DrillScene is an advanced software tool for monitoring and trend analysis during drilling operations. It creates a dynamic, real-time picture of the entire wellbore with changes between the model and reality visualized as trend graphs. This helps drilling analysts and engineers to optimize operational performance and to proactively avoid problems in the borehole.
DrillScene is the only software that simplifies real-time data analysis by using trends and deviations between modeled and actual data to monitor wellbore conditions.
DrillScene automatically converts raw well data into five clear, dynamic trends (see image above) and two modeled trends (Modeled ECD, and Transient ECD). These trends help your team understand and drill with a higher degree of control, whatever the downhole conditions.
DrillScene is deployed in the office or at the rig site for use by the Operations Team. It improves drilling operations by:
- Simplifying real-time data analysis to accelerate decision making
- Using advanced transient models to understand changing conditions
- Identifying performance improvements to drive drilling efficiency
- Revealing the symptoms of non productive time
A better understanding of borehole conditions
Real-time sensor data is available only at the bit and at the surface. DrillScene uses Sekal core technology to model a virtual well – providing data such as pressure, temperature, cuttings transport and friction – along the entire drillstring to compare the real-time data with.
In modern drilling operations, sensors are placed within the bottomhole assembly to reveal what is happening close to the bit, while the surface sensors indicate what is happening with the drilling fluid properties. The conditions in the rest of the borehole are not usually measured or understood. DrillScene fills the data gap behind the bit, enabling operators to assess crucial factors such as fluid volumes, cuttings proportions, pressure, temperature, ECD and friction. This helps drillers to identify the optimum conditions for each section being drilled.
How DrillScene can help
DrillScene detects the symptoms that enable your team to anticipate drilling events and avoid delays caused by issues such as hole cleaning, stuck pipe, lost circulation, formation damage and borehole instability. Anticipating problems and finding the right solution keeps drilling plans on schedule and ensures effective cost control for each well.
DrillScene offers a powerful combination of real-time trends and a detailed understanding of conditions in the borehole behind the bit. This enables the drilling team to conduct forward simulations and predict the likely results of any action or change in borehole conditions.
The DrillScene trend (left) shows Sliding Trend and Torque trends increasing over a period of 6-8 hours, but the drilling parameters (right) did not indicate any problems. The real-time operation team provided this information to the rig and the mud logger confirmed sticky clay coming over the shakers. Further circulation was performed and a potential stuck pipe situation avoided.
Simplify real-time data analysis and streamline decision making
Transforming raw data into clear trends helps the drilling team to understand dynamic conditions in the borehole and maintain high levels of operation time. By applying DrillScene, software users can detect symptoms leading to potential stuck pipe conditions earlier and quickly take corrective actions. With DrillScene, the operations team becomes a more focused and proactive partner in the drilling process and finds it easier to offer crucial, real-time support to the executing rig crew.
Optimize drilling parameters to drive drilling efficiency
The advanced transient models at the heart of DrillScene help users safely operate in narrow ECD margins with optimal drilling parameters. This reduces time spent on tasks such as drilling, tripping and casing runs. The model also helps the rig crew understand the location and movement of cuttings in the wellbore while drilling and during circulation. This facilitates hole cleaning and helps to reduce invisible lost time associated with actions such as stuck pipe, unnecessary wiper trips and extended hole cleaning circulation before pulling out of hole.
Discover how DrillScene can predict potential problems
A client prepared for a new well by using DrillScene to analyze the events that had led to a wash out in a previous well. The first well, in the same field and reservoir formation, had been run without DrillScene. Loading real-time data into DrillScene, the operation was re-run minute-by-minute and DrillScene models calculated. The results show an increase in APL deviation in the period from 17:00 until 01:00 and a drop in SPP deviation over the next 10 hours. The APL deviation then leveled off and decreased as ROP decreased. There is a clear difference between modeled and actual SPP between 05:00 and 09:00.
Identify symptoms for the issues that cause non productive time
DrillScene Replay studies help to establish the root cause of non-productive time related to issues such as stuck pipe, formation fracturing, fluid influx, and hole collapse. A replay study analyzes all real-time data recorded by the BHA and on the rig to establish the actions and hole conditions that led up to an NPT event. The planning and operation team can then apply this understanding of the problem to avoid similar issues in subsequent wells.
How a Replay study helps you analyze incidents and capture key lessons
In this Replay example, the client is pulling out of hole and the pump pressure, torque and hook load are falling as expected. The DrillScene modeled data is overlaid to reveal deviations in the modeled and observed data. (Right picture) Switching to the DrillScene trend window reveals a trend build-up between 13:00 and 17:00. If this information had been available, the RTOC would probably contacted the drilling crew and to discuss options on how to proceed. Drawing on this knowledge the client will be able to better plan and manage the next well in this field.
DrillScene case studies
DrillScene has been deployed commercially since 2011 and used by leading oil and gas companies around the world. The results from some of these operations are presented here to highlight the value of the DrillScene approach to real-time drilling monitoring.
The Norwegian Petroleum Directorate (NPD) registered 176 unplanned sidetracks on 558 development wells in the period 2013 – 2016. Complex, development wells carry a significant cost. Even with substantial efforts in planning and execution, by operators, service companies, and drilling crews, the result is approx. 31.5% unplanned technical sidetrack. The cost implications and potential consequences to production are enormous.
DrillScene reduced unplanned, technical sidetracks from 32% to 4%, delivering huge cost savings
DrillScene deployed on 72 wells, reducing sidetracks to only 3 (4.2%). The statisitical improvement when using DrillScene represents a huge cost saving potential for operations experiensing challenging well conditions.
Over a period of two and a half years (2013 to 2015) a large independent operator experienced a drilling statistics of 32% unplanned, technical sidetracks (90 sidetracks on 280 wells). This is in line with the NPD register. The operator estimates the cost to exceed USD220M per year. A study of 165 wells revealed that most of the incidents leading to sidetracks happened during pull out of hole (POOH).
To assist in the drilling execution of complex wells and well sections, DrillScene was utilized for advanced real-time monitoring in the real-time operations center (RTOC) and operational workflows. Complex wells for the operator included tight/narrow mud weight window wells, deviated wells, and ERD wells with complex hole cleaning and stability challenges. The drilling analysts used the software to perform situation examination, trend analysis, and provide proactive drilling advice.
The yearly cost saving potential for the operator is exceeding USD 180 M per year. Additional value by utilizing DrillScene in operations, such as early production, reduced time used on hole cleaning, and stability challenges not leading to sidetracks, are not included in this estimated cost saving.
Early warning to avoid stuck pipe
In the DrillScene trend window the deterioration in downhole conditions and rising torque and standpipe pressure are evident 4 hours before the stuck pipe incident. Given this advance notice, the rig crew could have avoided the stuck pipe situation.
DrillScene can provide early warning of stuck pipe symptoms, giving the rig and the operations team time to take remedial and stepwise actions. In this example from a well in Asia, the DrillScene trends clearly show a standpipe pressure (SPP) build up over a period of 4 hours and a sudden change in hydraulic jacking after 3 hours of increasing SPP. In this case, DrillScene could have presented the rig crew with advance notice of changes in downhole conditions and avoided the stuck pipe situation.
The conditions that lead to stuck pipe can be difficult to read in raw drilling data. Various factors may indicate potential problems, but often these are spotted only when the situation has developed to the point where the drill string sticks. By that stage, finding a solution has become very difficult. The raw data indicate that the hook load, torque and pump pressure measurements are reducing during POOH as would be expected. However, it is very difficult to assess whether the reduction is equal to the amount that would be expected.
Sekal has enhanced the performance of real-time drilling models and refined their use of real-time data.
The core of Sekal technology is a combination of three tightly coupled real-time dynamic models – hydraulic, mechanical and thermodynamic – that simulate the wellbore state and physical processes during drilling operations. These models work together continuously to assess drilling performance, borehole conditions, and associated risks.
Harnessing the power of dynamic modeling, Sekal products accurately model key drilling parameters and variables such as hook load, surface torque, cuttings transport, tank volumes, standpipe pressure and ECD in real-time.
This example shows deteriorating hole condition while pulling out of hole. The deteriorating trends were visible and building for 12 hours prior to pack-off. The increase in Sliding trend probably indicates drag in the wellbore, whereas the increase in Torque friction and APL deviation indicate cuttings build-up around the BHA. The decrease in FRW deviation may indicate that the BHA is being subjected to lifting forces of the kind expected in pack-off situations.
The models also calculate parameters such as temperature variation, sliding friction, rotating friction, and hydraulic friction in the wellbore. Each of these serves as a valuable indicator of changing hole conditions that could lead to problems.
DrillScene uses the technology to change the monitoring-paradigm from a “here and now” to a predictive environment. When used for look-ahead simulations the operation team can make what-if scenarios to fine-tune and optimize drilling parameters. Integrated on the rig’s hoist (draw works), rotating (top drive) and flow (mud pumps), DrillTronics enables automated drilling processes to be conducted within safe operational limits.
How it works
Sekal systems are unique because they drive the transient model in real-time using physical measurements from the rig, and calibrate the model using actual well conditions. The calibration process is conducted automatically whenever conditions are suitable.
Sekal systems are unique because they drive the transient model in real-time using physical measurements from the rig, and calibrate the model using actual well conditions. The calibration process is conducted automatically whenever conditions are suitable. DrillScene uses real-time dynamic ECD modeling (Figure to the left) to increase wellbore stability. The dynamic model calculates and shows the ECD’s dramatic variation and impact gel breaking can have on the formation. Gel breaking impact after being stationary for 0.5 minutes to 80 minutes (Figure to the right).
The tight coupling of the Sekal models means that when a parameter changes in one model, this is reflected in the other models. This unique and powerful combination of models means that our products can:
- Capture combined complex dynamic effects during changing or transient conditions such as temperature evolution, pump start-ups, flow changes, string acceleration, and gel breaking.
- Enable drilling and tripping optimization with higher confidence in tight margin conditions and/or when downhole pressure fluctuations are critical to wellbore stability.
- Visualize hole cleaning by assessing cutting generation and transportation based on penetration versus hole size, and how long it takes to circulate to surface
- Create realistic second-by-second dynamic downhole pressure simulations, hole cleaning and temperature evolutions
- Set and optimize drilling parameters so that users can drill safely close to the upper and lower geolimits.
- Greatly improve underbalanced drilling (UBD) and managed pressure drilling (MPD) operations by predicting how operational conditions and fluid properties influence pressure (ECD) and temperature
- Reduce the risk for human error on the rig and protect the wellbore as an integrated part of the drilling control system.
In recent years, Sekal systems have been applied in a variety of field settings, dealing with complex, extended reach, and highly deviated wells in some of the world’s most demanding oil and gas environments.