• Xưởng sửa chữa và chuẩn chỉnh máy địa vật lý

    Xưởng có nhiệm vụ chính là bảo dưỡng, sửa chữa và hiệu chỉnh các máy móc thiết bị điện tử phục vụ cho các đơn vị trong Xí nghiệp địa vật lý giếng khoan. Ngoài ra xưởng còn nghiên cứu đưa vào ứng dụng và phát triển công nghệ tin học trong công tác địa vật lý

  • Trung tâm Phân tích và Xử lý số liệu

    Có nhiệm vụ đánh giá chất lượng tài liệu do Xí nghiệp Địa vật lý thực hiện.

  • Đội công nghệ cao

    Khảo sát địa vật lý tổng hợp trong giếng đang khoan. Đo địa vật lý tổng hợp, bắn mìn.

  • Đội Kiểm tra công nghệ khai thác

    Có nhiệm vụ là đo khảo sát và kiểm tra công nghệ khai thác trong các giếng khai thác và bơm ép.

  • Đội Carota khí

    Đội Carôta khí có nhiệm vụ chính là khảo sát carota khí, cung cấp kịp thời các số liệu để xác minh trữ lượng, tình trạng các giếng khoan.

  • Đội thử vỉa

    Đội có nhiệm vụ thử vỉa ở các giếng khoan nhằm định hướng cho công tác khoan, xác định tình trạng và đo vỉa, cung cấp thông tin để xác định trữ lượng công nghiệp của giếng




Well testing

Advantages & Disadvantages



  • Able to log any angel well
  • Same log quality as standard tools
  • Tools always attached to drillpipe
  • Mud circulation pass the tools
  • Able to log long intervals
  • Accurate depth control




Rig up and logging takes longer than standard logging

Picture of TPL drillpipe conveyed system

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Vsprowess Software

Main Features

Three component processing of any survey configuration

Image reconstruction of P and S wave modes, both CDP mapping and migration, using simple dip, anisotropic models.

Time slice display of 3D datasets

Proximity surveys including anisotropy and simple dip

Q estimation

Wavelet extraction/matching

AVO/AVA analysis tools

Fracture monitoring display

Flexible display options

Input data formats include SEGY,SEG2 and MIRF

Velocity log calibration and synthetic seismogram

Import and display of LAS logs.

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Airgun And RSS-2 VSP Source Controller

I/O Sleeve Guns

Size: three sizes, with volumes of 10 in3,20 in3 or 40 in3.

Polarized timing coil

Measured standard deviation of 110µs with a 351µs dispersion

Tow clamps equipped with a top hat that minimizes electrical cable and air hose proplems during handing and

RSS-2 VSP Source controller

Automatic source array synchronisation

Window based software

Each RSS-2 controls up to 16 sources


Timing accuracy 0.1ms

Source signature telemetry

Readout of reservoir and gun pressure

Accepts hydrophone, shuttle, T/B coil etc

Automatic source switching from software



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Downhole Tool GeochainTM 42 Level Digital VSP Array

Main Features:

• Up to 42 satellites

• Standard 7 conductor wireline.

• Real time data transmission

• 3 component gimballed

• 24bit Delta-Sigma  convertors

• 180oC temperature rating

• Unique Active Cooling System for continuous operation at 180oC

• 20000psi pressure rating

• Up to 95m between satellites


8 satellites and VRS

GeochainTM – an 8 level array with VRS

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Downhole Tool ASR-1 Advanced Seismic Receiver

The ASR-1  Advanced Seismic Receiver

ARS-1 Specifications

Length 35” (884mm)
Diameter 3” (76mm)
Weight 38lbs (17kg)
Locking Range 22”(559mm) with an arm extender
Temperature 400oF (204oC)
Pressure 20000psi (1400bar)
Sensors SM-4HT 10Hz
Mounting 3 component gimbal
Well deviation 0o – 95o
Control panel GPP & GSP-1


         The ASR geophones a compact three component electromechanical downhole geophone. It is disigned for use in wells up to 20000psi and 200oC and provides fast arm cycle time with an arm force to weight ratio of 5:1.

Locking Arms

           The standard arm will accommodate boreholes from 5” to 13”, the short arm will accommodate borehole from 3 ½” to 9” and an extended arm can be use to increase this range to 22”. The locking force is constant to within 20% throughout its operating range and will lock into 9 5/8” casing in fifteen seconds when fitted with the standard arm.

Gimbal Element

The tool is provided with a three component gimballed package as standard using one high sensitivity SM4 high temperature element per axis. The gimbal assembly with faithfully follow any borehole deviation from vertical through to horizontal and slightly beyond.

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Surface Equipment GSP-1 VSP Data Acquistion System

Main Features:

• Up to 16 analogue   channels

• 512 Kb digital interface

• 24bit Delta-Sigma  convertors

• Built in firing circuit

• Full instrument tests

• USP interface

• Use standard PC running VSProwess software


Analogue section

No. of channels: 2-16
Sample interval 0.25, 0.5, 1.0, 1.25, 2.0, 2.5, 4.0, 5.0ms
 A/D converter 24bit Delta-Sigma
Dynamic range <112dB@ 0dB pri-gain (minimum)
Distortion <0.01% (0.003% typical)@ 31.25Hz, 15V pp signal
Noise <10µV rms @ 1ms, 0dB pre-gain
Input Diffirential 20V pp max
Inter-channel skew 256kbit/second
Timing Accuracy 10ppm

Digital section

Capacity   512Kbps datastream
 Interface RS422 (As2065 DIF module option)
Cable equalisation Fully automatic using internal DSP chip
Format Software configured to match system


Airgun firing pulse   Isolated 60V, 30ms pulse
Sound control outputs 4, opto-isolated
Timebreak inputs 3, opto-isolated
Remote start input 1, opto-isolated
Test system Fully automatic with comprehensive report generation
PC interface USP
Power requirements
95-260V ac, 50/60Hz universal input, 50Watts
Enclosure Standard 19” rack mounting


Communication with the PC recording system  is by USB serial interface. The USB interface will allow the panel to be used with all modern PC’s.

The GSP incorporates a single airgun firing circuit for use on simple checkshot surveys. For independent external control circuits give control over external source controllers such as our own RSS four gun remote gun firing system




The GSP-1 in use with a Dual analogue system

           The panel provides fully automatic DC offset and gain calibration along with full instrument tests. The I-test reports are generated on the PC for archiving or for passing on to the client.

          Fig1: Acquisition Observer Log

          Fig2: Stack plot of vertical and horizontal components.

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Toolpusher Features


  - Toolpusher is a tool transport system use to convey the logging tools to the bottom of the well, when e-line can not get the tools to T.D.

- In many instances experience has proven that much less rig time is used, if Toolpusher is utilized first. 

-  Depending on depth, Toolpusher operations consume about 3 to 4 time more time than e-line conveyed operations.

- Any e-line service can be provided via Toolpusher.

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Downhole Pressure And Temperature Equipments

 K10 “Quazrtz”

The K10 “Quartz” is a slick line, E-line , or coiled tubing conveyed downhole memory gauge with significantly enhanced capabilities. In the basic configuration it is a low-cost, hight realiability pressure and temperature recorder. With enhanced feature, it is a low-cost, instrument producing pressure, temperature, and flor along with depth data for a more complete well survey.


Entire designed, manufactured and assembled in U.S.A.

• “Quartzdyne” quartz resonator transducer

• Battery management system within sofware

• Buit-in Surface Readout (SRO) mode

• Delta P/Delta T sampling options

• Redundant memory

• Low power requirement

• USB interface for fast downloading

• Depth data with sireal encoder for Pressure/Time vs. Depth/Time

• Upgradeable Firmware

• Optional Flowmeter


Static and flowing gradient tests

• Downhole leak detection

• Detecting flowing zones

• Injection testing

• Gas lifting optimization

• Drillstem testing


At present, VSP well testing team uses Ecrin sofware includes modules for Pressure Transient Analysis (Saphir) and Production Analysis (Topaze).. This software can calculate reservoir parameters as Pi - initial pressure, K - permeability, C - well bore storage, S - skin, R - effect radius, Kh – Perm thickness product, etc. with high accuracy and reliability. It can interpret testing data on oil, gas, water well with different geologic models. 


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RTTS Safety Joint

RTTS Safety Joint

The RTTS safety joint is an optional emergency backoff device. The safety joint releases the workstring and tools above the packer if the packer becomes stuck during operations.The design of the RTTS safety joint makes unintentional operation difficult.

Features and Benefits

•  Positive sequence of operation helps prevent premature release.

•  Tools above it can be retrieved when string is stuck


The RTTS safety joint is run immediately above the RTTS packer so that the greatest number of tools above the packer can be removed.Before the safety joint can be used, a tension sleeve located on the bottom of the lug mandrel must first be parted by pulling up on the workstring.After the tension sleeve has parted, the safety joint is released by right-hand torque while the workstring is rotated a specified number of cycles.


RTTS Safety Joint

Casing Size (in) OD  in. (cm) ID   in. (cm) Thread connnections Length in.  (cm) Tensile Rating** lb (kg)     Burst Rating** psi (kPa)   Collapse Rating** psi (kPa)
7 to 7 5/8 5.00   (12.70)   2.44 (6.20)   2 7/8 EUE 39.9    (101.4)  

164,000  (74 390)  

   12,000        (82 738)  

  10,900        (75 153)

8 5/8 to 13 3/8 6.12   (15.54)   3.12 (7.92)   4 1/2 IF 42.7      (108.5)   301,000  (136 533)      13,700  (94 459)  

 10,400       (71 706)

These are the most common sizes. Other sizes may be available.

**The values of tensile, burst, and collapse strength are calculated with new tool conditions, Lame’s formula for burst and collapse strength, and stress

area calculations for tensile strength.

These ratings are guidelines only. For more information, consult your local Halliburton representative.

RTTS Packer

The RTTS packer is a full-opening, hookwall packer used for testing, treating, and squeeze cementing operations. In most cases, the tool runs with a circulating valve assembly.The packer body includes a J-slot mechanism, mech anical slips, packer elements, and hydraulic slips. Large, heavy-duty slips in the hydraulic holddown mechanism help prevent the tool from being pumped up the hole. Drag springs operate the J-slot mechanism on ≤ 3 1/2-in. (88.9-mm) packer bodies, while larger packer sizes ≥ 4-in. (101.6 mm) use drag blocks. Automatic J-slot sleeves are standard equipment on all packer bodies. 

The circulating valve, if used, is a locked-open/locked-closed type that serves as both a circulating valve and bypass. The valve automatically locks in the closed position when the packer sets. During testing or squeezing operations, the lock prevents the valve from being pumped open. A straight J-slot in the locked-open position matches with a straightJ-slot (optional) in the packer body. This combination eliminates the need to turn the tubing to close the circulating valve or reset the packer after the tubing has been displaced with cement.

Features and Benefits

•   The full-opening design of the packer mandrel bore allows 

large volumes of fluid to pump through the tool. Tubing-type guns and other wireline tools can be run through the packer.

•  The packer can be set and relocated as many times as necessary with simple tubing manipulation.

•   Tungsten carbide slips provide greater holding ability and improved wear resistance in high-strength casing. Pressure through the tubing activates the slips in the hydraulic holddown mechanism.

•  An optional integral circulating valve locks into open or

closed position during squeezing or treating operations,

and opens easily to allow circulation above the packer.


The tool is run slightly below the desired setting position to set the packer and is then picked up and rotated several turns. If the tool is on the bottom, only a half-turn is actually required. However, in deep or deviated holes, several turns with the rotary may be necessary. To maintain position, theright-hand torque must be held until the mechanical slips on the tool are set and can start taking weight.The pressure must be equalized across the packer to unset it.

As the tubing is picked up, the circulating valve remains closed, establishing reverse circulation around the lower end of the packer. The circulating valve is opened for coming out of the hole when the tubing is lowered, rotated to the right, and picked up.

RTTS Packer

Casing Size (in) OD in.(cm) ID in.(cm) Thread connnections Length in.(cm) Tensile Rating** lb (kg)  
7 5/8 20-39   6.35 (16.13) 2.40 (6.10) 4 5/32 in. 8 UNS 3 7/8 in. CAS
9 5/8 40-71.8 7.80 (19.81) 3.00 (7.62)  4 1/2 in. API IF T.J.  4 1/2 in. API IF T.J
29.3-53.5 8.15 (20.70) 3.75 (9.53) 4 1/2 in. API IF T.J. 4 1/2 in. API IF T.J.

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