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Short answer: casing pressure tests verify that the installed casing and its pressure-containing system can hold the required pressure; pressure-integrity, formation-integrity and leak-off tests characterize how much pressure the formation below the casing shoe can safely withstand; cement bond logs investigate whether cement is properly coupled to casing and formation; and temperature logs look for thermal anomalies that may indicate fluid movement. They answer different questions and are normally interpreted as one well-integrity program, not as interchangeable tests.
The applicable pressure, hold time, logging schedule and pass/fail rule depend on the well design, maximum anticipated operating pressure, regulator and permit. The U.S., Canadian, Ontario, UK and EPA examples below illustrate how requirements work; they are not a single worldwide standard.
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What each test is designed to prove
A casing integrity program examines three possible barriers: the steel casing, the cement sheath around it and the surrounding formation. A pressure test measures containment, an acoustic cement log measures bonding, and a temperature log detects thermal evidence of flow. Formation tests measure the pressure capacity of rock below a casing shoe.
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Repair common Windows errors and clear accumulated junk for a smoother, more stable PC - no reinstall needed.Free scan · no reinstall| Method | Primary target | Measured signal | Typical timing | Acceptance or interpretation |
|---|---|---|---|---|
| Casing pressure test | Casing, connections and pressure-containing system | Pressure response during a hold | After cementing and before drilling the cement plug or drilling ahead | Required pressure is held; a specified pressure decline triggers investigation, repair or retest |
| Pressure-integrity test (PIT) | Formation immediately below a casing or liner shoe, with cemented shoe support | Pressure response while pumping against the formation | After drilling a short interval below the shoe | Result is used to set the next casing depth and drilling-fluid program |
| Formation-integrity test (FIT) | Formation pressure capacity | Response at a predetermined pressure below leak-off | After drilling below the shoe | Formation accepts the planned pressure without leak-off or fracture behavior |
| Leak-off test (LOT) | Formation’s onset of fluid entry and fracture initiation | Pressure-volume trend as fluid starts entering the formation | After drilling below the shoe | Leak-off point supplies an upper bound for the operating pressure window |
| Cement bond log (CBL) | Cement-to-casing and cement-to-formation coupling | Downhole acoustic response | After cementing when quality or zonal isolation is uncertain; before and after a remedial squeeze where required | Log interpretation identifies bonded, unbonded or questionable intervals |
| Temperature log | Flow paths or injection-related integrity conditions | Wellbore temperature profile and anomalies | During a permit-defined mechanical-integrity demonstration or investigation | Anomalies are interpreted with pressure, cement and other evidence |
A pressure hold can demonstrate that a barrier contains pressure without locating a cement-bond defect. Conversely, a log can indicate poor coupling or fluid movement even when a short pressure test does not reveal a leak. Choosing the test therefore starts with the suspected barrier and the decision that must be made.
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Casing pressure tests: proving the steel barrier before proceeding
What the test checks
The operator isolates the casing, applies pressure internally and observes the pressure response for the required period. The test covers the casing body, connections, wellhead or other pressure-containing components included by the procedure. It is a containment check; it does not, by itself, map the quality of cement around the pipe.
U.S. offshore example
Under 30 CFR §250.1609, before drilling the plug after cementing, all casing strings except drive or structural casing must be pressure tested. The cited rule specifies at least 200 psi for conductor casing. For deeper strings it specifies 500 psi or 0.22 psi per foot, whichever is greater. If pressure falls by more than 10% in 30 minutes, the operator must repair the problem and retest. These are U.S. offshore requirements for the cited rule, not universal values.
Canadian regulatory wording
Section 43 of the Canadian Oil and Gas Drilling and Production Regulations requires the operator, after installing and cementing casing and before drilling out the casing shoe, to pressure-test the casing to the value needed to confirm integrity for maximum anticipated operating pressure. The wording makes the design basis important: the test value is tied to the planned operating envelope, not a generic number that applies to every well.
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How to run and document a casing test
- Confirm the approved test pressure, hold duration, fluid, pressure gauge range and isolation points in the well program and permit.
- Verify that cement has reached the required condition and that plugs, valves, test pumps and lines are rated for the planned pressure.
- Fill and bleed the system as specified so trapped air does not distort the pressure response.
- Raise pressure in a controlled manner, stabilize it, then record start pressure, end pressure, elapsed time, temperature and any observed leak.
- Compare the measured decline with the governing acceptance rule. A failure requires a controlled diagnosis, repair and a complete retest; drilling should not continue on an unexplained loss.
PIT, FIT and LOT: testing the formation below the shoe
Pressure-integrity test (PIT)
A PIT is performed below a casing or liner shoe after drilling a short, fresh interval. The cited U.S. offshore rule in 30 CFR §250.427 requires at least 10 feet and no more than 50 feet of new hole below the shoe. The operator tests to formation leak-off pressure or an approved equivalent drilling-fluid weight, then combines the result with pore-pressure estimates and actual hole behavior. That information determines how deep the next casing string can safely be set and what drilling-fluid density can be used.
Leak-off test (LOT)
During a LOT, hydraulic pressure is increased until drilling fluid begins entering the formation and the rock starts to fracture. The pressure-volume trend changes at leak-off, providing a practical indication of the formation’s pressure limit at that shoe. Because the test intentionally approaches fracture initiation, pumping rate, volume, pressure-calibration quality and the test procedure must be controlled and recorded.
Formation-integrity test (FIT)
A FIT applies a predetermined pressure below the expected leak-off pressure. It answers a narrower operational question: can the formation accept the planned pressure without showing leak-off or fracture behavior? A FIT is not a substitute for a LOT when the program requires the actual leak-off point. The selected pressure must come from the approved well design or regulator, rather than an assumed industry-wide value.
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Why formation results control drilling decisions
- The measured limit helps define the safe pressure window between expected pore pressure and formation breakdown.
- It can confirm that the cemented shoe and adjacent formation can support the planned drilling-fluid and well-control pressures.
- It provides a basis for casing depth, kick tolerance calculations and the next hole section’s fluid program.
- An unexpected early leak-off, inability to reach the planned pressure or unusual volume response requires engineering review before drilling ahead.
Cement bond logs: investigating cement and zonal isolation
What a CBL measures
A cement bond log is a downhole acoustic evaluation of how cement is coupled to the casing and formation. The tool response is interpreted over depth to identify intervals where cement appears bonded, partially bonded or unbonded. The log is especially useful when cement quality, channeling or zonal isolation is in doubt.
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When a CBL is useful
- Pressure testing shows containment but cannot identify whether a suspected issue is in the cement sheath, casing or another component.
- There is concern about a cementing job, a possible channel or communication between zones.
- A remedial cement squeeze is being considered and the operator needs to identify the interval requiring treatment.
- Regulation or a permit requires verification after remedial work.
Ontario standards call for a CBL before a remedial cement squeeze to identify the problem and after the squeeze to verify effectiveness. API TR 10TR1 covers cement-bond, compensated, ultrasonic and borehole-fluid-compensated cement-evaluation tools. The exact tool combination and interpretation criteria still depend on the well and the approved procedure.
Limits of acoustic interpretation
Acoustic logs are interpretation tools, not a direct photograph of the annulus. Tool centralization, casing size, borehole fluid, cement properties and formation conditions affect the response. A questionable interval should be evaluated with the operating history, cement records, pressure data and any required companion log rather than treated as an automatic proof of failure.
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Temperature logs: finding thermal evidence of movement
What a temperature log can reveal
A temperature log records the well’s temperature profile. An unexpected thermal anomaly may indicate fluid movement, injection-related behavior or another condition affecting mechanical integrity. The useful signal is often a change from the surrounding geothermal trend, so baseline conditions, logging speed and well operating state matter.
Why requirements are permit-specific
There is no universal temperature-log schedule. A permit may define the pressure state, stabilization time, logging direction, repeat frequency, depth interval and whether the temperature run must be combined with a CBL or radioactive-tracer log. An EPA draft permit illustrates this kind of well-specific mechanical-integrity requirement; its conditions should not be generalized to every injection or production well.
Interpreting temperature with other evidence
A temperature anomaly alone does not identify the exact leak path. Compare it with pressure behavior, cement-evaluation results, injection history and mechanical condition. A pressure test may establish containment while a temperature profile indicates movement under a different operating condition; together they can narrow the diagnosis and determine whether a more targeted investigation is needed.
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Choosing the right test for the integrity question
| If the immediate question is… | Start with… | What it can and cannot establish |
|---|---|---|
| Will the installed casing hold the planned pressure before drilling continues? | Casing pressure test | Establishes pressure containment under the test conditions; does not localize a cement defect. |
| How much pressure can the formation below the shoe withstand? | PIT, FIT or LOT as specified by the program | Characterizes formation capacity at that shoe; does not evaluate the full casing string. |
| Is cement coupled well enough to provide zonal isolation? | CBL or another approved cement-evaluation log | Provides interpreted bonding evidence; response depends on tool and well conditions. |
| Could fluid be moving behind pipe or into an injection interval? | Temperature log, often with pressure and cement evaluation | Shows thermal evidence of movement; normally cannot identify a path by itself. |
| Did a remedial squeeze fix the identified interval? | Post-squeeze CBL plus the required pressure demonstration | Checks cement response and containment using complementary evidence. |
Typical integrity workflow from cementing to drilling ahead
- Define the design basis. Record maximum anticipated operating pressure, casing design, cement objectives, formation pressures, regulator and permit conditions.
- Test the installed casing. After cementing and before drilling the plug or shoe, apply the approved casing pressure and document the hold.
- Investigate anomalies before drilling. If the pressure decline exceeds the applicable limit or a component leaks, isolate the source, repair it and retest.
- Drill the specified interval below the shoe. For the cited U.S. PIT rule, this is 10–50 feet of new hole; other jurisdictions or programs may differ.
- Run the approved formation test. Use a PIT, FIT or LOT according to the drilling program, and record pressure, volume, rate and formation response.
- Update the drilling window. Use the result with pore-pressure and hole-behavior observations to confirm casing depth and fluid density limits.
- Evaluate cement where uncertainty remains. Run a CBL or approved alternative when cement quality or zonal isolation is in doubt, and follow any pre- or post-squeeze requirement.
- Demonstrate mechanical integrity under the permit. Add temperature logging, tracer logging or repeat pressure testing when the permit or regulator requires it.
- Close the record. Preserve calibrated-gauge data, test charts, cement records, log files, interpretation, anomalies, repairs and retest results in the well file.
Common failure modes and practical responses
Pressure drops during a casing hold
First distinguish a real leak from temperature changes, trapped air, gauge error, pump or valve leakage and line expansion. Recheck the isolation and instrumentation, then perform the approved diagnostic. If the governing rule’s decline threshold is exceeded, repair and retest rather than accepting a marginal hold.
Unexpectedly low PIT or LOT result
Stop and compare the result with the planned formation pressure, mud weight, test interval and shoe condition. A weak or poorly supported shoe, an unsuitable test interval or a genuine formation limit can each produce an early response. The next casing depth and fluid program should be revised only through the approved engineering and regulatory process.
CBL indicates questionable bonding
Check tool quality, centralization, borehole fluid and the interpretation interval before deciding on remedial cement. If a squeeze is required, Ontario’s cited practice calls for a CBL before treatment and another after it to verify the result.
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Review the well’s operating state, stabilization time, logging speed and baseline profile. Repeat or combine the temperature run with the permit-required pressure, cement or tracer evaluation; do not infer a specific leak path from a single thermal feature.
Records and acceptance decisions
Every test report should identify the well, casing or shoe, depth, date, fluid, gauge and calibration status, applied pressure, rate, hold duration, start and end readings, temperature, observed volume, interpretation and disposition. State the governing rule or permit beside each acceptance criterion. This prevents a jurisdiction-specific value—such as the U.S. 200 psi conductor example, the 500 psi or 0.22 psi/ft deeper-string example, or the 10% decline in 30 minutes—from being misapplied to another well.
Regulators and operators should also distinguish a test result from an interpretation. A pressure trace is evidence of containment under defined conditions; a CBL or temperature log is interpreted evidence about bonding or movement. Combining the appropriate signals gives a stronger integrity decision than treating any one method as a universal pass/fail test.
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