DRC - Data Retrieval Corporation

General Discussion :: gas well deliverability

Author: franco_79_30
Subject: gas well deliverability
Posted: Fri Nov 09, 2007 6:59 am (GMT -5)
Topic Replies: 0

I am simulating a gas field. We only have one well drilled and one deliverability test. I need to know how I can pronosticate the deliverability change through time for this well in order to use the data with the simulator for all the wells.

Thanx

SPIDR News and Updates :: Lunch and Learn provides new tools for young Engineers

Author: Swartley
Subject: Lunch and Learn provides new tools for young Engineers
Posted: Wed May 30, 2007 4:54 pm (GMT -5)
Topic Replies: 0

At Data Retrieval Corporation we are always more then willing to teach new Engineers about the benefits of testing. It can be very beneficial for a company to provide their young employees with knowledge of technologies that they may not have learned of in school.

We feel that all new Engineers should learn that accurate well testing can be accomplished from surface. This will give them an invaluable tool to use when they come upon wells that are suitable to test from surface. If you are interested in setting up a presentation for your company please feel free to contact us any time.
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SPIDR Applications :: Subsea SPIDR Applications

Author: RodK
Subject: Subsea SPIDR Applications
Posted: Wed Oct 11, 2006 11:58 am (GMT -5)
Topic Replies: 0

We've recently been contacted by a Gulf of Mexico operator who is performing removal operations of platforms toppled by last years hurricanes, to monitor the casing pressure (at mudline) of shelf well(s) during Abandonment operations.

Because of our long-standing arrangement with Oceaneering where we supply SPIDR gauges to them for deepwater deployment, this is a fairly benign application for the SPIDR.
Oceaneering is able to supply and install the SPIDR and cabling back to the barge to monitor pressures, real-time, for extended periods. i.e. 30 days or longer as required.

We started working with Oceaneering about 5 years ago when an operator in the Gulf of Mexico who operated Subsea wells, experienced failure of his Downhole Permanent Pressure Gauge (DHP) and was concerned with producing the well at too high a drawdown and damaging the completion. The SPIDR / Oceaneering solution was pioneered, designed and utilzed to gather pressure data at the Subsea Wellhead for use in Pressure Transient Analysis.

This is an excellent application for a couple of reasons.

1) It can be used to establish a relationship between pressures with the DHP and the SPIDR while the DHP is still functioning as a backup in case the DHP fails at some future point.

2) As a stand alone pressure data gatherer when the DHP has already failed. DRC's core business is acquiring pressure and accurately converting that pressure to BHP via our proprietary algorithm

3) The system can be utilized by Oceaneering or rented out to other ROV operators who may have occasional Subsea work to perform where gathering pressure alone would not support the cost of the entire operation.

SPIDR Applications :: RE: Potential Application?

Author: stevefarnsworth
Subject: RE: Potential Application?
Posted: Tue Oct 03, 2006 1:18 pm (GMT -5)
Topic Replies: 1

The unfortunate nature of the situation you are explaining is that the well is on artificial lift. Regardless of what the well produces; oil, gas, and/or gas-condensate, the velocity in the tubing needs to be great enough to lift all the produced fluids to the surface naturally. There are some situations where a test procedure along with understood uncertainties will allow us to conduct testing from the surface in wells that don't naturally unload, but artificial lift negates that possibility.
_________________
Regards,
Steven Farnsworth
Sales Engineer
Data Retrieval Corporation
Ph (281) 444-5398 - Fax (281) 444-5397
Email : drc@spidr.com

SPIDR Applications :: Potential Application?

Author: prospectiveuser
Subject: Potential Application?
Posted: Tue Oct 03, 2006 10:27 am (GMT -5)
Topic Replies: 1

I'm fairly certain that the SPIDR will not work for this application, but I figured I'd ask.

Oil Well - ~20 Mscf/STB
Horizontal re-entry of a vertical well
~3300' of horizontal lateral
BHP ~ 1300 psi
BHT ~ 250 degrees
Producing ~ 70 BLPD
~70% Oil Cut
Producing via sucker rod pump

Relatively low H2S concentration

Can the SPIDR work on these types of wells?

General Discussion :: Commercial PTA Packages - The Pitfalls.......

Author: RodK
Subject: Commercial PTA Packages - The Pitfalls.......
Posted: Fri Feb 24, 2006 4:49 am (GMT -5)
Topic Replies: 0

Most operators have an in-house copy of one (if not more) of the major PTA packages on the market today. All of these packages have one thing in common. They typically use TYPE CURVE MATCHING in order to perform the analysis. The programs are very sophisticated and typically have a lot of options on them for use. They want to make it easy for the user by trying to create a match with a push of a button......

The point I want to make with this post is the following.......when Surface Pressure Data is collected it tends to scatter and be "noisy". This scattered data tends to be difficult to use on a derivative plot (which are used for type curve matching). In fact, a major reason why some people believe that surface pressure data is not valid is simply because they don't want to put in the extra time it takes to analyze a test. They typically would blame the perceived poor quality of the data as a reason not to use surface well testing. In effect what they are doing is letting their in-house software package and it's inherent limitation dictate what data they can use.

In addition, I believe there is more opportunity for an error in analysis with type curve matching.....and this error margin goes up significantly the less experience a person has using the software.

Here at DRC we utilize a method of PTA that's been around a while called MDH (Miller-Dyes-Hutchison) analysis. We analyze the semilog which we find is less prone to error and generate a derivative plot but only use it when the radial flow is not obvious in the semilog...so, it's used more as a check and confirmer. The analysis process is much more straightforward and therefore it's much more difficult to "go off the tracks" with wrong answers.

PTA is an art and a science. There is not one "right" answer but rather a range of answers that could be justified as being correct.

General Discussion :: RE: Build-Up on Tight Gas wells

Author: Stacy
Posted: Tue Jan 31, 2006 4:57 pm (GMT -5)
Topic Replies: 1

The amount of time required for a well to reach the mid-time, or radial flow, section for pressure transient analysis will be dependent on the permeability. The lower the permeability, the longer amount of time required to test a well.

One of the benefits of using a SPIDR system to test a low permeability well is the ability to download the data at any time during the test. Once the data has been downloaded then it can be evaluated for transient status. This minimizes the actual amount of shut in time required to test because as soon as radial flwo is achieved the well is brought back online. It also ensures that the test achieves its objectives.

Stacy
_________________
Petroleum Engineer, SPIDR Sales & Service

SPIDR Applications :: PreFrac Injection/Fall-off Testing utilizing the SPIDR

Author: RodK
Subject: PreFrac Injection/Fall-off Testing utilizing the SPIDR
Posted: Wed Nov 16, 2005 10:26 am (GMT -5)
Topic Replies: 0

We've recently talked with a lot of operators around the country...Rockies, Mid-Continent, S. Texas and found a large number of them perform DFIT tests. The use of this technique is rising rapidly for a number of reasons.
1) Infill drilling and the potential to encounter depleted zones. Typically log-derived correlations to determine permeability and reservoir pressure had not been successful at identifiying these depleted zones and an empirical method (DFIT) is required. "Incorrect reservoir pressure and permeability will typically result in wrong fracture geometry and pre-frac rate prediction" (SPE 90455)
2) As Frac jobs get bigger and more complex the $$ go up. Driving some engineering into optimizing the frac by the DFIT has become increasingly attractive.

Some of the issues that conspire against running these tests are the availability of a pumping unit or test pump. Typically in these busy times...frac scheduling is often many weeks in advance and the major companies often cannot spare personnel and/or equipment to perform these jobs.
The best option seems to be utilizing the "mom & pop" pumping companies.....all that's required is to pump water or KCL water at 2-3 BPM with a total volume pumped of 10-20 Barrels to achieve formation breakdown.
Using the SPIDR gauge for Pressure Data Acquisition seems to be an advantage as it allows the Operator to pump the job and then send the pump back to the base avoiding additional onsite charges. Allow the SPIDR to capture pressure overnight 24-36 hrs. download data and import into your analysis program.

So to capsulize.....

1) Perform DFIT one or more days ahead of the scheduled Frac job that allows the operator to take advantage of gathering at least 24 hrs. of falloff data and analyzing before the FRAC. Capture the Pressure data with SPIDR, download data the next day and email to engineer for analysis

SPIDR Applications :: Hurricane testing - An Explanation

Author: RodK
Subject: Hurricane testing - An Explanation
Posted: Thu Sep 22, 2005 11:08 am (GMT -5)
Topic Replies: 0

At DRC we often send out hurricane advisers prior to a Hurricane entering the Gulf of Mexico. We primarily email this out to our customers and other prospective clients who operate gas wells in the GOM and near shore Gulf Coast areas both inlandwater and land.
The reason we do this is because a lot of our clients have asked us to advise them or remind them about our services during this chaotic time. They realize that they are not going to get authorization to shut-in their wells during the normal course of business because of the current oil/gas pricing....however they desire information about their completions and reservoir as often as they can get it. Hence the dilemna!

A hurricane...while unfortunate...is often a good time to perform transient well testing because wells in the path or periphery of the hurricane will often be shut-in. These wells are perfect candidates to be tested.....after all for a transient test to be valid.....you need to either: a) start from a flowing situation and shut-in or b) start from a shut-in position and begin flowing......sometimes we are able to get valid data during the flow cycle if the choke size is opened or closed sufficiently to induce another transient but the conditions have to be good for this to be a valid method.

We have received a few emails back from prospective clients and others suggesting that we might be taking advantage of our clients by suggesting the use of our services during this time.
I believe if they understood the full story about the lack of opportunities to actually perform transient testing and the requests that we receive from many of our everyday customers asking for reminders.......they might have a different feeling of what we are actually trying to achieve and how we are actually performing a service that many of our customers have requested of us.

However, we welcome your feedback on this issue and please believe we don't take our responsibility lightly on this issue.

SPIDR Applications :: Are SPIDR"s Used to Record DFIT's?

Author: skeptic
Subject: Are SPIDR"s Used to Record DFIT's?
Posted: Mon Sep 19, 2005 3:37 pm (GMT -5)
Topic Replies: 1

I am looking at a campaign of pre-frac, injection fall-offs for one of my new wells in South Texas. Halliburton will be conducting a DFIT on each stage prior to the Fracture-Stimulation Treatment. Can the SPIDR be used for this service? What is it's maximum working pressure? What is the SPIDR's fastest sampling frequency? How long will it record at this frequency?

SPIDR Applications :: Hurricane's and other reasons that cause wells to shut-in

Author: RodK
Subject: Hurricane's and other reasons that cause wells to shut-in
Posted: Tue Aug 30, 2005 4:43 pm (GMT -5)
Topic Replies: 0

At DRC we always strive to provide information to our clients about understanding the "opportunities" to perform transient well tests. To do so, requires a flowing well to be shut-in and vice versa. With the high oil and gas prices the operators are extremely reluctant to shut wells in for the purposes of testing.....understandably so, after all this is their only revenue source.

With that said.....we seek to find opportunities for testing when wells will be shut-in anyway....this could coincide with rig moves, facility or pipeline maintenance, compression issues or facility upsets, etc. Sometimes operators are aware of scheduled downtimes and other times not.

DRC has a solution for both! We often remind our customers that Hurricane shut downs are opportunities to collect pressure data in order to calculate reservoir parameters so that they can use for P/Z calculation purposes and/or skin and perm for their nodal packages. In addition, testing can demonstrate near wellbore skin issues....pre and post treatment testing can give you a good handle on the effectiveness of your well treatment.

In most shut-ins the the Sub Surface Safety Valve (SSSV) will always be closed and thus surface testing is not valid (isolated from the reservoir)...however, by bringing a SPIDR out with the crew when they mobilize back to the platform...collecting pressure data by opening the SSSV (but not the wing valve) firstly can give a good approximation of BHP while a fixed choke drawdown on wells that flow and unload their liquids without slugging, is a good way to get your skin, permeability and Pwf information.

If you don't have any shut-ins anticipated....take a look at your operations report on the platform where you want to test. Often you will find inadvertant shut downs during the course of a month that will allow sufficient opportunities to collect useful pressure data for use in Pressure Transient Analysis. Permeability is directly related to shut-in time necessary to reach radial flow and the high perm. sands of the Gulf of Mexico typically reach radial flow in a matter of hours. So, putting a SPIDR out on your well for 30 days to capture pressure data is often a cost effective way of gleaning useful pressure information without trying to get management approval (and often scorn) to shut a well in for a well test.

SPIDR Technical Support :: RE: Data transfer remotely

Author: George Goody
Subject: Re: remote data
Posted: Mon Jul 18, 2005 1:50 pm (GMT -5)
Topic Replies: 3

rigpig69 wrote:

Power is not available and there is no Scada infastructure present. These need some type of portable system that functions on its own!

In this type of situation one must resort to a satellite telephone. These installations are solar powered and rent for about $10,000 including installation cost. The cost is the same whether for one month or three months. The cost includes minimal air time and can escalate if air time is greater than one hour per day.

Nathan

SPIDR Technical Support :: RE: Data transfer remotely

Author: rigpig69
Subject: remote data
Posted: Mon Jul 18, 2005 8:39 am (GMT -5)
Topic Replies: 3

Power is not available and there is no Scada infastructure present. These need some type of portable system that functions on its own!

SPIDR Technical Support :: RE: Data transfer remotely

Author: George Goody
Subject: Re: Data transfer remotely
Posted: Mon Jul 18, 2005 8:33 am (GMT -5)
Topic Replies: 3

rigpig69 wrote:

I am currently working on a project that requires monitoring daily and remote data collection of 10 wells that are in remote areas and engineering wants to be able to call or poll for data as these are unmanned platforms. Have you provided solutions in the past, and if so was it easy to perform installation.

Can you tell me more about these remote platforms. Is there any kind of SCADA system of computer link on board? Is there any power available?

SPIDR Technical Support :: Data transfer remotely

Author: rigpig69
Subject: Data transfer remotely
Posted: Sun Jul 17, 2005 6:16 am (GMT -5)
Topic Replies: 3

I am currently working on a project that requires monitoring daily and remote data collection of 10 wells that are in remote areas and engineering wants to be able to call or poll for data as these are unmanned platforms. Have you provided solutions in the past, and if so was it easy to perform installation.