| Type: | Core Drill |
|---|---|
| Usage: | Coring |
| Certification: | CE, ISO |
| Application: | Reaming |
| Industry: | Geological Survey |
| Payment Term: | Tt or LC |
| Samples: |
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| Customization: |
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Audited Supplier some additional details about diamond reamers:
Reamer applications in well completion: Diamond reamers are not only used during the drilling phase but also play a critical role in well completion operations. After drilling the wellbore, reamers can be deployed to clean and enlarge the wellbore in preparation for casing installation. This helps ensure proper cementing and casing placement, enhances wellbore stability, and improves overall well integrity.
Reamer deployment in sidetracking operations: Sidetracking involves drilling a new wellbore from an existing wellbore. Diamond reamers are commonly used in sidetracking operations to enlarge the existing wellbore and create a smooth path for the sidetrack wellbore. This enables better access to new target zones or bypassing damaged sections of the original wellbore.
Reamer selection based on formation properties: The selection of a diamond reamer is influenced by the properties of the formation being drilled. Different formations have varying hardness, abrasiveness, and other characteristics that impact the reamer's performance. Manufacturers and drilling engineers consider formation data, such as rock strength, mineralogy, and drilling history, to choose the most suitable reamer design and cutter configuration.
Reamer compatibility with drilling modes: Diamond reamers can be used in various drilling modes, including rotary drilling, rotary steerable drilling, and motor-assisted drilling. The design and functionality of the reamer are tailored to work effectively in different drilling modes, taking into account factors such as drilling dynamics, tool rotation speed, and directional control requirements.
Reamer design for specific formations: Some diamond reamers are specifically designed for challenging formations, such as hard rock, shale, or abrasive formations. These specialized reamers may feature enhanced cutter materials, modified cutter geometries, or additional cutter protection to withstand the specific challenges posed by these formations. By optimizing the reamer design for specific formations, drilling operators can achieve efficient wellbore enlargement and minimize tool wear.
Reamer monitoring for condition-based maintenance: Condition-based maintenance involves monitoring the performance and condition of the reamer in real-time to determine when maintenance or replacement is required. By integrating sensors and data monitoring systems, operators can track various parameters such as vibration, temperature, and cutting efficiency. This enables proactive maintenance planning, reduces downtime, and improves overall drilling efficiency.
Reamer advancements in downhole telemetry: Downhole telemetry technology allows for real-time data transmission from downhole tools to the surface. Diamond reamers can be equipped with telemetry capabilities, enabling operators to monitor and control the reamer's performance remotely. This technology enhances operational visibility, facilitates timely decision-making, and enables optimization of drilling parameters for improved reamer performance.
Reamer research and development: The development of diamond reamers is an ongoing process, driven by research and development efforts in the drilling industry. Manufacturers, service providers, and research institutions continually explore new materials, cutting technologies, and design innovations to enhance reamer performance, durability, and efficiency. This ongoing research contributes to the evolution of diamond reamers and their application in challenging drilling environments.
Diamond reamers are versatile tools that play a vital role in various stages of well construction. Their continuous improvement and adaptation to specific drilling conditions contribute to more efficient and successful drilling operations.
Model or type:
Specifications
| ITEM | DIAMOND BIT | Reaming shell | |||||
| "Q" Series Wireline assembly |
Size | Bit Outer Diameter | Bit Inner Diameter | ||||
| mm | inch | mm | inch | mm | inch | ||
| AQ | 47.60 | 1.88 | 26.97 | 1.06 | 48.00 | 1.89 | |
| BQ | 59.50 | 2.35 | 36.40 | 1.43 | 59.90 | 2.36 | |
| NQ | 75.30 | 2.97 | 47.60 | 1.88 | 75.70 | 2.98 | |
| HQ | 95.58 | 3.77 | 63.50 | 2.50 | 96.00 | 3.78 | |
| PQ | 122.00 | 4.80 | 84.96 | 3.35 | 122.60 | 4.83 | |
| Metric T2 Series | 36 | 36.0 | 1.417 | 22.0 | 0.866 | 36.3 | 1.429 |
| 46 | 46.0 | 1.811 | 32.0 | 1.260 | 46.3 | 1.823 | |
| 56 | 56.0 | 2.205 | 42.0 | 1.654 | 56.3 | 2.217 | |
| 66 | 66.0 | 2.598 | 52.0 | 2.047 | 66.3 | 2.610 | |
| 76 | 76.0 | 2.992 | 62.0 | 2.441 | 76.3 | 3.004 | |
| 86 | 86.0 | 3.386 | 72.0 | 2.835 | 86.3 | 3.398 | |
| 101 | 101.0 | 3.976 | 84.0 | 3.307 | 101.3 | 3.988 | |
T Series |
TAW | 47.6 | 1.875 | 23.2 | 1.31 | 48.0 | 1.89 |
| TBW | 59.5 | 2.345 | 44.9 | 1.77 | 59.9 | 2.36 | |
| TNW | 75.3 | 2.965 | 60.5 | 2.38 | 75.7 | 2.98 |
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| Reaming classification | |
| T series | T36,T46,T56,T66,T76,T86 |
| Cable series | AWL,BWL,NWL,HWL,PWL(Front end,rear end) |
| WT series | RWT,EWT,AWT,BWT,NWT,HWT(single tube/double tube) |
| T2/T series | T256,T266,T276,T286,T2101,T676,T686,T6101,T6116,T6131,T6146,T6H |
| WF series | HWF,PWF,SWF,UWF,ZWF |
| WG series | EWG,AWG,BWG,NWG,HWG(single tube/double tube) |
| WM series | EWM,AWM,BWM,NWM |
| Others | NMLC,HMLC,LTK48,LTK60,TBW,TNW,ATW,BTW,NTW,AQTK NXD3,NXC,T6H,SK6L146,TT46,TB56,TS116,CHD101 |
Q&A:
Q1. Why is blowout prevention critical for HPHT reaming?
A1. Well control infrastructure with tested equipment/personnel capabilities are mandatory to avert potential consequences under extremes from shallow-to-deep high-pressure zones.
Q2. How does reactive shale impact reaming differently than competent rocks?
A2. Weaker formations prone to swelling/structural damage require inhibition, stabilization, and lower pressures to avoid accelerated wellbore deterioration.
Q3. How does oil-based mud influence reaming differently than water-based?
A3. Lower density necessitates enhanced hydraulics/cuttings transport with environmental mitigations for the more toxic synthetic fluids compared to common water muds.
Q4. What factors impact MPD performance for long extended laterals?
A4. Modeling downhole conditions optimizes automated pressures compensating friction losses to maintain control/cleaning across considerable intervals far removed from surface.
Q5. Why isMANAGED PRESSURE important for depleted reservoir re-entry?
A5 Precisely regulating pressures into fragile void-laden intervals prevents losses without damage, enabling restimulation of compromised abandoned zones previously bypassed as uneconomic with standard methods.
Q6. How does HPHT geology impact operations compared to normal pressure?
A6 Specialized bottomhole environments necessitate temperature/wear-resistant components, precision controls maintaining stabilization across narrow extreme profiles conventional tools cannot access without modification or failure.
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