Discover the latest news, trends and happenings at Well Data Labs

Diverter Effectiveness – Analyzing One Piece of the Puzzle


In today’s industry climate, operators are relying on large data sets more than ever to make intelligent design decisions when it comes to drilling and completing wells. The first step in making those decisions is establishing a detailed understanding of what happened in previously drilled wells. But, as any engineer who has attempted such an endeavor clearly knows, this is more easily said than done. Many of the data sets vital to understanding the full story of what happened on an old well are challenging to analyze, much less compare against each other. At Well Data Labs, we work to make one of these data sets, detailed frac data, structured and useful for engineers so that they can answer questions and gain the insight needed to do what they do best: design more efficient wells. To better understand what happens when engineers are armed with the right data, we sat down with Darren Kirkwood to discuss the analysis he was able to carry out on completions data using the Well Data Labs application during his time at Fuse Energy.



What made you want to perform analysis on detailed, 1-second pumping data?

We were looking to evaluate the effectiveness of using biodiverter in our frac jobs. Biodiverter is a chemical that is pumped to block off some perforations in order to initiate more perforations so there should be a noticeable pressure increase when it is pumped into the wellbore. Biodiverter is fairly new, or at least it was new to us, so we wanted to be able to see if we were getting significant pressure increases and really try to understand what made for an effective biodiverter job. By looking at the completions data in one-second detail, we were able to see that in certain cases when the biodiverter was being pumped, we were not seeing any significant pressure responses and that made us want to think about why that was. We also wanted to see, when there was a pressure increase, how much of an increase should there be? Or in other words, what level of pressure increase is considered to be effective? We used the Well Data Labs app to map out the biodiverter pressure increases to see if they were happening or not, and if so, to what order of magnitude. With this data in hand, we could go back to our service company and try to figure out what level of responses we should be seeing and what happened when those responses were too weak or nonexistent.

Another thing we were interested in using this data for was in comparison with other detailed data sets like microseismic and chemical tracer data. We wanted to see if there was anything in the frac data, like ISIP, that we could use in conjunction with these other data sets. With the microseismic data, we were hoping to see what ISIP could tell us about what type of fracture we were looking at… was it a long, transverse fracture, or a larger area, more complex fracture? Then, using the chemical tracer data, we could determine which of those fracture types are contributing the most production.

Well Data Labs 1-second Stage Comparison

What insights did you gain in comparing frac data with those other sets?

The particular wells I was looking at were in the Barnett and in that formation it’s typical with microseismic data to see both longer transverse fractures and complex fractures in the same wellbore. I was starting to see correlations between ISIP and fracture type. It looked like the longer fractures had lower ISIP, which makes sense because you probably had a preexisting point of weakness there. For the complex fractures, where you don’t have that existing point of weakness, it looked like there was a higher ISIP.


Were there any practical ways to apply that information?

Ideally you would use this information while pumping the frac job. After taking your initial ISIP by pumping a little fluid followed by a shutdown, you could determine if you wanted to pump that stage based on the ISIP measured. So, if you didn’t want the longer, transverse fractures, you wouldn’t pump a stage that showed a lower ISIP. For us, what we were really trying to determine was what, if anything could the ISIP tell us upfront that would affect how we pump future frac jobs.


For your role as a reservoir engineer specifically, what was the value of having access to detailed frac data?

The main value for me, really, was being able to compare frac data with all of my other data sets. Frac data is a piece to the puzzle that is important to bring together with all of your other data sets such as microseismic and tracer as well as production data to really give you the full story of what happened in that wellbore.


When using the app, what features did you find most useful?

First was being able to quickly pick ISIP’s, biodiverter pressure increases, and other unique events for all stages in a horizontal well using the job view function. Second was being able to compare those data stage to stage in the same well, and well to well in different wells using the job compare function. Lastly was comparing the per stage data in the job compare function to other data sets like chemical tracer and seismic.



We’re always interested to hear how engineers are making the most of their completions data with the Well Data Labs application and hope to feature more of these interviews on our blog in the future. If you’ve ever thought about what insights might be hiding in your frac data and would like to learn more about what we’re doing, we would love to chat with you. Give us a call at 720-662-7771 or send an email to

Oilfield Data Analysis in the News


The latest edition of the Oil and Gas Financial Journal has dropped, and we are excited to share that Well Data Labs, along with three other fantastic Denver-based companies (PetroDE, FractureID, and Wizdom Land Solutions), are discussed in the feature article “Exciting Times in Oilfield Technology.”  As cool as it is to see our name on the fresh ink of a major E&P publication, we are even more thrilled to see the interest that the industry is taking in truly understanding their vast wealth of data.  A common theme that we hear when talking to engineers is that completion designs could be much better if they had the time, tools, and data to quickly evaluate design decisions.  Innovative technology is giving engineers a little bit more of all three, and we can’t wait to see what they will do.

Check out the article or the full March 2017 issue of the Oil and Gas Financial Journal.


What is WITSML?

It’s the 1970’s and it’s a boom time for oil and gas – all the major players of today and yesterday operate rigs throughout the country’s oil fields. The only thing the rigs produce in more volume than resources? Data.

The problem is that it’s the 1970s, and there’s no common language for that data. Copious amounts of it simply get lost in transit from the field to remote facilities – data that could be used to evaluate rig performance, analyze formations and more.

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Spotlight On: Fracture ID

Identify Well-to-Well Variability with Fracture ID’s Drillbit Geomechanics™

The Well Data Labs ‘Spotlight On’ Series takes a look at the technology being deployed on pads across US shale plays.  Whether it’s a new service being rolled out by Big Blue or Big Red, or a largely untested solution from a startup – we highlight interesting tech and give you the resources you need to evaluate its usefulness for your own operation.  Have something you want highlighted? Shoot us a note at!


For as long as we’ve been working to get oil out of the ground, the equation for stability and profitability looked like this:

Figure out the most economical drilling setup and replicate it across every well. If you need more efficiency, optimize your setup.

But what if we’ve been going about it backwards? What if, in a world of $45/barrel and not $100/barrel oil, the most economical thing to do is to vary your completion methods from well to well, increasing your efficiency and reducing waste?

Denver-based oil and gas service company Fracture ID believes revolutionary, affordable, scalable technology will drive a future where operators can be more agile in their well-by-well deployments – resulting in more efficiency and lower costs. Read More

The Refrac: Pumping New Life Into Shale

For as long as hydraulic fracturing, or fracing, has existed, the story goes the same way.

A well is drilled, cased, completed, and put on production. And the story always ends the same way too – eventually the well runs dry. Companies move on to tap new wells because the play is played out.

Right? Well, maybe not. Since the start of the downturn two years ago, more and more companies are evaluating the idea of trying to pump some new life into old wells.

Enter refracing (or hydraulic refracturing), and enter the industry’s latest attempt to stay alive in a low price environment. Read More

Pretty Treating Plots Don’t (Necessarily) Mean Pretty Production

I’m not an engineer. I was headed that way during my first year of undergrad at Virginia Tech’s College of Engineering, but I eventually yielded to the tempting promises of entrepreneurship proffered by the business school. Now, a decade later, I find myself leading business development for a tech company, but spending a significant portion of my time attending professional engineering lectures and trying to dissect and interpret fluid mechanics. I should have stayed in school… Read More

Bridging the IT Divide – Part 2

This is a series of guest posts by author and industry-insider Jim Crompton.  Crompton is an Energy Advisor for Rocky Mountain Innosphere and an independent consultant through Reflections Data Consulting LLC.


Getting to know IT

I hope that I am catching you before you have formed too critical of an opinion of your IT department. I know that the coffee pot conversations can sometime get pretty tough on IT. I can still remember when I was first transferred into the IT department (with a considerable promotion), and all I got from my former peers from earth science was skepticism, condolences and criticism. “What did you do wrong to get that job?,” they asked me. But IT is not that bad and the work they do is critical to the running of your company. So let’s talk about why they are not always on your side.

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Big Data or Buzzword Bingo?

Published over a month ago, I just had the opportunity to read a fantastic article by Anya Litvak of the Pittsburgh Post-Gazette, and thought it was worth sharing.  Titled “Shale companies turn to machines to crunch their drilling data,” Anya does a wonderful job of succinctly breaking down both the opportunities and the challenges of working with high-frequency, machine created data in the world of unconventionals.  Included in the article are highlights of the work of WVU’s Shahab Mohaghegh, a major SPE contributor and industry data scientist, and the efforts of major E&P’s and service companies like Shell, Range Resources, Southwestern, and Baker Hughes.

What do you think – is ‘Big Data’ an overused buzzword in our industry, or the beginnings of a smarter E&P “corporate brain,” as Neal Dikeman of Shell describes it?

Bridging the IT Divide – Part 1

This is a series of guest posts by author and industry-insider Jim Crompton.  Crompton is an Energy Advisor for Rocky Mountain Innosphere and an independent consultant through Reflections Data Consulting LLC.  


Houston, we have a problem!

While it makes great material for Dilbert cartoons, the often strained relationship between engineering and business groups with their internal IT departments can be a serious barrier to the adoption of emerging technology.  This challenge is more than just a common complaint around the coffee pot at work, but a potential rift that will limit just how successful and efficient both groups can be – and in today’s market, efficiency is king.

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Spotlight On: NCS Multistage

The Well Data Labs ‘Spotlight On’ Series takes a look at the technology being deployed on pads across US shale plays.  Whether it’s a new service being rolled out by Big Blue or Big Red, or a largely untested solution from a startup – we highlight interesting tech and give you the resources you need to evaluate its usefulness for your own operation.  Have something you want highlighted? Shoot us a note at!

Engineers were born to tinker

No matter the current trading price of WTI crude, one constant in our industry is that there will always be smart people in cubicles, laboratories, and frac vans across the country working tirelessly to find more efficient and effective ways of getting oil out of the ground.  One reason to pursue efficiency is the undoubtedly increasing pressure from whomever is paying the bills, but another likely reason is that the people working in this industry are tinkerers and testers; people who say, “there is a better way to do this.”  More than just a title, they are in their very nature, engineers.  

As someone who talks to petroleum engineers from a variety of operators and service companies every day, many of my favorite conversations begin with a passionate recommendation from an engineer to check out a new solution to a problem.  So that is what we are setting out to do with our ‘Spotlight On’ blog series: investigate different company’s ways of solving oilfield problems.  

We are kicking off this series by turning the spotlight on a company that has continued to set records and win awards for their ways of solving completions problems: NCS Multistage.   Read More