WELL CONTROL READINESS
RECOMMENDED BEST PRACTICES
When to perform a
Soak Test
• Before Deployment
• Consider performing abbreviated soak testing after initial recovery, before BWM begins
Test Step Duration
and Leak off rate
2 Primary configuration Modes:
1. Drilling (No PIPE) 1 hr (Per POD)
2. Non-Drilling (PIPE) 1 hr (Per POD)
• Configure BOP and allow Regulated Readback pressures to stabilize for 15 minutes.

• Apply MOPFLPS pressure for 30 minutes. Total System Pressure Leak Off Rate should not exceed a maximum of
3 psi/min over 5 minutes. If MOPFLPS is less than normal operating pressure start at normal operating pressure
• Rated working pressure (by OEM) for 30 minutes. Total System Pressure Leak Off Rate should not exceed a
maximum of 3 psi/min over 5 minutes.

• With Digital testing, along with visual inspection, these steps can usually be validated in 15 minutes
Minimum and
Maximum Pressures
• Non-shearing BOPs (Blind, Pipe, VBR).

• Minimum: MOPFLPS pressure
• Maximum: RWP by OEM.

• Sealing and non-sealing shear BOPs
• Minimum: Normal operating pressure
• Maximum: rated working pressure, or, highest pressure required to meet well shearing requirements.

• HP Close: RWP (Time at HP close may be abbreviated)
When latched to a
test stump without
digital monitoring
• •
• •
When latched to
a test stump with
digital monitoring
• Using software solutions to ensure no pressure differential across BOPs.

• Keep FSVs open when any BOPs are closed in Wellbore.

• Ensure there is always a wellbore bleed path when closing multiple BOPs
***Never close shear rams (UBSR, LBSR, or CSR) or other rams (e.g., UPR, LPR, MPR) without a bleed path.

To prevent high differential pressures from occurring, ensure the wellbore has no fluid.

If fluid is present in wellbore during soak testing,
soak test FSVs in open position while critical path functions are soak tested in closed position.

Ensure there is always a wellbore bleed path when closing multiple BOPs
***Never close shear rams (UBSR, LBSR, or CSR) or other rams (e.g., UPR, LPR, MPR) without a bleed path.

Leaking POD
Valves and
Regulators • Volumes to be physically taken and recorded for OEM tolerance reference.

• Reference OEM documentation in procedure for clarity.

Digitization of
leaks • If digital monitoring is available, collect physical fluid leak volumetric measurements, digital LOR data, digital
ROC data for further correlations.

BOP Control
systems with Fluid
Recovery Unit
• Since it is less likely to find leaks visually, digital monitoring is especially useful and can expedite fault finding
with system fully intact.

• By way of digital timeline of LOR increase
• Pressure trend anomaly correlation to a particular function.

Adjusting Regulators
• 500 psi (or less) increments allow for quicker stabilization with BOPs on Deck
QA/QC • Use of two person HOLD POINTS - Quality checkpoints that shall be completed before moving forward with a
procedure. • This may require verification by more than one party. Measurement verification, Workflow approvals, multi-
party collaborations, Troubleshooting, BOP and Test joint compatibility.

QA/QC • Critical hold points should require an Area Authority Approval to proceed. Sr. SSE, TP, STP, DSL, OIM, CM, ARM
HPU System
(e.g., 5K system)
• •
• •
Function Lock Outs
• Perform Function Lock outs whenever available. Software or Physical (Shear Rams particularly)
• This can be digitally verified as a QA/QC function
Test Joint
Installation • Verify Seals on test joint if applicable.

• Confirm BOP configuration is compatible with Test Joint size prior to installation in wellbore
BWM Time/Scope
Constraints Do not abbreviate Soak Testing without an MOC.

All Accumulators Isolated except one 12x15 gallon accumulator rack.

System Pressurized to 5000 psi
HPU Pumps OFF
Isolated racks should be bled below 4000 psi
Table 1: The full proposed initial draft submitted to the API Standard 53 subcommittee on soak testing best practices
24 SEPTEMBER/OCTOBER 2023 • DRILLING CONTRACTOR




WELL CONTROL READINESS
RECOMMENDED BEST PRACTICES (CONTINUED)
Prior to soak test,
complete: • EDS
• EHBS
• Function test
• Acoustic testing
• Pressure testing
• Setting of accumulator Pre-charge
Pre-deployment electrical integrity tests
After soak test
• •
• •
Remedial actions
Administrative • Include a section for handwritten notes for each test section of your RSOP. This will assist in creating
maintenance actions within your maintenance management systems.

Digital Troubleshooting
• Monitoring Pilot readback will give a good indication to where an issue is rooted. E.g.: working pressure – pilot
pressure = differential
• Pressure trend shape recognition can be informative to the root cause of pressure oscillations.

• Remote monitoring can expedite troubleshooting if communication between onshore and offshore teams is in
place prior to beginning tests.

Troubleshooting PODS Isolating
Systems • Certain OEMs have control POD “test” capabilities. When fault finding, there may be an advantage to placing
POD stingers inside of their test ring to determine where the leak or leak off is originating from. (CAUTION: Start
with lower pressures as to not wash stinger seals.)
Drift BOPs
Skid BOPs to Well Center
Check Stack and LMRP Bullseyes once Stack is picked up on first joint of riser.

Complete all Pre-deployment testing administrative duties
For acronyms not currently existing in STD 53
POD – Point Of Distribution
RSOP – Rig Specific Operating Procedure
LOR – Leak Off Rate
ROC – Rate Of Change
BWM – Between Well Maintenance
MOPFLPS – Minimum Operating Pressure For
Low Pressure Seal
Sr. / SSE – Senior / Subsea Engineer
TP – Toolpusher
OIM – Offshore Installation Manager
DSL – Drilling Section Leader
ARM – Assistant Rig Manger
STP – Senior Toolpusher
CM – Chief Mate
DRILLING CONTRACTOR • SEPTEMBER/OCTOBER 2023
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