A UK gas storage company needed to identify which wells were underperforming in order to maximise performance. The data acquisition operation was required to:

  • integrate well with platform processes
  • be carried out on all available wells in one campaign
  • have no impact on gas nominations.

Halliburton was able to provide a low cost solution with the SPIDR® system. Production personnel had no problem in programming and downloading data. Rig up was simple and the SPIDR® system was sufficiently robust to use on all available wells in one campaign. Data was captured with minimal impact on platform operations and no impact on gas nominations. The converted pressure data provided by Halliburton was reliable and helped the client identify a number of underperforming wells. Halliburton was quick and effective in their response to queries and their knowledge was invaluable in solving one or two unusual pressure responses. I would be more than happy to use Halliburton for future pressure data acquisition operations.

John Hall, Senior Production Technologist , Expro Group, Aberdeen, UK

In my business I spend a lot of time analyzing pressure data from fracture injection tests using NuTech's NuFIT process. The results of this analysis provide a measure of the permeability and pore pressure that is needed to understand if the reservoir will be commercial after completion. However in some cases the data can be difficult to analyze because of a high level of noise in the recording instrument and unexplained spikes in the data and periods with no data recorded. Other memory gauges can require extensive editing to correct these data problems, introducing uncertainty into the analysis. The Halliburton SPIDR® system gauge however consistently provides high quality data free of uncertainty. When asked what gauge I would use, I recommend the SPIDR® system gauge from Halliburton.

Corby Goodman, Senior Completion Engineer, NuTech Energy Alliance, Humble, TX

We have successfully used the SPIDR® surface pressure data instrument for well testing since 1995 on both gas-condensate wells and gas storage wells. SPIDR® provides valuable information at a very low cost. We have run them in conjunction with down hole gauges while running an extended well tests on single wells as well as multiple systems. The ease of hooking them to a well head and the non-intrusiveness of the equipment make it very practical. We have relied on the Halliburton engineers for information, converting the pressure transient data, and analyzing the results.

Jim Junkins, Manager of Operations, eCORP Development, LLC, Houston, TX

I have been pleased to be associated with Dr. Nathan Waldman before there was a concept of a SPIDR® system. Halliburton has been developing technology for surface to downhole pressure measurement for the past 29 years in parallel with my own efforts to develop a capillary wave based transient model. During those years the proof of concept has been to produce blind maps that compare well and in detail with seismic imaging. In order to perform this task the first step resides in data gathering. Stability of the instrumentation is critical to the task but the key is acquiring accurate surface to bottomhole pressure conversions. This is not as simple as the textbooks make it out to be. The key is relative pressure measurement with appropriate conversions for thermal decay. In the early 1980s it was my responsibility to sponsor an R&D effort in the National Laboratory System to produce such a surface pressure to downhole pressure algorithm. The US Dept of Energy spent half a million dollars and failed to produce credible downhole conversions when provided both surface and downhole pressure data. Halliburton succeeded and has produced over half of the data sets that WAVEX has used for "Blind Pressure Mapping." Halliburton and WAVEX began working together back in 1997 on a collaborative basis and have been delivering cost effective quality energy mapping since. Surface data works and works well on virtually all gas wells. It is the minority of cases that require downhole services. What is the point of risking a well with wire when wireless testing works on the vast majority of gas wells? We have had successes on oil wells as well when testing conditions were too severe to consider a downhole gauge. I am proud of my long association and moreover the stunning results that both companies have achieved.

Dr. Fred L. Goldsberry, P.E., Ph.D, MBA, President, Wavex, Inc., Houston, TX

Halliburton and the SPIDR® well testing system have been a great tool in the evaluation process of the wells I look over. They have been very dependable and accessible for the many years that I have been using them. I have been using the SPIDR® system for both the typical application of pressure transient testing (build-ups/drawdowns) as well as well pressure monitoring. During my time as production engineer looking over a very high-profile field, I had the SPIDR® system monitoring the well head pressure for the entirety of the intervention. The well was a high pressure, high temperature Gulf of Mexico gas-condensate reservoir and I was reluctant to run any downhole gauges. This allowed me to have high quality wellhead pressure data that would be converted to bottomhole conditions but also acted as a backup all other data being collected. This gave me an opportunity to collect values for permeability, skin and P* while the well was shut-in without added intervention. I trust in both the accuracy and reliability of the SPIDR® well testing system for all my surface pressure acquisition needs.

Timothy H. Bertsch, Artificial Lift Engineering Tech, Shell E&P, New Orleans, LA

The SPIDR® system 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® system 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® system gauge and Halliburton. 

Outside of the SPIDR® system, we also rely on the engineers at Halliburton 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 Halliburton.

Jim Skurner, P.E., Manager Reservoir Engineering, Enhanced Oil Resources, Inc.

As a 15+ year user of Halliburton's SPIDR® gauge, I can attest to its utility. The SPIDR® system 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® system to ensure that the SPIDR® system is giving us data that can reliably be used to estimate the required reservoir parameters, and it has.

Ralph R. Roesler, Sr. Reservoir Engineer, Southwestern Energy Company, Fayetteville, AR

Halliburton 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. Halliburton also gives great service and attention to detail.

Betsy Cook, Senior Engineer, Nexen Petroleum U.S.A. Inc., Dallas

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® system 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® system installation from an operational perspective.......

Gary Herricks, Reservoir Engineering Advisor, Chevron, Lafayette, LA