Automated drilling technology

Technical Specifications – Automated Drilling Technology Components

Iron Roughneck (TZG Series)

Control Loop Performance

Digital Twin & Remote Monitoring Capabilities

Product Types – Automated Drilling Technology Packages

We offer automated drilling technology in four progressive levels, each designed to integrate with new‑build rigs or retrofit existing fleets:

1. Level 1 – Mechanized Assistance – Iron roughneck, automated catwalk. No racking automation. Minimal software. Best for shallow wells or small drilling contractors.

2. Level 2 – Semi‑Automated Floor (SG Automated Drilling Technology) – Adds automatic connection sequences, fingerboard inventory tracking, and remote driller console. No floor crew required during tripping. Data logging standard.

3. Level 3 – Fully Automated Floor – Adds vertical racking arm, automated elevator latching, slip automation, and closed‑loop control loops. Crew reduced to one driller plus one maintenance technician. AI optimization available.

4. Level 4 – Remote + AI Driven – Driller operates from town office using remote console; local crew handles only maintenance and emergencies. Digital twin monitoring and AI optimization are standard.

Applications – Where Our Automated Drilling Technology Delivers

• Land drilling – multi‑well pads (shale, tight gas, CBM) – Automated floor slashes slips‑to‑slips time. Consistent torque across thousands of connections per well.

• Offshore platform drilling – ATEX‑certified components; remote operation from safe cabin. Operating on South China Sea platforms.

• Deepwater semi‑submersibles and drillships – Active heave‑compensated automation. Remote control from shore reduces offshore personnel count.

• Arctic winter drilling – Heated hydraulic and electric systems; remote driller console allows operation from heated cabin; all components low‑temperature rated (-45°C).

• Remote / frontier exploration – Minimal crew on site; remote supervisor manages multiple rigs simultaneously. Data historian optimizes the second well based on the first well’s performance data.

Why Choose SJ Petro for Automated Drilling Technology?

• Sinopec‑backed engineering – As a direct subsidiary of China’s largest oilfield equipment group, we have 314 R&D engineers, 2,100+ precision machines, and a 180,000+ m² manufacturing campus. Our automation engineers design systems that speak the same control language as our rigs — seamless integration, no third‑party black boxes.

• Kingdream collaboration – 40+ years of downhole expertise – Kingdream is a Sinopec group company with over four decades of dedicated downhole technology manufacturing history. Recognized as a national high‑tech enterprise and a leading oil drill bit manufacturer in China, Kingdream has developed a comprehensive range of automated functional products including drilling series, directional drilling series, and specialized bits. Through this collaboration, we bring world‑class downhole expertise into our surface automation strategy, creating an integrated drilling system from bit to top drive.

• API 8C, API 7K, API 13C, API 4F certified – Our automated hoisting and pipe handling components carry full API certification. Third‑party inspection (ABS, DNV, BV, SGS) is always welcome.

• Closed‑loop control from floor to bit – Our automation system integrates the top drive, iron roughneck, catwalk, racking arm, BOP control unit, and mud pumps. One console orchestrates the entire workflow.

• Retrofit‑friendly design – You do not need a new rig. Our iron roughneck, catwalk, and control modules can be added to existing rigs. We provide structural engineering for any mast or substation modifications.

• Digital twin enabled – Simulate the entire drilling program before the bit touches formation. The digital twin runs the same control code as the rig floor, making the transition from simulation to operation seamless.

• Remote troubleshooting and live support – Our engineers can log into the PLC remotely (with your permission) to diagnose faults, adjust parameters, and push software updates — reducing downtime.

• 24/7 spares support – We stock automation‑specific spares (sensors, solenoid valves, boards, joysticks) in Dubai, Singapore, and Houston. Delivery to most global rig sites within 48‑72 hours.

• Competitive direct‑manufacturer pricing – As a Sinopec subsidiary and OEM, our automation packages cost 15‑25% less than Western brands for equivalent API certification.

• Warranty – 24 months on automation electronics; 12 months on mechanical components. Extended warranty available.

Frequently Asked Questions (FAQ)

Q1: How much non‑productive time (NPT) can automation reduce?
Field data from multiple basins shows automated connection sequences alone reduce connection time by 30–40%. Closed‑loop auto‑drillers reduce vibration‑related NPT by 15–25%. Overall, operators report well delivery cycles shortened by an average of 1–1.5 days per well.

Q2: Do I need to buy a new rig to get automation?
No. We specialize in retrofitting automation components — iron roughneck, catwalk, racking arm, and control console — to existing rigs without replacing the entire mast and substructure. We provide full structural engineering support for necessary modifications.

Q3: How does your torque turn system work?
The PLC monitors torque via strain gauge pins in the roughneck. When the preset target torque is reached — programmed per connection type — the system automatically stops torque application and logs the peak value, the number of turns, and a timestamp. Data can be exported to USB drive or transmitted to the office.

Q4: Is the automation system failsafe if the PLC loses power?
Yes. All critical safety functions (emergency stop, brake application, BOP interlock) are hardwired or use redundant PLCs with battery backup. If the main controller fails, the system defaults to a safe state — all motion stops, brakes engage — and the operator takes manual control using backup joysticks.

Q5: Can the automation system control third‑party top drives and mud pumps?
Yes. Our control platform uses standard Modbus TCP/IP and Profibus protocols, making it compatible with most major top drive and pump manufacturers. The system can read existing sensors and write setpoints without replacing existing controllers.

Q6: What is the typical ROI for a full automation package?
Based on field data, the payback period for a Level 3 automation package ranges from 12‑24 months, depending on daily rig rate and annual operating hours. A 1.5‑day reduction per well on a 10‑well program easily justifies the investment.

Q7: How many people are needed on the rig floor after automation?
Level 1: 1‑2 operators needed. Level 2: 1 driller + 1 floor supervisor. Level 3: 1 driller only; no floor crew during tripping. Level 4: local maintenance technician only; driller operates from remote office.

Q8: Do you provide training for drillers on your automation system?
Yes. We provide a two‑week training program at our factory or your rig site: classroom instruction (automation theory, safety interlocks, controller interface) and simulator practice (hands‑on with the same HMI). Experienced drillers typically master the system within the first 2‑3 wells.

Q9: What documentation do you provide with automation systems?
You receive: full electrical and hydraulic schematics; PLC program with commented source code; HMI configuration files; operations manual; safety interlock logic description; material certificates for all structural components; and an installation and commissioning checklist. All documentation is digital and searchable.