Using Heat in Combination With Solvents To Clean Up Formation Flow Channels
- J.T. Rollins (Dowell) | L.C. Taylor (Dowell)
- Document ID
- Society of Petroleum Engineers
- Journal of Petroleum Technology
- Publication Date
- October 1959
- Document Type
- Journal Paper
- 33 - 36
- 1959. Original copyright American Institute of Mining, Metallurgical, and Petroleum Engineers, Inc. Copyright has expired.
- 4.1.5 Processing Equipment, 4.1.2 Separation and Treating, 5.1.1 Exploration, Development, Structural Geology, 4.2.3 Materials and Corrosion, 4.3.4 Scale, 5.2 Reservoir Fluid Dynamics, 1.8 Formation Damage, 3 Production and Well Operations, 2.2.2 Perforating, 4.6 Natural Gas
- 1 in the last 30 days
- 182 since 2007
- Show more detail
- View rights & permissions
A new stimulation technique has been developed for restoring blocked permeability in both injection and production wells. The method utilizes a combination of heat and chemical solvents to remove organic and inorganic deposits that have accumulated in formation flow channels and on the face of the wellbore, during operation. The treatment is conducted in two-stages. First, a gelled oil, carrying a suspension of 20-60 mesh magnesium pellets, is injected into the pay zone. This is followed by 15 per cent hydrochloric acid which, reacting with the magnesium pellets already in the well, liberates considerable heat (8,400 BTU/lb of magnesium). As a result, the temperature of the formation may be raised several hundred degrees. The spent acid is now produced from the well, followed by the oil which has picked up many paraffin and asphalt deposits liquefied by the liberated heat. In addition, the acid solution used to release the heat reacts with any lime, oxide or sulfide deposits on the face of the pay, dissolving and removing them. To date, this new heat application has been successful on about 60 per cent of production and injection wells treated. Many of these wells have failed to respond to other type treatments. As refinements and improvements are made in treating procedures and selection of wells for treatment, a higher success ratio may be expected.
Many wells show good output after initial stimulation treatments, but after a short time production falls off more rapidly than would be expected on the basis of formation pressure and permeability. The cause for such abnormal declines is usually either an equipment failure or change in formation characteristics. In the latter case, the trouble is frequently caused by some foreign material which partially plugs the flow channels, hindering the migration of reservoir fluids into the wellbore. Such plugging may result from either organic or inorganic mineral deposits, or both. The buildup of organic deposits often results from a decline in reservoir pressure which allows dissolved gas to break free.
|File Size||1 MB||Number of Pages||4|