Have you read this whitepaper?

SPE paper 169539:

Diagnostic Fracture Injection Tests: Common Mistakes, Misfires, and Misdiagnoses

by R.D. Barree, J.L. Miskimins, and J.V. Gilbert, Barree & Associates.

Over the last twenty years, Diagnostic Fracture Injection Tests, or DFIT’s, have evolved into commonly used techniques that can provide valuable information about the reservoir, as well as hydraulic fracture treatment parameters. Thousands are pumped every year in both conventional and unconventional reservoirs. Unfortunately, many tests that are pumped provide poor or no results due to either problematic data acquisition or incorrect analysis of the acquired data.

This paper discusses common issues and mistakes made while acquiring DFIT data, and provides details of what the author believes to be guidelines and rules of thumb on how to avoid them. It goes on to addresses potential problems that can occur during DFIT analysis, and more specific issues such as poor ISIP data from perforation restriction, loss of hydrostatic head, gas entry and the resulting phase segregation, and the use of gelled fluids.

Although industry thought-processes may have changed slightly since the paper was published in 2014, the ideas presented by the author are as relevant as ever   — remember, you only have one shot at performing a DFIT correctly!

The paper can be downloaded HERE from OnePetro.

Real-Time DFIT Data – A Case Study

Several months ago, Reservoir Data Systems was called upon by a notable client to provide real-time solutions on a large-scale data project. The client allocated an annual budget of $500k for the project, with the hopes of capturing DFITs on 50 wells ($10k being the average expected cost per gauge rental per test). Using memory gauges, the average test time was 20 days.

By utilizing Reservoir Data System’s EBOT Surface Pressure Gauges, FLOWBOT Flowing Rate Meters, and proprietary FASTRACK Real-time Communications Package, the client was able to view the data in real-time, which would result in significant gains of cost and efficiency.

By means of the RDS user portal, the client was able to visualize the tests in real-time  — they were able to actually see the pressure data, rather than hoping the memory gauge had captured everything reliably. Receiving the data instantly also allowed the customer to perform rolling analyses on each test, effectively cutting the total time of each test in half.

RDS Real-time Case Study Savings Figures

The significant time savings allowed the client to capture an additional 60+ wells of data while staying within the original budget. The incremental cost to perform the same amount of tests using the memory gauges, at twice the test length, would have increased their budget by over 600K.

The Reservoir Data Systems FASTRACK Real-Time Communications Package gives users a quick, easy, and cost-effective way to integrate real-time data into their operational processes — we help our clients make better, smarter, and faster decisions, while saving them both time and money.

RDS Real-time Benefits

For more information, CLICK HERE!

2017 Year in Review & Looking Ahead

Season’s Greetings from RDS!

It’s been a productive 2017 for us as the industry has started to respond to improved market conditions, and we are proud to say that we did not sit idle during the recovery period. We instead used the past year to strategically improve upon our services, grow our team, and continue to advance our company.

As another year of growth and reflection comes to a close, we would like to take a second and share a brief overview of the industry trends we observed over the past 12 months.

2017 saw a sizeable upsurge in onshore activity from clients who are major players in oil and gas — and it’s no surprise that a substantial amount of this activity was in the Permian Basin. We observed an increased demand for our REAL TIME data transmission services coupled with EBOT (surface) and JBOT (downhole) pressure gauges, as operators have once again begun placing emphasis on better understanding reservoir characteristics. We are seeing more DFITs and Frac Interference Monitoring with the operator’s intent of applying captured depletion, net pressures, BHP, etc. to their “big data” systems to make more informed decisions going forward.

It is also worth mentioning that we noticed different strategies employed by our small to mid-sized E&P clients. Many of these, particularly the smaller, private equity-backed, have begun using RDS to perform DFITs to better understand recently acquired fields, or to expand upon portfolio details in preparation of marketing their acreage position. Additionally, in this class of operator we saw a rise in both interest and utilization of newer technologies relating to Frac Interference Monitoring and emphasis placed on well-spacing optimization.

Looking at trends for 2018, we anticipate activity levels to improve further still as confidence in the market is restored and companies are eager to advance the development of existing acreage and prove up new acquisitions.

On the RDS front, next year will see the release of innovative new service lines and tools, and a full reimagining of our online portal that will change the way you receive data!

Best wishes to all for 2018, and stay tuned for more updates after the New Year. Have a safe and happy Holiday Season!

— The RDS Team