Jet Nozzle
A client of ours who has extensively used our software had came into an issue where they had used multiple jet nozzles set along their drill string. The goal was to help lift cuttings and optimize the necessary pump rate to achieve hole cleaning with the flow rates through the jet nozzle. They wanted to be able to adjust the Total Flow Area (TFA) and achieve the desired flow rate and hole cleaning efficiency. We began working on implementing this into Drillsoft HDX+. Our goal was to implement the feature in such a way that it doesn’t only simulate hole cleaning efficiency but also include the temperature changes that are created with having flow from the DrillString mix with the mud in the annulus. One important factor to consider was also the new friction created by having mud being flown out of the drill string at various depths. We successfully implemented the system and made it as user friendly as possible so that the user can access and optimize their TFA and flow rates through the jet nozzles without having to go through extra learning time. The new update was released within 2 weeks from the date it was requested following extensive quality control testing and discussions with the client. This feature is now available to all of the DrillSoft HDX+ users. And can be easily accessed by typing JetSub in any drill string component row and double clicking on it to see the TFA, Flow Percentage and Flow rate through each nozzle.

Riserless Drilling
During a marketing meeting where we presented our software to an offshore completions company, we were asked about simulating the pre-BOP Riserless Pump and Dump Drilling Operation. This was not something implemented in any of the DrillSoft Software before. However being able to simultaneously have multiple different muds in the well it was a simple feature to implement. After working for 2 days we were able to allow the user to eliminate the riser and simulate a riserless pump and dump drilling operation. The components that are important here to consider was the change in volume when the riser is removed, the new temperature profile with a cooler ocean temperature directly interacting with the returning mud in the annulus, and the heat transfer between the sea/ocean and the drillpipe and mud in the drillpipe. After verifying the stability and accuracy the feature was included in Drillsoft HDX and 3 days after the request was made, the feature was released to all DrillSoft HDX users. The feature was made so that no extra learning is necessary to activate the riserless drilling feature. We just added a disable button next to the riser in the configuration window. The user is able to see a breakdown of the volumes, flow rates, friction factors and temperatures and verify that the software is simulating Pump
and Dump.

Tool Joint Correction Factor
During a meeting with a client, they gave us feedback on the correction factors and requested the ability to adjust the ToolJoint Length. By default we had restricted the Tool Joint length to 10% of the overall length of the pipe section. After the discussions we began implementing the feature to allow users of all DrillSoft software to be able to customize their ToolJoint length by adding a box into the Tool Joint Correction Factor window. The user can customize the overall ToolJoint length by changing the percentage and choose a desired value. The new feature was released within 2 days of the request was made.

Pressure/Temperature Correction Factor
At Drillsoft we are always trying to provide you with the most accurate software with many features included to simulate the hydraulics of any operation from conventional drilling to riserless pump and dump operation, to deepwater HPHT MPD operation with Oil and Synthetic Based Mud. We are always open to feedback from our clients to implement new features or improve existing features and models. One task we recently undertook was to change and improve our Pressure and Temperature model with an improved empirical model for deep HPHT wells. We used information available in literature to implement the models. The result was improved accuracy to accommodate the density increase due to compression of the mud with higher pressure and the density decrease due to swelling and expansion of the mud with higher temperatures. Implementing this new Pressure/Tempeature into the density wasn’t the only task but also to include it into the rheology, viscosity, friction and overall hydraulics model of the software. After implementing these changes and running quality control tests we released the new model in all Drillsoft software updates. Following the update we received countless positive feedback for this update.

The post Customers’ inquiries of better services lead to invention of new features appeared first on Drillsoft®.

The concept of Hydraulic Optimization is based on the best condition to clean the well is when the force provided by the jets is the maximum. If you drill a shallow hole section, the maximum impact force is recommended. However, if you drill a deeper section, the maximum hydraulic horsepower is better than the maximum impact force.

Maximum Hydraulic Horsepower will happen when the pressure drop across the bit is equal to 65% of total pressure loss; therefore, 35% of total pressure loss occurs through the drill stem. Maximum Impact Force, based on the mathematical solution, this condition occurs when bit nozzles and circulation rate are properly selected to create pressure drop across the bit which is equal to 48% of total pump pressure. Many engineers just don’t have the right tools to do this and they have to use trial and error to get closer results, but when some element within BHA changes or the wells gets deeper they have do it all over again.

Drillsoft HDX helps to achieve these results effortless with just a few clicks.  

The pressure drop through surface equipment is one of the components in drilling hydraulics that must be considered. When we talk about surface equipment, we usually refer to the following equipment: stand pipe, surface hoses, a swivel, a goose-neck and a Kelly. Because of a number of several combinations of surface equipment, four popular combinations are selected and the surface equipment coefficients for calculating pressure loss are shown in the below table

• Red: Pressure Drop across bit is < 35%. Require optimization.

• Yellow: Pressure Drop across bit is > 35% and =< 48%. Optimization could be improved.

• Green: Pressure Drop across bit is > 48%. Good Optimization.

Many MPD engineers would say, “it’s now our call design or deal with hydraulic optimization”, I see the point; however a proactive engineer could offer a little advice to their clients on something that could improve drilling performance or perhaps jut increase the ROP, with just a few clicks!

To sum up, here the steps to optimize hydraulics:

1. Select surface equipment type

2. Enter maximum pump pressure

Drillsoft HDX shows three color codes for Bit hydraulics optimization:

3. Select any flow rate between Max Force impact and Max Hydraulic Horse power, depending on your goals.

4. Apply the suggested TFA Drillsoft make it easy!

The post Hydraulics Optimization appeared first on Drillsoft®.

Considering the full picture, planning and design of drilling hydraulics helps reduce non-productive time and cost. So, it is imperative to create a well-rounded hydraulics design.

Hydraulic simulators play an important part in designing the drilling hydraulics for a well. This design must be updated while drilling and hydraulics simulators with their rapid calculations allow the engineers to update their plans while drilling. A good simulator should include an accurate transient well model that calculates;

• Pressures — ECD’s
• Hole cleaning, cuttings carrying index, annular velocity
• Temperature
• Surge and Swab
• Kick management and well control 
• Rheology
• Pore and Fracture pressures,  etc.

All these components must be used together to provide an accurate hydraulics design for successful and efficient drilling operations. DrillSoft software packages deliver the tools necessary to create a transient hydraulics plan for all sections of the well. The efficient algorithms allow the user to rapidly obtain accurate results and also update the results based on new data from the well.

The software contains 5 graphs that plot pressures: ECDs, Temperature, Hole Cleaning Properties and Trends, which work together to provide an accurate plan. A well schematic that is updated real-time throughout the simulation is located on the left to provide a visual about what is going on in the well.

The configuration button allows the user to easily input the formation, well, tubulars, fluids specifications. After the well, a simple simulation can be run by inputting a pump rate hitting the play button.

Drillsoft HDX, HDX+ and PMCD software also allow the user to save all data from the simulation. It also generates configuration, hydraulics design, roll-over, batch-mode, well control, PMCD, Influx Management Envelope reports.

These reports and many other reports that can be generated from the Drillsoft software packages create the full transient hydraulics plan and design for a well.

The post Importance of Hydraulic Planning Prior to Drilling a Well appeared first on Drillsoft®.

During MPD connections we replace the annular friction by applying surface back pressure to achieve the target bottom hole pressure or target ECD.

This effect “bends” the annular profile to achieve the desire bottom hole pressure.

Imagine a sheet of paper and pushing one finger in the in the edge, the paper would deform according with the amount of pressure we apply, this effect is similar to the MPD connections since as we decrease the flow rate the annular friction decreases, but it does also in the annular profile gradually from the top to the bottom.

Let’s remember the friction depends on the rheology model and mud properties like viscosity among others. Meaning different rheology model will create different shape during the MPD connection schedule. This shape will be seen in the ECD profile (Check the video for more detail).

At Drillsoft we have implemented a new feature to illustrate this effect that sometimes is difficult to understand or comprehend. Below graphics show the 3 stages in the MPD connection. Blue line is the EMW and the red line shows the ECD profile. .

In the MPD connection you will see these profiles changing from the full flow rate to the pumps off.

Also notice how the ECD profile at the close the surface changes a lot and get “deflected” due the effect of the surface back pressure. Now you know what about to see in the following video.

The 3D view can show pressure profile or ECD profile. We choose the ECD profile since is more notorious to capture this effect.

Don’t miss out the next article, we will post the similar ECD en 3D with different well profiles (deviated, heavy pill in the annulus and much more…

If like this video or article please share with your friends.

If you have any question please comment below.

The post Have you seen a MPD connection in 3D? appeared first on Drillsoft®.

Drilling fluid hydraulics and hole cleaning is an integral part of the practical processes required for planning and drilling a well. Optimization of cuttings transport depends on so many factors- hole angle, cutting size, drill string rotation, drill pipe eccentricity, optimization of bit hydraulics, ROP, hole cleaning pills, cuttings transport ratio, cuttings bed properties, etc. The key to a successful hole cleaning relies upon integrating optimum drilling fluid properties with best drilling practices. The use of hydraulics and hole cleaning therefore goes beyond calculating pump pressures and jet nozzle selection, although these functions are critical to optimum bit performance (see this post). The primary use of drilling hydraulics and efficient, effective wellbore cleaning should be considered proactive to design, engineer and drill a well, with careful attention applied to hydraulics and hole cleaning aspects, to reduce or eliminate potential problems before they occur.

Flow Rate

Flow rate is one of the main factors affecting hole cleaning and when we talk about flow rate and hole cleaning. More flow rate is not always the way to improve hole cleaning because might cause erosion or hole washout, therefore enlarging the hole causing less annular velocity and decreasing cuttings transport. Below a useful table showing the recommended flow rate for highly deviated and horizontal wells:

Note : It is important to calculate minimum flow rates required for hole and wellbore conditions, i.e. hole angle, casing setting depth, mud properties, anticipated ROP’s etc. If not achievable, then ensure that drillstring engineering, BHA design, drilling & tripping procedures are in place to best manage cuttings beds that may form. Circulate the hole clean prior to tripping. A single bottoms up is not sufficient below a recommended bottoms up factor.

Symptoms of Inadequate Hole Cleaning

• Small volume of cutting at the shakers as compared to the volume of the hole drilled.
• Large amount of fill after trips.
• Increasing drag.
• Increasing Torque.
• Reground (small and rounded) cuttings.
• Increased ECD ans measured by the PWD tool.

Drilling problems

Poor hydraulics and wellbore cleaning may cause the following drilling problems.

• Inadequate cuttings evacuation from bit.
• Lower than expected drilling performance.
• Grinding of cuttings into fines at bit.
• Mud and solid control maintenance difficulties.
• Increased ECD.
• Increased mechanical torque and drag – especially for deviated holes.
• Over pull in the wellbore due to fines cuttings beds that often result in unnecessary backreaming.
• Stuck pipe.
• Fishing.
• Side-track of well.

Vertical wells

It is important to note that vertical wells are the easiest to clean where cutting beds will not form but where cuttings concentration and slip velocity considerations are perhaps the most important considerations when evaluating wellbore cuttings transport efficiencies.

Higher angle wells

In angles wells e.g. > 30degrees, hole cleaning and cuttings build up in the annulus is highly dependent upon hydraulic conditions. This is especially true in more deviated or horizontal wellbores.

This video show the differences between drilling a VERTICAL well and drilling a DEVIATED well.

Temperature/Pressure Effects on Mud Rheology

Temperature and pressure plays an important role in mud rheology and density because they vary with depth. The most significant effect is generally seen near the bit where the temperature is greater. This is also the location where most of the swab/surge pressure is developed, and swab/surge calculations may be affected significantly. Perhaps more significant than effects on pressure loss is the effect on the true yield value in the mud. Significant reduction in the yield value downhole, although the surface value is satisfactory for cuttings removal, could create hole cleaning problems. Mud flow rate and Mud Properties are perhaps considered the two major variables to ensure effective and efficient wellbore solids removal.

The post Hole Cleaning Problems? See How to Optimize Cuttings Transport and Drilling Hydraulics appeared first on Drillsoft®.

It’s very well-known and documented the pros and cons between these two methods, we show you the real or numeric quantification between them using both methods under the same conditions.

In the video, you will see a simulation of 10 barrels gas influx controlled using both methods, at the end you will see the comparison between them. The video will show:

• The pressure at Casing shoe at different stages during the well control
• The casing pressure trend during the well control.
• Maximum gas expansion and maximum pressure when kick reach surface.
• Strokes or time that takes to control them.

Don’t forget people, if you like this video please “Like”, “Favorite”, and “Share” it with your friends or colleagues to show your support- it really helps us out! If there’s something you like to see, drop us a line or comment below.

The post Unveiling the real differences between drillers and ‘wait and weight’ methods appeared first on Drillsoft®.

Remember Keep your ECD constant during reaming operations apply the surface back pressure accordingly. Drillsoft make it easy!

In this video show how Drillsoft can simulate this complex operation easily with a few clicks.

The post Enlarging Wellbore in MPD operations: watch out the friction! appeared first on Drillsoft®.

The post Surge and Swab effect during your simulation (RIH/POOH) appeared first on Drillsoft®.

The transient Temperature effect is very important in the accuracy of MPD/UBD calculations. Most people ignore this effect perhaps because they don’t have the right tools to calculate the transient effect, so many engineers just take the thermal gradient and use steady state formulas to calculate the bottom hole temperature.

What exactly is transient & how is it different from the steady-state vector calculator?

Transient phenomena are always presented during oil-well drilling, as an implicit result of changing the flow rate, pumping, and choke pressures while the fluid “mud” is circulating through the well. The process of circulation consists of 3 stages: (1) fluid enters the drill pipe with a known flow rate and specified temperature and flows down, (2) fluid exits the drill pipe through the bit and enters the annulus at the bottom, (3) the fluid flows up in the annulus and exits the annulus. There is a cross flow and therefore heat transfer between the fluids in the drill pipe and annulus via convection and also conduction through drill pipe. The annulus fluid temperature is determined by the rate of heat convection up the annulus, the rate of heat exchange between the annulus and drill pipe wall, and the rate of heat exchange between the formation and annulus fluid. The friction across the drilling system caused by hydraulic pressure loss also is one of the heat sources which are transferred by the force. Generally, the formation temperature is lower than the annulus fluid temperature at locations closer to the surfaces; however, for deeper locations formation temperature exceeds the annular fluid temperature. Therefore, circulation of mud cools down the near wellbore formation for deeper locations. Factor affects transient calculations:

• Duration of the drilling or circulation process
• Well geometry
• Thermophysical and transport properties of the drilling mud and formation
• Heat exchange between all zones

Steady states vector calculator have many assumptions:

• Heat transfer between annular fluid and formation is linear or constant.
• Neglect vertical heat transfer
• Formation is homogeneous
• Neglect thermophysical fluid’ properties.

Onshore Temperature Profile

  Let’s take a closer look at the Onshore wells (Graph 1) Blue arrows. You can notice during the circulation the lower annular zone cools down. The cooling effect depends on the flow rate, the physical properties of the fluid particularly mud density, specific heat and thermal conductivity. Also the heat exchange between the zones. Some fluids can return cooler or warmer depending if the well is deeper or shallow.

Offshore Temperature Profile

On the other hand the Offshore well the temperature profile changes considerable. First the negative temperature gradient in the ocean makes the temperature get event cooler then at the seabed the temperature changes because of the positive temperature gradient. When starts circulation the lower annular zone get cooler, however at some point in the annular it’s hotter than formation temperature. In the Riser is getting cooler again and might return cooler or hotter that surface temperature depending on the well geometry (deeper/shallow) and physical fluid’s properties among other conditions.

Why Temperature is significant?

Well Control:

Let’s consider a gas influx (Kick); generally the “PV= Constant” assumption appears to be more or less acceptable in evaluating a shallow gas kick. The perfect gas law “PV=nRT” improves the predictions including the effect of temperature. Here is when the Temperature plays an important role in our kick calculations.

As you can see the gas density is not constant during the influx control. Temperature changes circulating out the influx.

Thermal Expansion:

Thermal expansion of drilling muds, in areas with high geothermal gradients, can lead to unintentional underbalance-a kick may occur. In deep, hot wells, the densities of water and oil-based muds can vary significantly from the measured values at surface conditions. Calculations have shown that bottom hole pressures, predicted with constant surface density, are often in error by hundreds of psi.

Hydrates formation:

Another effect of the temperature is the formation of hydrates; studies have shown the hydrate formation during well-control and drilling operations are increasing. Below graph shows the hydrate formation region in offshore well. So modeling the transient temperature in offshore wells is very important to be aware if it’s possible avoid hydrates formation.

Now you know the importance of modeling a well using transient simulations. Drillsoft has developed a Transient Hydraulic Model you can easily plan your well successfully with a few clicks in a very ease-to use UI. Here a video showing the Transient Temperature Modeling in an Offshore well. https://youtu.be/gIHi4BCyoPU

The post Transient differences from steady-state calculations? appeared first on Drillsoft®.

Some of the Advanced diagnostic registers – Emerson’s Flow meter

Left & right POV, tube frequency/Tube period, Live Zero, Delta T are among the important register to get advanced diagnostics. Moreover its possible implement calculations to predict the variable process condition. E.g. based on the tube frequency the density in the flow meter can be calculated if doesn’t match with the current density most like something else is going through it. (Next article we will discuss how implement calculations to improve flow meter’s diagnostics). One of the best practices to predict anomalies is get historical values and graph them against time (trends), so field supervisors can see the flow meters’ behavior. Some times when the supervisor is expecting gas (connection gas, influx, etc.) coming out the meter, these variables can change drastically when the gas reach surface. Most of the time the presence of two-phase flow can cause noise in the measurement signal of a Coriolis meter and tends to reduce accuracy. When gas or solid particles are entrained the vibration of the tubes increases therefore requires more energy to keep vibrating at the same frequency making the drive gain signal rise. In this case Drive gain is more reliable that density as a diagnostic for entrained gas because density is also affected by changing fluid conditions such composition and temperature. All those advanced diagnostic tools are implemented in our Drillsoft products. Don’t forget people, if you like this article please “Like”, “Favorite”, and “Share” it with your friends or colleagues to show your support!

The post Get the Most of Coriolis Flow Meters. Improve Your Operations with This Advanced Diagnostics appeared first on Drillsoft®.