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Purpose-built Big Size Insert Drill Bit for hard and abrasive formations where gauge retention and bit life drive cost-per-foot.
Professional Insert Drill Bit with a dense TCI cutting structure that resists wear and stays on gauge through long intervals.
Balanced, Rotary Roller Insert Drill Bit geometry delivers a controlled bite, stable torque, and predictable ROP in sandstone, limestone, and dolomite.
Three-jet hydraulics sweep bottom-hole clean so the inserts cut crisply instead of regrinding fines.
Standard 6 5/8 API REG connection for quick rig-up and cross-fleet compatibility.
Fully Customized Insert Drill Bit options for nozzles, seals, gauge armor, and IADC tuning to align with your geology, mud program, and KPI stack.
637
1
tianjin ,shanghai
water well,oil well,HDD,exploration,etc
100% New
| Quantity: | |
|---|---|
When crews talk about “the bit that just stays on size,” they’re describing a TCI 637 workhorse like this 9 7/8" model. On bottom it feels composed—no chatter, no drama—just a steady pull as the cones seat and the inserts bite. The jets make that clean, even hiss that tells you cuttings are being swept away before they recirculate. Drillers notice the difference at the brake: torque is smoother, weight transfer is easier to hold, and ROP does not fall off a cliff as hours accumulate.
This is not a generic tri-cone. It is a Professional Insert Drill Bit engineered for hard-rock economics—fewer mid-run trips, cleaner hole condition, and a predictable torque signature that keeps the BHA happy. Whether you are driving footage through abrasive sand sequences, interbedded hard streaks, or tight limestone, the combination of TCI geometry, sealed bearings, and robust gauge protection is designed to deliver footage with discipline. If your goal is reliable penetration and consistent diameter on long sections, this 9 7/8" 637 is the dependable choice.
| Parameter | Value |
|---|---|
| Bit Size | 9 7/8" (250.8 mm) |
| IADC Code | 637 (TCI) |
| Series | HR |
| Connection | 6 5/8 API REG PIN |
| Bearing / Seal | Rubber sealed bearing |
| Nozzle | Three jet nozzles |
| Recommended RPM | 80–40 |
| Recommended WOB | 0.5–1.2 kN/mm |
| Applications | Water well, oil well, HDD, exploration |
| Suitable Formations | Hard formations with high compressive strength (e.g., sandstone, limestone, dolomite) |
Hard-rock tuned TCI structure: Short conical/spherical inserts and aggressive gauge rows maintain diameter and ROP in abrasive intervals.
Stable, sealed rotation: Rubber-sealed journal bearing holds lubrication, isolates solids, and supports smooth torque at disciplined WOB.
Hydraulics that protect ROP: Three-jet configuration targets cone bottoms and faces, clearing swarf and reducing regrind.
API-ready connectivity: 6 5/8 API REG interface integrates with heavy-duty BHAs and standard rig practices.
Customization without compromise: Nozzle orifice sets, extra hardfacing, gauge/shirttail armor, and alternative seal systems to match temperature, mud, and risk profile.
B2B reliability: Traceable build records, pre-shipment inspection, and packaging that arrives rig-ready with labeled nozzle IDs and pin protection.
What it means operationally: IADC codes align bit geometry to lithology, enabling faster bit selection and fewer surprises on bottom. TCI is the preferred path in hard and abrasive rock because inserts hold shape and gauge; milled tooth excels in soft-to-medium intervals where long steel teeth “slice” material at high ROP.
Quick reference
| IADC (Roller Cone) | Tooth Type | Formation Target | Operational Notes |
|---|---|---|---|
| 1XX–3XX | Milled Tooth | Soft → Medium | High ROP, larger cuttings, lower DP |
| 4XX–5XX | TCI | Medium | Transitional zones; balanced life/ROP |
| 6XX–7XX | TCI | Medium-Hard → Hard | Abrasive sands, limestone, dolomite; strong gauge retention |
How this product fits: 637 sits in the hard-rock end of the TCI family. Expect disciplined WOB, moderate rpm, and long, steady footage with reduced diameter loss.
Engineering lens: The bearing system sets the ceiling for run length and stability. For hard formations and longer intervals, sealed journal bearings are the default, keeping the rotation smooth and protected from solids.
Open Bearing: Lowest initial cost for short, benign runs; more exposure to solids and shorter life.
Sealed Journal: The reliability standard for hard-rock; preserves lubricant, blocks solids, and stabilizes cone tracking under load.
Rubber O-ring Seals: Proven, economical sealing for typical temperatures and conventional run lengths.
Metal Face Seals: Higher temperature/pressure tolerance, favored for deep, hot, or extended runs.
Decision signals
Choose O-ring when cost control and standard temperature dominate.
Choose metal face when heat or ultra-long footage is in play.
Journal bearings typically provide the smoothest torque in hard rock; pair with conservative rpm and clean hydraulics.
Keep the hole on size. Gauge preservation does more than avoid reaming; it stabilizes the BHA, reduces torque spikes, and supports cleaner trajectory control.
Gauge Inserts: Carbide compacts in the outer rows defend diameter through abrasive sections.
Hardfacing: Wear-resistant overlays on the gauge and shoulders delay washout and extend useful life.
Shirttail Armor: Reinforced heel protection where flow converges; resists erosion and strand-out damage.
Implementation checklist
Specify gauge row layout and hardfacing thickness for your solids load.
Add enhanced shirttail pads when running high GPM or weighted mud.
After trip, inspect gauge wear flats to tune the next bit order.
Clean bottom-hole, protect ROP, and manage standpipe pressure. Three jets are the proven baseline for scouring the cone bottoms and faces so inserts stay cutting instead of rubbing. The goal sound is uniform and crisp—evidence that fines are being swept clear, not recirculated.
Execution framework
Define flow and surface pressure targets from your pump curve and mud weight.
Calculate jet impact force and confirm adequate HSI for your WOB and rpm plan.
Select a three-jet set that sweeps the bottom without eroding gauge armor.
Record nozzle IDs on the bit label; verify at QA before shipment.
Customization paths
Mixed orifice sizes by port to tune sweeping pattern.
Optional center-jet in problematic cleaning regimes.
Replaceable nozzle hardware for fast rig-side swaps.
Start controlled, tune from evidence. With a 9 7/8" 637 TCI, crews typically begin with moderate rpm and increase WOB in small steps until torque smooths and ROP rises without spiking standpipe pressure.
WOB: Add gradually; watch for a clean, linear ROP response. If torque climbs with no footage gain, pull back or improve cleaning.
RPM: Hold steady while you escalate WOB to isolate formation response; avoid skating which polishes inserts.
Flow: Raise until cuttings are sharp and discrete, not slurries of fines.
Torque Signature: “Quiet” torque indicates inserts are engaging; erratic spikes point to recirculation, overload, or nozzle mismatch.
Field routine
Log ROP, torque, differential pressure, and cuttings every stand.
Adjust one variable at a time for clean diagnostics.
Revisit nozzle IDs if cleaning lags behind WOB.
Fit for your BHA from day one. The bit ships with 6 5/8 API REG, which is the go-to connection for 9–12¼" classes in heavy-duty strings. Match the pin to collar OD, torque capacity, and hydraulic plan to avoid bottlenecks or over-torque.
Connection quick map
| Bit Class | Typical API REG | Notes |
|---|---|---|
| 6–8 ½ in | 4-1/2 REG | Lighter BHAs, smaller collars |
| 9–12 ¼ in | 6-5/8 REG | Standard heavy-duty choice |
| ≥12 ¼ in | 7-5/8 REG | Highest torque capacity strings |
Procurement tips
Request pin protector, doped threads, and a connection tag with make-up torque guidance.
Ask for thread-gage results and material traceability tied to serial number.
Align connection choice with expected motor/rotary torque envelope.
Water Well: Predictable footage in abrasive aquifers; clean samples from effective jetting.
Oil & Gas: Interbedded hard stringers where TCI gauge retention reduces mid-run trips.
Geothermal: Elevated temperatures and aggressive lithology; pair with metal seals when heat is high.
Mining/Exploration: Consistent hole size for sampling and tools; minimized reaming improves schedule certainty.
HDD: Stable trajectory in abrasive urban formations; controlled cutting action reduces over-gauging and pullback issues.
Operational value
Fewer bit trips, steadier torque, cleaner hole—benefits that roll up into lower cost-per-foot and tighter project control.
IADC & Tooth Geometry: Shift within TCI families or compare against Milled Tooth Insert Drill Bit options when soft zones dominate.
Hydraulics: Three-jet baselines with mixed orifice IDs; optional center-jet for stubborn cleaning challenges.
Gauge/Armor: Extra gauge inserts, heavy hardfacing, and enhanced shirttail pads for high-GPM programs.
Bearings/Seals: Rubber O-ring for standard duty; metal face seals for high temperature or extended footage.
Threading & Labeling: API pin options, serialized tracking, and nozzle kit labels to simplify rig-site QA.
Outcome: A Customized Insert Drill Bit that aligns ROP, footage per run, and trip frequency with your KPI targets—without over-engineering cost.
Dimensional Control: Body OD, gauge diameter, cone runout, nozzle IDs, and thread profile recorded against serial number.
Thread Integrity: API thread gage pass/fail results, doped and protected for shipment.
Materials & Heat-Treat: MTRs and heat-treat charts maintained for audit.
Functional Checks: Lubrication fill, seal integrity, and balanced rotation verified.
Documentation & Media: Outgoing inspection report plus optional video; processes aligned with ISO 9001 and API practices.
Packaging: Export-grade wooden case, cone locks, and external spec labeling for rapid yard acceptance.
Result: Lower receiving risk, faster rig readiness, and fewer surprises on bottom.
Lower cost-per-foot: Gauge retention and sealed stability reduce nonproductive trips and sustain ROP in abrasive intervals.
Predictable for crews: Smooth torque and clean hydraulics make it easier to hold weight and rpm—less fighting the string, more footage.
Traceable quality: API-aligned connections, recorded gaging, and serial-linked documentation support your QA audits.
B2B-first service: Engineering review of logs, nozzle/orifice pre-set to your flow, and armor choices locked before shipment.
MOQ & Lead Time: Typical MOQ of 1 piece; standard builds and small lots often ship within common industry lead times depending on stock and customization.
Packaging: Plywood/wooden export cases with cone locks and thread protectors; external labels listing bit size, IADC, and nozzle IDs for instant rig-site identification.
Logistics: Flexible dispatch via sea or air from major ports; scheduling aligned to spud dates.
Documentation: Inspection reports and optional video; ISO/API credentials available on request.
After-Sales: Technical selection support, post-run reviews, and quick-turn spares.
Yes, if your logs indicate hard, high-compressive formations such as abrasive sandstone, tight limestone, or dolomite. For softer intervals, consider a milled tooth configuration or a lower IADC within the TCI family.
Absolutely. Metal face seals extend temperature and pressure tolerance and are preferred for deep or hot wells and extended intervals. We will confirm compatibility with your operating envelope.
Begin within the recommended window for this bit size and IADC—moderate rpm and incremental WOB increases—then tune off torque smoothness, cuttings shape, and standpipe stability.
Yes. We can preset nozzle orifices to your target flow and standpipe pressure, add extra gauge inserts and hardfacing, and enhance shirttail pads for high-GPM programs.
Each bit ships rig-ready with pin protector, nozzle set installed and labeled, and a specification/inspection packet. On request, we include outgoing video inspection and serial-linked documents for your QA files.
When crews talk about “the bit that just stays on size,” they’re describing a TCI 637 workhorse like this 9 7/8" model. On bottom it feels composed—no chatter, no drama—just a steady pull as the cones seat and the inserts bite. The jets make that clean, even hiss that tells you cuttings are being swept away before they recirculate. Drillers notice the difference at the brake: torque is smoother, weight transfer is easier to hold, and ROP does not fall off a cliff as hours accumulate.
This is not a generic tri-cone. It is a Professional Insert Drill Bit engineered for hard-rock economics—fewer mid-run trips, cleaner hole condition, and a predictable torque signature that keeps the BHA happy. Whether you are driving footage through abrasive sand sequences, interbedded hard streaks, or tight limestone, the combination of TCI geometry, sealed bearings, and robust gauge protection is designed to deliver footage with discipline. If your goal is reliable penetration and consistent diameter on long sections, this 9 7/8" 637 is the dependable choice.
| Parameter | Value |
|---|---|
| Bit Size | 9 7/8" (250.8 mm) |
| IADC Code | 637 (TCI) |
| Series | HR |
| Connection | 6 5/8 API REG PIN |
| Bearing / Seal | Rubber sealed bearing |
| Nozzle | Three jet nozzles |
| Recommended RPM | 80–40 |
| Recommended WOB | 0.5–1.2 kN/mm |
| Applications | Water well, oil well, HDD, exploration |
| Suitable Formations | Hard formations with high compressive strength (e.g., sandstone, limestone, dolomite) |
Hard-rock tuned TCI structure: Short conical/spherical inserts and aggressive gauge rows maintain diameter and ROP in abrasive intervals.
Stable, sealed rotation: Rubber-sealed journal bearing holds lubrication, isolates solids, and supports smooth torque at disciplined WOB.
Hydraulics that protect ROP: Three-jet configuration targets cone bottoms and faces, clearing swarf and reducing regrind.
API-ready connectivity: 6 5/8 API REG interface integrates with heavy-duty BHAs and standard rig practices.
Customization without compromise: Nozzle orifice sets, extra hardfacing, gauge/shirttail armor, and alternative seal systems to match temperature, mud, and risk profile.
B2B reliability: Traceable build records, pre-shipment inspection, and packaging that arrives rig-ready with labeled nozzle IDs and pin protection.
What it means operationally: IADC codes align bit geometry to lithology, enabling faster bit selection and fewer surprises on bottom. TCI is the preferred path in hard and abrasive rock because inserts hold shape and gauge; milled tooth excels in soft-to-medium intervals where long steel teeth “slice” material at high ROP.
Quick reference
| IADC (Roller Cone) | Tooth Type | Formation Target | Operational Notes |
|---|---|---|---|
| 1XX–3XX | Milled Tooth | Soft → Medium | High ROP, larger cuttings, lower DP |
| 4XX–5XX | TCI | Medium | Transitional zones; balanced life/ROP |
| 6XX–7XX | TCI | Medium-Hard → Hard | Abrasive sands, limestone, dolomite; strong gauge retention |
How this product fits: 637 sits in the hard-rock end of the TCI family. Expect disciplined WOB, moderate rpm, and long, steady footage with reduced diameter loss.
Engineering lens: The bearing system sets the ceiling for run length and stability. For hard formations and longer intervals, sealed journal bearings are the default, keeping the rotation smooth and protected from solids.
Open Bearing: Lowest initial cost for short, benign runs; more exposure to solids and shorter life.
Sealed Journal: The reliability standard for hard-rock; preserves lubricant, blocks solids, and stabilizes cone tracking under load.
Rubber O-ring Seals: Proven, economical sealing for typical temperatures and conventional run lengths.
Metal Face Seals: Higher temperature/pressure tolerance, favored for deep, hot, or extended runs.
Decision signals
Choose O-ring when cost control and standard temperature dominate.
Choose metal face when heat or ultra-long footage is in play.
Journal bearings typically provide the smoothest torque in hard rock; pair with conservative rpm and clean hydraulics.
Keep the hole on size. Gauge preservation does more than avoid reaming; it stabilizes the BHA, reduces torque spikes, and supports cleaner trajectory control.
Gauge Inserts: Carbide compacts in the outer rows defend diameter through abrasive sections.
Hardfacing: Wear-resistant overlays on the gauge and shoulders delay washout and extend useful life.
Shirttail Armor: Reinforced heel protection where flow converges; resists erosion and strand-out damage.
Implementation checklist
Specify gauge row layout and hardfacing thickness for your solids load.
Add enhanced shirttail pads when running high GPM or weighted mud.
After trip, inspect gauge wear flats to tune the next bit order.
Clean bottom-hole, protect ROP, and manage standpipe pressure. Three jets are the proven baseline for scouring the cone bottoms and faces so inserts stay cutting instead of rubbing. The goal sound is uniform and crisp—evidence that fines are being swept clear, not recirculated.
Execution framework
Define flow and surface pressure targets from your pump curve and mud weight.
Calculate jet impact force and confirm adequate HSI for your WOB and rpm plan.
Select a three-jet set that sweeps the bottom without eroding gauge armor.
Record nozzle IDs on the bit label; verify at QA before shipment.
Customization paths
Mixed orifice sizes by port to tune sweeping pattern.
Optional center-jet in problematic cleaning regimes.
Replaceable nozzle hardware for fast rig-side swaps.
Start controlled, tune from evidence. With a 9 7/8" 637 TCI, crews typically begin with moderate rpm and increase WOB in small steps until torque smooths and ROP rises without spiking standpipe pressure.
WOB: Add gradually; watch for a clean, linear ROP response. If torque climbs with no footage gain, pull back or improve cleaning.
RPM: Hold steady while you escalate WOB to isolate formation response; avoid skating which polishes inserts.
Flow: Raise until cuttings are sharp and discrete, not slurries of fines.
Torque Signature: “Quiet” torque indicates inserts are engaging; erratic spikes point to recirculation, overload, or nozzle mismatch.
Field routine
Log ROP, torque, differential pressure, and cuttings every stand.
Adjust one variable at a time for clean diagnostics.
Revisit nozzle IDs if cleaning lags behind WOB.
Fit for your BHA from day one. The bit ships with 6 5/8 API REG, which is the go-to connection for 9–12¼" classes in heavy-duty strings. Match the pin to collar OD, torque capacity, and hydraulic plan to avoid bottlenecks or over-torque.
Connection quick map
| Bit Class | Typical API REG | Notes |
|---|---|---|
| 6–8 ½ in | 4-1/2 REG | Lighter BHAs, smaller collars |
| 9–12 ¼ in | 6-5/8 REG | Standard heavy-duty choice |
| ≥12 ¼ in | 7-5/8 REG | Highest torque capacity strings |
Procurement tips
Request pin protector, doped threads, and a connection tag with make-up torque guidance.
Ask for thread-gage results and material traceability tied to serial number.
Align connection choice with expected motor/rotary torque envelope.
Water Well: Predictable footage in abrasive aquifers; clean samples from effective jetting.
Oil & Gas: Interbedded hard stringers where TCI gauge retention reduces mid-run trips.
Geothermal: Elevated temperatures and aggressive lithology; pair with metal seals when heat is high.
Mining/Exploration: Consistent hole size for sampling and tools; minimized reaming improves schedule certainty.
HDD: Stable trajectory in abrasive urban formations; controlled cutting action reduces over-gauging and pullback issues.
Operational value
Fewer bit trips, steadier torque, cleaner hole—benefits that roll up into lower cost-per-foot and tighter project control.
IADC & Tooth Geometry: Shift within TCI families or compare against Milled Tooth Insert Drill Bit options when soft zones dominate.
Hydraulics: Three-jet baselines with mixed orifice IDs; optional center-jet for stubborn cleaning challenges.
Gauge/Armor: Extra gauge inserts, heavy hardfacing, and enhanced shirttail pads for high-GPM programs.
Bearings/Seals: Rubber O-ring for standard duty; metal face seals for high temperature or extended footage.
Threading & Labeling: API pin options, serialized tracking, and nozzle kit labels to simplify rig-site QA.
Outcome: A Customized Insert Drill Bit that aligns ROP, footage per run, and trip frequency with your KPI targets—without over-engineering cost.
Dimensional Control: Body OD, gauge diameter, cone runout, nozzle IDs, and thread profile recorded against serial number.
Thread Integrity: API thread gage pass/fail results, doped and protected for shipment.
Materials & Heat-Treat: MTRs and heat-treat charts maintained for audit.
Functional Checks: Lubrication fill, seal integrity, and balanced rotation verified.
Documentation & Media: Outgoing inspection report plus optional video; processes aligned with ISO 9001 and API practices.
Packaging: Export-grade wooden case, cone locks, and external spec labeling for rapid yard acceptance.
Result: Lower receiving risk, faster rig readiness, and fewer surprises on bottom.
Lower cost-per-foot: Gauge retention and sealed stability reduce nonproductive trips and sustain ROP in abrasive intervals.
Predictable for crews: Smooth torque and clean hydraulics make it easier to hold weight and rpm—less fighting the string, more footage.
Traceable quality: API-aligned connections, recorded gaging, and serial-linked documentation support your QA audits.
B2B-first service: Engineering review of logs, nozzle/orifice pre-set to your flow, and armor choices locked before shipment.
MOQ & Lead Time: Typical MOQ of 1 piece; standard builds and small lots often ship within common industry lead times depending on stock and customization.
Packaging: Plywood/wooden export cases with cone locks and thread protectors; external labels listing bit size, IADC, and nozzle IDs for instant rig-site identification.
Logistics: Flexible dispatch via sea or air from major ports; scheduling aligned to spud dates.
Documentation: Inspection reports and optional video; ISO/API credentials available on request.
After-Sales: Technical selection support, post-run reviews, and quick-turn spares.
Yes, if your logs indicate hard, high-compressive formations such as abrasive sandstone, tight limestone, or dolomite. For softer intervals, consider a milled tooth configuration or a lower IADC within the TCI family.
Absolutely. Metal face seals extend temperature and pressure tolerance and are preferred for deep or hot wells and extended intervals. We will confirm compatibility with your operating envelope.
Begin within the recommended window for this bit size and IADC—moderate rpm and incremental WOB increases—then tune off torque smoothness, cuttings shape, and standpipe stability.
Yes. We can preset nozzle orifices to your target flow and standpipe pressure, add extra gauge inserts and hardfacing, and enhance shirttail pads for high-GPM programs.
Each bit ships rig-ready with pin protector, nozzle set installed and labeled, and a specification/inspection packet. On request, we include outgoing video inspection and serial-linked documents for your QA files.
