CASE HISTORIES

Field Trials and Results:

1. Morrison Petroleum Ltd. 9D-35-35-6 W4 (Consort, Alberta)
2. Anderson Exploration 14-31-4-4 W4 (Manyberries, Alberta)
3. Omega Hydrocarbons Ltd. 87-4 W6 (Worsley, Alberta)
4. Tarragon Oil and Gas 10B-13-20-20 W4 and 13C-13-20-20 W4 (Jumpbush, Alberta)
5. Rising Resources Ltd. Townships 46 & 48 W5 (Pembina, Alberta)
6. Universal Exploration Ltd. A multi-well pool at 15-16 W3 (Swift Current, Saskatchewan)
7. Numac Energy Inc. 5-15-118-7 W6 (Shekelie, Alberta)
8. Talisman Energy Inc. 6-32-75-14 W4 and 11-9-79-15 W4 (Lac La Biche, Alberta)
9. Murphy Oil Company Limited 6-7-87-9 W5 (Red Earth, Alberta)
10. Fletcher Challenge Petroleum Inc. 8B-28-36-5 W4 (Consort, Alberta)
11. Chevron Canada Resources 4-12-74-6 W5 and 8-25-73-6 W5 (Slave Lake, Alberta)
12. International Colin Energy Corporation 1-22-90-5 W5 (Red Earth, Alberta)
13. Venator Petroleum Canada Ltd. 8-11-7--6 W6 (Grand Prarie, Alberta)
14. Renaissance Energy Ltd. 8-11-55-20 W4 (Elk Island, Alberta)
15. Poco Petroleums Ltd. 8-23-53-18 W4 (Beaverhill Lake, Alberta)
16. Imperial Oil Resources Ltd. 8-6-65-3 W4 (Cold Lake, Alberta)
17. Shell Canada Limited. 14-33-85-18 W5 (Peace River, Alberta)
18. Bow Valley Energy Ltd. Well T-62 (Tanjung, Indonesia)

 

 

1. Morrison Petroleum Ltd.
Well Location: 9D-35-35-6 W4 (Consort, Alberta)
Description: Serious paraffin problem downhole and in the flowline. Pigging from the wellhead to the treater took 7-8 days. The problem prior to Para-Tech's involvement was treated by a chemical drip and monthly batch treatment of chemicals. In addition, hot oiling occured every 2-3 months.
Production: 20 bbls/d Oil
Remedy: Six pairs of surface blocks were installed on the flowline.
Result: One week after installation of the surface blocks, the pig would travel unrestricted in the flowline. Six months after installation, chemicals and hot oil treatments were discontinued, and the well has produced continuously to date. This was the first Enercat installation
Confirmation: Keith Hannah
2. Anderson Exploration Ltd.
Well Location: 14-31-4-4-W4 (Manyberries, Alberta)
Description: A Sunburst oil well, 25 years old, hot oiled every 30 days. Between hot oil treatments production would drop 65%. The 2.5 km flowline was pigged routinely.
Production: 35 bbls/d Oil, 800 mcf/d Gas
Remedy: 3 Enercats were installed downhole.
Result: The well has not been hot oiled since the Enercats were installed. The flowline has not requires pigging. Visual inspection of the flowline at the pig launcher confirms no wax visible in the flowline. Production has stabilized and several other wells in the pool have been equipped with Enercats. This was the first downhole Enercat Installation (1991).
Confirmation: Lee Van Buskirk
3. Omega Hydrocarbons Ltd.
Well Location: A five well pool at 87-4 W6 (Worsley, Alberta)
Description: Five oil wells with serious wax and water problems, deemed uneconomic by Gulf Canada prior to the sale to Omega.
Production: 120 bbls/d Oil from five wells.
Remedy: All five wells equipped with from 3-5 Enercats each.
Result: Production from the five wells total 600 bbls/d Oil, with no hot oiling required. Inspection post installation revealed no wax or scale in the production tubing, flowlines, separators, treaters or storage tanks. A slight flim of sticky residue exists in the bottom of the 1500 bbl shipping tank.
Confirmation: Dennis Hall
4. Tarragon Oil and Gas
Well Location: 10B-13-20-20 W4, and 13C-13-20-20 W4 (Jumpbush, Alberta)
Description: Severe wax deposition treated by hot oiling every 3 weeks. These wells are equipped with progressing cavity pumps.
Production: 150 bbls/d Oil per well.
Remedy: 3 Enercats were installed downhole on each well.
Result: The wells produced with no sign of wax deposition for 8 months, then began to wax up. The Enercats were retrieved and found to have been rendered inoperative by virtue of the build up of Iron Sulfide deposits caused by exposure to Hydrogen Sulfide. They were replaced with internally coated tools and the wells have produced without further paraffin deposition to date. All Enercats are now internally coated with a light epoxy coating.
Confirmation: Duncan Chisholm
5. Rising Resources Ltd.
Well Location: Townships 46 & 48 W5 (Pembina, Alberta)
Description: Cardium Oil wells which all experienced wax deposition in the top third of the production tubing. Treatments included chemical batching, hot oiling and rig work every 3-6 months.
Production: 5-25 bbls/d Oil, 5-25 bbls/d water.
Remedy: Approximately 20 of the wells in this area have been equipped with Enercats, varying from 1-2 tools per well depending on volume of fluid.
Result: Each well has produced without need for additional treatment since the Enercats were installed. The operating company has pulled rods in some wells to confirm that the tools are performing downhole. These wells continue to be free of wax and scale.
Confirmation: Brian Hayward
6. Universal Exploration Ltd.
Well Location: A multi-well pool at 15-16 W3 (Swift Current, Saskatchewan)
Description: All of the wells in the pool experienced downhole and surface wax, requiring regular treatment such as circulation and hot oiling.
Production: 20-70 bbls/d Oil
Remedy: Five wells were equipped with Enercats over a period of time commencing June '93, from 1-3 tools being installed on each well.
Result: The wells equipped with Enercats are now producing at an increased level, with no further requirement for treatment with chemicals or hot oil.
Confirmation: Leroy Peats
7. Numac Energy Inc.
Well Location: 5-15-118-7 W6 (Shekelie, Alberta)
Description: This well was a flowing Keg River well, which was treated for wax every 4-5 days by wireline, before being placed on pump. The H2S content is 16%.
Production: 180 bbls/d Oil
Remedy: 7 Enercats were installed downhole in November 1993.
Result: No downhole treatment has been required since the installation. There is still some wax appearing in the flowline. The pump was pulled in November 1995 and no visible evidence of wax deposition was observed. Numac has installed Enercats in other areas.
Confirmation: John Graham
8. Talisman Energy Inc.
Well Location: 6-32-75-14 W4 and 11-9-79-15 W4 (Lac La Biche, Alberta)
Description: McMurray gas wells with tar like asphaltene deposition downhole. The wells were on continuous chemical injection in order to sustain production. These wells would have to be shut in during the summer months because of insufficient chemical storage at the well sites, and the sites are inaccessible due to the muskeg during this time.
Production: 150 mcf/d gas, per well.
Remedy: 3 Enercats were installed on each well in 1994.
Result: Chemical treatment was discontinued and the wells have produced at a stable rate with no signs of asphaltene deposition.
Confirmation: Jack Lee
9. Murphy Oil Company Limited
Well Location: 6-7-87-9 W5 (Red Earth, Alberta)
Description: A Keg River oil well in an area known for severe wax deposition. The well was directionally drilled under a lake and equipped with a progressing cavity pump.
Production: 100 bbls/d Oil, 1 mmcf/d Gas.
Remedy: Six Enercats were installed on the tubing string above pump.
Result: The well has maintained uninterrupted production with no signs of wax deposition since the installation.
Confirmation: George Becker
10. Fletcher Challenge Petroleum Inc.
Well Location: 8B-28-36-5 W4 (Consort, Alberta)
Description: Oil well with wax deposition requiring periodic hot oiling.
Production: 25 bbls/d Oil
Remedy: Two Enercats were installed as tail joints in July 1994.
Result: The well has not been hot oiled since the installation. There is no evidence of wax anywhere. The companyt has installed Enercats in other wells in the area. Once Enercat is sufficient for this rate of production.
Confirmation: Howard Bye
11. Chevron Canada Resources
Well Location: 4-12-74-6 W5 and 8-25-73-6 W5 (Slave Lake, Alberta)
Description: Directionally drilled oil wells under Lesser Slave Lake. These wells had severe wax deposition which required regular treatment.
Production: 100 bbls/d Oil, 25 bbls/d Water for both wells
Remedy: These wells were changed from gas lift to rod insert pumps in March, 1994 and equipped with Enercats.
Result: Both wells have produced steadily without any evidence of wax deposition.
Confirmation: Dave Shepherd
12. International Colin Energy Corporation
Well Location: 1-22-90-5 W5 (Red Earth, Alberta)
Description: This is a pumping Keg River Oil well which experienced heavy wax deposition, and required regular treatment with chemicals and hot oiling.
Production: 315 bbls/d Oil
Remedy: In June 1994 the well was equipped with 7 Enercats. These were placed at regular intervals on the production tubing.
Result: The well has produced steadily since the installation without the need for any further treatment for wax build up.
Confirmation: Rob Paul
13. Venator Petroleum Canada Ltd.
Well Location: 8-11-7--6 W6 (Grand Prarie, Alberta)
Description: Newly completed Doe Creek Oil well in November 1995. The adjacent oil well has wax deposition down hole and in the flowline, requiring hot oil treatments and frequent pigging.
Production: 43 bbls/d Oil
Remedy: Two Enercats were installed on the production tubing on completion.
Result: No hot oil treatments have been required on this new well. No wax has been observed at the pig catcher after pigging. The field operator has noticed a significant difference between the two wells as far as wax deposition, pigging, maintenance and production.
Confirmation: Tony Van Winkoop
14. Renaissance Energy Ltd.
Well Location: 8-11-55-20 W4 (Elk Island, Alberta)
Description: Directional, sour Oil well with significant wax deposition downhole, requiring regular batch treatments and rig work.
Production: 44 bbls/d Oil, 94 bbls/d Water
Remedy: 4 Enercats were installed as tail joints.
Result: No further downhole treatment has been required. The flowline has seen some wax deposition from time to time.
Confirmation: Milt Rooney/Randy Keith
15. Poco Petroleums Ltd.
Well Location: 8-23-53-18 W4 (Beaverhill Lake, Alberta)
Description: This is a Sparky Oil well requiring hot oil treatments every 2-3 months.
Production: 10 bbls/d Oil, 22 bbls/d Water
Remedy: One Enercat was installed below the pump in June 1995.
Result: No further treatments for wax deposition have been required since installation.
Confirmation: Kevin Hertz
16. Imperial Oil Resources Ltd.
Well Location: Esso T-31 Leming/Ethel Lk 8-6-65-3 W4 (Cold Lake, Alberta)
Description: 90m Water source well for SAGD Heavy Oil recovery. This well was scaling up every nine days in pump and tail joints.
Production: 188 bbls/d Water
Remedy: Four Enercats were installed as tail joints with the aim of increasing production to 630 bbls/d.
Result: The well has pumped continuously at a rate of 188 bbls/d for 2 months since installation. There has been no evidence of scale deposition. The production rate has not increased because of sand inflow problems. Imperial is currently conducting a trial on a producing pad.
Confirmation: Dave Gardiner
17. Shell Canada Limited
Well Location: 14-33-85-18 W5 (Peace River, Alberta)
Description: A vertical heavy oil well on steam flood (SAGD). The down hole pump and production tubing would scale up every 3 to 4 weeks and need tobe replaced.
Production: 400 bbls/d fluid at a 10% tar cut.
Remedy: In May 1995 four Enercats were installed below the pump.
Result: Six months after installation the well was still on continuous production and visual inspection of the downhole pump and tubing showed no sign of scale deposition. Production increased to 800 bbls/d of fluid with pump efficiencies improving 50-55% to 80-86%. Since this first installation Shell has equipped a number of wells in this project with excellent results.
Confirmation: Samantha Nicholson
18. Bow Valley Energy Ltd.
Well Location: Well T-62 (Tanjung, Indonesia)
Description: An Oil well with paraffin content in excess of 30%. During cool periods of the day and evening, production would drop substantially. The flow line would require frequent hot water flushing.
Production: 40 bbls/d Oil.
Remedy: 3 Enercats were installed on the production tubing.
Result: Average production increased to 80 bbls/d Oil. Continuous flowline pressure was maintained and hot water flushing was discontinued.
Confirmation: Ron Linder

 

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