of water, clay, weighting

material and chemicals, used to lift rock cuttings from the drill bit to the surface)

under pressure through the kelly, rotary table, drill pipes and drill collars A

diagrammatic representation of the circulatory system is:



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Pump - sucks mud from the mud pits and pumps it to the drilling

apparatus

Pipes and hoses - connects pump to drilling apparatus

Mud-return line - returns mud from the hole

Shale shaker - shaker/sieve that separates rock cuttings from

the mud

Shale slide - conveys cuttings to the reserve pit

Reserve pit - collects rock cuttings separated from the mud

Mud pits - where drilling mud is mixed and recycled

Mud-mixing hopper - where new mud is mixed and then sent

to the mud pits

Blowout preventer - high-pressure valves (located under the land rig or on

the sea floor) that seal the high-pressure drill lines and relieve pressure when

necessary to prevent a blowout (uncontrolled gush of gas or oil to the surface,

often associated with

fire).



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Fig : BOP

2.5 Testing For Oil

Drilling continues in stages: The crew drills, then runs and cements new casings,

then drills again. When the rock cuttings from the mud reveal the oil sand from

the reservoir rock, the crew may have reached the well's final depth. At this point,

crew members remove the drilling apparatus from the hole and perform several

tests to confirm this finding:

Wire line logging – lowering nuclear, density, sonic and various other

tools to take measurements of the rock formations there

Drill-stem testing - lowering a device into the hole to measure the

pressures, which will reveal whether reservoir rock has been reached

Core samples - taking samples of rock to look for characteristics of

reservoir rock

On confirming the presence of oil the major steps involved in oil production are:

a) Perforation: A perforating gun into the well to the production depth. The

gun has explosive charges to create holes in the casing through which oil

can flow. a) After the casing has been perforated, they run a small-

diameter pipe (tubing) into the hole as a conduit for oil and gas to flow up

through the well. A device called a packer is run down the outside of the

tubing. When the packer is set at the production level, it's expanded to

form a seal around the outside of the tubing. Finally, they connect a multi-



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valve structure called a Christmas tree to the top of the tubing and cement

it to the top of the casing. The Christmas tree allows them to control the

flow of oil from the well. After the well is completed, the crew must start

the flow of oil into the well. For limestone reservoir rock, acid is pumped

down the well and out the perforations. The acid dissolves channels in the

limestone that lead oil into the well.

For sandstone reservoir rock, a specially blended fluid

containing proppants (sand, walnut shells, aluminum pellets) is pumped down

the well and out the perforations. The pressure from this fluid makes small

fractures in the sandstone that allow oil to flow into the well, while the proppants

hold these fractures open. Once the oil is flowing, the oil rig is removed from the

site and production equipment is set up to extract the oil from the well.



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3. Directional Drilling

Directional drilling is a subsection of drilling which involves deviating a well bore

along a planned course to a subsurface target whose location is a given lateral

distance and direction from the vertical.

3.1 Applications of Directional Drilling 3.1.1 Sidetracking: Side-tracking was the original directional drilling technique.

Initially, sidetracks were “blind”. The objective was simply to get past a fish in

vertical hole. Oriented sidetracks are performed to hit a specific target. It may be

necessary due to an unsuccessful fishing job in a deviated well. Oriented

sidetracks are most widely used. They are performed when, for example, there

are unexpected changes in geological configuration (Figure 1-1).

Figure 1-1 Side tracking



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3.1.2 Inaccessible Locations: Targets located beneath a city, a river or in

environmentally sensitive areas make it necessary to locate the drilling rig some

distance away. A directional well is drilled to reach the target (Figure 1-2).

Figure 1-2 Inaccessible locations

3.1.3 Salt Dome Drilling: Salt domes have been found to be natural traps of oil

accumulating in strata beneath the overhanging hard cap. There are severe

drilling problems associated with drilling a well through salt formations. These

can be somewhat alleviated by using a salt-saturated mud. Another solution is to

drill a directional well to reach the reservoir (Figure 1-3), thus avoiding the

problem of drilling through the salt.



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Figure 1-3 Salt dome drilling

3.1.4 Offshore Multiwell Drilling: Directional drilling from a multiwell offshore

platform is the most economic way to develop offshore oil fields (Figure 1-4).

Onshore, a similar method is used where there are space restrictions e.g. jungle,

swamp. Here, the rig is skidded on a pad and the wells are drilled in “clusters".

Figure 1-4 Offshore multiwell drilling



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3.2 Types of Directional Wells

A carefully conceived directional drilling program based on geological

information, knowledge of mud and casing program, target area etc., is used to

select a hole pattern suitable for the operation. However, experience has shown

that most deflected holes will fit one of the following types.

Directional Patterns

L profile well (Build And Hold)

S profile well (Build and Drop)

J profile well (Deep Kick-Off and Build)

Horizontal well (can be a sub category of J profile well)

– Single

– Extended reach drilling (ERD)

– Multilateral

3.2.1 “L” profile (Build and Hold)

The well is drilled at shallow depth and the inclination is locked in until the target

zone is penetrated.

Fig. “L” profile well Fig. “S” profile well



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3.2.2 “S” Type Well

The well is deflected at a shallow depth until the maximum required inclination is

achieved. The well path is then locked in and, finally, the inclination is reduced to

a lower value or, in some cases, the well is returned back to vertical by gradually

dropping off the angle.

3.2.3 “J” Type Well

The well is deflected at a much deeper position and after achieving the desired

inclination the well is locked in until the target zone is penetrated.

Fig: “J” type well Fig: Horizontal well



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3.2.4 Horizontal Well

The well is deflected at a deeper depth and the angle of inclination achieved is

90 degree.

3.3 Geometry of a Directional Well A directional well is drilled from the surface to reach a target area along the

shortest possible path. Owing to changing rock properties, the hole path rarely

follows a single plane but, instead, changes its inclination and direction

continuously. Thus, the deviated well should be viewed in three dimensions, such

that hole inclination and hole direction are specified at each position. Terms that

are commonly used in directional drilling are defined below.



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Fig: S profile showing different parts.

A simple build/hold/drop well profile, known as an "S" well, is shown in Figure

above.

The kickoff point (KOP) is the beginning of the build section. A build section is

frequently designed at a constant buildup rate (BUR) until the desired hole angle

or end-of-build (EOB) target location is achieved.

Hole angle, or inclination, is always expressed in terms of the angle of the

wellbore from vertical.

The direction or azimuth of the well is expressed with respect to some reference

plane, usually true north. The location of a point in the well is generally



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expressed in Cartesian coordinates with the wellhead or the rig's rotary kelly

bushing (RKB) usually as the reference location.

True vertical depth (TVD) is expressed as the vertical distance below RKB.

Measured depth (MD) The distance measured along the actual course of the bore

hole from the surface reference point to the survey point.

Departure / drift is the distance between two survey points as projected onto the

horizontal plane.

The EOB specification also contains another important requirement, which is the

angle and direction of the well at that point. The correct angle and direction are

critical in allowing the next target to be achieved; also, it may be necessary to

penetrate the pay zone at some optimum angle for production purposes.

A tangent/hold section is shown after the build section. The purpose of the

tangent is to maintain angle and direction until the next target is reached.

In the example well, a drop section is shown at the end of the tangent. The

purpose of a drop is usually to place the wellbore in the reservoir in the optimum

orientation with respect to formation permeability or in-situ formation stress;

alternatively, a horizontal extension may be the preferred orientation in the case

of a pay zone that contains multiple vertical fractures or that has potential for gas

or water coning.



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4. DRILLING OF DIRECTIONAL WELL

Directional wells are drilled with specialized equipments which are placed in the

Bottom Hole Assembly. There are many specialized equipments which are used

to drill directional wells. Some of the combinations of the specialized directional

equipments are:

1. Steerable Downhole Mud Motor (SDMM) & Measurement While Drilling

(MWD).

2. Whipstock & MWD.

3. Jetting & MWD.

In all these combinations the former refers to directional equipment which

actually deviates the well from the vertical. The latter refers to a measurement

system which detects the change in orientation of the well caused due to the

former. Earlier a magnetic single shot or multiple shot was used to determine the

direction and orientation of the well. However a MWD system has completely

replaced the magnetic single or multiple shot as it gives readings in real time.

Largely, a combination of SDMM and MWD system is used in the drilling

industry.



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4.1 Bottom Hole Assembly The diagrammatic representation of a BHA is as follows:

The bottom hole assembly is connected to the rig through a series of drill pipes.

SAMPLE BHA



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4.2 SIZES OF BHA COMPONENT

Sizes of BHA components for different hole section

Hole section

CASING SIZE SDMM TUBULARS MULESHOE

THREAD CONNECTIONS

26” 20” 9 5/8” 8” 5” 7 5/8” R 7 5/8” R 17 ½ “ 13 3/8“ 9 5/8” 8” 5” 6 5/8” R 7 5/8” R 12 ¼” 9 5/8”” 8” 8” 5” 6 5/8” R 6 5/8” R 8 ½” 7” 6 ¾” 6 ¾” 3 ½” 4 ½” R 4” IF 6“ 5” 4 ¾” 4 ¾” 2 7/8” 3 ½” R 3 ½” IF

All sizes in inches

4.3 PARTS OF A BHA

4.3.1 Drill bit

The drilling bit will perform the cutting of the formation. There are different types

of drill bits which are suitable for different formations and downhole applications.

Every bit has an IADC (International Association of Drilling Contractors)



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nomenclature e.g. A tricone bit might have an IADC number as 117 where the 1st

digit refers to the formation, 2nd to the teeth, 3rd to the bearing. A few examples

of bits are Poly Crystalline Diamond Cutter bit (PDC), Tricone Roller Bit (TCR),

coring bit.

Fig. PDC Bit Fig. TCR Bit



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4.3.2 Steerable Downhole Mud Motor

Fig. Steerable Down Hole Mud Motor



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Steerable Downhole Mud Motor

The above figure shows a steerable downhole mud motor connected to a bit.

Motor Selection

• These are the three common motor configurations which provide a broad range

of bit speeds and torque outputs required satisfying a multitude of drilling

applications.

• High Speed / Low Torque - 1:2 Lobe

• Medium Speed / Medium Torque – 4:5 Lobe

• Low Speed / High Torque – 7:8 Lobe

High Speed / Low Torque (1:2) motor typically used when:

• Drilling with diamond bits.

• Drilling with tri-cone bits in soft formations.

• Directional drilling using single shot orientations.

• Medium Speed / Medium Torque (4:5) motor typically used for: • Conventional and directional drilling

• Diamond bit and coring applications

• Sidetracking wells

Low Speed / High Torque (7:8) motor typically used for:

• Most directional and horizontal wells.

• Medium to hard formation drilling.

• PDC bit drilling applications

Components of PDM Motors

• Dump Sub Assembly

• Power Section



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• Drive Assembly

• Adjustable Assembly

• Sealed Bearing Section

Dump Sub Assembly

• Hydraulically actuated valve located at the top of the drilling motor

• Allows the drill string to fill when running in hole.

• Drain when tripping out of hole

• When the pumps are engaged, the valve automatically closes and directs

all drilling fluid flow through the motor.

Power Section

• Converts hydraulic power from the drilling fluid into mechanical power to drive

the bit

• Stator – steel tube containing a bonded elastomer insert with a lobed, helical

pattern bore through the center.

• Rotor – lobed, helical steel rod

• When drilling fluid is forced through the power section, the pressure drop across

the cavities will cause the rotor to turn inside the stator.

• Pattern of the lobes and the length of the helix dictate the output characteristics

• Stator always has one more lobe than the rotor.

• Stage – one full helical rotation of the lobed stator.

Dump Sub • Allows Drill String Filling and Draining

• Operation

- Pump Off - Open

- Pump On - Closed

• Discharge Plugs

• Connections



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• With more stages, the power section is capable of greater differential pressure,

which in turn provides more torque to the rotor.

The stator elastomer can be made of different materials, such as NBR, HNBR,

EPDM etc. The elastomer is chosen considering the type of operation involved.

For higher temperature and pressure conditions, where oil based mud is used;

better elastomers such as HNBR is used.

Drive Assembly

• Converts Eccentric Rotor Rotation into Concentric Rotation– Universal Joint

Adjustable Assembly

• Can be set from zero to three degrees

• Field adjustable in varying increments to the maximum bend angle

• Provides a wide range of potential build rates in directional and horizontal wells

Sealed Bearing Section

Drive Assembly Sealed Bearing

Section



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• Transmits axial and radial loads from the bit to the drillstring

• Thrust Bearing • Radial Bearing

• Oil Reservoir • Balanced Piston

• High Pressure Seal •Bit Box Connection

Operation modes

Rotating mode- In this mode the entire drill string is rotated with the help of rotary

table. The drill bit is rotating due to the combined action of mud motor and the

rotary table speed.

Sliding mode- In this mode the entire drill string is not rotated. The drill bit is only

rotating due to the mud motor. The bend of the mud motor is made to face in a

specified direction or angle. Drilling carried out in this way is called sliding.

4.3.3 Float Sub

Fig. Float sub and float valve



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Float sub houses the float valve which acts as a non return valve and

prevents the backflow of mud into our tool during a sudden pressure shoot

up.

4.3.4 UBHO (Universal Bore Hole Orienting subs)

Fig. UBHO

UBHO’s are also called mule shoe subs as they house the mule shoe.

The muleshoe is inserted for the alignment of the MWD string. At the

bottom of the MWD tool is a cut with mates with the landing key in the

muleshoe. The key helps in orienting the MWD string with the bent in the

mud motor.



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4.3.5 NMDC (Non Magnetic Drill Collar)

Fig. NMDC

NMDCs house the MWD tool. Usually 2 non magnetic drill collars are used

in the BHA in order to reduce the magnetic interference between the

earths magnetic field and the magnetic field from the other magnetic

components in the drill.string. NMDC’s are made up of stainless steel.

4.3.6 Heavy Weight Drill Pipes

Fig. A stand of HWDP comprising 3 HWDPs

As the name suggests the HWDP’s are heavier than normal drill pipes and

impart weight to the BHA. But we must be careful as to how many weights

are used as the weight given to the bit will be difficult to control



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4.3.7 Drill Collars

Drill Collars also contribute weight to the BHA which in turn provides the

pressure to the bit required for drilling. Drill collars are larger than normal

drill pipes.

There are a few more important components in the BHA that have not been

shown in the schematic diagram

4.3.8 Stabilizers

Stabilizers provide stiffness to the BHA and they are of the same size of

the hole being drilled or 1/8”, ¼”, ½” underguaged. The placement of

stabilizers is extremely critical in a BHA as it would help in the building,

holding and dropping sections of a well.

There are majorly two types of stabilizers:

1) Near bit stabilizers: They are screw on stabilizers and are

screwed on the bearing assembly of the mud motor.

2) String stabilizers: As the name suggests the string stabilizers

are present in the string or the BHA usually at 30 or 60 feet

from the bit.

Stabilizers can also be classified by the nature of the blades.

1) Integral blades: Stabilizers which are manufactured along with the blades

2) Welded blades: Such stabilizers have welded blades.

Note: The blades can be spiral or straight.



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Integral Blades Welded Blades

Fig. String stabilizer Reasons for Using Stabilizers

• Placement / Gauge of stabilizers control directional

• Stabilizers help concentrate weight on bit

• Stabilizers minimize bending and vibrations

• Stabilizers reduce drilling torque less collar contact

• Stabilizers help prevent differential sticking and key seating.

4.3.9 Crossovers

Drill pipe, drill collar and other specialized drill string items do not have

standardized threads. In order to assemble two drill string elements having

different connections a cross over is used.

Types of cross overs:

A) Box by box

B) Box by pin

C) Pin by pin



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Fig. Showing A, B, C types of crossovers.



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5. Measurement 5.1 INCLINATION/ AZIMUTH/ MEASURED DEPTH

Any form of measuring instrument has to measure the values of azimuth,

inclination and measured depth to know the location of the well bore that has

been drilled by the directional driller. These values let a directional driller know

whether he is in the right path or not

Hole Direction/ Azimuth is the angle, measured in degrees, of the

horizontal component of the borehole or survey instrument axis from a

known north reference. This reference is true north and is measured

clockwise by convention. Hole direction is measured in degrees and

expressed in either azimuth form (0° to 360°) or quadrant form (NE, SE,

NW, SW)



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Inclination is the angle, measured in degrees, by which the wellbore or

survey instrument axis varies from a true vertical line.

Measured depth refers to the actual length of hole drilled from the surface

location (drill floor) to any point along the wellbore.

5.2 True North and Magnetic North

Geographic North or True North is one end of the line drawn through the center

of the earth’s rotational axis. Magnetic North is one end of the line drawn

through the center of the earth’s magnetic field. The lines lie near each other but

they are not aligned. They diverge and provide two different points of reference.



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5.3 Earth’s Magnetic Field

The outer core of the earth contains iron, nickel and cobalt and is ferromagnetic

so the earth can be imagined as having a large bar magnet at its center, lying

(almost) along the north-south spin axis. The magnetic field lines emerging from

the magnetic North are parallel to the surface of the Earth at the equator and

point steeply at the poles.

5.4 Earth’s Magnetic Components



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• B = Total field strength of the local magnetic field

• Bv = Vertical component of the local magnetic field.

• Bh = Horizontal component of the local magnetic field.

Magnetic Dip Angle/ Magnetic Inclination Angle

Lines of magnetic force radiate from earth’s core. The angles at which magnetic

force lines penetrate the earth surface determine the strength of magnetic field.

Magnetic Declination

It is the difference in degrees between magnetic north and true north at a given

location.An uncorrected azimuth called the raw reading is first corrected for

magnetic declination and then for others.



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6. Measurement While Drilling

6.1 Introduction As we know most of the wells today are deviated wells. Thus while drilling such

wells it is important to know the exact orientation and location of the wells. A

Measurement While Drilling system provides the orientation of the well in real

time.

6.2 What Is MWD? Measurement While Drilling (MWD) systems measure formation properties

(natural gamma rays), wellbore geometry (inclination, azimuth), drilling system

orientation (toolface), and mechanical properties of the drilling process.

Traditionally MWD has fulfilled the role of providing wellbore inclination and

azimuth in order to maintain directional control in real time.

6.3 Mud Pulse Telemetry

The MWD tool is normally placed in the bottom hole assembly of the drillstring,

as close to the drill bit as possible. The MWD tool is an electromechanical device

which makes the measurements described above, and then transmits data to

surface by creating pressure waves within the mud stream inside the drillpipe.

These pressure waves or pulses are detected at the surface by very sensitive

devices (standpipe pressure transducers with pre-amplifiers) which continuously

monitor the pressure of the drilling mud. These data are passed on to

sophisticated decoding computers which deconvolute the encoded data from

downhole. This whole process is virtually instantaneous, thus, enabling key

decisions to be made as the wellbore is being drilled. Other, more exotic

transmission systems do exist e.g. drillpipe acoustic, electromagnetic and

hardwire telemetry. But the vast majority of all commercial systems utilize mud

pulse telemetry by generating either a pulse or a modulated carrier wave which is

propagated through the drilling fluid at roughly the speed of sound in mud (i.e.



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4000-5000 ft./sec or 1200-1500 m/sec). Mud pulse telemetry MWD tools use

positive pulse, negative pulse or carrier wave (mud siren) schemes to transmit

measured parameters from downhole to surface in realtime to aid in formation

evaluation, directional control, drilling efficiency and drilling safety. Downhole

information is registered by the MWD sensors and then passed on to the MWD

tool microprocessor. The microprocessor then routes this information to the

surface by activating the tool transmission system. Mud pulse telemetry involves

the modulation of the flow of mud through the drillstring by means of a

mechanical valve or rotary valve mounted within the MWD tool. At the surface,

the data are decoded and depth correlated. The data are then output to hard

copy and graphical display, much like a wireline logging system. The true value

of MWD can thus be appreciated by its provision of real time dynamics and

directional drilling data augmented by real time formation evaluation

measurements, which are considered equivalent and often times superior to

sophisticated wireline logs.

As MWD tools and measurements have become more reliable and cost

effective, the practice of replacing both standard (e.g. gamma ray, resistivity) logs

and triple combo (which also include neutron porosity and formation density

measurements) wireline logs has become common place.



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6.4 MWD Principles Three Basic Telemetry Types:

6.4.1 Positive Mud Pulse Telemetry

Positive mud pulse telemetry (MPT) uses a hydraulic poppet valve to

momentarily restrict the flow of mud through an orifice in the tool to generate an

increase in pressure in the form of a positive pulse or pressure wave which

travels back to the surface and is detected at the standpipe.

6.4.2 Negative Mud Pulse Telemetry

Negative MPT uses a controlled valve to vent mud momentarily from the

interior of the tool into the annulus. This process generates a decrease in

pressure in the form of a negative pulse or pressure wave which travels back to

the surface and is detected at the standpipe.



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6.4.3 Continuous Wave Telemetry

Continuous wave telemetry uses a rotary valve or “mud siren” with a

slotted rotor and stator which restricts the mud flow in such a way as to generate

a modulating positive pressure wave which travels to the surface and is detected

at the standpipe.

6.4.4 Electromagnetic Telemetry

The electromagnetic telemetry (EMT) system uses the drill string as a

dipole electrode, superimposing data words on a low frequency (2 - 10 Hz)

carrier signal. A receiver electrode antenna must be placed in the ground at the

surface (approximately 100 meters away from the rig) to receive the EM signal.

Offshore, the receiver electrode must be placed on the sea floor. Currently,

besides a hardwire to the surface, EMT is the only commercial means for MWD

data transmission in compressible fluid environments common in underbalanced

drilling applications. While the EM transmitter has no moving parts, the most



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common application in compressible fluids generally leads to increased

downhole vibration. Communication and transmission can be two-way i.e.

a) downhole to uphole: Mud telemetry

b) uphole to downhole. The EM signal is attenuated with increasing well

depth and with increasing formation conductivity.



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6.5 MWD TOOL Components 6.5.1 Dummy Switch

It is the up hole end component of the MWD tool. It helps in lowering

down the tool and retrieving the tool when a stuck up takes place.

6.5.2 Centralizer



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Centralizer has the function of keeping the MWD tool centered inside the Monel.

It prevents excessive lateral vibrations and also provides electrical connections

between battery, electronics and pulsar driver.

6.5.3 Electronics Module

The electronics module can be easily identified as it is the longest component in

the MWD string. Electronics module is also known as the Direction and

Inclination (DnI) module and it is the brain of the string. It is majorly composed of

a circuit with three important sensors temperature, accelerometers and

magnetometers being at 1.6 feet away from the downhole end of the DnI module.

Sensors

A) Temperature

Our tool works efficiently within the range 0- 150 degree Celsius hence it is

important that the DnI module houses a temperature sensor. The temperature

sensor is activated earlier than the accelerometers and magnetometers are.

B) Accelerometer

Accelerometers are used to measure the earth’s local gravitational field.

Each accelerometer consists of a magnetic mass (pendulum) suspended in an

electromagnetic field. Gravity deflects the mass from its null position. Sufficient



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current is applied to the sensor to return the mass to the null position. This

current is directly proportional to the gravitational force acting on the mass. The

gravitational readings are used to calculate the hole inclination, toolface, and the

vertical reference used to determine dip angle.

There are 3 accelerometers aligned in the 3 axis directions to read the

gravity field individually in the X, Y, Z direction and then the effective gravity field

is calculated.

C) Magnetometer

Magnetometers are used to measure the earth’s local magnetic field. Each

magnetometer is a device consisting of two identical cores with a primary winding

around each core but in opposite directions. A secondary winding twists around

both cores and the primary winding. The primary current (excitation current)

produces a magnetic field in each core. These fields are of equal intensity, but

opposite orientation, and therefore cancel each other out such that no voltage is

induced in the secondary winding. When the magnetometer is placed in an

external magnetic field which is aligned with the sensitive axis of the

magnetometer (core axis), an unbalance in the core saturation occurs and a

voltage directly proportional to the external field is produced in the secondary

winding. The measure of voltage induced by the external field will provide precise

determination of the direction and magnitude of the local magnetic field relative to

the magnetometer’s orientation in the borehole.

There are 3 magnetometers aligned in the 3 axis directions to read the

magnetic field individually in the X, Y, Z direction and then the effective magnetic

field is calculated.



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6.5.4 Gamma Tool

The tool consists simply of a highly sensitive gamma ray detector in the form of a

scintillation counter. The scintillation counter is composed of a thalium activated

single sodium iodide crystal backed by a photomultiplier. When a gamma ray

strikes the crystal a small flash of light is produced. This flash is too small to be

measured using conventional electronics. Instead, it is amplified by a

photomultiplier, which consists of a photocathode and a series of anodes held at

progressively higher electrical potentials, all of which are arranged serially in a

high vacuum.

The Gamma tool can be easily identified in the string as it is the shortest

component of the string.



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6.5.5 Battery

• Lithium thynoil chloride battery.

• Rated voltage 28.8 V & 26 amp-hour

• Thresh hold voltage is 21.5 v

Battery is discussed in detail towards the end.



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6.5.6 Pulsar Driver System

The Pulsar driver can be identified easily in the MWD string as it has screen

housing at the down hole end. The pulsar driver system possessed by Jindal has

a BL 3 phase DC motor which is controlled by the Electronic module through the

electrical pin connections present in the various MWD tool components. The up

hole connections of pulsar driver system have 6 pin male connection. The down

hole end is connected to the stringer assembly.

The pulsar driver is divided into 3 major sections

A) Snubber assembly- mainly consists of the electric circuit

B) Oil fill housing- mainly houses the 3 phase BL DC motor and capacitor bank.

C) Screen housing- consists mainly of the bellow, servo shaft, servo poppet.



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6.5.7 STRINGER ASSEMBLY

The different components used to assemble the stringer assembly are shown in

the diagram below. The components of the stringer assembly are 4, 5, 6, 7, 8, 6, 10, polypack and

servo orifice. The piston shaft is hollow and on top of the shaft is fixed lower piston cap, poly

pack, upper piston cap and servo orifice in sequence. This assembly is then

placed inside the helix/stinger. This combination is then screwed in the

planum/stringer barrel which has a spring inside. A poppet is now attached to the

end of the stringer shaft. Our stringer assembly is now prepared. The stringer

assembly is attached to the downhole end of the pulsar driver.



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Fig Stringer Assembly



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6.6 MWD STRING 6.6.1 Gamma Job

D/I Module – Centralizer – Battery Module – Centralizer – Gamma Module –

Centralizer – Pulsar Driver – Stringer Assembly

6.6.2 Non-Gamma Job Battery 2 – Centralizer – D/I Module – Centralizer – Battery 1 – Centralizer –

Pulsar Driver – Stringer Assembly



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Fig. String for Gamma Job Fig. String for Non-Gamma Job Fig. Monel



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6.7 Placing MWD tool in the BHA

Fig. showing

the placement

of MWD

1. Above the SDMM, a

Universal Bent Housing

Orienting (UBHO) sub is

torqued. A mule shoe is

oriented inside the

UBHO in such a way that the

landing key is in line with the

bend of the mud motor.

This process is called

scribing.

2. The mule shoe is then

fixed inside the UBHO with

the help of 2 set screws.

3. Non Magnetic Drill

Collars are torqued above

the UBHO.



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4. The programmed MWD tool with the helix facing down hole are lifted from the

spear point of dummy switch and lowered into the NMDC. The helix of the MWD

tool sits inside the landing key of mule shoe (in the UBHO).

5. Further one more NMDC is torque, if required, followed by Drill collars and

Heavy weight drill pipe.

6.8 KINTEC PIN CONNECTIONS



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6.9 Working of MWD tool

When the pumps are switched on the single axised accelerometer in the

snobber assembly of the Pulser Driver senses the vibrations and sends

the same message to the DnI through pin 7. The DnI awaits for a few seconds known as the transmit delay time before

it activates the pulsing action in the Pulsar Driver through pin 6. The to and fro motion of the servo poppet produces the pressure waves

which contains the data from the DnI module. The amplitude of these

pressure waves are very low and are required to be amplified in order to

be transmitted to the transducer at the surface.

PIN 1 GROUND 0 V PIN 2 BATTERY-1 28.8V PIN 3 BATTERY-2 28.8V PIN 4 B- BUS 27.9V PIN 5 Q-BUS 0-2.5V PIN 6 PULSE 05V PIN 7 FLOW 05V PIN 8 GAMMA 05V PIN 9 MOD-1 ---- PIN 10 MOD-2 ----



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The amplification of the pressure amplitude is done by the stringer

assembly. When the tool is placed in the muleshoe, the servo poppet as

well as the stringer poppet are in the closed position. When mud flows through the NMDC housing the MWD tool, there is a

pressure difference because of which the stringer poppet retracts and

compresses the spring in the plenum. The stringer poppet is now in the

open position. The 3- phase DC motor controls the movement of the servo poppet. The

servo poppet when is in the open position provides a free path to the mud

to enter the plenum. Hence the pressure inside and outside are balanced. The spring will now try to reach its least energy position as all forces are

balanced except for the spring force. Hence the spring now expands

pushing the poppet back to its closed position. This causes an increase in

pressure & cause the pulse magnitude to increase. The servo poppet closes and the process is repeated. The servo orifice on the upper piston cap allows the mud to bleed during

the compression and expansion of the spring. The magnified pulse now travels through the mud in the drill string and is

read by the pressure transducer.



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6.10 MWD Tool Retrieval Equipment

The outer diameter of our tool is 1.88” hence in the case of a stuck up it is

possible for us to retrieve the MWD string with the help of equipments above.

There are two types of assembly for tool retrieval depending upon the

angle of the well. Well the angle of inclination is less than 45 degrees we

use a overshot, sinker bar and cross over.

For angles more than 45 degrees we use a spring jar which provides

flexibility to the assembly.

The selection of overshot bell is integral and the difefernt sizes of overshot

bells are 1.75”, 2” and 2.25”



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The assembly is run along with the CCL (casing collar locator) tool of the

wireline unit.

Go down with the wireline unit while monitoring tension and depth.

One it has reached the bottom, rather found the tool, move up and down

while monitoring the tension.

6.11 TOOLFACE The angle at which the steering tool is pointed is termed as the toolface.

Fig. Toolface

Toolfaces are used to change the hole direction. The low angles the

accelerometers are not as accurate as the magnetometers so low angle toolface

are based on magnetic readings. Using magnetic toolfaces means pointing the

steering tool in the direction of the target.



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Once the direction/azimuth is achieved the toolface changes from magnetic

toolface to gravity toolface. The well bore has achieved direction and can be

moved left or right of the original direction.

6.12 Fluidic Vortex

The fluidic pulser generates a vortex within a chamber by momentarily

restricting the mud flow, thus creating a turbulent flow regime. The resulting

change in pressure loss can be switched on and off rapidly, circa 1millisecond,

and the resultant pressure wave created can be of high amplitude (145 psi).

MWD directional survey instrument is used to monitor the direction (magnetic)

and inclination (the angle of the tool's long axis from vertical) of the borehole.

In the MWD drilling environment, there are many sources of magnetic

interference that can cause inaccurate directional measurements. A

ferromagnetic steel object that is placed in a magnetic field will become

magnetized. The amount of induced magnetism is a function of the external field

strength and magnetic permeability of the object. In order to prevent magnetic

interference, the directional survey instrument is housed in a nonmagnetic

stainless steel collar. The MWD tool is usually arranged in a section of the

bottom-hole assembly (BHA) which is made up of a series of non-magnetic

collars to reduce the impact of the drilling assembly's steel components on the

magnetic field at the location of the survey sensor.

It is possible to optimize the position of the survey instrument by

estimating the pole strength for various BHA configurations, based upon

downhole field measurements. However, even if the correct non-magnetic collar



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spacing is used, there could still be other sources of magnetic interference which

will cause erroneous directional readings. These include “hot spots” in the non-

magnetic steel or areas of mechanical damage caused by rethreading/welding or

manufacturing impurities. A continual quality assurance procedure ensures that

such anomalies are not present in MWD collars and stabilizers. More

significantly, other BHA components may be made of magnetic material and/or

already has magnetic anomalies that affect azimuth readings. Other sources of

magnetic interference may be caused by proximity to iron and steel

magnetic materials from previous drilling or production operations, magnetic

properties of the formation, and concentrations of magnetic minerals (iron pyrites,

etc) in excess of six percent.

6.13 Azimuth Correction Technique

It is often advantageous to reduce the number of non-magnetic drill collars

so that the directional and formation evaluation sensors can be located closer to

the bit. (This also eliminates the extra cost of using monel collars.) This will assist



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in real-time decision making by allowing readings to be made as soon as

possible following formation penetration. To address this problem, a number of

methods have been devised for making corrections to magnetic surveys. The

following correction techniques are designed to reduce the influence of spurious

magnetic fields associated with the BHA:

Magnetic Azimuth Correction Algorithm

This is a proprietary method by which magnetic azimuth can be calculated

in the event that the z-axis magnetometer reading is corrupted by a spurious

longitudinal field resulting from an insufficient length of nonmagnetic BHA

components. The tool senses such a spurious field as a bias on the z-

magnetometer measurement. The method requires the operator to specify

expected values for total magnetic field and dip angle, and it then computes the

azimuth angle which is consistent with a magnetic field vector as close as

possible to the expected value. Accuracy of this azimuth angle is dependent on

the accuracy of the input nominal values for the earth's magnetic field and gravity

field. The corrected magnetic azimuth accuracy is dependent on the surface

location of the well and the direction and inclination that is being drilled. At higher

latitudes and higher inclinations and the farther the direction is from north or

south, the accuracy of the corrected azimuth will degrade. The operator will have

to decide whether to use the corrected azimuth or the uncorrected azimuth based

on concerns for azimuth accuracy.

Rotation Algorithm

This is a refinement to the Magnetic Azimuth Correction Algorithm above,

which makes use of downhole tool rotation to reduce errors caused by bias in x-

axis and y-axis magnetometers, in addition to the z-axis magnetometer bias.

Also, accelerometer bias errors on the x-axis and y-axis can be reduced with this

procedure. Such biases may be caused not only by calibration drift, but also by

magnetic hot spots in the drill collar or by magnetic junk affixed to the outside of



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the collar. This method requires a minimum of three surveys at different tool face

angles, to define a circle centered at a point which represents the transverse

biases. This method can reduce errors caused by magnetic anomalies which

rotate as the survey tool is rotated. It does not reduce errors which do not rotate,

such as interference from an adjacent casing string.

6.14 Basic Hydraulics 6.14.1 System Pressure

System pressure is the pressure felt throughout the system. While drilling, the

cuttings must be removed either with the help of water, weighted mud, foam,

steam or air. The column of water or mud in the hole is called the drilling fluid and

they exert a hydraulic pressure against the formation. This is known as the

hydrostatic head or hydrostatic pressue. It is usually measured in pounds per

square inch

Bernoulli’s principle

Fig. Hydraulic system with a restriction



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The diagram illustrates 3 different pressure regions. The pressure in or after the

restriction is higher. In the area of restriction the pressure is relatively low. After

the restricted area the pressure returns to normal.

6.14.2 Annular Velocity

It is the velocity the fluid is flowing with in closed pressure system such as the

annulus. Erosion on the metal surfaces of the MWD tool as well as around areas

where restriction occurs are directly related to annular velocity and the amount

od solids in the mud. There are two flow regimes Turbulent and Laminar.

Turbulent flow oocurs when the velocity reaches a critical point known as the

critical velocity. Below the critical velocity we have a laminar flow of mud.

Fig. Example of turbulent and laminar flow

A more turbulent flow gives better hole cleaning. But turbulent flows can cause

washout of the hole.



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6.14.3 Pressure Pulses

Most tools today use bernoulli’s principle to communicate between tool and the

surface computer. The data from the tool is encoded as pressure pulses and

decoded at the surface. The high pressure pulses are formed due to the

restriction in the hydraulic system. A sensor at the surface converts the

mechanical pressure into electrical signals. The electrical signal is send to signal

converter and to a computer. The surface computer decodes the data and

displays it on the screen.

6.14.4 Drilling Fluid

In the oil and gas industry the drilling fluid is referred to mud exceptions being

foam and air. The fluid column (mud) acts as part of the communication system

also known as the qbus.

The mud system controls the quality of the mud and is critical for successfully

transmitting MWD data. Thick or more viscous mud affect pulses by creating less

sharp peaks. Sometimes when gas or mud enters the mud it gives symptoms

that look like pulse failure.

6.15 Factors Affecting the Mud Pulse There are a number of sources of interference in the MWD drilling

environment, although the main ones are as follows: 6.15.1 Mud Pump Noise

Excessive noise, either from the mud pumps or high torque mud motors

can, in rare instances, create unacceptable signal to noise ratios. In order to

prevent this, some MWD companies deploy surface measurement of pump

strobes in order to characterize a mud pump signature. This is then used in the



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surface decoder as a pump subtraction filter. In many cases, the pump

subtraction filter can be used to detect premature pump damage before any other

physical signs are available.

6.15.2 Rig and Drill string Noise

Drill string vibration will, typically, generate high frequency noise which

can lead to a dramatic deterioration of the transmitted signal. Very often, by

simply making adjustments to the WOB and RPM, it is possible to avoid

damaging critical torsional and lateral resonance. A number of vibration

prediction programs are available which can estimate critical RPM for a given

drilling assembly. It is also possible to use high frequency surface measurement

devices, such as the Baker Hughes INTEQ ADAMS and DynaByte technology

provided by the Drilling Dynamics Group. (The Drilling Dynamics Group within

Baker Hughes INTEQ uses EXLOG (now part of Baker Hughes INTEQ), ARCO

and ELF patented surface measurement technologies).

6.16 Reliability Reliability is the probability of a product performing without failure, a

specified function under given conditions for a given period of time. A unit of

measure is Mean Time Between Failure (MTBF). In this respect, the reliability

standard is expressed as follows:

Reliability = MTBF = Operating Hours (Perfect Hours)

Failure

Factors Affecting Reliability:

• Shock and Vibration

• Telemetry System



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• Downhole Temperature

• Drilling Practices

• Complexity of Tool

• Service Company Quality Assurance (TQM)

• Competition

• Training



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7. TENSOR MWD BATTERY MANUAL

GE Power Systems supplies this manual for information and insight to our

clients on safe handling and transportation of Lithium battery products. This

manual contains information supplied by battery and battery pack manufacturers

and suppliers. The information contained within is easily obtained via the Internet

or by contacting the Battery Suppliers listed in the front of the manual.

http://www.spectrumbatteries.com/supp2.htm

http://www.spectrumbatteries.com/Prod_in/chart.htm http://www.batteryeng.com/safety.htm http://www.spectrumbatteries.com/Prod_in/passivation_information.htm http://www.batteryeng.com/func_perf.htm

PLEASE NOTE AND READ – THE ABOVE HYPERLINKS.

These hyperlinks can be used to access more detailed data about battery

manufacturers and battery pack assembly companies..

SAFE STORAGE AND HANDLING

In most cases, improper handling and storage, resulting in such problems

as overheating and short-circuiting cause damage to batteries. The common

safety practices have been outlined below; safety precautions to take with regard

to all aspects of battery storage and handling.

Storage:



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1. Shelf Batteries should be stored in their original shipping boxes, if possible, to

keep them isolated from each other, preventing external short circuits. Do not

store batteries loosely, and do not place batteries on metal surfaces.

2. Temperatures and Environment

Batteries should be stored in a cool, dry, well-ventilated area with an

optimal storage temperature range of 0-25_C. If prolonged storage is anticipated,

batteries should be protected against excessive humidity. This will prevent

moisture from forming an electrical pathway between the feed-through terminal

and battery cover, which can lead to severe galvanic corrosion of the feed-

through pin, thus compromising the hermeticity of the battery.

3. Hazard Consideration

Lithium battery storage areas should be clearly marked and provided with

“Lith-X” fire extinguishing material. Batteries might burst if subjected to excessive

heating. In case of fire, only “Lith-X” fire extinguisher should be used, as water

will cause exposed lithium to ignite. Signs should clearly state – WATER IS NOT

TO BE USED IN CASE OF FIRE.

LITHIUM BATTERY SAFETY MANUAL The following paragraphs will discuss the safe handling of Lithium Thionyl Chloride (LTC) batteries under the abnormal hazardous conditions of:

1. Leaking or venting batteries, 2. Hot batteries,

3. Exploding batteries, 4. Lithium fires.

Personnel Protective Equipment Required:



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Safety Glasses, Rubber Gloves, Helmet with full face shield, Flak Jacket

with gloves, Riot Shield, Respirator with canisters for Acid Gases or full-

face respirator with acid gas cartridges.

Other Equipment Required:

Infrared Temperature Probe, Sodium Carbonate (Soda Lime) or Sodium

Bicarbonate (Baking Soda), Vermiculite, Fire Extinguisher containing Lith-

X Graphite powder, extended Non-conductive pliers or tongs, Thermal

resistant gloves (welding gloves).

7.1 PROCEDURE FOR LEAKING OR VENTED BATTERIES

Leaking or vented batteries should be isolated from personnel and

equipment. If possible, the area should be vented to the outside. Prior to

handling, the temperature of the batteries should be checked with a remote-

sensing device such as an infrared temperature probe. If the batteries are at

ambient temperature, they should be handled with rubber gloves or non-

conductive pliers or tongs and placed in plastic bags containing Sodium

Carbonate. Spilled electrolyte should be absorbed with Sodium Carbonate and

placed in plastic bags. All bags should be placed in a sealed and labeled drum

with Vermiculite or other non-flammable cushioning material such as sand or

Sodium Carbonate to cushion the batteries. These materials should be disposed

as previously discussed under Safe Disposal in the Lithium Battery Safety

Manual.



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7.2 PROCEDURE FOR HOT BATTERIES As soon as a hot battery is detected, all personnel should be

evacuated from the area. The temperature of the battery should be

monitored with a remote-sensing device such as an infrared temperature

probe. The area should remain evacuated until the battery has cooled to

ambient temperature. When the battery has returned to ambient temperature,

it can be handled by an operator wearing protective equipment (face shield,

flak jacket and gloves) with non-conductive pliers or tongs. The batteries

should be placed in plastic bags containing Sodium Carbonate and then

placed in labeled drums containing Vermiculite or other non-flammable

cushioning material such as sand or Sodium Carbonate. These materials

should be disposed of as previously discussed under Safe Disposal in the

Lithium Battery Safety Manual.

OR

If liquid nitrogen is available, the battery should be placed in liquid

nitrogen/or dry ice with a pair of tongs. Once frozen, the battery must be

dissected and the components neutralized in a soda ash water bath. Unused or

partially used Lithium must be set aside to hydrolyze.

If the battery is thawed and not dissected, the battery will return to its

original state of being hot (short-circuited) and may explode.

If the battery vents or explodes, it should be handled with the procedure

for vented or exploding batteries.

7.3 PROCEDURE FOR EXPLODING BATTERIES



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If a battery explodes, all personnel should be evacuated from the area.

The area should be vented to the outside until the pungent odor is no longer

detectable. If the expelled material is on fire, it should be treated as described

below in the procedure for a Lithium fire. After the residue has cooled, it can be

absorbed with Sodium Carbonate and placed in plastic bags. All bags should be

placed in a sealed and labeled drum with Vermiculite or other non-flammable

cushioning material such as sand or Sodium Carbonate to cushion the s. These

materials should be disposed as previously described under Safe Disposal in the

Lithium Battery Safety Manual.

7.4 PROCEDURE FOR A LITHIUM FIRE Evacuate the premises. Personnel should avoid breathing the smoke from

a lithium fire, as it may be corrosive. Trained personnel wearing self-contained

breathing apparatus or a respirator with acid gas cartridges should use Lith-X fire

extinguishers to fight the fire. When the fire is extinguished and the residue

cooled, it can be absorbed with Sodium Carbonate and placed in plastic bags. All

bags should be placed in a sealed and labeled drum with Vermiculite or other

non-flammable cushioning material such as sand or Sodium Carbonate to

cushion the s. These materials should be disposed properly.

7.5 LITHIUM BATTERY SAFETY With proper use and handling, lithium batteries have demonstrated an

extensive safety record. The success and wide use of lithium batteries is partially

because they contain more energy per unit weight than conventional batteries.

However, the same properties, which result in a high energy density also,

contribute to potential hazards if the energy is released at a fast and uncontrolled



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rate. In recognition of the high-energy content of lithium systems, safety has

been incorporated into the design and manufacture of all batteries. However,

abuse or mishandling of lithium batteries can still result in hazardous conditions.

The information provided here is intended to give users some guidelines to safe

handling and use of lithium batteries.

Abuse

In general, the conditions that cause damage to batteries and jeopardize

safety are summarized on the label of each. These conditions include:

• Short Circuit

• Charging

• Forced Over-discharge

• Excessive heating or incineration

• Crush, puncture, or disassembly

Very rough handling or high shock and vibration could result in damage.

NOT DESIGNED FOR CHARGING OR RECHARGING

PRODUCT NAME: Lithium Oxyhalide Primary Battery (MWD)

CHEMISTRY SYSTEM: Lithium/thionyl Chloride

CHEMICAL FORMULAS: Li/ SOCI2

TOXIC, CAUSTIC OR IRRITANT CONTENT

Important Note: The battery container should not be opened or incinerated since

the following ingredients contained within could be harmful under some

circumstances if exposed.

In case of accidental ingestion of a cell or its contents, obtain prompt medical

advice.

MATERIALS



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Lithium is included in this section due to its vigorous reaction with water

forming a caustic hydroxide.

Lithium (Li)

Thionyl Chloride (SOCI2)

7.6 STORAGE AND DISPOSAL TIPS STORAGE: Store in a cool place but prevents condensation on the batteries.

Elevated temperatures can result in shortened battery life.

FIRE: If batteries are directly involved in a fire, DO NOT USE WATER, CO2, DRY CHEMICAL OR HALOGEN EXTINGUISHERS. A Lith-X (graphite base) fire

extinguisher or material is the only recommended extinguishing media for fires

involving lithium metal or batteries. If a fire is in an adjacent area, and batteries are

packed in their original containers, the fire can be fought based on fueling material,

e.g., paper, and plastic products. Avoid fume inhalation.

DISPOSAL: DO NOT INCINERATE or subject batteries to temperatures in excess of

212°F (100°C). Such abuse can result in loss of seal, leakage, and/or explosion.

Dispose of in accordance with appropriate Federal, State, and Local regulations.

Section 10 Version 2.00; February, 2002; BattM 16

HANDLING AND USE PRECAUTIONS

MECHANICAL CONTAINMENT: Encapsulation (some potting) will not allow for

expansion. Such enclosure can result in high-pressure explosion from heating due to

inadvertent charging or high temperature environments (i.e., in excess of 100°C).

SHORT-CIRCUIT: Batteries should always be packaged and transported in such a

manner as to prevent direct contact with each other. Short-circuiting will cause heat

and reduce capacity. Jewelry, such as rings and bracelets, should be removed or

insulated before handling the batteries to prevent inadvertent short-circuiting through



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contact with the battery terminals. Burns to the skin may result from the heat

generated by a short- circuit.

CHARGING: These batteries are not designed to be charged or recharged. To do so

may cause the batteries to leak or explode.

OTHER: If soldering or welding to the terminals or case of the battery is required,

exercise proper precautions to prevent damage to the battery which may result in

loss of capacity, seal, leakage, and/or explosion. DO NOT SOLDER to the case.

Batteries should not be subjected to excessive mechanical shock & vibration.

7.7 HANDLING AND INSPECTION GUIDELINES

The most frequent forms of abuse can easily be identified and controlled in the

workplace. All spirally, wound batteries are internally protected against the hazards

associated with short circuits. This is accomplished by incorporating a fast acting fuse

under the terminal cap. It is our experience that inadvertent short circuits (resulting in

open fuses) are the largest single cause of field failures. Batteries with open fuses

(characterized by zero voltage) should be disposed of or returned to the

manufacturer for rework. Never attempt to remove the terminal cap or replace the

internal fuse.

Problems associated with shorting as well as other hazardous conditions can be

greatly reduced by observing the following guidelines:

• Cover all metal work surfaces with an insulating material.

• The work area should be clean and free of sharp objects that could puncture

the insulating sleeve on the battery.

• Never remove the shrink-wrap from a battery pack.



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• All persons handling batteries should remove jewelry items such as rings,

wristwatches, pendants, etc. that could be exposed to the battery terminals.

• If batteries are removed from their original packages for inspection, they should

be neatly arranged to preclude shorting.

• Individual cells should be transported in plastic trays set on pushcarts. This will

reduce the chances of the batteries being dropped on the floor, causing physical

damage.

• All inspection tools (calipers, rulers, etc.) should be made from non-conductive

materials, or covered with a non-conductive tape.

• Batteries should be inspected for physical damage. Batteries with dented cases

or terminal caps should be inspected for electrolyte leakage. If any is noted, the

battery should be disposed of in the proper manner.

STORAGE

Batteries should be stored in their original containers. Store batteries in a

well ventilated, cool, dry area. Store batteries in an isolated area, away from

combustible materials. Never stack heavy objects on top of boxes containing

lithium batteries to preclude crushing or puncturing the case.

7.8 HANDLING DURING PRODUCT ASSEMBLY

• All personnel handling batteries should wear appropriate protective equipment

such as safety glasses.

• Do not solder wires or tabs directly to the battery. Only solder to the leads

welded to the battery by the manufacturer.



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• Never touch a battery case directly with a hot soldering iron. Heat sinks should

be used when soldering to the tabs, and contact with the solder tabs should be

limited to a few seconds.

• Batteries should not be forced into (or out of) battery holders or housings. This

could deform the battery pack causing an internal short circuit, or fracturing the

glass to metal hermetic seal.

• All ovens or environmental chambers used for testing batteries should be

equipped with an over-temperature controller to protect against excessive heat.

• Do not connect batteries of different chemistries together.

• Do not connect batteries of different size together.

• Do not connect old and new batteries together.

• Consult manufacturer before encapsulating batteries during discharge.

Batteries may exceed their maximum rated temperature if insulated.



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8. QMWD – SAP SYSTEM

8.1 System Description: The surface system measures mud pulses in the mud column using a

pressure transducer that decodes the MWD survey, tool faces and logging

information. In addition, the surface system tracks the depth of the drilling

assembly, saves data, and displays information for system operators. The SAI

(Safe Area Interface) acts as the system hub in the safe area and performs the

following functions:

The SAI contains a receiver board (qBUS Node 05) that digitizes and

decodes input from the surface sensors including the mud pulse pressure

transducer, hook load transducer, and depth encoder.

The SAI is connected to the hazardous area sensors through certified

intrinsic safety barriers.

The qNIC, now included in the SAI, performs interface functions between

the Safe Area Personal Computer and the qBus system on the SAI. The

SAPC must be running qMWD/W32 software.

The SAI transmits display information for the display side of the legacy

DRT as a display option. It is connected to the legacy DRT through

intrinsic safety barriers.

The SAI contains an RJ-45 to fiber optic Ethernet converter that is

connected to a router and PC in the safe area via RJ-45 Ethernet cables.

It may connect to a Rig Floor Display via fiber optic cable or copper cable

option.

The SAI connects to the MWD electronics for configuration.



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The SAI downloads high-speed data from the PWR tool memory to the

PC.

NOTE: A hot-work permit must be obtained before dumping data from the

PWR tool.

The mud pulse pressure transducer is a 4-20 mA output device with a

range of 0-6,000 psi that senses the pressure in the mud column. Its

output is converted to pressure pulses and decoded by the SAI. It is

mounted into the standpipe.

The Rig Floor Display is designed and certified for use in Zone 1

environments and receives Ethernet data via a fiber optic cable or copper

cable. Power requirements are 120 or 240 VAC. A compass rose is

displayed that is similar to the qMWDPC/W32 software.

The legacy DRT (Driller’s Remote Terminal) is an intrinsically safe Receiver

and Display used with the Safe Area Supply Box. These legacy devices may be

used as Rig Floor Displays with the SAI. The legacy DRT receives power and

data from the SAI through intrinsic safety barriers via the SAI to RT cable, 250

feet (PN 384022). If depth data is required, the system can be run in one of two :

Configuration 1: Directional only with depth input from an outside source.

NOTE: If a depth system is required then depth input may be supplied a serial

connection to a WITS system (Well Information Transfer System).

Configuration 2: Depth tracking, with the J Box, hook load pressure transducer,

and depth encoder added to the system with accompanying cables.



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The type of hook load & pressure transducer used depends on the point of

connection:

The hydraulic sensor type is connected to the hydraulic input of the weight

indicator on the rig floor. The hydraulic sensor is a 4-20 mA output device

with a range of 2,000 psi. The tension meter type, called a hook load

sensor, is connected to the drill line on the dead line anchor.

Both sensors detect whether the entire drill string or just the Kelly or top

drive is

o attached to the traveling block. Hook load sensors allow the system

measure

o Weight On Bit (WOB). Either type of hook load sensor may be used

in a

o hazardous area.

The Geolograph encoder tracks movement of the Geolograph line, which

moves up and down with the traveling block. Movement of the Geolograph

line is quated to measured depth. Output of the encoder is a 2-line,

quadrature-phased electrical

o signal, which allows the system to measure the amount and

direction of block

o travel.

Geolograph encoders are used in the hazardous area. However, the

preferred method for measuring depth is to place an encoder at the water

union of the drawworks drum. Drawworks encoders are always installed

on the right-hand side of the drawworks as viewed from the rotary table.



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A drawworks encoder tracks the movement of the drum as the drilling line

is spooled off or on and converts the rotational motion to linear depth. Two

(2) magnetic pickups detect phase difference in the signal output as the

disk rotate, which creates a signal pulse that indicates direction of travel.

Like the Geolograph encoder, the drawworks encoder is also used in the

hazardous area.

8.2 Toolface Offset Procedure

With the tool assembled, to contain at least the survey electronics module

and the pulser module, connect the programming cable to the

programming plug and connect to the uphole end of the MWD tool. Set the

tool on V-blocks in a near horizontal position and orient the muleshoe key

slot so it faces UP.

Double click on the TFO Procedure Icon to start the Tool Face Offset

Procedure.

With both the downhole tool and the remote terminal connected to the

system, the program should quickly address both systems. If either of the

two modules is not connected, the routine will look for the absent node and

then enter into the routine with a warning screen. The Warning Screen will

identify which of the systems it could not locate and ask the operator if he

would like to Abort, Retry or Ignore. Depending on which routine the

operator wishes to follow, select the appropriate option.



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If the operator wishes to ‘Zero the Gravity Toolface Angle’, once the tool is

located, then the operator can select the appropriate option and continue to

the screen that will allow this procedure.

DOUBLE CHECK TO INSURE THAT THE KEYWAY IS LOCATED IN THE

UP POSITION. This procedure is performed specifically in the DownHole

Tool. Select the first command to Zero the Gravity Toolface Angle. Notice

the number in the second line, Gravity Toolface Angle, which is below the

update line, will change to zero. Simultaneously, the value of the

Instrumentation Mounting Offset will be changed from its previous value to

the previous value of the Gravity Toolface Angle. Also, that the value of that

space will be added to the Total Toolface Correction.

At this point, if the operator knows the DAO (Driller’s Assembly Offset), then

enter this value into the system. The DAO value maps to the surface gears

Remote Terminal.

Quit this routine. IT IS IMPORTANT TO QUIT THE ROUTINE BEFORE

DISCONNECTING THE PROGRAMMING CABLE. OTHERWISE, THE

DiAA LABEL WILL REMAIN ON AND THE TOOL SENSORS WILL WORK

CONTINUOUSLY. If the batteries are connected to the tool and the

connection is broken before quitting the routine, the batteries will have to be

disconnected from the electronics to reset the tool. All corrections and

configuration files will remain stored in the processor, but the TFO

correction routine should be run again if any connections are broken and/or

re-torqued. The offset may be different.

DO NOT MAKE ANY ASSUMPTIONS.



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Disconnect the programming cable and assemble the spear-point on the top

of the downhole tool.



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8.3 Summary of the features of qMWD V 01.30

I. New Features A. qMWD

1. qMWDPC / RT - Drawworks encoder depth tracking

NOTE: Version qMPRX-D3 Vb1.61f or later must be installed in the MPRx 05 of

the RT for drawworks capability.

2. qMWDPC - Utilities for:

a. Drawworks encoder calibration

b. Geolograph encoder calibration

c. Hookload calibration

3. qMWDPC - Database size reducing features:

a. Allows user to set a minimum distance of pipe movement before a

new depth record is written

b. Allows user to set a lower and upper limit on the depths allowed to

write database records, (prevents records with 0 depth in database).

c. User has the option to mark multiple gammas at the same depth as

bad when written to the database, (can be undone in LogView)

d. User can set limits on gamma data which will cause out of range

gammas to be marked bad

4. qMWDPC – Audible alarms will be made for the following events:

a. Flow off – 2 dings

b. Flow on – 1 ding

c. Sync detected – 1 ding

d. End of survey – 1 ding



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e. RT power failure – 3 dings

f. RT power restored – 1 ding

g. QDT_EDR Interface loss of communication with EDR – 3 dings

5. qMWDPC - A function has been provided to convert measured depth to TVD

and vice versa

6. qMWDPC - Surveys are now fully editable and new ones can be added. The

survey calculation window will automatically update TVD when a new survey is

entered or received from the RT; survey closures will automatically be calculated

and stored whenever a new survey is received. Tie-ins can now be edited in the

survey calculation window.

NOTE: LogView V02.01d updates only new surveys, so any edits made to

surveys that had already been loaded into a log database will not be updated. To

get these changes into the log database, the user will have to start a new log

database. LogView VB2.01e and later reads ALL surveys in when an update is

performed.

7. qMWDPC – the maximum number of TFAs possible based on print

width and print header type selected is now automatically computed for the users

selection

8. QDT_EDR Interface

a. Inclination and Azimuth will be output to the WITS port to 1 decimal

place.

b. Fixed problem that was preventing communications with the Pason

EDR in half-duplex mode

B. MWDRoll32

Win9x / WinNT 4.0 version of MWDRoll test



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NOTE: MWDRoll32 MUST NOT be run at the same time as any qMWD app as it

changes the PC’s LnkA and this will have disastrous effects on any qMWD/W32

app running at the same time. MWDRoll32 does, however change it back when it

exits, so all qMWD/W32 apps will then run as normal.

C. MemoryIO/W32

If MemoryIO/W32 is on the PC where this CD is being installed it will

be automatically updated to V01.01.

NOTE: Do NOT attempt to re-load MemoryIO/W32 V01.00 on this PC after

loading qMWD V01.30 as it will cause qMWD/W32 apps to fail.

II. Bug Fixes and Enhancements

8.4 Summary of features of qMWDPC V 01.20



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1. Survey will now print in meters when meters are selected as the unit.

2. Only good surveys will be printed by the survey print function.

3. Several bugs with ASCII logging files in association with logging in variable

units have been fixed

4. Reduced the size of the scroll view for the gamma window to prevent the user

being locked out for long periods when scrolling

5. Added Pumps Up Time and Pumps Down Time to pumps on and off event log

messages stored in C:\MWDEvent.Log to allow user to more easily track

circulating hours. Pump accumulators will be in the next release.

6. Extensive work to prevent the writing of bad records to the data base when

RT has a power failure has been done.

7. Temperature was not being stored with the gamma records

8. An invalid error message box was being displayed every time a database was

opened

in the year 2000. This will no longer be displayed.

9. Added the ability to display TVD in the Telemetry window

10. Corrected survey calculations to take absolute value of course length when

calculating dogleg severity.

III. Changes since Beta qMWD Vb1.30d

A. MWDRoll32

1. Puts gamma on the display

2. When Azimuth is 0 for inclination during the roll test, the beta of

MWDRoll32 was not treating readings near 359.9 as close to 0, but as 359.x

away from 0 and failing the tool. This has been fixed.



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B. qMWD/W32

1. qMWDCnfg

a. will not attempt to send “DSTy” (Depth Sensor Type) to an MPRx with an ASW

earlier than 1.61f

b. fixed 4 problems with implementation of access control using capability codes

c. new defaults for access control settings have been supplied

2. qMWDPC

a. It will not start another copy of the calibration utilities if they are already running

b. The ‘Recalc’ button has been restored to the survey calculation window. A

checkbox has been provided to allow the user to prevent recalculation on every

survey edit (see help).

c. The accept/reject survey dialogs will no longer stack up. If a new survey has

been received before the displayed accept/reject dialog has been responded to,

the default action will be performed (see help)

d. Will no longer attempt to write an invalid record to the database, but will inform

the operator and log the error

e. A crash that occurred when the user pressed the Exit button in the depth

setting dialog before the operation was complete has been fixed.

f. Fixed the archive database template archive.db. The user was unable to open

an archive database when Kilodekanewtons were selected as the units of force

in qVarUnits. The error message was ‘No Current Record’.

3. TFO Procedure - Fixed error that was setting IMO in MPTx when user was

setting DAO in MPRx

4. QDT_EDR Interface - Fixed problem that was preventing communications with

the Pason EDR in half-duplex mode.



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C.Recorder to Log Merge Utility Beta

A new version, Vb1.00b of this utility that allows plotting of recorded data

has been included for evaluation. This version will allow the user to create a new

data set consisting of recorded data only or to merge the recorded data with an

existing data set containing pulsed data. Please let us know how this utility works

and what we can do to improve it, if necessary.

8.5 Summary of New Features in qMWD V02.02 Common Features to V02.00 2-Bay and 3-Bay Systems A. Features available with upgraded PC software for all versions of firmware

1. qMWD/W32 software runs under Windows 2000 Pro SP4 and XP Pro SP2

2. qMWDCnfg/W32 has transparent plug and play, giving the customer the ability

to use any combination of downhole and receiver firmware seamlessly.

3. Configurations are written to a database.

4.Greatly enhanced configuration print with the option for a summary or complete

report.

5. The ability to send and receive WITS data via TCP/IP as well as via serial

COM.

6. Support for the qVision rig floor display.

7. The qW32 Server automatically finds the COM port that the qNIC is connected

to an accumulated Pumps Time Window that gives the user the ability to track

and edit pump times on a daily or per job basis.

9. The default for Flow Evaluation time is set to 25 seconds to prevent short flow

on and off cycles which may cause the downhole tool to quit sending surveys.



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B. Features available with upgraded PC software and receiver firmware

1. The ability to work seamlessly with LogView II, the log data storage, downhole

data recorder retrieval and data editing application.

2. The ability to work seamlessly with RTView, the remote real-time log plotting

and final presentation log application with the ability to produce PDF files and to

print to any Windows compatible printer.

3. Any number of remote computers can display a real-time log with sensor data

depth offset with RTView.

4. A percent decode variable is computed by the receiver and displayed in

qMWDPC/W32.

5. The option to defeat or change the sliding window for the averaging of decode

quality and confidence values.

6. The ability to issue a command to the receiver to force it to stop decoding

pulses

C. Features available with upgraded surface software and firmware requiring upgraded downhole firmware

1. The option to detect drill string rotation and eliminate toolface updates when

rotating.

2. The option to set up the system to send and detect a sync sequence after

every complete Toolface/Logging sequence.

3. The option to repeat the same survey data sequence a number of times to

assist in survey decoding when drilling in lost circulation conditions.

4. The option to force the receiver to stop attempting to decode data and go into

resync mode at any time if the resync feature is enabled.

5. Short Flow Off Downlink allows the user to defeat the transmission of survey

data and to limit the number of Toolface/Logging sequences after a pump cycle



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9. TRU-VU USER GUIDE

9.1 TRU VU DATA WISE SYSTEM SETUP Do not start up the computer, plugged into the TRU VU system.

On the laptop have the external comport (gold wire cable) plugged into the

bottom. USB comport. With the desktop you don't use the external cable,

you have two comports already. Put the TRU VU key in.

Now start up the computer and enter the TRU VU program by the short

cut on the desk top.

On the welcome to TRU VU screen: select "new" if you are starting a new

well.

Create a new well name , job #, or you can "browse" for a old well that you

want

To open in the database. "proceed" confirm "yes" if that’s the well you

want.

*for a new well have a "check mark" in the require initial setup file.

"browse"

Highlight "india" "proceed". This is a pre-configured setup so you don't

have to create one .

If this is a new well being created click "yes" for first time that the program

has been started.

*If this is a well that already has been started from before click "no"

because all your settings will be changed.



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If this is an old well that you are re-opening, you can now plug in the Tru

vu system to your computer.

*the black serial "T" cable plugs into the back of the data wise box into

RS232 port which will plug into comport 1. The grey q-bus cable plugs into

the comport 2. The other end plugs into the q-bus port on the saps.

If it is a new well a TRU VU setup screen will come up. This is where you

add all your well information.

LOADER SCREEN

Goto: "browse", highlight on "india", "open", "load"

SURVEY SCREEN

You want "minimum radius of curvature"

Put in information for :"proposed direction(vs)", "proposed declination",

"dogleg" set

At 30, "survey to bit", "gamma to bit". (leave "wet connect to bit" and "gsi

to bit" at

Zero, (unless you know what they are or mean?)

Hit "set" after changing each one of them.

USER VARIABLES SCREEN

Do not touch.

DATABASE SCREEN

Change units to "metric".

Change granularity to ".2" increments

Leave your start depth at zero, because if you put a depth in there you will

not be able to enter a tie in survey, or any survey before that depth you

have entered.



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CLICK ON "SAVE DATA" BEFORE YOU LEAVE THIS SCREEN. ASSOCIATIONS SCREEN

Make sure you are in "custom configuration"

Have: an "x" infront of these associations by highlighting them. Then click

on "connect to input" which will put a check mark infront of "connect to

input".

TRU VU DATA WISE SYSTEM SETUP AZM

MWD LISTENER TYPE 1

TAG 2 (AZM)

BLOCK INPUT

TRU VU CONDUIT

ENCODER/COUNTER 1

DIP

MWD LISTENER TYPE 1

TAG 7 (DIPA)

GAMMA

MWD LISTENER TYPE 1

TAG 8 (GAMA)

HOOKLOAD WHEN YOU CALIBRATE THE HOOKLOAD YOU WILL HAVE A



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TRU VU CONDUIT "CHECK MARK" INFRONT OF "SCALE INPUT VALUE"

ALSO.

ANALOG 1

H TOTAL

MWD LISTENER TYPE 1

TAG 12 (MAGF)

INCLINATION

MWD LISTENER TYPE 1

TAG 3 (INC)

PUMPS OFF TIME (MWD)

MWD LISTENER TYPE 1

MUD PUMPS OFF TIME

PUMPS ON TIME (MWD)

MWD LISTENER TYPE 1

MUD PUMPS ON TIME

PUMP PRESSURE

MWD LISTENER TYPE 1

TAG 10 (PMPP)

TOOL TEMPERATURE

MWD LISTENER TYPE 1

TAG 4 (TEMP)

TOOL VOLTAGE

MWD LISTENER TYPE 1

TAG 13 (BATV)

TOOLFACE GRAVITY

MWD LISTENER TYPE 1



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TAG 5 (GTFA)

TOOLFACE MAGNETIC

MWD LISTENER TYPE 1

TAG 6 (MTFA)

TRU VU DATA WISE SYSTEM SETUP DEVICES SCREEN

This should be all configured already in the "india" setup file. If not have these

set:

DEVICE:

CLICK ON MWD LISTENER TYPE 1

SETUP: ALWAYS "SAVE" YOUR DATA IF YOU LISTENER ONLY CHANGE ANY OF YOUR

CONNECTION: CONFIGURATIONS, BEFORE YOU GOTO COM 2 THE NEXT STEP.

HAVE: TIMEOUT COUNT SET AT [10]

SPEED [9600]

LISTENING ID [7]

PUMP STATUS [1]

DEBUG MODE [0]

*LEAVE THE REST ALONE.

NEXT DEVICE:

NETWORK

SETUP:

BLANK

CONNECTION:

[NONE]



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NEXT DEVICE:

TRU VU DATABOX

SETUP:

8 ANALOGS/4 DIGITALS

CONNECTION:

ISA CARD/PCMCIA CARD

*HAVE DATABOX ENABLED [OFF]

NEXT DEVICE:

TRU VU CONDUIT

SETUP:

SERIAL MODE

CONNECTION:

COM 1

*HAVE TIMEOUT COUNT [10]

SPEED [9600]

TACHOMETER CLIP TIME [2 TO 65 SECONDS] [30]

COUNTER +/- JUMP MAXIMUM [5000]

These are the comports where the information is coming from. If you don't

have that symbol showing up. You have a com port not configured right. If there

is a grey symbol with a blue clock beside it, it means your system is not hooked

up to a com port or you have to unplug the TRU VU system from your com ports,

exit out all programs, and restart your computer. Open up the job you want and

then reconnect your TRU VU system to your com ports.

TRU VU DATA WISE SYSTEM SETUP



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"F3" SCREEN "GRAPH 1" is where you want "gamma" on the left hand side in #1 and "rop" on

right hand side in #5. To setup the screen, click on the "wrench" now you will see

Slot #1 flashing this is where you enter "gamma" by going up to the top right and

Click on the down arrow below "depth" arrow. Scroll down until you see "gamma"

Highlight it. Now you will want to set the scale. Go down and click at the right "0"

Now you can enter your gamma maximum scale at "100". Now you will want to

set up ROP.

Goto #5 and click on it. Now it will flash. Go up and click on the down arrow

And scroll down till you see "ROP". Highlight it, and now set your scale by

clicking on the right "0" and put in "150" for a maximum rop scale. Then go up top

and click on the wrench again. Now it is set up.

If you need to edit the graph. Click on the "pencil" the gamma screen will

now be ready to be edited. With the mouse click on where you want to edit from

and scroll down slowly to where you want to stop editing from. Then go and click

on the "disk" picture to save the new edit or click the "trash can" to go back to the

original way it was. Then click on the pencil to finish editing. If you want to edit

"ROP" click on the pencil ,then click on the #"5" at the bottom. Now you are ready

to edit.

Click on the "disk" to save or "trash can" to restore to old data. When done

click on "pencil" to finish.

9.2 PRINTING PLOTS MD GAMMA, MD ROP PLOTS

Click on the "printer", now you will be in the "graph point" screen.

At the top you want to be in:



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GRAPH 1: TRACES 1-3, API, 8", MD/TVD, 2 DATA TRACKS (SHOULD BE

TOP OF LIST.)

Be careful not to click on the "locked" bottom, it will lock you out from editing the

plotter setup. (there are notes on how to un-lock it on page 7).

In the general options screen you want:

Click on the "pencil" so you can edit the information.set your depths

AXIS: MD

Res: 1 to 500 or 700, user defined (larger the number the shorter the plot)

Big header path: c:\tvc\headers\header.big Header path: c:\tvc\headers\headers.md.txt Trailer path: c:\tvc\headers\headers.apg

If your not in these, click "browse" find them, highlight them. "Open" now it will be

There.

Casing symbol 0.25

Heavy div 5

Annotation 25

FRONT 10

CHECKED MARKED SURVEY -1

CHECKED MARKED COMMENTS -1

In the tracks and traces screen you want:

Click on these to highlight them, so then you can see what they are configured to.

TRACKS



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#1: LINEAR GRID(0.000)

0 TO 2.5

LINEAR GRID MD


BLACK NONE CYAN

2 4

0

4

TRACES

#1: [GR1, TR1] (#1 LINEAR GRID (0.000)

[GR1, TR1] #1: LINEAR GRID(0.00)

0 0 UNAVERAGED

....,THICK BLUE

NONE

TRACKS

#2: AXIS ANNOTATION (2.500)

2.5 TO 3.25

AXIS ANNOTATION MD

BLACK NONE BLUE

0 0

0

0

TRACES

#2: [GR1, TR2] (#1: LINEAR GRID (0.000)

[GR1, TR2] #1: LINEAR GRID (0.000)



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0 0 UNAVERAGED

. ., THICK BLACK

NONE

TRACKS

#3: LINEAR GRID (3.250)

3.25 TO 5.75

LINEAR GRID MD

BLACK NONE CYAN

2 4

0

4

TRACES

#3: [GR1, TR3] (#1: LINEAR GRID (0.000)


0 0 UNAVERAGED

. . . . ., THICK GREEN

NONE

TRACKS

#4: SURVEY COMMENT (5.750)

5.75 TO 8

SURVEY COMMENT DEFAULT

BLACK NONE GREEN

0 0

0

0

TRU VU DATA WISE SYSTEM SETUP PAGE 6



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TRACES

#4: [GR1, TR5] (#3: LINEAR GRID (3.250)


0 0 UNAVERAGED

...., THICK BLUE

NONE

TRACKS

#5: COMMENT (5.750)

5.75 TO 8

COMMENT MD

BLACK NONE BLUE

0 0

0

0

TRACES

#5: [GR1, TR3] (#3: LINEAR GRID (3.250)


0 0 UNAVERAGED

. ..., THICK BLACK

NONE

TRACES

#6: [GR1, TR3] (#3: LINEAR GRID (3.250)


0 0 UNAVERAGED

. . . . ., THICK GREEN

NONE



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NOW YOU CAN "CLICK" ON THE "PRINTER" SYMBOL TO PRINT THE PLOT.

TO PRINT PLOTS TVD GAMMA, TVD ROP PLOTS IN THE GENERAL OPTIONS SCREEN YOU WANT:

CLICK ON THE "PENCIL" SO YOU CAN EDIT THE INFORMATION.

SET YOUR DEPTHS

AXIS: TVD RES: 1 TO 500 OR 700, USER DEFINED (LARGER THE NUMBER THE

SHORTER THE PLOT)

BIG HEADER PATH: C:\TVC\HEADERS\HEADER.BIG HEADER PATH: C:\TVC\HEADERS\HEADERS.TVD.TXT TRAILER PATH: C:\TVC\HEADERS\HEADERS.APG

IF YOUR NOT IN THESE CLICK "BROWSE" FIND THEM, HIGHLIGHT THEM.

"OPEN" NOW IT WILL BE

THERE.

CASING SYMBOL 0.25

HEAVEY DIV 5

ANNOTATION 25

FRONT 10

CHECKED MARKED SURVEY -1

CHECKED MARKED COMMENTS -1



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TRACKS: CHANGE "TRACK #1 TO TVD AXIS

CHANGE "TRACK #2 TO TVD AXIS

CHANGE "TRACK #3 TO TVD AXIS

KEEP #4 TO DEFAULT CHANGE "TRACK #5 TO TVD AXIS

*KEEP THE REST OF THE TRACES THE SAME..

*WHEN THE TRACKS AND TRACES ARE SET UP YOU ONLY HAVE TO CHANGE YOUR: DEPTHS, AXIS TO MD OR TVD, "HEADER PATH" TO MD OR TVD, AND YOUR TRACKS #1, #2, #3, AND #5 TO MD OR

TVD. TO PRINT OFF THE MD PLOT OR TVD PLOT.

If you accidentally locked the graph 1 so you can't edit it for the MD and TVD

plots.

Go to start, explore, c:\, tvc, graphs, click on "000" this will be the graph 1 with 8" Right click when highlighted=>open=>scroll down 7 rows till you see "locked = 1" It should be "locked = 0" make sure not to erase anything else. =>exit out.=>

save. F6 SURVEY STATION "Station edit" is where you add surveys.

"view" this is where you can view, edit surveys, and print them out.

Put in from: eg "0" to "23" with "standard survey worksheet" and press "printer" it

Print them out. If you press "trash" you will delete them. If you want a 3d view of



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The plot.=> on the down arrow click on "3d views of survey data"=> "apply",=>

"print"

SURVEY TIE IN

Put in survey depth (in msl-survey depth) this is rig md depth - kb - survey offset

Eg

Station depth = 100m in a tie in survey depth and tvd should be

Inc = 0 the same. Get the "ns" and "ew" from d.d

Azm = 0 they should be zero for a new well??

Tvd = 100m Make Sure That Your Tie In Is The Same As

VS = 0 THE D.D TIE IN.

DL = 0

NS COOR. = 0

EW COOR. = 0

CLICK ON "DISK" MAKE SURE "TVD" HAS SAME VALUE AS "SURVEY DEPTH", ON YOUR TIE IN SURVEY.

If not goto "station edit" highlight the tie in survey=> goto the tvd box and enter

the

TVD in there. Click on "disk" THEN YOU CAN PUT IN YOUR NEXT REAL SURVEY.

"Targeting" this is where you can put your target information. Then it will tell you where you should be aiming for your inc and azm to get there. Shift f5 (reports): enter well info.=>"save"

Shift f7 (depth set): this is where you set your msl measured depth and msl bit

depth

Click on "set" to save.



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CTRL F4 DATABASE:

You want specific database: set to "depth"

Job back up: in browse box type: c:\tvc\job# (the job # is what you called the

well at the start of the well.

Down at the bottom click on "add all" => "save" this will save all the database in

the

Job file in the "c:\ drive" in "tvc", in welldata.

If you put in: a:\tvc\job# in the browse box this will save that job data to a floppy.


EDITING

Operation: you can edit your database, eg. If you want to erase part of your

database. Highlight "delete record" and put in a:

Range start (start depth)

Range end (end depth)

"EDIT NOW"

IMPORT/EXPORT

For las file

Specific database "depth"

At the bottom click on what you want to export eg. Gamma, rop, depth will be

there already. In the browse box type in :

A:\JOB# "EXPORT" THIS WILL SEND IT TO THE FLOPPY

AUTOMATIC BACK UP



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SPECIFIC DATABASE: "DEPTH"

FILENAME: (JOB#)

CHECK MARK "ENABLE AUTOMATIC BACK UP"

CHECK MARK "INCREMENTAL AUTO BACK UP"

SELECT "ADD ALL" IT WILL DO A JOB BACK UP EVERY: MIDNIGHT, 6 AM, NOON, 6 PM. CTRL F5 DEPTH TRACKING

Depth tracking: this is where you calibrate your draw works decoder.

Put the drum decoder on the drawworks.

9.3 CALIBRATION Select drilling line encoder or horses head.

Now get the driller to go up all the way with the kelly and pipe to the top of the

Next stand to the rig floor. You know the stands length. Come down to the TRU

VU System. Click on the kelly top "get" and put the "height" of the stand there.

Now get the driller to come all the way down to the floor. Measure the distance

from were the kelly screws into the pipe, down to the rig floor. Now goto TRU VU

At the kelly down click on "get" and put the "height" in there.

Now you are calibratied so click "save".

Now shift f7, enter the correct kelly down - minus the little that the top drive

Can't make it to the floor, from that stand. Enter the same depth for the bit depth.

All in MLS depths. Click on "set" to save. Now, the driller can make his

connection.

THERE ARE OTHER WAYS TO CALIBRATE THE DEPTH DECODER BUT THIS IS EASY AND ACCURATE.

The driller has to work the pipe anyway, so if you need to recalibrate acouple of



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Times, or after any trips, it isn't very time consuming. Other wise, just edit your

depths and fix up your gamma, and rop logs.

The "drawworks encoder" works well if you have enough layers on the drum to

make it accurate.


HOOK CALIBRATION

SETUP (CTRL F7)

ASSOCIATIONS

GO DOWN TO X HOOKLOAD CLICK ON IT. "CHECK MARK" SCALE INPUT

VALUE.

eg: IN 75 TO 5 INPUT 8.365

OUT 137 TO 10 RESULT 16.12

75000 LBS IS THE ACTUAL HOOKLOAD FOR THE BLOCKS AND TOP DRIVE.

137000 LBS IS THE ACTUAL WEIGHT OF STRING, BLOCKS, AND TOP

DRIVE.

SO, I PUT 75 AND 137 FOR EASY FIGURING.

WITH HOOKLOAD OFF THE DEADLINE, THE UNIT WAS READING 4.3

AMPS (LINE DIAPHRAM CLAMP) SO I PUT IN ALITTLE MORE eg. 5 AMPS. PUT THE HOOKLOAD SENSOR ON THE DEADLINE. WITH SLIPS OUT 137000 LBS(137) @ 10. WITH THE SLIPS IN 75000 LBS(75) @ 5. WITH THIS CONFIGURATION I GOT

A INPUT = 8.365 AMPS.



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AND A RESULT = 16.12 AMPS. "Save" it might not be accurate, but it worked on this rig. You can play around

with numbers to make it more accurate. All this does is tells you when you are

"on" or "off" bottom, your WOB (if configured) and your hookload.

IN "DEPTH TRACKING" (CTRL F5) => "MISCELLANEOUS":

SLIP SET POINT 15

STRING MOTION 0.1

ON BOTTOM STATUS 0.3

TOOL VOLTAGE LOW 30 (THIS IS FOR WIRELINE LOGS)

HIGH 99

ROP MODE: DEPTH OVER TIME(HOUR)

"SAVE"

This seems to work good for tracking depth.

As the hookload increases with weight from pipe, lower the slip set point from 15

to 14 and the "slips in" didn't come on when sliding or rotating with a lot of weight

on the bit.

9.4 MISCELLANEOUS NOTES: GAMMA FACTORS: IN INDIA, PROGRAM YOUR TOOL TO HAVE THESE

FOR GAMMA FACTORS DOWNHOLE.

8" monels - 6 6 3/4" monels - 5 4 3/4" monels - 1.5



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With the "drawworks encoder", have it so when the blocks are going up so are

the counts, when the blocks go down so are the counts. This is done by the way

you put it on the drum. Test it in the shack first to see which way it should

goWireline logs.


On a wiper trip or bit trip, make sure, that on the way back to bottom, that the bit.

Depth doesn't go past your total depth. Otherwise you will be added new depths

and logs to the database. You can stop this by clicking on "shift f2" the "quick

bar" screen. On page 3, set "yes" to slips manual and make sure slips set says "yes". When on bottom set your total depth and bit depth, and change

slips manual back To "no". Now it will tell you when slips are set (in) or (out) by

the hookload reading.

Or

You can enter a smaller bit depth than your total depth. So it will never pass your

total depth. When on bottom just reset your bit depth. You shouldn't have to

recalibrate the encoder, just try resetting your depth first when on bottom.

9.5 TRU-VU RENEWAL PROCEDURE

FOR RENEWAL OF THE TRU-VU SOFTWARE PLEASE DO THE

FOLLOWING:

TALK TO MR TODD POMEROY OF TRU-VU SYSTEMS ,HOUSTON ON THE

FOLLOWING NO. 281-784-5533 OR 281-443-7209.



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GIVE HIM YOUR TRU-VU KEY NO.( WHICH FOR THIS KIT IS 4074)

YOU CAN GET IT BY GOING TO TRU VU DATAWISE SCREEN HIT F8

(HAVING LOCK SIGN) . THEN HIT GET CODE. YOU WILL GET A TEN-DIGIT

CODE AS WELL AS YOUR TRU-VU KEY NO. . GIVE HIM BOTH. HE WILL

AGAIN GIVE YOU A TEN DIGIT NO. WHICH YOU WILL HAVE TO FEED IN TO

THE SAME WINDOW (GOTO F8), HIT GET CODE, FILL THE NEW CODE IN

THE EMPTY BOX, HIT ACCEPT AND HIT SAVE.

YOU WILL GET A RENEWAL MESSAGE



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10. DRILL WELL USER GUIDE

10.1 CONFIGURATION: The Configuration Screen was designed to allow the Operator to program

the Transmitter and the Receiver. To access the Configuration Screen the

Operator must press the Tools button to change to the Tools Screen, then press

the Config button located on the Tools Screen.

The Configuration Screen will launch in a separate window. The “Setup”

menu allows the operator to choose which combination of Transmitter and

Receiver that he will be programming. Double Click on the Transmitter/ Receiver

combination of choice and a list of Configuration Parameter Groupings will be

presented.

To access the parameters for each grouping, double click on the grouping

choice.

Change the parameter(s) and press “APPLY”, to apply the parameter

changes. Once all the parameter changes are completed, the operator must

choose the device to which he wants to store the configuration parameters. The

choices are Rx (Receiver), Tx (Transmitter) or Both and are presented on the

Configuration Parameter Grouping screen. The operator should make sure that

he has chosen to “Store To” from the drop down menu. Once the choice of

device is made, press the “PROCEED” button and confirm the choice that was



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made. If the choice is confirmed the process will continue. The Communication

(with device) Screen is presented next.

Note: If the Receiver is being configured the pumps should be off. See the

section on Receiver Configuration Mode for an explanation. If a parameter needs

to be changed while the pumps are on, use the xxTalk utility.

CONFIGURING THE RECEIVER

In the case above, the receiver is being configured. The “Status” box

indicates the present status of the configuration process. The box below this

shows the parameters and values that were sent to the Receiver for

configuration. The progress bar shows what percentage of the configuration

process has completed. Once the configuration has completed the Receiver is

immediately queried for the parameters that were just stored to it. These

parameters are sent back to the laptop to be verified. The parameters are verified

and shown in the box as in the figure above. A configuration file is displayed in

notepad, which the operator can immediately print. This file is also stored in

C:\Program Files\Camber Technology\DrillWell\MWDLogging In the directory Job#\BitRun#, where Job# is the Job Number that the Operator

entered when Drill Well was launched, and BitRun# is the BitRun number created

for the Job Number.

e.g C:\Program Files\Camber Technology\DrillWell\MWDLogging\25000\BitRun1



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CONFIGURING THE TRANSMITTER

In order to configure the transmitter, the Laptop that is running Drill Well

must be connected to the Transmitter via the XL50 Translator Box. Connect the

XL50 Translator Box to the Laptop with either a serial cable or with the USB

cable provided.

Note: Do NOT connect both the Serial Cable and the USB cable at the same

time. Use one or the other. If the Operator chooses to use the USB cable he

must install the driver provided with it. He will also have to change the COM Port

which Drill Well is configured to work with (COM 1 is the default). Once the USB

driver is installed it works in the same manner as using a serial cable.

Connect one end of the serial cable to the XL50 and the other end to the

COMPORT of the Laptop. Connect the XL50 programming cable from the XL50

to the Transmitter.

Note: If the Laptop does not have a COM Port the Operator will need to connect

a USB to Serial Adapter or use the USB cable provided with the XL50. Once the

configuration parameters are set, choose to “Store To” the Transmitter and the

Communication Screen will be presented. The Serial Communication box shows

the Communication between Transmitter and Drill Well through the XL50. Once

the Transmitter is configured the parameters are immediately requested from the

Transmitter and verified against what was sent. Important Note: Don’t use the Power supply for the XL -50 Translator box when the tool is connected with the battery or else if you want to check only the electronics then it is possible to use the power supply for the Translator box. If you not follow the procedure it will cause serious problem in the tool

or XL – 50 Translator box.



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CONFIGURING BOTH THE RECEIVER AND TRANSMITTER

If you choose to configure both the Receiver and Transmitter, the

Transmitter will be configured first, followed by the Receiver.

10.2 LOADING PARAMETERS FROM A DEVICE If you wish to load parameters from either the Receiver or Transmitter or

both, simply choose to “Load From” instead of “Store To”. The parameters will be

requested from the device. Once the parameters are returned from the device

they will be displayed in notepad. The file that is created is called Job#_Params

and is located in

C:\Program Files\Camber Technology\DrillWell\MWDLogging\Job#\BitRun#

e.g.

C:\ProgramFiles\CamberTechnology\DrillWell\MWDLogging\11111\BitRun1\11111_Params.txt RECEIVER CONFIGURATION MODE

The Receiver works in two modes, Broadcast and Chat. When the

receiver is decoding survey and toolface logging data it is operating in broadcast

mode. In order to configure the Receiver, it must be put into Chat Mode. When

the Receiver is in chat Mode it no longer broadcasts information, instead it is

waiting for commands from the Drill Well Software. Once the Configuration

process is complete the Drill Well Software will return the Receiver into

Broadcast mode.



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10.3 xxTALK UTILITY The xxTALK Utility allows the Operator to communicate with both the Receiver

and Transmitter. This utility can be used to query and change individual

parameters in the Receiver or Transmitter without having to go through the

configuration process.

Note: In order to talk with the Transmitter the Laptop must be connected to the

XL50 using a straight thru serial cable or the USB cable, and the XL50 must be

connected to the Transmitter with the XL50 Programming cable.

To launch the xxTALK Utility press F4.

QUERYING A PARAMETER WITH xxTALK To query a parameter simply choose one of Both, Tx Only or Rx Only, enter the

parameter label in the QUERY box and press ENTER. In the picture above the

both the Receiver and the Transmitter are being queried for the value of the

Receiver Delay Time Parameter , rxdt. The Receiver and Transmitter reply after

approximately 5 seconds with their value for rxdt. Note: If an invalid parameter is entered, neither the Receiver nor Transmitter will

respond. See Appendix A for a list of common parameters.

CHANGING A PARAMETER WITH xxTALK To change a parameter with xxTALK chooses one of Both, Tx Only or Rx Only.

In the QUERY window type parameter label = value and press ENTER.



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e.g. To change the value for the Receiver Delay Time , rxdt, to 45 seconds, type

rxdt = 45 and press ENTER. The Receiver and Transmitter reply after

approximately 5 seconds with their value for rxdt. Note: In order to change parameters in the Transmitter and some parameters in

the Receiver, the user capability code will have to be changed to permit this.

10.4 DRILLWELL MAIN SCREEN Rcvr Msg – Displays the current contents of the Receiver Status Register

STOP Button – Stops the Drill Well program

Status Temp

High (LED) – Turns Bright Red when the Receiver decodes a temperature down

hole that is greater than the high temperature threshold set by the operator.

Battery Use

Battery 1 (LED) -- Bright green when Battery 1 is in use, otherwise dark green.

Battery 2 (LED) – Bright green when Battery 2 is in use, otherwise dark green.

Low Battery (LED) – Bright red when either the Battery 1 or Battery 2 voltage

falls below the battery voltage threshold, otherwise dark red.

Communication

Serial Lnk (LED) – Bright Green when the Serial COM Port is set, otherwise

dark green

Serial Rd (LED) – Bright Green when data is being read from the Serial COM

Port otherwise dark green.

Serial Wr (LED) – Bright Green when data is being written to the Serial COM

Port otherwise dark green.



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Pumps

On/Off (LED) – Bright Green when pumps are on. Dark Green when pumps are

off.

Time Up – Time that the pumps have been up (on) for.

Time Down – Time that the pumps have been down (off) for.

Guidance Rosebud

Outermost Half Ring – Read from the bottom starting at 180 Degrees to 0

Degrees. This is used to display the Inclination on a scale from 0 to 180 Deg.

Azimuth Ring – This ring is a full 360 Degrees and is used to display the

Azimuth. This is the ring next in from the Outermost Half Ring.

Toolface Display – This display takes up the remaining five rings into the center

of the Guidance Rosebud. There are 5 toolfaces displayed. The latest toolface

and 4 previous toolfaces. The latest toolface is displayed in the outermost of the

5 toolface display rings. In the picture above the latest toolface is displayed in

yellow. The 4 history toolfaces are displayed in red.

Centre of the Guidance Rose – The numerical value of the latest toolface is

displayed at the center of the Guidance Rose. When a new toolface is decoded

the value in this area will flash with a red background.

TELEMETRY DATA SCREEN

The Telemetry Data Screen contains 3 grids. The 3 grids display

Synchronization, Survey and Toolface Logging data respectively.



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Synchronization Grid – The Synchronization Grid contains 3 columns SyTT,

SyQF, SyCF and displays a history of Synchronizations between the Receiver

and Transmitter.

SyTT – Synchronization Time

SyQF -- Synchronization Quality Factor

SyCF – Synchronization Confidence Factor

Survey Grid – The Survey Grid contains 14 columns and displays a history

of decoded surveys. The latest survey is shown at the bottom

of the grid.

SuTT -- Time Survey was decoded at.

SuSq -- The decoded survey sequence number.

Dpth – The Depth that the survey value is associated with.

WdQF – The Quality Factor of the decoded survey word.

WdCF – The Confidence Factor of the decoded survey word.

Inc – Decoded Survey Inclination

Azm – Decoded Survey Azimuth.

gTFA – Decoded Survey Gravity Tool Face

mTFA – Decoded Survey Magnetic Tool Face

DipA – Decoded Survey Dip Angle

MagF – Decoded Survey Total Magnetic Field

Temp – Decoded Survey Temperature

BatV – Decoded Survey Battery Voltage

Grav – Decoded Survey Total Gravity

Toolface Logging Sequence Grid – The Toolface Logging Sequence Grid

displays the decoded tool face logging sequence words. The latest word



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decoded is shown in green. This grid will display the last 20 words decoded

before resetting.

WdTT – Time Word was decoded at.

Dpth -- Depth associated with the decoded word.

WdQF – Quality factor of decoded word.

WdCF – Confidence factor of decoded word.

TLSq – The decoded tool face logging sequence number.

gTFA – Decoded gravity tool face

mTFA – Decoded magnetic tool face

Gamma – Decoded gamma count.

Temp – Decoded Temperature

TmpW – High Temperature Warning Flag (True/False)

BatV – Decoded Battery Voltage.

BatW – Low Battery Voltage warning flag (True/False)

Bat2 – Battery 2 switch flag (On/Off)

10.5 TOOLS SCREEN The Tools Screen was designed to give the Operator access to the following

tools:

Chat – A utility which will allow the Operator to put the Receiver card into

Chat Mode in order to change parameters and

perform diagnostic procedures.

Config – Allows the Operator to configure both the Receiver and

Transmitter.

Send Msg – Allows the Operator to send a message to the Rig Floor

Computer.



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Setup – Allows the Operator to change parameters that are frequently

changed, including HiPL,LoPL,DAO,and PALMode.

Firmware – Allows the Operator to change the Firmware on the

Receiver card (Future Addition)

TFO Procedure – Tool Face Offset Procedure

Allows the Operator to “High Side” the Transmitter.

WITS Setup – Allows the Operator to change the WITS Tag value of parameters

that are being sent to another system using the WITS protocol or being received

by Drill Well

from another system using the WITS Protocol.

10.6 Depth Tracking Setup The Depth Tracking Setup Screen allows the Operator to set how Drill

Well will get a value for bit depth. To access the Depth Tracking Screen press

the GO button beside Depth Tracking.

The choices are:

Manual – The Operator will manually enter the Bit Depth every time pumps go

off.

From WITS – Drill Well use the value for Bit Depth that is received via the WITS

protocol from the laptop COM Port. By default Drill Well expects the Bit Depth to

come via WITS. Choose one of the options and press the APPLY button.

10.7 TFO Procedure



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The Tool Face Offset Procedure allows the operator to Zero the Gravity

Toolface Angle, Set the Instrumentation Mounting Offset in the Transmitter and

the Drill Assembly Offset in the Receiver. To access the TFO Procedure, press

the TFO Procedure button on the Tools Screen.

Note: In order to use this tool the laptop running Drill Well must be connected to

the XL50 translator box with a serial cable or USB cable, and the XL50 must be

connected to the Transmitter with the XL50 programming cable. The TFO

Procedure will automatically query the Transmitter for the value of it’s Gravity

Toolface Angle (gTFA), and Tool Face Offset (TFO).

Gravity Toolface Angle – gTFA from the Transmitter.

Instrumentation Mounting Offset (IMO) – Tool Face Offset in Transmitter.

Drill Assembly Offset – DAO value set in the Receiver.

Total Tool face Offset – IMO + DAO.

Set DAO – Allows the Operator to set the DAO in the Receiver.

Zero gTFA – Allows the Operator to Zero the Gravity Toolface Angle.

Set IMO – Allows the Operator to set the Toollface Offset in the Transmitter.

Print – Allows the Operator to Print the stored data from the Toolface Offset

Procedure.

Store – Stores Toolface Offset Procedure Data to a file.

Exit – Exits the TFO Procedure

Number of Updates – The number of times the TFO Procedure has queried the

Transmitter and received a response.

FOR EXAMPLE:

The Transmitter has the following values:



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Gravity Tool Face Angle = 239.1 Degrees Instrumentation Mounting Offset = 325.05 Degrees The Receiver has the following value: Drill Assembly Offset = 23 Degrees The Total Toolface Offset is a sum of the IMO and DAO. Total Toolface Offset is 348.05 Degrees

Zeroing the Gravity Toolface Angle

This option will set the gTFA in the Transmitter to 0 degrees, by adding the

correction in reference to the position of the Transmitter. To Zero the Gravity Toolface Angle press the Zero gTFA button. Be patient and

allow between 5-10 updates before the Gravity Toolface Angle changes to 0

degrees. The Transmitter has the following values:

Gravity Tool Face Angle = 0 Degrees

Instrumentation Mounting Offset = 204.15

The IMO is calculated as follows: (gTFA + IMO) MOD 360 (239.1 + 325.05) MOD 360

564.15 MOD 360

MOD is short for MODULUS

MODULUS is mathematical operation which calculates the remainder from the

division of one number by another.

Thus, 564.15 MOD 360 = the Remainder when 564.15 / 360 = 204.15

The Total Toolface Offset is a sum of the IMO and DAO .

Total Toolface Offset is 227.15

To store the current values of the Gravity Toolface Angle,



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Instrumentation Mounting Offset (IMO), Drill Assembly Offset and Total Toolface

Offset to a file, press the Store button.

To print this file, press the Print button to open the file in notepad and print the

file from here.

10.8 WITS Setup The WITS Setup Screen allows the Operator to change the WITS tag

value associated with a WITS input or output variable as it relates to Drill Well.

To access the WITS Setup screen press the WITS Setup button on the Tools

Screen.

The Operator can choose to change the WITS tag value for values that

Drill Well is sending out the COM Port or for values that Drill Well is reading in

from the COM Port.

For values that are being received or “WITSed IN”, the Operator can

change what WITS tag the variable will be recognized as. Once all changes are

made Press the APPLY button.

For values that are being sent or “WITSed OUT”, the Operator can

change what WITS tag the variable will be sent as, or enable or disable whether

the variable will be sent at all by checking or unchecking the WITS checkbox for

the variable.

ABBREVIATIONS

A ABat2thr Auto Bat2 Latching Threshold



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AqT1 Acquistion Time for ModN = 1




AvAk Average Pulse Amplitude Coefficient

AvCn Number of WORDS averaged for Average Confidence Factor

AvQn Number of WORDS averaged for Average Quality Factor

B BcCR Receiver Broadcast Control Register

BcPSDD P/S Diagnostic Data

BcRxPD Receiver Diagnostic Data

BcRxSB Receiver Status Block

BcRxSM ASCII Receiver Status String

BcRxWD Receiver Waveform Data Block

BcSuSD Survey Sequence Data Block

BcSuSq Survey Sequence Number

BcSuWd Survey Decode Word Block

BcSynD Receiver Synch Data Block

BcTLSD T/L Sequence Data Block

BcTLSq T/L Sequence Number

BcTLWd T/L Decode Word Block

BcUFR MPRx_Update Flag Register

BEvT Battery Voltage Averaging & Evaluation Time

BR Serial Baud Rate Port

BR0 Serial Baud Rate Port 0



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BR1 Serial Baud Rate Port 1

BSBcI Battery Status Broadcast Interval

BSfmt Battery Status Format String

BThr Battery Threshold

C CmTF Correct for Magnetic TFA Declination

CPQFk Coefficient

CrLf Carriage Return Line Feed

CTO CTO

D DFmt Directional Automatic Data Formatting String

DiAA Directional Automatic Data Acquisition Switch

DiAF Directional Automatic Data Formatting Switch

DipT Dip Angle Tolerance

DiSmpR Sensor Sampling Rate

DiSO Directional Sensor to Bit Offset

DLAuExDT Downlink Auto Extend Delay Times

DLSv Save Commands

DLTP Command Time Period

DLTy Command Set

DminAvgT Minimum Sensor Averaging Time

DSinv Inverted Sensor Mount

DSminOff Minimum Sensor Power-Off Time

DSPC Directional Sensor Power Control Switch

DUpT Directional Data Update Time



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DwnL Downlinking Commands

E EvIM Evaluation Mode

F FDM Flow Detection Method

FEvT Flow Evaluation Time

FOffThr Flow Off Threshold

FOnThr Flow On Threshold

FSBcI Flow Status Broadcast Interval

FSfmt Flow Status Format String

G GaAA Gamma Automatic Data Acquisition Switch

GaAF Gamma Automatic Data Formatting Switch

GaSO Gamma Sensor to Bit Offset

GFmt Gamma Automatic Data Formatting String

GMax Maximum Gamma Sampling Time

GMin Minimum Gamma Sampling Time

GrvT Gravity Magnitude Tolerance

Gsf Gamma Scale Factor

GSPC Gamma Sensor Power Control Enable Switch

GUpT Gamma Data Update Time

GV0xr Generic Variable Cross Reference 0






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GWuT Gamma Sensor Warmup Time

H HdCk Type of Header Check Bits

HiPL High Pulse Amplitude Limit

HiTWthr High Temperature Warning Flag

HiTWthr Receiver High Temperature Warning

HostID Host Node Designation

I IBSO Inclination at bit Sensor to Bit Offset

IMO Instrumentation Mounting Offset

IncT Inclination Switch Threshold

InvF Inverted Flow Switch

L LnkA Link Address

LnkL Link Line

Loc Site Location Label

LoPL Low Pulse Amplitude Limit

LoVWThr Low Battery Threshold Warning Voltage

M MagT Magnetic Field Tolerance



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MDec Magnetic Declination

MFoGpwr2 Coefficient

ModN Mode Number

mTTy Magnetic Toolface Type Calculation

mwdCMode MWD Compatibility Mode

MxyT Delta Magnetic Field in the X and Y direction

N NDip Nominal Dip Angle

NGrv Nominal Gravity Magnitude

NMag Nominal Magnetic Field

NSyP Number of Synch Pulses

P PALf Pulse Amplitude Limits Factor

PALk Pulse Amplitude Limits Coefficient

PALmode Pulse Amplitude Limits Mode

PALratio Pulse Amplitude Limits Ratio

PEvT Pumps On/Off Evaluation Time

PmpT Pumps On Threshold

PSFtol Power Supply Fault Level Tolerance

PSWtol Power Supply Warning Level Tolerance

PTfs Pressure Transducer Rating

PTG Pressure Transducer Gain

PTO Pressure Transducer Offset

PTTy Pressure Transducer Current Range



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PTyp Pulser Type

PW1 Pulse Width for ModN = 1




PWin Pulse Driver Signal Widths

R RcdFlwEv Record Flow

ReSO Resistivity Sensor to Bit Offset

RxDT Receiver Delay Time

RxFBwf Receiver Filter Bandwidth

RxSBcI Receiver Status Broadcast Interval

S SCBCC1 Serial Communciations Blcok Check Type

SCHdrs0 Serial Communciations Headers 0 On-Off

SCHdrs1 Serial Communciations Headers 1 On-Off

SHSz Survey Header Size

SSN1 Survey Sequence Number for ModN =1




SSq1 Survey Sequence 1






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StAvgT Steering Mode Averaging Time

STk1 Phase Correction

STk2 Tx & Rx Clock Difference

StSR Directional Steering (T/L) Data Sampling Rate

StST Directional Steering (T/L) Data Sampling Time

SuAM Directional Survey Acquisition Mode

SuAvgT Survey Mode Sensor Averaging Time

SuDT Directional Survey Delay Time

SuSR Directional Survey Data Sampling Rate

SuST Directional Survey Data Sampling Time

SyTy Synch WORD format

SyWF Synch Window Factor

T TFOC Toolface Offset Correction

THSz Toolface/Logging Header Size

TLT1 T/L Tx Time Limit for ModN = 1




TmpT High Temperature Threshold

tmSBcI Telemetry Status Broadcast Interval

tmSBcM Transmitter Status Control Register

tmSfmt Transmitter Status Control Register

TmTF True Magnetic Toolface Angle

TSN1 T/L Sequence Number For ModN = 1



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TSq1 Toolface/Logging Sequence 1




TxDT Transmitter Delay Time

Glossary: (last pages) Short Definitions: ACCELEROMETER A device for measuring the acceleration of a body in a

particular direction. Accelerometers are used in downhole tools to sense changes

of direction of the tool with respect to the Earth's gravity factor.

ACTUATOR A part of the MWD transmitter, it is the hydraulic component that

creates the pressure pulse.

AVERAGE ANGLE METHOD A mathematical model, approximating a wellbore,

based upon a simple average of adjacent station inclination angles and adjacent

station azimuth angles.

AZIMUTH Azimuth is the angle between the horizontal component of the

borehole direction at a particular point and the direction of north. The angle

should always be expressed in the 0-360 degree system. The angle may refer to

either magnetic, true (geographic), or grid north; whichever referred to must

always be clearly indicated (also known as bearing).



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BOTTOM HOLE ASSEMBLY That portion of the drill string below the drill pipe;

including some but not necessarily all of the following:

bit, stabilizers, drill collars, reamers, drilling jars, heavy weight pipe, and assorted

subs.

CASING Steel pipe placed in the well as drilling progresses to prevent the wall of

the hole from caving in during drilling and to provide a means of extracting

petroleum if the well is productive.

CLOSURE ANGLE The direction of the closure distance.

CLOSURE DISTANCE Horizontal displacement from the surface location.

COURSE DEVIATION Displacement from vertical between two survey points.

COURSE LENGTH The difference in measured depth or the along hole depth

from one station to another.

DECLINATION The angular difference in azimuth readings of magnetic north

and true north. The magnetic declination varies with time and place. The

magnetic declination is by definition positive when magnetic north lies east of

true north, and negative when magnetic north lies west of true north.

DEPARTURE The east or west coordinate that describes the plan view location

of a target.

DIFFERENTIAL PRESSURE The difference between off-bottom pressure and

stall pressure of a mud motor.

DIRECTIONAL DRILLING Intentional deviation of a well bore from the vertical.

DIRECTIONAL SURVEY A logging method that records hole drift, or deviation

from the vertical, and direction of the drift (e.g. single shot, multishot, MWD).

DISPLACEMENT The horizontal displacement from surface distance.



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DOGLEG The total angular change between the tangent to the bore hole at one

point and the tangent to the bore hole at another point. A dogleg may result from

changes of inclination and/or azimuth.

DOGLEG SEVERITY (DLS) The rate of angular change of the bore hole

direction between two consecutive bore hole survey stations, expressed in

degrees per 100 feet (o/100 feet).

DRILL COLLAR Heavy, thick walled tube used between the drill pipe and the bit

to weight the bit in order to improve its performance.

GALLING Abrasion to unprotected metal surfaces. When drill collar threads are

galled, they must be re-cut, or damage to a mating connection will result.

GO DEVIL To allow the survey instrument to free fall through the drilling fluid.

Recovery is by an overshot or pulling the string.

GRID CORRECTION The angular correction converting azimuth readings of true

north and grid north. The grid correction is by definition positive when true north

lies east of grid north, and negative when true north lies west of grid north.

GRID NORTH (GN) Within a rectangular grid system, the direction which is

parallel to the central meridian of longitude through the grid origin.

GYROSCOPE Comprises a spinning mass mounted within a gimbal system. In

absence of friction and unbalance the spinning mass would remain stationary in

inertial space and ideally act as a portable reference direction.

GYRO SURVEY INSTRUMENT A survey instrument which uses an oriented

gyroscope to determine the azimuth angle at the survey point.

HIGH SIDE The 12:00 position of the well bore or the top of the hole.

HIGH SIDE TOOL FACE Direction the bit is facing as referenced to the 12:00

position of the well bore. Also known as gravity tool face.



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HORIZONTAL DISPLACEMENT The horizontal distance from a vertical line

through the well head to a selected point along the well bore.

INCLINATION The angle as measured between the well bore and vertical.

ISOGONIC CHART A chart showing lines of equal magnetic declination super-

imposed on a geographical map.

JETTING Through some soft formations, more than adequate deviation and

penetration rates can be achieved by using one large bit nozzle and the rest

small or blank. The large nozzle is oriented in the desired direction, the rotary

locked, and the pumps turned on. The washing action creates a pocket into

which the bit is spudded. Alternate periods of jetting and drilling ahead, using the

same BHA, establish the desired inclination and azimuth angles.

KICK-OFF POINT Point at which deliberate deviation is begun in a well bore.

LATITUDE The north or south coordinate that describes the plan view location of

a target.

MAGNETIC INTERFERENCE The influence of magnetic fields other than the

nominal earth's magnetic field on magnetic sensing instruments.

MAGNETIC NORTH (MN) The direction of the horizontal component of the

Earth's magnetic field at a particular point on the Earth's surface. A compass will

align itself in the direction of the field with the positive pole of the compass

pointing to the magnetic north.

MAGNETIC METHOD OF ORIENTATION The magnetic method of orientation is

a method of orienting tools, after they have been run into the hole in any random

direction, by simply rotating the drill pipe in a direction determined from a single

shot record. In this method, a special survey instrument containing a magnetic

pointer, in addition to the compass and angle unit, is positioned opposite three

pairs of magnetic inserts in the non-magnetic drill collar. The angular relationship



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of the three magnet pairs to the BHA is determined when the BHA is made up.

From the pointer's direction, which is recorded on the survey picture, the azimuth

angle of the BHA can be determined.

MAGNETIC TOOL FACE The direction the bit if facing as referenced to

magnetic north.

MAGNETOMETER An instrument which measures the strength of a magnetic

field in a particular direction.

MEASURED DEPTH The entire course length of the well that has been drilled as

measured from the rotary kelly bushing.

MINIMUM CURVATURE (CIRCULAR ARC) The mathematical method

recommended to calculate horizontal and vertical coordinate out of the measured

values of along hole depth (ADH), inclination (I), and azimuth (A).

MUD MOTOR A hydromechanical device utilizing drilling fluids to rotate the bit

without rotating the drill string.

MULTISHOT SURVEY DEVICE A survey instrument capable of obtaining

several surveys either on a wireline or while pulling out of the hole.

(See SINGLE-SHOT SURVEY DEVICE).

NON-MAGNETIC DRILL COLLAR A drill collar made of a type of steel which

has a negligible influence upon a compass.

OVERSHOT Grapple device used to retrieve a survey instrument which has

been go-deviled into the hole.

POPPET VALVE A conical shaped device which extends on the end of the

actuator. It extends or retracts, restricting the flow of mud, thus creating the

pressure pulse.

PRESSURE PULSE The MWD downhole assembly generates pressure pulses

in the drilling mud by retracting and extending the poppet valve. The type of



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pulse (zero or one) is determined by the time the plunger is allowed to remain in

the extended position.

PROPOSED DIRECTION The direction referenced to magnetic north that a well

bore must follow to reach its target.

PROTRACTOR Angle measured device designed to fit against curve of drill pipe

body. Used to measure adjustments of tool face direction.

REACTIVE TORQUE When a mud motor is running, two basic sets of forces are

involved. One set causes the shaft to turn. The other acts in the opposite

direction and tries to turn the body of the mud motor. These latter forces are the

reactive torque. Since reactive torque has an effect on MWD high side readings,

an effort should be made to survey while the bit is off-bottom, thus avoiding the

effects of reactive torque.

ROTOR The rotating component of a turbine stage, consisting of hub and a vane

which transmit torque to the main drive shaft.

SCRIBE LINE Reference line cut along the body of the sub or tool.

SINGLE SHOT SURVEY DEVICE A survey device which utilizes either a

magnetic compass on a gyroscope to measure the inclination and direction of the

well bore. The device takes a photograph of the compass or gyro after being

positioned in the well bore. The photograph is developed once the tool is

removed and the survey is read.

STABILIZER A short sub with blades attached which is of outside diameter equal

to, or slightly smaller than, the diameter of the hole being drilled. The blade

arrangement allows fluid returns while supporting the drill string against the walls

of the hole.

STATOR The stationary fluid guide of a turbine, positioned before its companion

rotor.



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SURVEY INSTRUMENT Electromechanical or mechanical device to measure

either or both azimuth angle and inclination and to record these values

photographically or mechanically.

TONGS The large wrenches used for turning when making up or breaking out

drill pipe, casing, tubing, or other pipe. Power tongs are pneumatically or

hydraulically operated tools that serve to spin the pipe up tight, and to apply the

final makeup torque.

TOOL FACE The direction in which the motor or large jet is oriented. This

measurement can be made based on magnetic north or the high side of the hole.

TOOL JOINT A heavy coupling element for drill pipe made of special alloy steel.

Tool joints have coarse, tapered threads and seating shoulders designed to

sustain the weight of the drill stream, withstand the strain of frequent coupling

and uncoupling, and provide a leak proof seal.

TOTAL VERTICAL DEPTH True vertical depth to last drilled point in hole which

is the sum of all vertical depths. Used interchangeably with true vertical depth.

TRANSDUCER The transducer utilized by MWD is connected to the standpipe

and changes the pressure pulses generated by the downhole assembly into

electrical signals which can be processed by the surface electronics.

TRANSMITTER Part of the MWD downhole tool, the transmitter is the power

generation unit, both electrical and hydraulic. It also takes the electrical output of

the CDS and converts it to a pressure pulse.

TRUE VERTICAL DEPTH (TVD) The actual vertical depth as measured from the

rotary Kelly bushing.

TURBINE An axial mud flow device which converts linear hydraulic mud flow to

rotary mechanical power. This powers the transmitter and electronics in the

MWD tool.



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TURBO DRILL Downhole mud motor based on the turbine principal.

UPHOLE MUD FILTER The uphole mud filter is placed in the joint of drill pipe

directly below the kelly and is designed to capture any sizeable debris which

could block or damage the downhole turbine or the poppet valve aperture.

VERTICAL SECTION Horizontal distance drilled towards the target, measured in

the plane of the proposed direction.

WIRELINE STEERING TOOL Steering tools used close to the bit which measure

and transmit survey data to the surface via a wireline.

WHIPSTOCK A wedge-shaped steel tool having a tapered concave groove down

one side to guide the whipstock bit into the wall of the hole.



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