We are the missing link between rig heave and conditions downhole. Our proprietary simulation technology predicts variations in downhole pressure and flow, induced by rig heave during drilling and completion operations carried out from floating rigs. This helps managing risks related to breaching well pressure margins or damaging downhole tools as well as reduces weather-related non-productive time (WOW).
Read about our surge & swab simulation services
Our field-proven simulation technology has been utilized by operator companies worldwide. We can provide accurate rig heave limits throughout your well when drilling and/or installing liners, casings and completions. You will know exactly how much rig heave your well can take at all depths and for all operations. We can also calculate maximum recommended speed (RIH/POOH) for uncompensated tripping. Click here to see how our clients saved up to $1,000,000 investing only around $50,000 in simulations during well planning.
Reduce costs by tripping faster (optimized tripping speed throughout the well)
Reduce Waiting On Weather (WOW) by optimizing heave limits based on properties of YOUR well
Manage risk through early warning possible breach of well pressure margins
Safer drilling operations with less emissions
When the drill pipe is put in slips during break-out or connection of the next stand, the topside heave compensation of the drill string is disabled. The whole drill string starts to move up and down with the rig. Same thing happens when running liners/casings or installing completions.
When drill string, liner/casing, or completion moves downwards, there is a sudden increase in downhole pressure ("surge"), which can surpass fracture pressure and severely damage the well impairing its future productivity.
When drill string, liner/casing or completion moves upwards, there is a sudden decrease in downhole pressure ("swab"). If downhole pressure falls below the pore pressure hydrocarbons can start flowing into the wellbore. If downhole pressure falls below hole collapse limit the well section can collapse.
SURGES IN ANNULUS FLOW
Surge & swab induced by rig heave causes annular flow surges. Some tools in the string such as slips/packers are triggered by an increase in annulus flow. Completion string might be set prematurely if the flow limit is exceeded, leading to costly downtime. Other downhole tools might be damaged by excessive annulus flow. Heave limit recommendations, provided by equipment suppliers are usually generic and not tailored to your well.
DYNAMIC RIG HEAVE LIMIT™
We are experts at simulating the motion of the bit (and/or the end of the completion string, liner or casing) in relation to rig heave. Using our proprietary surge & swab simulator we perform calculations that take into account downhole surge & swab, pressure margins of your well and completion tool annulus flow limitations. Based on these calculations we come up with a recommendation of how much rig heave your well can take during connections and uncompensated tripping before the margins are breached. We provide customized recommendations for different depths in the well and different operations (drilling, running of liners/casings and installing completions). Our goal is that you know exactly how much rig heave your well can take at all times when heave compensation is disabled (for example during connections).
OTHER SIMULATION SERVICES
We are specialists in simulations of downhole pressure and flow and our services are cost-efficient and quick. We have experience with performing a wide range of studies where downhole conditions are in focus, for example operability studies for floating rigs in harsh weather environment based on limits of the wells to be drilled. Get in touch with us to discuss your needs and we will come up with a solution!
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Our simulator is a precise numerical model of the fluid dynamics coupled with the string dynamics. Specific heave time series can be applied as input to simulations, or they can be based on statistical wave data combined with a vessel specific response amplitude operator (RAO).
Flows and pressures inside the string and in the annulus, as well as below the string are dynamically simulated. String stress and velocity are also simulated to include the important effects of elasticity. A Herschel-Bulkley type rheology is used for the fluid, with frictional pressure drop calculations based on API recommended practice. Use of floating fluid inside the string can be configured for simulation of floating liners and casings.
The geometry configuration allows for different cross-sectional flow areas along the pipe and annulus, representing the different sections of a well such as riser, cased sections, liners, and open hole. A 3D well curvature is possible to configure, resulting in changed hydrostatic pressure and additional contact friction between the pipe and well wall/casing.
We get the drilling & well data and agree on the goals of the simulation
We develop timeseries with multiple simulations of downhole pressure variations at selected connection depths (usually 5-10 per well section)
We continuously compare simulated surge & swab pressures with provided well pressure margins and define maximum allowed rig heave that corresponds to surge & swab being equal to the well pressure margins at connection depth in question. To calculate rig heave limit related to maximum allowed flow past completion string packers we use simulated flow in the well induced by rig heave through surge & swab.
We provide a rig heave profile (we call it Dynamic Rig Heave™) through the well sections of interest.
We can also provide recommendations for running speed (RIH/POOH) for drill string, liners/casings and/or completion string. We are able to account for heave effects downhole if your rig is not equipped with active heave compensation of if you trip using elevators.
WHAT PEOPLE SAY
“No-one is offering a comparable commercial solution today, either for pre-planning or real time”
– Major operator company
Determination of Dynamic Limits for Rig Heave and Running Speed Based on Drilling Parameters, Well Data and Completion Tool Limitations - Case Studies
This paper is co-authored by Norske Shell and OMV. We present novel methodology for how to utilize rig heave limit in drilling & well operations and case studies from two wells in Norway.
Presentation at the SPE/IADC Drilling Conference and Exhibition (virtual)
Significant Surge and Swab Offshore Brazil Induced by Rig Heave During Drill Pipe Connections
The paper was presented by John-Morten Godhavn (Equinor). We simulated surge & swab during connections when drilling pre-salt reservoir section of a well on the Bacalhau field. Surge & swab magnitude was comparable to what we earlier recorded in the North Sea at higher rig heave. This can be explained by very long vertical trajectory of the well offering little friction to hold the drill string in place during connections. SPE-200518. The paper was also published in the SPE Drilling & Completion Journal.
Presentation at the SPE/IADC MPD Conference and Exhibition (virtual)
Verification of Downhole Choke Technology in a Simulator Using Data from a North Sea Well
Presentation at the SPE/IADC Drilling Conference and Exhibition (The Hague, The Netherlands)
the paper was co-authored by NTNU and Equinor. SPE-194143, also published in the SPE Drilling & Completion Journal.
NORWEGIAN E&P COMPANY
Field development project. Surge & swab during connections calculated for drilling and completion of several wells.
NORWEGIAN RIG OWNER
Specialized surge & swab calculations used internally in a rig improvement project.
INTERNATIONAL E&P COMPANY
Field development project. Surge & swab during connections calculated for drilling of several wells. Rig operability based on well limits estimated.
Dynamic rig heave limits calculated for running liners and casings on Geographe offshore natural gas field in Otway basin.
THE LEADERSHIP TEAM
Co-Founder and CEO
MSc in Cybernetics from the NTNU and business studies at BI. More than 10 years of experience within oil & gas projects. Prior to joining Heavelock AS Martin had worked 8 years for Norwegian oilfield service company Reinertsen with maintenance and modifications on the Norwegian Continental Shelf.
Co-Founder and CTO
PhD in Process Technology and MBA in Technology Management. Background from various technical, project and operational roles with Norske Skog, Reinertsen, BRI Cleanup and Equinor in Norway and abroad. Considerable offshore experience from NCS, South-China Sea and offshore Brasil.