Complete Logging While Drilling System (ComLWD ...Insert mode, different sizes of instruments, electronic circuit are interchangeable, saving the cost Two kinds of pulser, have more

Complete Logging While Drilling System (ComLWD)

Integrated Logging While Drilling (InteLWD)

Hostile Logging While Drilling System (HostileLWD)

Lithology Logging While Drilling System (LithoLWD)

Geology Logging While Drilling System (GeoLWD)

Survey Direction Tools

Common Coiled Tubing Drilling (ComCTD)

GeoSteering

www.RenheSun.comwww.geovista.cn

Bottom Hole Assembly (BHA)


ComLWD

PressureAzimuthal Gamma RayResistivityDirectional Sensor Vibration

InteLWD

AWD

MRI

BCP-O

CCN

RAD

LWD-O

RSU

-O

-OOOOOOOOOOOOOOOO

MWD

AWD

CCN /GCN + CWD

RAD

EPR

Near-BitAGR

PCD

Downhole Motor

GC

N

DoDDDDDDDDDDDDDDDDDDDDDDDDDDD

MWD/LWD/RSS/GSD BHA Configuration


InteLWDNuclear Magnetic Resonance Imaging While Drilling Tool (MRI)Acoustic While Drilling (AWD)Caliper Corrected Neutron Porosity (CCN)Rotary Azimuthal Density (RAD)Bi-directional Communication & Power System While Drilling (BCP-O)Logging While Drilling-O (LWD-O)Rotary Steerable Unit (RSU)

ComLWDWireless Measurement While Drilling (MWD)Caliper Corrected Neutron Porosity (CCN)/Generator Caliper Corrected Neutron Porosity (GCN) + Ultrasonic Caliper Measurement While Drilling (CWD)Rotary Azimuthal Density (RAD)Acoustic While Drilling (AWD)Electromagnetic Propagation Resistivity (EPR)Pressure & Caliper Measurement While Drilling (PCD)Downhole MotorNear-Bit Azimuthal Gamma Ray (AGR)

HostileLWDWireless Measurement While Drilling (MWD)Bi-directional Communication & Power Module-Hostile (BCP-H)Logging While Drilling-Hostile (LWD-H)

GeoLWDAzimuthal Gamma Ray (AGR)Pressure & Caliper Measurement While Drilling (PCD)Ultrasonic Caliper Measurement While Drilling (CWD)Gyroscope Wireless Measurement While Drilling (GyroMWD)Near-Bit Inclination and Gamma Module (NGR)

LithoLWDCaliper Corrected Neutron Porosity (CCN)Rotary Azimuthal Density (RAD)Generator Caliper Corrected Neutron Porosity (GCN) + Ultrasonic Caliper Measurement While Drilling (CWD)Nuclear Magnetic Resonance Imaging While Drilling Tool (MRI)Acoustic While Drilling (AWD)Formation Tester While Drilling (FTD)

Common Coiled Tubing Drilling (ComCTD)


PC

TM

CD

PC

S

MO

SFV

SE

OT

2-3/

8” M

otor

DP

T

VD

S-2

IGR

GO

T-D

EP

R-2

UQ

C /

LQC

2-7/

8” M

otor

MO

SFV

SE

OT

IGR

GO

T-D

VD

S-3

EP

R-3

MC

D

PC

S

PC

S

PC

TU

QC

/ LQ

C

DP

T

2-7/

8” M

otor

MO

SFV

SIG

RM

WD

-3E

PR

-3M

CD

MVA

UQ

C /

LQC

Quick Connnect Sub (UQC and LQC)

Pressure Control Sub (PCS) (Optional)

Mechnical Circulating and Disconnect Sub (MCD)

Mechnical Orienting Sub (MOS)

Power and Communication Tool (PCT)

Drilling Performance Tool (DPT) (Optional)

Vibration& Shock Digital Attitude Sensor (VDS-2)

Electromagnetic Propagation Resistivity Tool (EPR-2)

Inclination and Gamma Ray (IGR)

Gyroscope Orientation Tool-Drilling (GOT-D) (Optional)

Electrical Orienting Tool (EOT)

Float Value Sub (FVS)

2-3/8” / 2-7/8” Motor

2-1/2 in. Wireline ComCTD3-1/8 in. Wireline ComCTDQuick Connnect Sub (UQC and LQC)




Power and Communication Tool (PCT)


Vibration& Shock Digital Attitude Sensor (VDS-3)



Gyroscope Orientation Tool-Drilling (GOT-D) (Optional)

Electrical Orienting Tool (EOT)


2-7/8” / 3-1/8” Motor

3-1/8 in. Mud Pluse ComCTDQuick Connnect Sub (UQC and LQC)




Main Valve Assembly (MVA)

Wireless Measurement While Drilling-3 (MWD-3)





2-7/8” / 3-1/8” Motor

DP

T

ComLWD

LWD has the advantage of measuring properties of a formation before drilling fluids invade deeply. Further, many wellbores prove to be difficult or even impossible to measure with conventional wireline tools, especially highly deviated wells. In these situations, the LWD measurement ensures that some measurement of the subsurface is captured in the event that wireline operations are not possible. Timely LWD data can also be used to guide well placement so that the wellbore remains within the zone of interest or in the most productive portion of a reservoir, such as in highly variable shale reservoirs.

Introduction

Specifications

ApplicationsUse generator model, in one run can drill long time without replacement battery, and security

Insert mode, different sizes of instruments, electronic circuit are interchangeable, saving the cost

Two kinds of pulser, have more choice to save cost

Have 3.375 in slim-hole instruments, can meet the requirements of slim-hole

Can be connected to neutron density and acoustic instruments to logging more project

Have Gamma inclination, it is easy to do direction drilling job


Tool OD (Nominal)Well OD.

Connections

Dogleg Severity

Mud Flow Range

��

3-3/4" to 5-7/8"(96-150 mm)

3" CPD box up and 3" CDP

pin downMax Rotating

20°/30 mMax Sliding

45°/30 mBattery

80-160 gpm

��

5-7/8" to 6-3/4"(150-172 mm)

3-1/2" IF box upand 3-1/2" I.F.


12°/30 m Max Sliding

30°/30 m

100-350 gpm

��

8-1/2" to 9-7/8" (216-251 mm)

4-1/2" I.F. box up and 4-1/2" I.F.



16°/30 m

300-800 gpm

��

9-7/8" to 12-1/4" (251 mm-311 mm)

6-5/8" Reg. box up and 6-5/8" Reg.



8°/30 m

300-1100 gpm

��

12-1/4" to 26" (311 mm-660 mm)7-5/8" Reg. box up

and 7-5/8" Reg. pin down

Max Rotating 8°/30 m

Max Sliding 8°/30 m

300-1100 gpm

General Tool Specifications

General Tool SpecificationsMaximum TemperatureMaximum PressureSand ContentLost Circulation MaterialPulsation DampenerData AcquisitionTelemetry TypeMud PumpsDownhole RPM

Pulser Pressure Drop

DP at BitMud Filter (Uphole)Full Survey Transmission

300°F(150 °C)20000 psi （138 MPa）maximum volume recommended<1%Fine to medium nut plugRecommended set to 1/3 stand pipe pressureMud pulse telemetry to surface and downhole memoryPositive pulseEither duplex or triplex± 80% maximum deviation from the mean Operating rpm (e.g., 100 rpm: Operation Range = 20-180 rpm)Pressure drop dependent upon mud weight, flow rate, MWD tool valve gap, and data transmission rate.No restrictionsMost sizes supplied55 seconds from Pumps-On


Introduction


InteLWD is the new generation logging while drilling system, this system integrates the measurement of orientation, gamma, resistivity, borehole & annular pressure and drilling tool vibration, this system realize combined with CCN (Caliper Corrected Neutron Porosity), RAD (Rotary Azimuthal Density), MRI (Nuclear Magnetic Resonance Imaging While Drilling), AWD (Acoustic While Drilling), PCD (Pressure & Caliper Measurement While Drilling) and FTD (Formation Tester While Drilling). Improve the reliability of tools, reduced the connection point, and make the sensors distance from BHA to Bit optimized. This system also can realize the two-way communication with the surface system at the same time, can be combined with the rotation direction (RSU) realize geosteering.

SpecificationsHole size 5-7/8”to 6-3/4” 8-1/2”to 10-5/8” 10-5/8”to 12-1/4”OD 4-3/4” 6-3/4” 9-1/2”Connection Up NC38 box NC50 box 7-5/8" Reg box Down 3-1/2" Reg box 4-1/2" Reg box 7-5/8" Reg box 6-5/8" Reg. boxBuild rate 0-10°/100 ft 0-6.5°/100 ft 0-6.5°/100 ft Max DLSD 10°/100ft (Rotation) 13°/100ft (Rotation) 6.5°/100ft (Rotation) 30°/100ft (NO rotation) 20°/100ft (NO rotation) 9°/100ft (Rotation) Flow Range 125-220 GPM 211-470 GPM 395-660 GPMPower Drilling fluid driven TurbineMax RPM 400rpmMax Temperature 302 °F (150 ℃)Max Pressure 20000psi(138MPa)� �� Max LCM 40ppb=114kg/m3Vibration 5g RMS


Electronic Magnetic Resistivity

2 MHz Resistivity

Phase Difference Range: 0.1 - 3,000 ohm-m

Accuracy: ±1% (0.1-50 ohm-m)

±0.5 mmho/m (>50 ohm-m)

Attenuation Range: 0.1 - 500 ohm-m

Accuracy: ±2% (0.1-25 ohm-m)

±1 mmho/m (>25 ohm-m)

Vertical Resolution 8 in.(20 cm)

for 90% response in conductive beds

400 kHz Resistivity

Phase Difference Range: 0.1 - 1,000 ohm-m

Accuracy: ±1% (0.1 - 25 ohm-m)

±1 mmho/m (>25 ohm-m)

Attenuation Range: 0.1 - 200 ohm-m

Accuracy: ±5% (0.1 - 10 ohm-m)

±5.0 mmho/m (>10 ohm-m)

Vertical Resolution 12 in. (30 cm)

for 90% response in conductive beds

Pressure

Range 0 - 25000 psi

Resolution 5 psi

Accuracy ±0.25% of full scale

GR

Tool Type Scintillation

Range 0-500 API

Accuracy ± 2.5 API/100 API

Vertical Resolution 6 in. (153 mm)

Vibration

Probe Type Axial vibration z-Accelerometer

Lateral vibration x-y Accelerometer

Accleration Range 0 to 15 g

Frequency Range 0 to 82 Hz

Rotating & stick slip

Probe Type Two Axis Magnetometer

Range 0 to ±1000 rpm

Accuracy ±1%

Specifications

Azimuth Module


Sensor Type

MTF/GTF

Tri-axial Accelerometer

Tri-axial Flux Gate

Operator selectable (default:3° )

Measurement

Inclination

Azimuth

Toolface

Magnetic TF

Gravity TF

Total Magnetic Field

Dip Angle

Range

0°-180°

0°-360°

0°-360°

0°-360°

0-100000 nT

-90°~90°

Resolution

0.09°

0.35°

1.4°

1.4°

35

0.04°

Accuracy

±0.1°

±1°

±1.5°

±1.5°

±1500

±0.3°

Hostile Logging While Drilling System (HostileLWD)


IntroductionApplicationsUse generator model, in one run can drill long time without replacement battery, and security

Rotary pulser, adapt to all kinds of Mud, with high LCM also can work

Have Azimuth Gamma, it is easy to do direction drilling job

If the well depth more than 5000 meters, or need use high LCM while drilling to control the mud loss, for this hostile situation we have special tools HostileLWD, can use in max temperature of 175℃ and max pressure 25000 psi, rotary pulser can adapt to bad mud environment.

SpecificationsGeneral Tool Specifications:Tool O.D. (Nominal)Hole Diameter

Connections

Dogleg Severity

Mud Flow Range

��5-3/4" to 6-3/4"(146 - 172 mm)3-1/2" IF box up and 3-1/2" I.F. pin downMax Rotating 10°/30 m Max Sliding 30°/30 m125-220 gpm

��8-3/8" to 10-5/8" (212 - 270 mm)4-1/2" I.F. box up and 4-1/2" I.F. pin downMax Rotating 13°/30 m Max Sliding 20°/30 m211-470 gpm

Operating Specifications:Maximum TemperatureMaximum PressureSand ContentLost Circulation MaterialPulsation DampenerData AcquisitionTelemetry TypeMud PumpsDownhole RPM

Pulser Pressure Drop

DP at BitMud Filter (Uphole)Full Survey Transmission:

350°F(175 °C)25000 psi （172.4 MPa）maximum volume recommended<1%Fine to medium nut plugRecommended set to 1/3 stand pipe pressureMud pulse telemetry to surface and downhole memoryPositive pulseEither duplex or triplex± 80% maximum deviation from the mean Operating rpm (e.g., 100 rpm: Operation Range = 20-180 rpm)Pressure drop dependent upon mud weight, flow rate, MWD tool valve gap, and data transmission rate.No restrictionsMost sizes supplied55 seconds from Pumps-On

The LithoLWD service provides Azimuthal Sectored Density Images, as well as Photoelectric and Caliper measurements while drilling. Also can provides lithology-independent porosity, pore-sized istribution, continuous permeability and direct hydrocarbon detection, real-time compressional and shear wave travel-time measurements in slow and fast formations, real-time pressure measurements.Each data point is tied to a corresponding Caliper measurement to ensure accurate density evaluation with minimal stand-off effect. Caliper measurements are used also for neutron porosity borehole environmental compensation and give an accurate borehole profile for borehole volumes or wellbore stability applications.

Caliper Corrected Neutron Porosity (CCN)Rotary Azimuthal Density (RAD)Generator Caliper Corrected Neutron Porosity (GCN)Nuclear Magnetic Resonance Imaging While Drilling Tool (MRI)Acoustic While Drilling (AWD)Formation Tester While Drilling (FTD)

LithoLWD Service Benefits to clients are listed as:

Lithology Logging While Drilling System (LithoLWD)

Introduction


Applications

A selection of Tool sizes for to accommodate a wide variety of bit size

Fully Compensated High Quality Density Measurement

High Resolution Real-Time Formation Density Image

Accurate Borehole Caliper Measurement

Fully Characterised Compensated Neutron Porosity Measurement

Accurate Photoelectric Cross Section Measurement

Real-Time Borehole pressure, it is easy to control the well

Seamless BHA’s designed for Rotary Steerable Systems & advanced Formation Evaluation Services

The GeoLWD service provides Azimuthal and Near-Bit Gamma Ray, downhole pressure and caliper, as well as Neutron Porosity.

Azimuthal Gamma Ray (AGR)Pressure & Caliper Measurement While Drilling (PCD)Ultrasonic Caliper Measurement While Drilling (CWD)Gyroscope Wireless Measurement While Drilling (GyroMWD)Near-Bit Inclination and Gamma Module (NGR)

GeoLWD Service Benefits to clients are listed as:

Geology Logging While Drilling System (GeoLWD)

IntroductionApplications

Azimuthal and Near-Bit Gamma Ray, it is easy to do direct drilling and accurately find the target formation

Accurate Borehole Caliper Measurement

Real-Time Borehole pressure, it is easy to control the well

Fully Characterised Compensated Neutron Porosity Measurement

Seamless BHA’s designed for Rotary Steerable Systems & advanced Formation Evaluation Services

Features

Solenoid Pulser：---Easy for maintenance---Anti-corrosion---Wide range flowrate

Rotary Pulser

ValveAssembly

MechanicalAssembly Motion Control

Module

Features

Rotary Pulser：---Increased reliability pulser.---An ultra-reliable, high-efficiency DC brushless motor and controller.---More durable shafts and seals, and better serviceability.

Wireless Measurement While Drilling (MWD)


ApplicationsSteering drilling systems for re-entry and horizontal wells

Directional control

Relief well drilling

Precision geosteering in high angle wells

IntroductionMWD provides directional-drilling measurements. It helps for decision support for the smooth operation of the drilling by collected wellbore data in real-time like as deviation, azimuth, BHA tool face.

Bypass Conduit Restrictor Valve Body Control Valve

Valve Spring SolenoidPilot Valve Flow Path Main Valve Flow Path

Solenoid Pulser

Wireless Measurement While Drilling (MWD)


Tool Size: 3.375 in. (Battery)/4.75 in./6.75 in./8.25 in./9.5 in. (Generator)Maximum Pressure: 20000 psi (137.9 MPa) / 25000 psi (172 MPa) (option)Maximum Temperature: 300oF (150oC)

1 Assumes typical magnetic field values at 30° latitude.2 Accuracy applies to inclinations greater than 5.0°.

SpecificationsApplicationsSteering drilling systems for re-entry and horizontal wells

Directional control

Relief well drilling

Precision geosteering in high angle wells

Measurement Range Resolution Accuracy

Inclination 0° - 180° 0.1° ± 0.2°

Azimuth1, 2 0° - 360° 0.35° ± 1.0°

Toolface

Magnetic1 0° - 360° 1.4° ± 1.5°

Gravity2 0° - 360° 1.4° ± 1.5°

Temperature 150oC / 175oC 2oC ±3.0oC (option)

Dip Angle1 -90° - 90° 0.044° ± 0.3°

MTF/GTF Switching Inclination Degrees: Operator Selectable (default set at 5°)

Flow Range(Ipm)

302-605 lpm

606-1,211 Ipm606-833 Ipm

1,136-2,555 Ipm1,136-1,703 Ipm

1,514-3,407 Ipm1,514-2,271 Ipm

2,271-5,100 Ipm2,271-3,407 Ipm

Tool Size

3-3/8 in.

4-3/4 in.

6-3/4 in.

8-1/4 in.

9-1/2 in.

Restrictor ID

40mm

49 mm (standard)47 mm (low Flow)

52 mm (standard)50 mm (low flow)



Flow Range(gpm)

80-160 gpm

160-320 gpm160-220 gpm

300-675 gpm300-450 gpm

400-900 gpm400-600 gpm

600-1,350 gpm600-900 gpm


IntroductionApplicationsProvides formation resistivities

Provide realtime formation evaluation services

Provide wellbore placement

Improve geosteering capabilities

Transmits electromagnetic waves into formation and measures the change in physical character of the wave on its return. The change in physical character of wave gives an indication of the Resistivity of the drilled formation.

Electromagnetic Propagation Resistivity (EPR)

Operates at frequency of 2 MHz and 400 KHz Compensated antenna design with dual spacing transmitter pairs

8 quantitative resistivities with separate depths of investigation (3.375 in. provides 4 quantitative resistivities)Works in all mud types

Features

Specifications

Phase Difference

Attenuation

Range

Accuracy

Range

Accuracy

VerticalResolution

8 in. (20 cm) for 90% response in conductive beds

2 MHz Resistivity0.1 to 3,000 ohm-m

±1% (0.1 to 50 ohm-m)±0.5 mmho/m (> 50 ohm-m)

0.1 to 500 ohm-m±2% (0.1 to 50 ohm-m)

±1.0 mmho/m (> 50 ohm-m)

400 kHz Resistivity0.1 to 1,000 ohm-m

±1% (0.1 to 25 ohm-m)±1.0 mmho/m (>25 ohm-m)

0.1 to 200 ohm-m±5% (0.1 to 10 ohm-m)

±5.0 mmho/m (>10 ohm-m)12 in. (30 cm) for 90%

response in conductive beds

Tool O.D.

Length

Hole Sizes

WeightEquivalent Stiffness

O.D. x I.D.

Connections

Dogleg Severity

Temperature

PressureMud Flow

RangeLost

Circulation Material

Pulsation Damper

Data Acquisition

Telemetry Type

3.375 in.

7.4 ft. (2.3 m) 3.75 in. to 5.875 in.

(96-150 mm)

175 lbs. (79 kg)

None

3 in. CDP Box Uphole3 in. CDP

Pin DownholeMax. Rotating (°/100 ft.) 20Max. Sliding (°/100 ft.) 45

4.75 in.

12 ft. (3.7 m)5.875 in. to 6.75 in.

(150-172 mm)

600 lbs. (272 kg)4.597 in. x 2.250 in.

(116.76 mm x 57.15 mm)3-1/2 in. I.F. box up and3-1/2 in. I.F. box down

Max Rotating (°/100 ft) 12Max Sliding (°/100 ft) 30

160 - 320 gpm (606-1,211 lpm)

6.75 in.

12 ft. (3.7 m)8.5 in. to 9.875 in.

(216-251 mm)

1,280 lbs. (581 kg)6.625 in. x 2.81 in.

(168.2 mm x 71.4 mm)

4-1/2 in. I.F. box up and 4-1/2 in. I.F.

box downMax. Rotating

(°/100 ft) 9Max. Sliding (°/100 ft) 16

300-675 gpm(1,126-2,555 lpm)

Fine to medium nut plug

8.25 in.

12 ft. (3.7 m)

12.25 in. (311 mm)

1,595 lbs. (725 kg)8.23 in. x 4.005 in.

(209 mm x 101.7 mm)

6-5/8 in. Reg box up and

6-5/8 in. Reg box down

Max Rotating (°/100 ft) 8.2Max Sliding (°/100 ft) 8.2

400-900 gpm (1,514-3,407 lpm)

300°F (150°C)20,000 psi (137.9 MPa)

Mud pulse telemetry to surface and downhole memory

Positive Pulse

Recommended, 1/3 Standpipe Pressure

80 -160 gpm (302-605 lpm)

Inclination and Gamma Module (IGR)

ApplicationsShale content evaluation

Stratigraphic Correlation

Lithology determination

Bed boundaries estimation

IntroductionThe Gamma instruments measures the natural radioactivity emanating from the formation.

Tool OD 3.375 in./4.75 in./6.75 in./8.25 in.Gamma SpecificationMaximum Temperature: 300°F (150°C)Type ScintillationMeasurement API GRRange 0 - 250 APIAccuracy ±3% API of full scaleVertical resolution 6 in. (153 mm)

Inclination SpecificationMaximum Temperature: 150°C/175°C (option)Sensor Type Z axis accelerometerRange 0 - 180° degreesAccuracy ±1°@INC>30°

Specifications


Azimuthal Gamma Ray (AGR)

ApplicationsGeo confirmation of sedimentary structure

Confirmation of bed boundaries and orientation

IntroductionThe wellbore cross-section is divided into 8 sectors. The GR is allocated in these sectors.Determine the shale content in the sandstone and mudstone

Specifications

Inclination SpecificationMaximum Temperature: 150°C/175°C (option)Sensor Type X-Y axis accelerometer Z axis accelerometerRange 0 - 180° degreesAccuracy ±0.1°

Gamma SpecificationMaximum Temperature 150°C/175°C (option)Type ScintillationMeasurement API GRRange 0 - 500 APIAccuracy ±3% API of full scaleVertical Resolution 6 in. (153 mm)

ApplicationsGeostopping Top of productive reservoirs Top of coring sections Casing point selections High-risk zones

Geosteering Well placement

Near-Bit Inclination and Gamma Module (NGR)


The NGR system can accurately measure inclination and gamma on the near-bit, and provides early formation identification, structure and reservoir characteristics while drilling. The rapid identification of geological targets, formation bed boundaries, and potential trouble zones, enables operators to efficiently reach the most productive zones.

Introduction

SpecificationsGamma SpecificationMaximum Temperature: 300°F (150°C)Type ScintillationMeasurement API GRRange 0 - 250 APIAccuracy ±3% API of full scaleVertical Resolution 6 in. (153 mm)NGR SpecificationMaximum Temperature: 150°C/175°C (option)Sensor Type Z axis accelerometerRange 0 - 180° degreesAccuracy ±1°@INC>30°Hole Diameter 3.375 in. Tool 3-3/4 in. to 5-7/8 in. (95-149 mm) 4.75 in. Tool 5-3/4 in. to 6-3/4 in. (146-172 mm) 6.75 in. Tool 8-3/8 in. to 10-5/8 in. (212-270 mm) 8.25 in. Tool 10-5/8 in. to 12-1/4 in. (251-311 mm)

The CCN and RAD offers measurement of formation density, neutron porosity, borehole caliper, and formation imaging. You can geosteer the well for maximum reservoir exposure. Neutron porosity and bulk density are critical for the quantification of hydrocarbons in the reservoir.

Caliper Corrected Neutron Porosity (CCN)

Introduction


ApplicationsAccurate, real-time quantification of porosity and gas identification for saturation calculations

Reservoir Navigation using high-resolution imaging and gas—oil/water identification in real-time

Wellbore stability analysis using azimuthal caliper and density imaging in real-time

Structural formation dip analysis and updating reservoir models from density imaging

SpecificationsService Formation PorosityTool Type Caliper Corrected NeutronDiameter 8.25 in. With 10.125 in. upset 6.75 in. with 7.50 in. upset 4.75 in. Weight 8.25 in.1325 lbs. (600 kg) 6.75 in. 893 lbs. (405 kg) 4.75 in. 1100 lbs. (498 kg) (CCN and RAD 4)Maximum Temperature 300°F (150°C)Maximum Pressure 20000 psi (137.9 MPa)Maximum Dogleg Severity 8.25 in.: 6.5°/100 ft. Rotating - 12°/100 ft. Sliding 6.75 in.: 9°/100 ft. Rotating - 16°/100 ft. Sliding 4.75 in.: 4 blade - 10°/100 ft. Rotating - 25°/100 ft. Sliding 3 blade - 15°/100 ft. Rotating - 30°/100 ft. SlidingEquivalent Stiffness 8.25 in.: 8.25 in. x 2.813 in. 6.75 in.: 6.79 in. x 2.26 in. 4.75 in.: 4.82 in. x 1.87 in.Detectors Lithium-6 Iodide Crystal with Photomultiplier tube for both Near and Far detectors Porosity Accuracy 0.5 pu below 10 pu；5% of reading for 10-50 puVertical Resolution 8.25 in.: 24 in. (61 cm) 6.75 in.: 24 in. (61 cm) 4.75 in.: 24 in. (61 cm)Statistical Repeatability ± 0.6 pu@20 pu @ 200 ft./hr.Maximum logging speed 180 ft./hr (@2 points/ft.)Depth Of Investigation 10 in. estimated for 8.5 in. 10 pu boreholeRadioactive Source Am 241 - Be Strength: 5 Curies (185 GBq)Measure Point 4.6 ft. (1.4 m) (From downhole tool end)Voltage 30 Vdc Current Draw 160 - 170 milli Amps

The CCN and RAD offers measurement of formation density, neutron porosity, borehole caliper, and formation imaging. You can geosteer the well for maximum reservoir exposure. Neutron porosity and bulk density are critical for the quantification of hydrocarbons in the reservoir.

Rotary Azimuthal Density (RAD)

Introduction


ApplicationsAccurate, real-time quantification of porosity and gas identification for saturation calculations

Reservoir Navigation using high-resolution imaging and gas—oil/water identification in real-time

Wellbore stability analysis using azimuthal caliper and density imaging in real-time

Structural formation dip analysis and updating reservoir models from density imaging

SpecificationsService Formation Bulk Density Service with Hole CaliperTool Type Rotational Azimuthal DensityDiameter 8.25 in .6.75 in. 4.75 in.Weight 1945 lbs. (881 kg)@8.25 in. 1092 lbs. (495 kg)@6.75 in. 1100 lbs. (498 kg)@4.75 in. (CCN and RAD 4)Maximum Temperature 300°F (150°C)Maximum Pressure 20000 psi (137.9 MPa)Maximum Dogleg Severity 8.25 in.: 6.5°/100 ft Rotating - 12°/100 ft. Sliding 6.75 in.: 9°/100 ft. Rotating-16°/100 ft.Sliding 4.75 in.: 4 blade-10°/100 ft. Rotating-25°/100 ft. Sliding 3 blade-15°/100 ft. Rotating-30°/100 ft. SlidingEquivalent Stiffness 8.25 in.: 8.25 in. x 2.813 in. 6.75 in.: 7.01 in. x 1.87 in. 4.75 in.: 4.82 in.x 1.87 in.Detectors NaI Scintillation Crystal with photomultiplier tube for both Long and Short Spaced detectorsDensity SpecificationsRange 1.6-3.1 g/ccAccuracy ±0.015 g/ccStatistical Repeatability ±0.025 g/cc@200 ft/hr (60 m/hr) and 2.5 g/ccVertical Resolution 18 in. (45 cm) (full resolution)Downhole End Measure Point 5.1 ft (1.5 m)Photoelectric Factor SpecificationsRange 1-100 Barnes/electron (B/e)Accuracy ±0.25 B/e from 2-5 B/eStatistical Repeatability ±0.25 B/e@200 ft/hr (60 m/hr)Vertical Resolution 6 in. (150 mm) (full resolution)Downhole End to PeMeasure Point 5.1 ft. (1.5 m)Acoustic Standoff Caliper SpecificationsRange 0-2 in.Accuracy ±0.075” up to 0.5” ±0.125”up to 1.0” ±0. 25”up to 2.0”Maximum Logging Speed 180 ft/hr (@2 points/ft)Radioactive Source Cs137 Strength:2 Curies (74 GBq)Voltage 30 VCurrent Draw 350 mA~390 mA

Acoustic While Drilling (AWD) provides real-time compressional and shear wave travel-time measurements in slow and fast formations.Shear and comressional slowness with computed semblance values are acquired using a stateof-the art acoustic source combined with multiple arrays of receivers.Advanced downhole processing and wavefrom stacking techniques ensure reliable and fully compensated measurements.

Acoustic While Drilling (AWD)

Introduction

6.75 in. SpecificationsNominal O.D. 6.9 in. (175.26 mm)Max. Tool O.D. (inc. wear bands) 7.5 in. (190.5 mm)Fishing Stub Length 55 in. (1,397 mm) (for new collar)Hole Size 8.5 in. (216 mm) to 0.625 in. (270 mm)Length 23.8 ft. (7.254 m)Tool Mass (in air) 2,500 lbm (1,134 kg)Makeup Torque 25,000 ft-lbf (33,895 N.m)Max. Rotary Torque 16,000 ft-lbf (21,693 N.m)Max. Torque (pin yield) 42,700 ft-lbf (57,893 N.m)Max. Dogleg SeverityRotating 8o/100 ft. (8o/30 m)Sliding 16o/100 ft. (16o/30 m)Max. Operating Temperature 300oF (150oC)Max. Operating Pressure 20,000 psi (137.9 MPa)Max. Differential Pressure 5,000 psi (35 MPa)Max. Flow Rate 800 gal US/min (3,028 L/min)Max. Sand Content 3%Max. LCM Size 0.63 in. (16 mm)Equivalent Bending Stiffness 35 ft. (10.67 m) (6.5 in. O.D. and 2.81 in. I.D.)Bending Strength Ratio 2Average Inertia 62 in.Max. Jarring Load 330,000 lbm (149,685 kg)Max. Tensile Load 330,000 lbm (149,685 kg)Max. W.O.B. 100,000 lbm (444,822 N)Max. Shock (Electronics) 250 g for 100,000 cyclesMeasure Point From Tool Bottom 14 ft (4.267 m)


ApplicationsOptimize mud-weight selection

Predict pore pressure independent of temperature and salinity effect

Identify top-of-cement

Understand rock mechanical properties

Measure porosity sourceless

Position bit-on-seismic using synthetics

Identify gas influx or formation gas

Perform many other standard sonic applications

For ComLWD and InteLWD

Acoustic While Drilling (AWD)

MeasurementsCompressional Wave Transit Time Real-time and memoryShear Wave Transit Time (fast formation) Real-time and memory�� Measurement Range All tools 40 - 230 us/ft. dependent on mud typeTransmitter-Receiver Spacing 10 ft. (3.048 m)Acoustic Aperture 2 ft. (0.61 m)Max. Recording RateReal Time And Memory 6 in. 10 sSampling At 180 ft./hMemory Only 6 in. 1 sSampling At 180 ft./hrMemory Capacity 6 days@10 s record rate or 12 days@10 s rate for dual memory toolsPower Supply Battery and turbineCollar Attenuator Efficiency 60 dBDump Time (memory full) 70 minTop and bottom connector NC46


6.75 in. SpecificationsApplicationsOptimize mud-weight selection

Predict pore pressure independent of temperature and salinity effect

Identify top-of-cement

Understand rock mechanical properties

Measure porosity sourceless

Position bit-on-seismic using synthetics

Identify gas influx or formation gas

Perform many other standard sonic applications

For ComLWD and InteLWD

Pressure While Drilling (PWD)

PWD can accurately detect the annular pressure, the borehole pressure and temperature.Used to judge the underground complex situation, such as well leakage, blowout, well inflow and monitoring well, and conductive to the control of well safety.

Introduction

Specifications

ApplicationsConductive to the control of well safety

Optimizing the acquisition period

Minimizing the total time required to accurately measure annular pressure


Tool O.D. 4.75 in. / 120 mm 6.75 in. / 172 mm 8.25in./210mmLength 5 ft.-6.93 in. (1.7 m) 4 ft.-8 in. (1.424 m)Maximum Temperature 150oC/175oC (option)Maximum Pressure 20000 psi (137.9MPa)/25000 psi (172 MPa) (option)Flow range 160-320 gpm 300-675 gpm 400-900 gpmData Acquisition Type Real-time & Downhole RecordData Transmit Type Positive pulsePressure Measurement Range 0 - 25000 psiAccuracy ± 0.25% full scale


Pressure & Caliper Measurement While Drilling (PCD)Ultrasonic Caliper Measurement While Drilling (CWD)

FeaturesAccurate downhole measurement of equivalent circulating density

Swab/surge pressure monitoring while tripping and reaming

Accurate downhole measurement of hydrostatic pressure and effective mud weight

Accurate measurement of caliper

PCD can accurately detect the annular pressure, the caliper, the borehole pressure and temperature. If PCD has no pressure measurement function, it is CWD(Ultrasonic Caliper Measurement While Drilling).It is used to judge the underground complex situation, such as well leakage, blowout, well inflow and monitoring well, and conductive to the control of well safety.

Introduction

SpecificationsMaximum Temperature 300oF（150°C）Maximum Pressure 20,000 psi (137.9 MPa)Tool Diameter 4.75 in. (120mm)Make-up Length 6ft.-2.8in. (1.9 m)Operating Time Real-Time/ No Limited 90-260hrsFlow range 100-300gpmData Acquisition Type Real-time&Downhole RecordData Transmit Type positive pulsePressure Measurement Range 0-25000 psiCaliper Measurement Range 0-2inCaliper Accuracy ±0.075” up to 0.5” ±0.125” up to 1.0” ±0.25” up to 2.0”

The GCN is a logging-while-drilling tool that uses a pulsed neutron generator instead of a chemical source. The instrument only use one drill collar，it uses an open bus structure can be combined with other LWD tools. It is used to monitor formation porosity during drilling to achieve “chemical source free logging”.It consists of pulsed neutron generator, neutron detector, processing circuitIt needs to be combined with PCD (Pressure& Caliper measurement while drilling) for neutron porosity corrected.

Generator Caliper Corrected Neutron Porosity (GCN)

Introduction

SpecificationsMaximum Temperature 300oF（150°C）Maximum Pressure 20,000 psi (137.9 MPa)Tool Diameter 4.75 in. (120mm)Make-up Length 15ft.-8.98in. (4.8 m)Neutron Energy 14 MeV Neutron Yield > 1*108 n/sMeasurement Range 0 to 100 p.u.Measurement Accuracy 0.5 p.u. below 10 p.u.; 5% of measurement otherwiseRepeatability ±0.6 p.u. @ 20 p.u. @ 200ft./hr.


FeaturesSafety, environmental protection, non-radioactive to operator

High pulse neutron energy, high count rate, it can be extended for full spectrum measurement

With open bus structure, it can be combined with other LWD tools

Bi-Directional Communication & Power System include downhole instrument (BCP-O) and downlink devices (BPC，NPG).

The BCP-O (Bi-Directional Communication & Power Module-O) is capable of generating 300 Watt power output, providing 33 Vdc to the InteLWD system, providing circuit breaker protection for upper and lower mounted instruments, detecting downlink data by monitoring turbine speed, transmitting data to the surface via a pulser .It can be installed in any position of the instrument string, which provides a lot of conveniences for the logging.

The BPC (Bypass Controller) sends commands from the surface to downhole instrument by controlling the NPG (Negative Pulse Generator) which controls the mud flow.

Bi-directional Communication & Power System While Drilling

Introduction

Specifications


Applications

Bypass Controller (BPC) Negative Pulse Generator (NPG)

Transmission of downhole data to surface

High density downhole sensor data storage

Transmission of surface commands to downhole

BCP-O MWD-ALT-O MWD-CVA-O MWD-MVA-O

SLEEVEBCP-O

Tool O.D.

Make-up Length

Weight

Flow Range

Max TemperatureMax Pressure

Max Turbine RPM

Output

Max Power output

4.75 in.

14.11 ft. (4.3 m)

771 lbs. (350 kg)

125 - 220 gpm

6.75 in.

10.85 ft. (3.3 m)

1,006 lbs. (455 kg)

211 - 470 gpm

8.25 in.

11.81 ft. (3.6 m)

1,587 lbs. (720 kg)

395 - 900 gpm

300oF (150oC) Upon Request 350oF (175oC)20,000 psi (137.9 MPa)

5000 33 Vdc±1300 Watts

LWD-O combines real-time azimuth , gamma ray , resistivity, annulus pressure and vibration measurement together. This reduces the number of connection joints, improvereliability, and optimize the distance from BHA sensors to drilling bit. InteLWD consists BCP-O, directional sensor, resistivity, pressure sensor, gamma ray, master controller memory.

Logging While Drilling-O (LWD-O)

Introduction

Specifications


ApplicationsMaximized drilling efficiency and wellbore placement with automated rotary drilling

Reduced risk of differential sticking via continuous rotation

Extended horizontal and lateral capabilities for maximum payzone contact—increasing production rates and extending the life of the well

Improved hole quality and hole cleaning to reduce completion risks

Tool O.D.

Make-up Length

Hole Diameter

Dogleg Severity

Max Temperature

Max Pressure

Max Rotation RateMax Lost Circulation

Material

4.75 in.

20.34 ft. (6.2 m)

5-3/4 in. to 6-3/4 in.(146-172 mm)

Wtih Rotation 10°/100 ft.Without Rotation 30°/100 ft.

6.75 in.

17.06 ft. (5.2 m)

8-3/8 in. to 10-5/8 in.

(212-270 mm)

With Rotation 13°/100 ft.Without Rotation 20°/100 ft.

8.25 in

19.0 ft. (5.8 m)

10-5/8 in. to 12-1/4 in.

(251-311 mm)


300oF (150oC) Upon Request 350oF (175oC)20,000 psi (137.9 MPa)

400 rpm

40 ppb=114 kg/m3

Max Temperature 300oF (150oC)

Max Pressure 20,000 psi (137.9 MPa)

Max Rotation Rate 400 rpm Max Lost Circulation Material 40 ppb=114 kg/m3

Sto

p S

ubB

CP

-O

Directional SensorVibration, Stick-Slip

Azimuthal Gamma Ray

Annular Pressure

EPR

Sto

p S

ub

The system based on advanced closed-loop circulation system on the basis of successful application, using the new MWD technology in the design of RSU. This new system opens up a new field of directional well drilling.The system allows you to navigate precisely into the target using superior directional control in the most challenging well profiles. You can add and combine any of our LWD and drilling optimization systems into an integrated bottomhole assembly for your application requirements.

Rotary Steerable Unit (RSU)

Introduction

Specifications


ApplicationsPrecise reservoir navigation

Exact wellbore placement

Early detection of bed boundaries

Geo-confirmation of sedimentary structures

Offers a smooth wellpath and excellent hole quality for faster completions and enhanced production

Identifies hole cleaning problems and fluid influx into the wellbore

Optimizes drilling performance and reliability

Increased Rate Of Penetration (ROP)

Tool O.D.

Make-up Length

Weight

Hole Diameter

Build Rate

Dogleg Severity

Max Temperature

Max Pressure

4.75 in.

14.55 ft. (4.4 m)

1102 lbs. (500 kg)

6 in. to 6-3/4 in.(152-172 mm)

0-10°/100ft (30 m)

Wtih Rotation 10°/100 ft.

Without Rotation 30°/100 ft.

6.75 in.

7.22 ft. (2.2 m)

905 lbs. (410 kg)

8-3/8 in. to 10-5/8 in.(212-270 mm)

0-6.5o/100 ft (30 m)

With Rotation 13°/100 ft.


9.5 in.

7.22 ft. (2.2 m)

1322 lbs. (600 kg)

10-5/8in. to 12-1/4in.(270 mm x 311 mm)

0-6.5o/100 ft (30 m)

With Rotation 6.5°/100 ft.


300oF (150oC)

20,000 psi (137.9 MPa)

By Providing lithology-independent porosity, pore-sized istribution, continuous prmeability and direct hydrocarbon detection, the MRI delivers a step change in real-time producibility assessment for complex reservoirs.While drilling a well with a challenging trajectory to target a complex carbonate reservoir the MRI (The high-quality, real-time magnetic resonance) to evaluate rock and fluid properties and obtain accurate lithology independent porosity and continuous permeability to optimize placement of the wellbore, the advanced petrophysical evaluation improved testing and completion design and calculated reservoir producibility for focus on well.

Nuclear Magnetic Resonance Imaging While Drilling Tool (MRI)

IntroductionApplicationsContinuous,real-time,lithology-independent porosity without chemical sources.

Resistivity-independent pay identification.

Continuous,real-time permeability evaluation.

Thin-bed characterization.

Carbonate facies characterization.

Irreducible water saturation.

Gas-bearing reservoir evaluation.

Heavy oil and tar identification.

Pore-sized istribution, distribution


SpecificationsMaximum Temperature 300oF (150oC)Maximum Pressure 20,000 psi (137.9 MPa)Max. Tool O.D. (single-sleeve stabilizer) 6.9 in. (175 mm)Make-up Length 32.38 ft (9.87 m)Weight 3385.4 lbm. (1535.6 kg)Borehole Size Range 8.25 to 10.375 in. (20.96-26.36 cm)Normal Collar O.D. 6-3/4 in. (171.5 mm) API toleranceThread Connections 4-1/2 in. IFVertical Resolution Static 1.5 in./min-4 in./min (3.81cm/min-10.16 cm/min)Vertical Resolution Dynamic 10 in.@50 ft./h (25.4 cm@15 m/h)----0.25 m/min 20 in.@100 ft./h (50.8 cm@30 m/h)----0.5 m/minMeasurement of Porosity 0-100 puMin mud Resistivity 0.02 ohm.mShell Diameter 15 in.(381 mm)Shell Thickness 0.24 in. (6 mm)Max.Number of Echoes 2000Min.Echo,Spacing 0.6 msT2 Distribution 0.5 to 5,000 msPrecision ＜10 pu/PAPDepth of Investigation 15 in. (356 mm)Antenna Vertical Resolution 5.9 in. (150 mm)Static Field Gradient 58 gaussFreq of Sensitive Volume 245 kHzOperating Position CentralizedHole Deviation Vertical to HorizontalPower Supply turbine alternatorDogleg Sliding 16°/100 ft (16°/30 m) Rotating 8°/100 ft (8°/30 m)Max.System Shock Level 30 min at shock level 5 (50-gn threshold or accumulatd 200000 shocks above 50 gn)Torque 23,500 ft.lbf (31,800 N.m)Max. PH ＜9

Measuring formation pressure accurately while drilling helps put wells in the best place in less time.Using the formation pressure while drilling service reduces the formation pressure uncentainty associated with drilling,minimizes the risk,and reduce cost.

Formation Tester While Drilling (FTD)

Introduction

SpecificationsMaximum Temperature 300oF（150°C）Maximum Pressure 20,000 psi (137.9 MPa)Tool Diameter 6.75 in. (170 mm)Measure type probe pretestPressure Gauges quartz & strainPower supplies Battery, MWD turbine ALTProbe dimensions 2.25"(OD)×0.56"(ID)Pretest Volume 0-25ml fully adjustableDraw down rate 0.1-2ml/sDelta pressure >6000psiSetting piston diameter reach 2in more than tool ODMemory Capacity 80 pretest of 5-min durationBattery Capacity 150 pretestMaximum dogleg severity rotary 8°/100ft； sliding 16°/100ftHydraulic system pressure 2500psi (17.2MPa)


ApplicationsProvides accurate real-time pressure measurements

Permits pressure gradient definition

Contributes data to calibrate pore pressure models

Helps define gradients,idendify contact points,and update reservior models

Bi-directional Communication & Power Module-Hostile (BCP-H)

IntroductionApplicationsTransmission of downhole data to surface

High density downhole sensor data storage

Transmission of surface commands to downhole

Bi-directional Communication & Power Module-Hostile (BCP-H) and downlink devices (BPC, NPG).The BCP-H (Bi-directional Communication & Power Module-Hostile) is capable of generating 300 Watt power output, providing 33 Vdc to the InteLWD system, providing circuit breaker protection for upper and lower mounted instruments, detecting downlink data by monitoring turbine speed, ptransmitting data to the surface via a pulser .It can be installed in any position of the instrument string, which provides a lot of conveniences for the logging. The BPC (Bypass Controller) sends commands from the surface to downhole instrument by controlling the NPG (Negative Pulse Generator) which controls the mud flow.

SpecificationsTool O.D.

Make-up LengthWeight

Flow RangeMax Temperature

Max PressureMax Turbine RPM

OutputMax Power output

4.75 in.14.11 ft. (4.3 m)771 lbs. (350 kg)125 - 220 gpm

6.75 in.10.85 ft. (3.3 m)

1,006 lbs. (455 kg)211 - 470 gpm

350°F (175°C)25000psi (172.4 Mpa)

500033 Vdc±1300 Watts

BCP-O MWD-ALT-OMWD-Rotary

Pulser MWD-MVA-O

SLEEVEBCP-H


Rotary Pulser

ValveAssembly

MechanicalAssembly Motion Control

Module

Logging While Drilling-Hostile (LWD-H)

ApplicationsMaximized drilling efficiency and wellbore placement with automated rotary drilling

Reduced risk of differential sticking via continuous rotation Extended horizontal and lateral capabilities for maximum payzone contact—increasing productionrates and extending the life of the well

Improved hole quality and holecleaning to reduce completion risks

IntroductionLWD-H combines real-time azimuth, gamma ray, resistivity, annulus pressure and vibration measurement together. This reduces the number of connection joints, improve reliability, and optimize the distance from BHA sensors to drilling bit. InteLWD consists of BCP-O, directional sensor, resistivity, pressure sensor, gamma ray, master controller and memory.

SpecificationsMax Temperature 300oF (150oC)Max Pressure 20,000 psi (137.9 MPa)Max Rotation Rate 400 rpmMax Lost Circulation Material 40 ppb=114 kg/m3

Tool O.D.Make-up LengthHole Diameter

Dogleg SeverityMax Temperature

Max PressureMax Rotation Rate

Max Lost CirculationMaterial

4.75 in.20.34 ft. (6.2 m)

5-3/4 in. to 6-3/4 in.(146-172 mm)

Wtih Rotation 10°/100 ft.Without Rotation 30°/100 ft.

6.75 in.17.06 ft. (5.2 m)

8-3/8 in. to 10-5/8 in.(212-270 mm)


350oF (175oC)25,000 psi (172.4 MPa)

400 rpm40 ppb=114 kg/m3

Sto

p S

ubB

CP

-OD

irect

iona

l Sen

sor

Vibr

atio

n, S

tick-

Slip

Azi

mut

hal

Gam

ma

Ray

Ann

ular

P

ress

ure

EP

RS

top

Sub


ApplicationsCollision Avoidance

Multi-Well / Pad Drilling

In-Fill Drilling

Magnetic Ranging

Gross Error Detection

Survey Validation

Whipstock Orientation

Kick-off Assurance

Sidetrack / Re-Entry

Ellipse of Uncertainty Reduction

Gyroscope Wireless Measurement While Drilling (GyroMWD)


The GyroMWD system delivers superior reliability and the ultimate drilling confidence by: Enabling precision surveying in the presence of magnetic interference Providing preventative measures for collision avoidance Providing seamless compatibility with existing MWD, LWD systems Enabling operational efficiency through flexibility of BHA configurations Enabling significant savings by the elimination of NPT from wireline orientation and survey check-shot runs

Introduction

SpecificationsGeneralTool Collar Size Dog Leg Severity (per 100 ft/30m) Sliding Rotating3.375 in. 37° 15°4.750 in. 30° 10° 6.750 in. 19° 8° 8.250 in. 12° 7°9.500 in. 12° 6°

Pressure 20,000 psi (140 MPa)Gyro Temperature 240° F (115° C)Lost Circulation Material (LCM) Medium nut plug 40 lbs/bbl (18 kg/bbl) (MP)Gyro Vibration 8grms (all axis)Operating Time 40 to 250 hrs depending on slide ratio or rig operations

Instrument Accuracy Stable MeasurementInclination ± 0.1° (all angles)Azimuth ± 2° ( 3° < inclination < 30°)Tool Face ± 1.5° System Accuracy Subject to Well Profile

Pulser

MWD Battery (3.375 in.) / MWD Generator (4.75 in. / 6.75 in. / 8.25 in. / 9.5 in.)

MWD DirectionalPackage

Gyro Directional Package

2-1/2 in. Common Coiled Tubing Drilling-Wireline (ComCTD-2W)


FeaturesFlexible setup the integrated CTD system

Data transmission & communication via mono conductor CT e-line

Selectable directional system with reliable and automated closed-loop steering control

Resistivity & GR LWD service

Real-time WOB, bore & annular pressure, and vibration data

Depth control and circulation capability by specific BHA services

The 2.5 in. toolsize has been designed to cover hole sizes from 2.75 inches up to 3.5 inches. This system provides flexibility in configuration to allow tailoring the level of service at the rigsite for Coiled Tubing Drilling (CTD) operations in standard and thru-tubing re-entry slimhole applications to meet customer service needs

Introduction

Quick Connnect Sub (UQC and LQC)Pressure Control Sub (PCS) (Optional)Mechnical Circulating and Disconnect Sub (MCD)Mechnical Orienting Sub (MOS) Power and Communication Tool (PCT)Drilling Performance Tool (DPT) (Optional)Vibration& Shock Digital Attitude Sensor (VDS-2)Electromagnetic Propagation Resistivity Tool (EPR-2)Inclination and Gamma Ray (IGR)Gyroscope Orientation Tool-Drilling (GOT-D) (Optional)Electrical Orienting Tool (EOT)Float Value Sub (FVS)2-3/8” / 2-7/8” Motor

Components

Wireline

Tool Size OD 2.5 in. (63.5 mm)Borehole Size 2.75 in. to 3.5 in. (70 mm to 89 mm)System Length 74.47 ft (22.70 m)System Weight 935 lb (424 kg)System Connection top / bottom 1.5 in. AMT box / pinPower Source Via CT e-lineCommunication & Telemetry Via CT e-line

Tool Specifications

WirelineCamesa 1N 32 PTZ

Camesa 1N 22 PTZ (ETFE)Camesa 1K 22 PTZ (ETFE)Camesa 7H 42RP (Optional)

WiresMonoMonoMonoSeven

OD [in.]5/167/327/327/16

Specified Length23,000 ft (7,000 m)18,000 ft (5,500 m)18,000 ft (5,500 m)23,000 ft (7,000 m)

PC

TM

CD

PC

S

MO

SFV

SE

OT

2-3/

8” M

otor

DP

T

VD

S-2

IGR

GO

T-D

EP

R-2

UQ

C /

LQC



BenefitsOn-location BHA adjustments based on operational needs

High real-time data density for operating efficiency improvements

Precise directional control for additional reservoir access, optimized wellbore placement and reduced drilling time

Increased section length in horizontal reservoir section by adjustable steering control and coverage of high dogleg requirements in build sections

Geo-steering capability for increased production and improved reservoir contact

Drilling parameter optimization for improved ROP and drilling efficiency

Precise and reliable ECD control and management for risk reduction

Hole cleaning and precise depth correlation improvements while tripping

Maximum Flow Rate 80 gpm (300 lpm)Maximum Build Up Rate 50°/100 ft (50°/30 m)Pressure Drop with Water (w/o PDM) 650 psi at 80 gpm ( 4.5 MPa at 300 lpm)Maximum Operating WOB 15 klb (67 kN)Maximum WOB to Failure 20 klb (88 kN)Maximum Operating Overpull 15 klb (67 kN)Maximum overpull to Failure 20 klb (88 kN)Maximum Hydrostatic Pressure 15,000 psi (103 MPa)Maximum Differential Pressure With Circulation Ports (EDC) 1,500 psi (10.3 MPa) Without Circulation Ports (ED) 4,500 psi (31 MPa)Operating temperature limits Maximum 300°F (150°C) Minimum 40°F (4°C)Sand Content <1% Solid Content (Maximum) 7%LCM 10 ppb = 28 kg/m³, fine nutplug

Operating Specifications & Limits (Sliding operation only)

Tool SpecificationsTool Name

UQCLQC

PCS (Optional)MCDMOSPCTDPT

VDS-2EPR-2 (Optional)

IGRGOT-D (Optional)

EOTFVS

2-3/8” Motor

Length0.82 ft (0.25 m)0.82 ft (0.25 m)0.92 ft (0.28 m)3.94 ft (1.20 m)8.20 ft (2.50 m)7.71 ft (2.35 m)3.64 ft (1.11 m)5.91 ft (1.80 m)9.50 ft (2.90 m)3.51 ft (1.07 m)

12.63 ft (3.85 m)5.35 ft (1.63 m)1.67 ft (0.51 m)9.84 ft (3.00 m)

Weight33 lb (15 kg)33 lb (15 kg)26 lb (12 kg)18 lb (8 kg)

61 lb (27 kg)66 lb (30 kg)33 lb (15 kg)53 lb (24 kg)

121 lb (55 kg)33 lb (15 kg)

196 lb (89 kg)40 lb (19 kg)44 lb (20 kg)

180 lb (80 kg)




Data transmission & communication via mono conductor CT e-line





The 3.125 in. toolsize has been designed to cover hole sizes from 3.5 inches up to 4.75 inches. This system provides flexibility in configuration to allow tailoring the level of service at the rigsite for Coiled Tubing Drilling (CTD) operations in standard and thru-tubing re-entry slimhole applications to meet customer service needs.

Introduction

Components

Wireline

Tool Size OD 3.125 in. (80 mm)Borehole Size 3.5 in. to 4.75 in. (89 mm to 121 mm)System Length 78.24 ft (23.85 m)System Weight 1470 lb (667 kg)System Connection top / bottom 2.375 in. PAC box / pinPower Source Via CT e-lineCommunication & Telemetry Via CT e-line

Tool Specifications

WirelineCamesa 1N 32 PTZ

Camesa 1N 22 PTZ (ETFE)Camesa 1K 22 PTZ (ETFE)Camesa 7H 42RP (Optional)

WiresMonoMonoMonoSeven

OD [in.]5/167/327/327/16

Specified Length23,000 ft (7,000 m)18,000 ft (5,500 m)18,000 ft (5,500 m)23,000 ft (7,000 m)

Quick Connnect Sub (UQC and LQC)Pressure Control Sub (PCS) (Optional)Mechnical Circulating and Disconnect Sub (MCD)Mechnical Orienting Sub (MOS) Power and Communication Tool (PCT)Drilling Performance Tool (DPT) (Optional)Vibration& Shock Digital Attitude Sensor (VDS-3)Electromagnetic Propagation Resistivity Tool (EPR-3) (Optional)Inclination and Gamma Ray (IGR)Gyroscope Orientation Tool-Drilling (GOT-D) (Optional)Electrical Orienting Tool (EOT)Float Value Sub (FVS)2-7/8” / 3-1/8” Motor

2-7/

8” M

otor

MO

SFV

SE

OT

IGR

GO

T-D

VD

S-3

EP

R-3

MC

D

PC

S

PC

TU

QC

/ LQ

C

DP

T



Maximum Flow Rate 130 gpm (490 lpm)Maximum Build Up Rate 45°/100 ft (45°/30 m)Pressure Drop with Water (w/o PDM) 350 psi at 132 gpm (2.4 MPa at 500 lpm)Maximum Operating WOB 25 klb (111 kN)Maximum WOB to Failure 35 klb (155 kN)Maximum Operating Overpull 25 klb (111 kN)Maximum overpull to Failure 35 klb (155 kN)Maximum Hydrostatic Pressure 15,000 psi (103 MPa)Maximum Differential Pressure With Circulation Ports (EDC) 1,500 psi (10.3 MPa) Without Circulation Ports (ED) 4,500 psi (31 MPa)Operating temperature limits Maximum 300°F (150°C) Minimum 40°F (4°C)Sand Content <1% Solid Content (Maximum) 7%LCM 10 ppb = 28 kg/m³, fine nutplug


Tool Specifications

On-location BHA adjustments based on customer requirements

High real-time data density for operating safety & efficiency improvements

Precise directional control for maximized reservoir contact, optimized wellbore placement and reduced drilling time

Increased section length in horizontal reservoir section by adjustable steering control and flexibility for high dogleg requirements in build sections

Optimized formation evaluation and geosteering capability for increased production and improved well placement




Benefits

Tool NameUQCLQC

PCS (Optional)MCDMOSPCTDPT

VDS-3EPR-3 (Optional)

IGRGOT-D (Optional)

EOTFVS

2-7/8” / 3-1/8” Motor

Length0.82 ft (0.25 m)0.82 ft (0.25 m)0.92 ft (0.28 m)3.94 ft (1.20 m)8.20 ft (2.50 m)7.94 ft (2.42 m)3.64 ft (1.11 m)5.91 ft (1.80 m)

12.86 ft (3.92 m)3.71 ft (1.13 m)

12.63 ft (3.85 m)5.35 ft (1.63 m)1.67 ft (0.51 m)9.84 ft (3.00 m)


139 lb (63 kg)132 lb (60 kg)119 lb (54 kg)99 lb (45 kg)

256 lb (116 kg)64 lb (29 kg)

196 lb (89 kg)90 lb (41 kg)44 lb (20 kg)

220 lb (100 kg)

3-1/8 in. Common Coiled Tubing Drilling (ComCTD-3)


Data transmission & communication via mud pulse





The 3.125 in. toolsize has been designed to cover hole sizes from 3.5 inches up to 4.75 inches. This system provides flexibility in configuration to allow tailoring the level of service at the rigsite for Coiled Tubing Drilling (CTD) operations in standard and thru-tubing re-entry slimhole applications to meet customer service needs.

Introduction

Components

Tool Size OD 3.125 in. (80 mm)Borehole Size 3.5 in. to 4.75 in. (89 mm to 121 mm)System Length 79.82 ft (24.33 m)System Weight 2001 lb (912 kg)System Connection top / bottom 2.375 in. PAC box / pinPower Source BatteryCommunication & Telemetry Positive Mud Pulse

Tool Specifications

Quick Connnect Sub (UQC and LQC)Pressure Control Sub (PCS) (Optional)Mechnical Circulating and Disconnect Sub (MCD)Mechnical Orienting Sub (MOS) Main Valve Assembly (MVA)Wireless Measurement While Drilling-3 (MWD-3)Electromagnetic Propagation Resistivity Tool (EPR-3)Inclination and Gamma Ray (IGR)Drilling Performance Tool (DPT) (Optional)Float Value Sub (FVS)2-7/8” / 3-1/8” Motor


PC

S

2-7/

8” M

otor

MO

SFV

SIG

RM

WD

-3E

PR

-3M

CD

MVA

UQ

C /

LQC

DP

T


Tool SpecificationsTool Name

UQCLQC

PCS (Optional)MCDMOSMVA

MWD-3EPR-3 (Optional)

IGRDPTFVS

2-7/8” Motor

Length0.82 ft (0.25 m)0.82 ft (0.25 m)0.92 ft (0.28 m)3.94 ft (1.20 m)8.20 ft (2.50 m)

2.56 ft ( 0.78 m)3.38 ft ( 9.40 m)30.84 ft (3.92 m)3.71 ft (1.13 m)3.64 ft (1.11 m)1.67 ft (0.51 m)9.84 ft (3.00 m)


139 lb (63 kg) 66 lb ( 30 kg)

992 lb ( 450 kg)256 lb (116 kg)

64 lb (29 kg)119 lb (54 kg)44 lb (20 kg)

220 lb (100 kg)

Maximum Flow Rate 130 gpm (490 lpm)Maximum Build Up Rate 45°/100 ft (45°/30 m)Pressure Drop with Water (w/o PDM) 350 psi at 132 gpm (2.4 MPa at 500 lpm)Maximum Operating WOB 25 klb (111 kN)Maximum WOB to Failure 35 klb (155 kN)Maximum Operating Overpull 25 klb (111 kN)Maximum overpull to Failure 35 klb (155 kN)Maximum Hydrostatic Pressure 15,000 psi (103 MPa)Maximum Differential Pressure With Circulation Ports (EDC) 1,500 psi (10.3 MPa) Without Circulation Ports (ED) 4,500 psi (31 MPa)Operating temperature limits Maximum 300°F (150°C) Minimum 40°F (4°C)Sand Content <1% Solid Content (Maximum) 7%LCM 10 ppb = 28 kg/m³, fine nutplug


3-1/2 in. Common Coiled Tubing Drilling (ComCTD-3)

On-location BHA adjustments based on customer requirements

Precise directional control for maximized reservoir contact, optimized wellbore placement and reduced drilling time

Increased section length in horizontal reservoir section by adjustable steering control and flexibility for high dogleg requirements in build sections

Optimized formation evaluation and geosteering capability for increased production and improved well placement




Benefits

GeoSteering


SignificanceThe geosteering uses real-time geological parameters to clarify various uncertainties and effectively control the landing and direction of the well trajectory, and adjust the well trajectory to travel through the target layer to achieve the purpose of improving the drilling rate.

Geosteering MethodStratigraphic model prediction curve methodThe geosteering uses real-time geological parameters to clarify various uncertainties and effectively control the landing and direction of the well trajectory, and adjust the well trajectory to travel through the target layer to achieve the purpose of improving the drilling rate.

Establishing a stratigraphic model

Adjusting the stratigraphic modelAdjust the formation model, the prediction curve is consistent with the measured curve

Uncertainty

Formation Dip

Reservoir Depth

Formation Thickness

Lithological Change

GR imaging layer interface methodThe formation morphology and formation apparent dip (ADIP) can be determined.

Under UpUp GR

Down GRUp GR

Technology Features


Automatic projection of adjacent wellsThe adjacent well stratigraphic interface and logging curve depth are dynamically corrected to the current horizontal well projection profile based on formation occurrence.

South

Profile Orientation

Trajectory Profile

East

Real Drilling Track

TVD

Adjacent well 1 Adjacent

well 1well 1 well 1

Seismic, LWD, Logging Data access

Multi-mode projection

Seismic, LWD , Logging Data ReceptionTransmission protocol: WITSDictionary Management: Open ManagementSupport instruments: Baker Hughes, Halliburton, Schlumberger, COSL, GE, etc.

Seismic, LWD data receiving transmission channel:COM port: baud rate and data bitTCP/IP protocol: IP and port

Logging data receptionDatabase Access (.mdb)Data table (.xls)

Logging data receiving methodFile access form

Real-time acquisition of Seismic Data, LWD Data, Logging Data, real-time display of data and channel connection status.

Seismic LoggingData

LWD

Software

The software can be project based on the profile orientation or the trajectory profile.

Multiple modeling methods Construction diagram modeling Multi-well comparison modeling Seismic slice modeling Construction dip modelingThe user selects one of the methods suitable for this block to establish a formation model.

Construction diagram modeling:Establish an initial model based on the target layer (top / bottom) interface.

NO X Y TVDss NO X Y TVDss

COM port link connectionTransmit Receive

Technology Features


Multi-well comparison modeling:Establish an initial model based on the destination layer interface of multiple adjacent well projections.

Construction dip modeling:

Seismic slice modeling:Establish an initial model based on seismic slices along a horizontal well trajectory.

When the viewing angles of the A target to the B target formation are substantially the same.A model can be created directly given a view angle of the formation.Generally used for geometrically oriented horizontal wells.

Formation angleContour map of the top layer of the target layer

Target layer real-time alarmReal-time monitoring of the relative position relationship between the drilling trajectory and the target layer, alarming according to the target layer and the set parameters, and monitoring the track entry and exit layer in real time.

Actual logo layer

Design logo layer

Design track

��

�� Adjustment track

Alarm: Will drilling into

Alarm: Will drilling target

Alarm: the next boundary will be drilledAdjustment track

Alarm: the upper boundary will be drilledAdjustment track

Finish

Target formation

Establish an initial model based on the dip angle of the target stratum.

Technology Features


Comparing the measured and predicted curves, adjusting the stratigraphic model, the prediction is consistent with the measured curve, indicating that the stratigraphic model is basically consistent

The formation pattern and the apparent dip angle of the formation are determined by GR imaging, and the stratigraphic section and trajectory are adjusted in real time.

Interactive picking of the formation dipDue to the uncertainty of the dip angle of the formation, the determination of the dip angle of the formation is the basis for guiding the drilling during the geosteering process.By picking the formation dip module to select points or take segments on the trajectory, the point dip or the average inclination of the well segment can be picked up and displayed and output.

Rapid input and calculation of drilling trajectoryIn order to meet the requirements of on-site work, the DrillDevi Input and TVD Calculation module can be used to quickly input the drilling inclination data and calculate the drilling trajectory.

Real-time analysis and adjustment of stratigraphic sections Curve predictionAfter many years of theoretical research, the theoretical modeling of GR, AC and LLD has been completed, and the practical application has achieved good results. The geological model is adjusted mainly by predicting curves through theoretical models.

Horizontal well GR correction calculation

6 in. 8.5 in.6 in. 8.5 in.

GR Borehole Correction Chart GR Borehole Correction Chart

Software Module


Module NameBasic PlatformData Collection

Real-time display

Real-time alarmSingle well trajectory calculation

Multi-well TVD calculation

Vertical formation model

Transverse stratigraphic model

Generating stratigraphic section

Logging curve prediction

Target layer real-time alarm

AGR/RAD Imaging

Pick up the formation dip

Boundary distance calculation

Manual packagingAutomatic packaging

Function DescriptionWork area management, well management, data management, system management, etc.Real-time acquisition of Seismic, LWD, Logging Data.Display depth and time domain data in real time, and provide preprocessing tools such as GR calibration and curve splicing.Set alarm parameters to alarm abnormal real-time data.Calculate parameters such as vertical depth, horizontal displacement, east-west displacement, and north-south displacement of the main horizontal well.The TVD batch calculation is performed on the depth domain log data, the stratified data, the interpretation conclusion, the lithology profile, etc., and the data of the TVD domain or the TSD domain is formed.A vertical stratigraphic model is established based on a lithology curve of the target well or adjacent well target segment.The formation interface morphology of the target layer (or a nearby layer) is established based on the structural dip angle, structural map, multi-well contrast or seismic slice data.Combining the vertical and lateral stratigraphic models, a stratigraphic profile is generated to form an initial stratigraphic model.According to the wellbore or adjacent well logging curve, the GR, DT and LLD prediction curves of the horizontal well along the design trajectory and the real drilling trajectory are calculated inversion.The relative positional relationship of the drilling trajectory in the formation model is monitored in real time, and the situation of the top and bottom interface of the formation and the entry and exit of the drill bit into the target layer are warned in advance.The AGR/RAD Imaging can be generated based on the up and down GR and Density for judging the entry and exit layers.Interactively select points on the target layer interface of the formation model and display the apparent dip angle of the formation.Given a certain stratum boundary, calculate the parameters of the track point corresponding to TVD, MD, top margin, and bottom margin.The button triggers a package upload.The package is automatically packaged and uploaded after the completion of the phase.

Software

Alarm Settings

Time domain,

depth domain

Data AccessAGR / RADLogging Data

Basic data loading Establish initial modeling

Real-timemonitoring

Real-timeorientation

Gyroscope Orientation Tool-Continuous (GOT-C)


ApplicationsMeasure well trajectory inside the drill pipe, casing, tubing and openhole.

Measure orientation & trajectory while drilling

Measure orientation for sidetracking whipstock tool and directional perforation

Measure directional parameters under magnetic interference conditions (such as cluster wells).

IntroductionGyroscope Orientation Tool provides accurate and free magnetic interference directional survey in drill pipe, cased holes and production tubing, or in areas of magnetic interference. The GOT also can be run into drill pipes. The flexibility of the design allows the combination with additional services such as Gamma Ray, CCL. Also for direction perforating.

SpecificationsMaximum Temperature 350°F(175°C) for 4 hoursMaximum Pressure 15,000 psi (103.4 MPa)Make-up Length 31 ft.(9.48 m) (without SKB)Approx. Weight 134 lbs(61 kg) (without SKB)Tool Diameter 2.25 in. (57 mm)Maximum Hole Diameter 12.0 in. (305 mm)Maximum Logging Speed 100 ft/min (30 m/min)Orientation Sensor Dynamically Tuned GyroscopePower Requirements:Operating Voltage & Current 200 Vac, 75 mAMaximum Tensile Load 14000 lbs (6350 kg)Wireline Requirements Mono ConductorLogging Mode ContinuousSensor Accuracy:Azimuth +/-1.5 deg. @ 0 deg.~60 deg. +/- 2.5 deg. @ 85 deg.~89 deg.Deviation +/- 0.1 deg. @ 0 deg.~60 deg. +/- 0.25 deg. @ 60 deg.~89 deg.Gravity Tool Face +/- 0.5°(When the deviation is greater than 2 degrees)Gyro Tool Face +/- 2°(When the deviation is less than 2 degrees)

The SST is mainly used in the well attitude and temperature measurement of well drilling. It is suitable for the sitting-key and slickline job. It uses an embedded system to process data, eliminating manual reading errors, and acquires 9 sets of data at each measurement point with data self-checking.The MST is used for trajectory measurement of well drilling and geological exploration. It acquires 5000 sets of multiple points well attitude parameters within one time, which could draw the well trajectory map conveniently and quickly. The MST is used for surveying: MST measures data during POOH after the instrument is directly put into the bottom of the well, and read-out data after POOH, therefore, no need slikline or winch. There are three types: Throw Type, Self-floating Type and Sitting-Key Type.The Throw Type is directly put into the drill pipe, and drop to the bottom of the drill pipe by its own gravity, and read-out memory data and process after POOH.Self-floating Type has a float, it is necessary to pump on, and it reach the bottom of the drill pipe. After the pump turned off, the instrument floats up to the wellhead, and read memory data and process.The Sitting-Key Type needs to be equipped with slick line. It is used to direction drilling.

Single-shot Survey Tool (SST)Multi-shot Survey Tool (MST)

Introduction

High precision solid state sensor

150 °C high temperature battery

Data with real-time clock labels

Features

SpecificationsMaximum Temperature 300oF（150°C）Temperature Accuracy ±2 °CMax Pressure 140 MPa (20,000 psi)Outside Diameter 1.77 in. (45 mm)Inclination Range 0°-180° Inclination Accuracy ±0.2°Azimuth Range 0°-360°Azimuth Accuracy ±1°Highside Toolface Range 0°-360°Highside Toolface Accuracy ±1.5°Magnetic Toolface Range 0°-360°Magnetic Toolface Accuracy ±1.5°Magnetic Field Strength Range 0 -100 uTMagnetic Field Strength Accuracy ±0.5 uTDIP Range -90°-90°DIP Accuracy ±0.3°


ApplicationsWell trajectory monitoring

Provides attitude, magnetic field, temperature and power parameters

No need wire winches for self-floating type tool, conveyed by mud

NO.

1234567891011

60116012601360146015

Absolute Time

h: m: s12:08:0012:08:0112:08:0212:08:0312:08:0412:08:0512:08:0612:08:0712:08:0812:08:0912:08:10

13:48:1113:48:1213:48:1313:48:1413:48:15

Inclinationdeg2424242424

24.12424242424

11111111

11.2

Azimuthdeg

188.1188.1188.4188.4188.4188.4188.4188.4188.4188.4188.4

180.6180.6180.4180.4180.5

Magnetic Highside

deg201.1201.1201.1201.1201.1201.1201.1201.1201.1201.1201.1

339.2339.2339.2339.2339.2

Gravity Highside

deg16.1161616161616161616

15.8

158158158158159

TemperatureoC

41.241.241.241.241.241.241.241.241.241.241.2

23.823.823.823.823.8

Magnetic Field

StrengthuT

45.245.245.345.245.245.245.245.245.245.245.2

45.245.345.345.245.2

DIPdeg45.845.845.845.845.845.845.845.845.845.845.8

45.845.845.845.845.8

NO.

123456789

Absolute Time

h: m: s8:30:008:30:018:30:028:30:038:30:048:30:058:30:068:30:078:30:08

Inclinationdeg0.40.30.40.40.40.40.40.40.4

Azimuthdeg

161.8161.8161.9161.8161.9162

161.9161.9161.9

Magnetic Highside

deg118.1118.1118.1118.1118.1118.2118.1118.1118.1

Gravity Highside

deg315.8161.9161.9161.8161.7161.8161.8161.8161.8

TemperatureoC

23.223.223.223.223.223.223.223.223.2

Magnetic Field

StrengthuT

45.245.245.345.245.245.245.245.245.2

DIPdeg45.845.845.745.845.845.845.845.845.8

SST

MST

The RMR system works with well‐to‐well separation distances up to 50m.The RMR systems are used to drill the majority of SAGD pairs worldwide. It can be combined with CTT (Downhole Casing & Tubing Tractor).

Rotary Magnet Ranging (RMR)

Introduction


ApplicationsDrilling stacked horizontal well pairs for steam‐assisted gravity design (SAGD)

Infill drilling and collision avoidance

Wellbore Intersections for well control or pipelines

Observation well placement

Coalbed methane degasification wells

Nominal O.D. 1.75 in. (44.5 mm)Hole Size Range 3.875 in. and UpMin Tubing I.D. 2.875 in. (73 mm)Max Tubing I.D. NALength 8.2 ft. (2.5 m)Weight 60 lbs. (27.3 kg)BHA Connection 2.375 in. Reg and Up

Max Operating Temperature 350oF (175oC)Max Operating Pressure 20,000 psi (137.9 MPa)Accuracy 16 to 49 ft/5 to 15 m 5%Accuracy 49 to 82 ft/15 to 25 m 5%Accuracy Beyond 82 ft/25 m 5%Max Range 164 ft (50 m)

Specifications

Chief Operating Officer Wan HuiMobile:(+86) 13811697302 Tel :(+86) 010-89765689-807Email: [email protected] China Sales Supervisor Ding Litao Mobile:(+86) 13718369420 Email: dinglt@renhesun. com

China Sales ManagerDing Litao Mobile:(+86) 13718369420Email: [email protected]

Middle East Area ManagerWang Yuwen Mobile:(+86) 18910290806Email: [email protected]

International Sales Manager Sharry Liu Mobile:(+86) 13911317865 Email: [email protected]

International Sales Director Chen Gang Mobile:(+86) 13817367599 Email: chengang@renhesun. com

Middle East Operation Manager Zhen Shunli Mobile:(+86) 13683631587Email: [email protected]

China

Add: No. 1, Hua Chang Road, Science & Technology Park, Changping District, BeijingTel: (+86) 010-89765689-818 Zip:102200

Middle East

Russia

Add: No. 64, Novaya Street, Karmaskaly Town, Karmaskaly, Republic of Bashkortostan Tel: (+7) 9872578985 Zip:453020

South America

Add: University Avenue, between Traposos and Chorro streets, Centro Empresarial Building, tenth floor, Office number 10-C, Caracas. Tel: (+58) 04143200710

friendly cooperation

Marketing Manager Zhang Xujie Mobile:(+86) 13521254100Email: [email protected]

Product Manager Zhang Hong`ai Mobile:(+86) 18911632096Email: [email protected]

Russian Operation Manager Guo Feng Mobile:(+86) 13811796429 (+7) 917-3697194Email: guofeng@renhesun. com

Russian Technical Manager Chen Hua Mobile:(+86) 13811209770 (+7) 917-7358296Email: chenhua@renhesun. com

South America Technical Manager Gao Lijun Mobile:(+86) 15110265323Email: [email protected]

Documents

Complete Logging While Drilling System (ComLWD ...Insert mode, different sizes of instruments, electronic circuit are interchangeable, saving the cost Two kinds of pulser, have more