Digital Petroleum Atlas
Tovrea Field
General Information
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Digital Petroleum Atlas |
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| Tovrea Field Oil & Gas Data | |||
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General Field Information | |
| Geologic Province: | Goodland Anticline |
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| Exploration Method: | Washdown of well with log and sample show |
| Surface Formation: | Pleistocene Sanborn Formation |
| Oldest Formation Penetrated: | Arbuckle |
| Drilling Casing Practices: | The wells are drilled with rotary rigs primarily using fresh water mud systems, although salt systems have also been used. Surface casing of 8 5/8" is set to depths of 332 to 442 feet. A 7 7/8" hole is then drilled to total depth, often to the Mississippian Dolomite, and a 4 1/2" production casing is set. Completion practices vary from perforating and producing naturally to perforating and acidizing individual zones with up to 2000 gallons of acetic/HCI acid mixtures. The multiple pay zones are typically commingled after later workovers if all are not opened on the initial completion. Scale formation can occur in the Marmaton wells, but is satisfactorily managed with inhibitors. |
| Electric Logging Practices: | Radiation-Guard-Caliper |
| Comments: | Data Source: KOGF, Vol. 5. Other Shows: Tarkio, Howard, Toronto, LKC A-Zone, E-Zone, G-Zone, K-Zone, L-Zone, M-Zone, Lenapah, Cherokee Sands |
| Discussion: | Subsurface mapping, log evaluation and examination of samples from the Jackson, Shear, and Parker #1 Briney (Drilled in 1958) prompted Thunderbird Drilling, Inc. to washdown that well in May 1978. After setting 4.5 production casing, 10 feet of the Upper Pawnee Limestone was perforated and acidized. Swab tests recovered 22 BOPH and the well was subsequently put on pump for 136 BOPD, establishing the Briney Field. Immediately after Thunderbirds discovery, Nielson Enterprises drilled and ran production casing on the #1 Tovrea, 1 mile to the northwest of the #1 Briney. After perforating and acidizing 10 feet of Upper Pawnee Limestone, the well was put on pump for 105 BOPD, establishing the Tovrea field. Log evaluation and subsurface mapping of the two fields reveals northwest trending lenses of porosity in the Lansing-Kansas City and Marmaton limestones. These porous zones are productive where they cross the northeast flank of two positive features mapable on the H-zone, J-zone, Upper Altamont, and Upper Pawnee formations. |
Discovery Well(s) |
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| Discovery Date | Well Name | Available Well Data | Oil Production | Gas Production | LAS File Viewer with Core Data Plots | Core Image | Core Data Table |
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| 07 SEP 1978 | Tovrea 1 | 
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No Gas Production | No Digital LAS Files | No Core Images | No Core Data |
| Well Location: | NE SW 31-T5S-R36W |
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| Rotary Total Depth: | 4970 |
| Production Zone: | Marmaton Group |
| Data Source: | DISCOVERY 600 |
| Discovery Date | Well Name | Available Well Data | Oil Production | Gas Production | LAS File Viewer with Core Data Plots | Core Image | Core Data Table |
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| 26 SEP 1995 | Tovrea 1 |
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No Gas Production | No Digital LAS Files | No Core Images | No Core Data |
| Well Location: | E2 SE SW 31-T5S-R36W |
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| Rotary Total Depth: | 4642 |
| Production Zone: | Lansing - Kansas City Supergroup |
| Data Source: | DISCOVERY 7576 |
Summary Production Information | |
| Field Size: | 1280 acres |
| Total Wells: | 27 |
| Productive Oil Wells: | 8 as of July 2024 |
| Abandoned Wells: | 9 |
| Cumulative Oil: | 543,415.67 bbls as of July 2024 |
Producing Formation:Kansas City: H-Zone |
| Depth Top: | 4666 feet |
| Geological Age: | Kansas City Group, MIssourian Stage, Upper Pennsylvanian Series |
| Depositional Environment: | Regressive Carbonate Shoals |
| Formation Lithology: | limestone, white, fossiliferous, fair-good vuggy and pinpoint porosity |
| Formation Geometry: | Lenticular carbonate shoals associated with positive features |
| Trap Type: | Combination structural-stratigraphic |
Kansas City: H-Zone (Kansas City Group) |
| Thickness: | 10 feet |
Kansas City: H-Zone (Kansas City Group) |
| Produces Oil: | Yes |
| Maximum Net Pay: | 8 feet | Average Net Pay: | 6 feet |
| Drive Mechanism: | Gas in solution, water |
| Initial Pressure: | 1260 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | Water Injection | Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Proven Production: | 480 acres | Production Well Spacing: | 40 acres |
Kansas City: H-Zone (Kansas City Group) |
| Average Oil API Gravity: | 34 |
Kansas City: H-Zone (Kansas City Group) |
| Maximum Porosity: | 13 % | Average Porosity: | 9 % |
Producing Formation:Kansas City: J-Zone |
| Geological Age: | Kansas City Group, Missourian Stage, Upper Pennsylvanian Series |
| Depositional Environment: | Regressive Carbonate Shoals |
| Formation Lithology: | limestone, white, fossiliferous, vuggy and pinpoint porosity |
| Formation Geometry: | Lenticular carbonate shoals associated with positive features |
| Trap Type: | Combination structural-stratigraphic |
Kansas City: J-Zone (Kansas City Group) |
| Maximum Net Pay: | 6 feet | Average Net Pay: | 6 feet |
| Drive Mechanism: | Gas in solution, water |
| Initial Pressure: | 1250 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | Water injection | Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Proven Production: | 480 acres | Production Well Spacing: | 40 acres |
Kansas City: J-Zone (Kansas City Group) |
| Average Oil API Gravity: | 34 |
Kansas City: J-Zone (Kansas City Group) |
| Maximum Porosity: | 17 % | Average Porosity: | 13 % |
Producing Formation:Upper Altamont |
| Geological Age: | Marmaton Group, Desmoinesian Stage, Middle Pennsylvanian Series |
| Depositional Environment: | Oolitic Carbonate Shoal |
| Formation Lithology: | Limestone, white fossiliferous, fair-good porosity vuggy, pinpoint, and interoolitic porosity. Some excellent interoolitic porosity. |
| Formation Geometry: | Lenticular oolite shoal associated with positive feature. |
| Trap Type: | Combination structural-stratigraphic |
Upper Altamont (Altamont Limestone Formation) |
| Maximum Net Pay: | 6 feet | Average Net Pay: | 5 feet |
| Drive Mechanism: | Gas in solution, water |
| Initial Pressure: | 1385 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | Water injection | Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Proven Production: | 480 acres | Production Well Spacing: | 40 acres |
Upper Altamont (Altamont Limestone Formation) |
| Average Oil API Gravity: | 26 |
Upper Altamont (Altamont Limestone Formation) |
| Maximum Porosity: | 20 % | Average Porosity: | 15 % |
Producing Formation:Lower Altamont |
| Geological Age: | Marmaton Group, Desmoinesian Stage, Middle Pennsylvanian Series |
| Depositional Environment: | Oolitic Carbonate Shoal |
| Formation Lithology: | Limestone, white fossiliferous, fair-good porosity vuggy, pinpoint, and interoolitic porosity. Some excellent interoolitic porosity. |
| Formation Geometry: | Lenticular carbonate shoals associated with positive features. |
| Trap Type: | Combination structural-stratigraphic |
Lower Altamont (Altamont Limestone Formation) |
| Maximum Net Pay: | 6 feet | Average Net Pay: | 5 feet |
| Drive Mechanism: | Gas in solution, water |
| Initial Pressure: | 1100 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | Water Injection | Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Proven Production: | 480 acres | Production Well Spacing: | 40 acres |
Lower Altamont (Altamont Limestone Formation) |
| Average Oil API Gravity: | 26 |
Lower Altamont (Altamont Limestone Formation) |
| Maximum Porosity: | 14 % | Average Porosity: | 11 % |
Producing Formation:Upper Pawnee |
| Geological Age: | Marmaton Group, Desmoinesian Stage, Middle Pennsylvanian Series |
| Depositional Environment: | Carbonate Shoal |
| Formation Lithology: | Limestone, white-tan, microcrystalline to dense, some fragmental limestone with grained vuggy porosity. |
| Formation Geometry: | Lenticular carbonate shoals associated with positive features. |
| Trap Type: | Combination structural-stratigraphic |
Upper Pawnee (Pawnee Limestone Formation) |
| Maximum Net Pay: | 16 feet | Average Net Pay: | 10 feet |
| Drive Mechanism: | Gas in solution, water |
| Initial Pressure: | 1465 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | Water Injection | Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Estimated Ultimate Recovery: | 380,000 bbls oil from all reservoirs combined |
| Proven Production: | 480 acres | Production Well Spacing: | 40 acres |
Upper Pawnee (Pawnee Limestone Formation) |
| Average Oil API Gravity: | 36 |
Upper Pawnee (Pawnee Limestone Formation) |
| Total Solids: | 34763 ppm |
| Chloride Equivalent: | 16362 ppm | Barium: | 0 ppm |
| Bicarbonates: | 0 ppm | Calcium: | 0 ppm |
| Calcium Bicarbonate: | 2107 ppm | Calcium Sulfate: | 1361 ppm |
| Iron: | 0 | Magnesium: | 0 ppm |
| Magnesium Sulfate: | 722 ppm | Silica: | 0 |
| Sodium Sulfate: | 3623 ppm | Sodium Chloride: | 25950 ppm |
| Strontium: | 0 | Sulfates: | 0 ppm |
Upper Pawnee (Pawnee Limestone Formation) |
| Maximum Porosity: | 14 % | Average Porosity: | 10 % |
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