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The following material was emailed to us by David Mallard of Microfrac Technologies Corp.  AnaLog Services, Inc. has no economic interest in Microfrac, and we make no representations as to the accuracy of the material on this page (we have verified nothing on this page).  Minimal spelling and grammatical corrections have been made, but we lack the time to properly edit this material.

From: Beth and David Mallard <mew@gte.net>
To: syd levine <analog@logwell.com>
Sent: Wednesday, November 01, 2000 6:31 PM
Subject: MICROFRAC QUESTIONS

Microfrac Technologies Questionnaire

[Introduction deleted.]

Procedures and Wireline Service Company Questions:

1. Describe the tool and propellant.  How can we prove that this propellant is an improvement over what has been used in the industry?  Is it a vast improvement or just a tweak of what has been out there?

Currently the tool is in the third phase of development that has taken over five years of R&D to develop.  The dynamics of our tool out shines all other attempts at developing a High Energy Pressure Frac for use in oil and natural gas recovery for the following reasons:
  (1) Our research team just won a $6 million dollar Navy contract to evaluate and assist major military contractors like Thiokol, General Dynamics, and Raytheon, which contractors recently blew up 56 artillery pieces in a futile attempt to launch a 105 cannon shell 90 miles (historically shells fire at 18 miles).  Our scientists were able to launch their first shell 93 miles by developing a sophisticated rocket assist unit, which did not explode when the shell was fired. To date our team has completed 38 successful test firings and have reached a distance of 138 miles.  While this example may seem unrelated to down hole performance, and fracturing it is not, billion dollar companies with tremendous resources were unable to complete this task, as they have been unable to develop as much controlled power and thrust, as we have in our MICROFRAC X-2000 down hole-tool.
  (2) There exist thousands of combinations of chemicals, but we have 8 formulas that really work.  [Unverified assertions about competitors deleted.]
  (3) All other types of down-hole pressure fracs have 25% of the power curve we have developed; not all tools are the same.
  (4) While our competition is playing with VWs, our system would be akin to a racing Turbo Porsche.
  (5) The base tool is 2 inches by 17 inches.  2 Grains loaded in a 10 foot hollow carrier make 1 tool.  Each Grain will cover a 5- foot pay zone.  Tools may be divided into 1 grain shots for smaller pay zones, but for marketing purposes 1 tool must always equal 2 grains.
  (6) In the final analysis, customers are focused on potential results.  In recent tests, with Thiokol scientists present, we saw physical communication with an adjacent sister well some 1,250 feet away in a Tennessee Limestone bed at 1,600 feet.  Other chemical base pressure tools are advertised as developing energy releases to 60 feet, if that.
  (7) Our early tests in Casper, Wyoming, produced a production curve registering 22:1.  Before releasing our energy, the well was producing 1,250 barrels of fluid per day.  After we shot a 10 foot zone and a 20 foot zone production dramatically increased to over 24,800 barrels of fluid per day.  Some five months after that demonstration, the test well is still holding at 19,000 barrels of fluid per day.  A complete DOE report should be made available to all interested customers.
  (8) The fracturing benchmark for most contemporary fracturing methods ranges from a 200 to 300% increase.  Lighter rock formations, like shale, tight sandstones and methane coal-beds will stay open longer than heavier rock formations.
  (9) As a rule of thumb, our system should out gun other attempts at this technology 3:1; however, we cannot predict the outcome of any well situation or promise results, as each formation and well history is widely different with many variations, which make it impossible to guess or guarantee.
(10) Our early tests indicate we are way beyond just a tweak.  Several countries have had their engineering firms review our technology, and contracts are forthcoming for entire nations and their national oil and gas reserves.


2. Is the propellant placed in a canister?  Just what are the components of the tool?

We can deliver the tool into the well bore via a hollow carrier, which must be watertight at deeper levels.  This is helpful in that the carrier acts as a container to harness all the energy and direct it horizontally into the pay zone.  We have also been improving several other systems to accommodate shallow wells, using a light weight fiberglass carrier joined to an ignition stem, which allows for maximum energy releases, avoiding loss of wire line and damage to well casing. Please note that well selection is important (wells that take a lot of water, over 1,000 barrels per day are thought to be already open).  We should be looking for wells that have tighter porosity and permeability in the under 18 milidarcy range.  The tools are cylinders of complex energetic materials.  The formulas are secret company property and will not be disclosed.  We have engineered a chemical mask so that no amount of spectra-analysis can determine the formula.


3. Who needs to handle and load the tool?

All field wire line services will need an ATF license to handle the tools.


4. What tools go down the hole?  GR, CCL, Canister

The tools can be designed to accommodate a wide variety of well bore situations from smaller pay zones of 4 feet to large 100 to 300 foot pay zones.  Delivery has become an important part of the equation for safety and optimum results.  Wire line companies who desire to work the Microfrac tool must pay $1,000 [sheesh, editor] for a short course in proper down-hole delivery of the tool.  A teaching video is in the works.  Our engineers will recommend the proper number of tools and their mode of delivery into the well bore.  There are so many variations and needs requirements, that at this writing each well must be individually evaluated to formulate the number of tools needed to service the well and the custom carrier designed for the job.  Right now we have a hollow carrier format, providing the well bore is 5.5 inches or greater.  We can join a number of tools in a string to service a greater pay zone and we have a light-weight fiberglass water proof carrier complete with a hot rod connection for perfect ignition.  In one of our recent tests the force of the suction was so intense a ¼ inch solid steel connecting rod 2 inches in circumference, collapsed to an 1/8th inch opening (another incredible Microfrac first!).


5. What type of wireline cable is required?

Standard wire line cable is okay.  The tools are lightweight.  A 10 -foot hollow carrier, filled with frac sand and 2 grains of our tool will weigh less than 200 pounds.


6. Can slickline be used?

Yes, slick wire line is okay, as long as it will support the rated weight of 200 to 300 pounds.


7. How is the canister/tool physically and electrically attached to the wireline?  Is it a normal oilfield procedure, or are there special instructions we will have to supervise with each service company?

We have developed several ignition systems with the assistance of Well Services in Crossville, TN.  The wire line operators will connect their normal firing wire to a fireplug, detailed in the operator's guideline handbook.  Additional firing systems are being evaluated; however, Well Services will be happy to advise other wire line operators.  Note:  Most operators are aware of basic firing procedures for perforation guns; the system is similar.


8. Can we design the tool so that it can be easily handled by the wireline company when it is attached to their tools?

Our Microfrac tools are universally designed to be used by any wire line service rig on the planet.  Any decent wire line crew will have no problem using this tool in the field with just a little coaching from a telephone consult, video or instruction guide line, being developed by Microfrac.


9. Will a wireline company have any liability and safety problems running the Microfrac tool?

Most small and independent wire line service companies carry $2 million dollars in personal injury and well damage coverage.  These coverages are normal and will be more than sufficient to offset risk and use.


10. How is it fired from the surface?  Is it a normal wireline electric command from the truck or will they need special equipment and instructions?

Wire line trucks are outfitted with normal fire wire capability.  When they lower our tool to the desired depth, they set and push their firing ignition system.  An electrical current races through the inside of the wire and sets off a small blast, which in turn ignites the tool.  Please note our tools DO NOT EXPLODE!!!  They ignite and generate a massive energy pulse wave that slams into the formation rock at 22 miles per second, loading the rock with more energy than the rocks can absorb, thereby fracturing the surrounding formation in a radial fashion.  This pulse wave has 4-5 energy cycles.  The energy cycles closest to the well bore mouth are the strongest.  As the energy moves through the rock and around the rock, it loses it's intensity the farther out it goes from the ignition site (the well bore).


11. What is the best method of igniting the subsurface tool; primer cord, blasting cap, or by another method?

The best method of igniting the tool is by threading 100-grain deflagration fire wire cord by hooking it to the wire line firing wire system with an electrical system called a bobby pin.  80-grain det cord has been successfully used, but it tends to chunk out the tool and lessen the results of the frac.  By staying in the ignition loop, our engineers have created a full 40% increase in efficiency.


12. What is destroyed or damaged?  Canister, wireline tools, wireline?

By using the hollow carrier, with 4-10 ¾ holes per running foot, providing the hollow carrier is thick walled ¼ inch steel, no wire line should be lost.  The 2 grains convert to hot gases and are loaded into the formation pay zone thereby fracturing the pay zone and melting migrating fines and paraffin wax clogging the perforation holes.  Once new pools of energy are stimulated, energy in the form of oil or gas or methane gas begins to flow again.  This is the whole reason behind the secondary recovery effort.  NOTE:  It is worth noting that no well ever runs dry.  Most wells retain up to 70 to 85 percent of their reserves!  The challenge is to stimulate these wells to optimize the recovery.  Most wells will only give up 30% of their reserves.  Any effort to increase the recovery up to 40-50% will be well received in the oil patch.  Our tools are an economical and efficient solution in the over all recovery effort.


13. Can we prove to the wireline company that we will not destroy their wireline or sub-surface tools?

Yes, providing they listen to our wire line advisors and follow our instructions.  We have already bent the learning curve and they will profit from our collective experience, if they listen and follow our tried and true methods.


14. If there is any damage who is liable to pay for the replacement?

Liability issues fall with the well operator and the wire line operator.  Once we deliver the tool they are on their own.  We are no different than any other well services company in that respect.  Old well casings or casing that are not properly cemented must be avoided.  Shooting wells that are near underground water tables must be closely analyzed.  Along with well histories common sense must be applied to every well setting.  Many potential problems will be avoided, if everyone looks before they leap into a completion situation and follow our instructions.  Greed and taking inappropriate short cuts must be avoided and in so doing "train wrecks" will be few and far between.


15. Is there any junk left in the hole or trash that will need to be recovered?

It is possible in a misfire to occasionally lose an entire tool.  In most cases, there is minimal debris and tools or connecting pieces can be fished out.  Most wells are designed with 30-40 foot rat holes for any unwanted junk that falls to the bottom of the well.


16. How much fluid in the wellbore is required to be above the tool?  Is it a hydrostatic safety precaution, an energy absorbing technique, or a surface safety factor?

In most gas well settings, we only need a water block that will offset bottom hole pressures, formation pressures, which will widely vary from well to well.  In oil wells we need to use a diesel block, which will decrease the swabbing unit time at the well.  For safety's sake a good water or diesel block will help direct the energy outward, not upward, and depending on the depth of the pay zone, a water block can be installed to within 200 feet of the ground.  Hydrostatic pressure will keep oil and gases from exiting the newly fraced well until they are removed.  A good rule of thumb is that hydrostatic weight is equal to ½ of the distance of the column of water or fluid.  If we were working at 6200 feet, the hydrostatic pressure bearing down on the release of the new energy trying to surface is 3,100 pounds.  This weight must be removed before the oil well is put on pump or we can get an accurate picture of the true gas flow in the recovery effort.  A hollow carrier could withstand pressures of 9,000 pounds working at a depth of 18,000 feet or 3 miles below the surface.  Warning:  All port plugs must be absolutely water-tight!!!


17. Is there a recommended or minimum hydrostatic head needed to safely use the tool?  Why?

The minimum head should be equal to the bottom hole pressures.  Bottom hole pressure is 2,000 pounds, at 5,000 feet of depth, we should develop a 4,000 foot fluid block, which would give us 2,000 pounds of hydrostatic pressure.  Why?  (1) We want the force of the energy to go outward not upward.   (2) We want to contain any upward surge within the well bore so no spillage occurs around the surface of the well.


18. Does it matter if the fluid pad is water, oil, acid or other?

The block should be water for gas and methane wells, and crude oil or diesel for oil formations.


19. Can the wellbore be empty?

Yes, I have read of dry shots, but they are rare and much more dangerous and more difficult to fire the tools remotely underneath a wire line block.  We would not want a steel block to become airborne and land on anything.

Exercise extreme caution when working with explosives.  Stay alert and THINK; complacency kills!  Follow the guidelines in the American Petroleum Institute (API) Recommended Practices for Oilfield Explosives Safety, RP 67.

Last 10-20-10