| Type: | Core Drill |
|---|---|
| Usage: | Core Drilling |
| Certification: | CE, ISO |
| Application: | Reaming |
| Industry: | Geological Survey |
| Payment Term: | T/T or L/C |
| Samples: |
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| Customization: |
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Some more details about diamond reamers:
Reamer size ranges: Diamond reamers are available in a wide range of sizes to accommodate different wellbore diameters. They can be as small as a few inches in diameter for shallow wells or as large as several feet for deepwater or ultra-deepwater drilling. The size of the reamer is determined based on the desired wellbore diameter and the specific drilling objectives.
Reamer types: Diamond reamers can be classified into various types based on their design and functionality. Some common types include roller cone reamers, polycrystalline diamond compact (PDC) reamers, and impregnated diamond reamers. Each type has its own advantages and is suitable for specific drilling conditions and formations.
Reamer run optimization: Optimizing the timing and duration of the reamer run is crucial for efficient drilling operations. Factors such as the formation characteristics, drilling fluid properties, and drilling parameters are considered when determining the optimal run length for the reamer. This ensures effective wellbore enlargement while minimizing operational risks and costs.
Reamer cutters and cutter arrangements: Diamond reamers utilize various types of cutters, including natural diamond cutters and synthetic diamond cutters. The cutters are strategically arranged on the reamer body to ensure efficient cutting action and debris removal. Cutter arrangements can vary, ranging from spiral arrangements to staggered or offset patterns, depending on the specific reamer design and drilling requirements.
Reamer run evaluation: After a reamer run, an evaluation is conducted to assess its performance and the quality of the wellbore enlargement. This evaluation involves inspecting the reamer for wear, examining the condition of the cutters, and analyzing the wellbore geometry. The data gathered from the evaluation helps in optimizing future reamer runs and improving overall drilling efficiency.
Reamer compatibility with drilling fluids: Diamond reamers are designed to perform effectively in various drilling fluid environments. They can withstand the abrasiveness and corrosiveness of different drilling fluids, including water-based muds, oil-based muds, and synthetic-based muds. The reamer's materials, coatings, and cutter designs are selected to ensure compatibility and durability in specific drilling fluid systems.
Reamer deployment in underreaming operations: Diamond reamers are frequently used in underreaming operations, where they are deployed to enlarge the wellbore diameter below the casing shoe. Underreaming helps facilitate proper cementing and casing placement, enhances wellbore stability, and improves well productivity. Diamond reamers designed for underreaming operations feature specific cutting structures and robust construction to handle the challenging downhole conditions.
Reamer inspection and quality control: Manufacturers and service providers follow strict quality control procedures to ensure the reliability and performance of diamond reamers. Reamers undergo rigorous inspection and testing processes, including dimensional checks, cutter quality assessments, and structural integrity evaluations. This quality control ensures that the reamers meet industry standards and perform effectively in demanding drilling environments.
Diamond reamers continue to evolve as drilling technologies advance and drilling challenges become more complex. Ongoing research and development efforts focus on enhancing reamer performance, durability, and compatibility with emerging drilling techniques and formations. These advancements contribute to improved drilling efficiency, reduced operational costs, and increased success rates in wellbore enlargement 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 |
|
| 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 drill string design important for highly deviated reaming?
Strength, fatigue life, sealing integrity, and handling torque/weight become critical across extended laterals to prevent failures maintaining downhole conditions over long reaches.
Q2. What challenges arise when reaming thin pay zones or depleted sections?
Accurate exclusion/control prevents losses compromising targeted intervals while optimizing exposure evaluating remnant volumes through balanced pressures/fluids.
Q3. How does complex geology impact pressure management during reaming?
Changing lithology dictates vigilant control adjusting pumps based on downhole sensors to contain pressures across gradients without exceeding strengths or inducing uncontrolled flows.
Q4. Why is directional modeling beneficial for multi-lateral planning?
Simulations validate intersection points and curve tolerances selecting optimal BHA/parameters to drill multiple branches within design preventing costly misruns from trajectory inaccuracies.
Q5. What considerations apply for sour gas or H2S zone reaming?
Personnel safety and wellbore integrity require specialized non-sparking equipment, corrosion resistant alloy BHA, controlled annular pressures, and detailed hazard monitoring/elimination protocols.
Q6. Why is annular pressure important for horizontal laterals?
Managing friction/pressure losses across extended inclines maintains efficient hole cleaning/directional control despite degradation preventing stuck pipe without needing swab-prone density adjustments.
Q7. How does casing cementing benefit from smooth, centered holes?
Consistent zonal isolation results between borehole wall and installed strings through reinforced quality cement placement across intervals uniformly prepared by quality reaming techniques.
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