Testimonials

The SPIDR device is attractive to us at EOR for many reasons.  For our St. John’s CO2/Helium project, the information we gather in the evaluation phase of the reservoir is valuable for future development plans going forward.  Understanding the reservoir deliverability helps us estimate the number of wells we need to fill our pipeline and future infill wells required.  This in turn helps us estimate capital expectations for the project in whole. 

Operationally, the SPIDR is non-intrusive and is very cost-effective, especially when compared to running downhole gauges for pressure transient testing.  Our CO2 field is in a remote location and the simplicity of installation and ease of moving from well to well with the gauge is a very attractive feature.  Understanding the skin damage to a well helps us review our drilling practices and make changes where necessary.  This is all being done via the SPIDR gauge and Data Retrieval Corporation. 

Outside of the SPIDR, we also rely on the engineers at DRC to convert and analyze our pressure transient data.  Their expertise in well testing has been an added benefit to our company and gives us confidence in the results we are receiving from the SPIDR gauge and DRC.

The SPIDR was very convenient to use for MFO tests we performed in the Piceance basin. We had the flexibility to perform 3 MFO tests without having to worry about having extra equipments and someone staying on location just to record pressure for at least 30 hrs. The ability to sample data every second with such a small tolerance is also key to have reliable analysis.
Using the SPIDR to record decline pressures in a MFO test is the most convenient and cost effective solution to get reservoir parameters such as mobility and reservoir pressures.

As a 15+ year user of DRC's SPIDR gauge, I can attest to its utility. The SPIDR has given the operator a low-cost alternative to downhole gauges, especially when running an extended well test or back-to-back tests on multiple wells. The gauge is easy to program and operate. At Southwestern Energy our field operations personnel keep it in their office, program it and install the gauge on a well as per the engineer's instructions. No need to pay for and wait on slickline units to run downhole gauges. The field hand can query the gauge at any time while it is in operation and download and email the data to the engineer. I have used downhole gauges a few times in conjunction with the SPIDR to ensure that the SPIDR is giving us data that can reliably be used to estimate the required reservoir parameters, and it has.

DRC has done a great job in acquiring build-up and draw-down data from several wells in one of Nexen's fields, in the Gulf of Mexico, that is a high yield, high temperature, and high pressure gas field with C02. Because of the mechanical risks.....running pressure gauges in the wellbore is not desirable. DRC also gives great service and attention to detail.

We have successfully used the surface acquired pressure data to influence both operational decisions and reservoir interpretations. The ability to provide low cost continuous drawdown information has been very helpful in getting an early assessment of reservoir size, drive mechanism and flow efficiency on several key projects in the Gulf of Mexico shelf HPHT trend (retrograde condensates - 25-75 Bbl/MMSCF yields). When also linked with the reservoir dimensioning capabilities of WaveX, the combination becomes a very cost effective and powerful tool. Chevron-GOM has actually revised a HPHT well's planned TD with a rig on location, when the WaveX interpretation, using real time SPIDR data from discovery well, indicated the drill's development location was being adequately drained.....saved - $1.5 - $2.0 MM in drilling cost, as well as resulted in an alternate take point in adjacent fault block, effectively increasing the reserves & usefulness of the well bore.

Doug Bourque would also be a good reference, especially for the ease of SPIDR installation from an operational perspective.......