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An organoclay grade for high-pressure, high-temperature (HPHT) drilling cannot be selected from a powder specification or a single room-temperature viscosity result. The decision depends on how the complete oil-based mud behaves after exposure to the well's planned temperature, pressure, shear history and static period. Compare low-shear rheology, gel recovery, barite sag, emulsion stability and filtration before and after the chosen aging program. This page is for mud engineers designing an HPHT OBM or SBM, especially where suspension and restart behavior are critical. Camp-Shinning can provide candidate grades and documents for a controlled laboratory comparison; no universal temperature rating is asserted here.
Temperature and pressure can alter base-fluid viscosity, emulsion stability and the interactions between organoclay, emulsifier and solids. A sample that appears adequate before aging may show weak suspension, excessive structure or changed filtration afterward. HPHT is therefore a fluid-system test condition, not a blanket label attached to a grade. For standard oil-based mud selection see OBM drilling fluids; for the wider material topic see high-temperature stability.
| Candidate | Public basis | Additional HPHT evidence required |
|---|---|---|
| CP-992 | Wet-process grade for oil-based and synthetic muds, with public easy-dispersion claim | A signed, grade-specific HPHT aging report in a comparable formulation |
| CP-982 | Conventional OBM candidate; its public page describes moderate-temperature use | Use as a comparison/control only where the planned conditions fit its documented range |
| Other documented grades via Product Finder | Grade-specific screening | Current TDS, lot COA and matching formulation data |
Do not transfer a limit or result from another grade or base oil. Ask the technical team to identify the exact test formulation, aging duration and temperature/pressure conditions behind any proposed rating.
Build control and candidate muds with the same base oil, emulsion package, oil/water ratio, solids and density. Record the organoclay addition level and mixing energy. Measure baseline rheology and electrical stability, then age each mud at the engineering program’s specified conditions. After aging, record 600/300 rpm and low-shear readings, yield point, 10-second/10-minute gel, electrical stability, density and static/dynamic sag. Record the instrument temperature; cooled readings alone do not describe downhole behavior. Use the current laboratory method applicable to the system, including ISO 10414-2 for oil-based fluid characteristics. The final accept/reject limits come from the well program, not this page.
The filter cake and filtrate can change when emulsion and solids distribution change, while extra clay can alter rheology and pumpability. Run the required HPHT filtration test on the same aged formulations used for rheology comparisons. Report filter medium, pressure differential, test temperature, duration, filtrate volume and cake observations. The fluid loss control guide explains why a lower filtrate volume cannot be credited to organoclay without a matched control.
| Report field | Control | Candidate | Required note |
|---|---|---|---|
| Base oil and complete additive package | Record actual measured value | Identical formulation except candidate | State all differences |
| Aging temperature, pressure, duration | Record actual measured value | Identical condition | No unqualified “HPHT stable” claim |
| Pre/post-aging YP, gels, low-shear readings | Record actual measured value | Record actual measured value | Include units and instrument temperature |
| Static/dynamic sag | Record actual measured value | Record actual measured value | State orientation and static time |
| HPHT filtrate and cake observations | Record actual measured value | Record actual measured value | State medium and differential pressure |
Use each grade’s TDS addition route: disperse it in the actual base fluid under specified shear before evaluating the complete emulsion and weighted mud. Confirm the activator requirement for that grade; do not treat easy dispersion as proof of self-activation. If gel collapses after aging, examine organoclay/base-oil match, emulsion condition, contamination and aging procedure. If gel rises excessively, inspect treatment level and solids loading. If sag or filtration worsens, change one formulation variable at a time and repeat the matched trial. Do not use this page for a water-based HPHT mud; follow the WBM application and its separate test plan.
Request a grade-specific laboratory report with the complete mud recipe, method, aging conditions and measured before/after values. Match those conditions to the planned well before setting a numerical acceptance threshold or using a field case as a reference.
What makes a drilling fluid HPHT? The well program defines the temperature/pressure conditions and acceptance criteria; a generic label alone is insufficient.
Is CP-992 automatically suitable for every HPHT well? No. It is a candidate for testing, and grade-specific results must match the planned conditions.
Which rheology result matters most? Evaluate low-shear behavior, yield point, gel development and restart/pumpability together.
Should filtration be measured before or after aging? Both are informative; the acceptance decision needs the condition specified by the well program.
Can room-temperature testing confirm downhole suspension? No. Include elevated-condition testing and an appropriate sag method.
Does an ISO/API test method certify the organoclay? No. It specifies how the fluid is tested, not an automatic product approval.
What should I send for grade screening? Base oil, oil/water ratio, density, peak and sustained temperatures, aging time, shear equipment and acceptance limits.
Request current grade documents, samples and an HPHT comparison plan. See oilfield applications and grade selection.
By CP Organoclay · Updated 24 September 2026. For grade-specific technical review, contact the Camp-Shinning Application Technology Team with your complete fluid formulation and test conditions.
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