Digital Petroleum Atlas
Celia South Field
General Information
|
|
Digital Petroleum Atlas |
|
| Celia South Field Oil & Gas Data | |||
|---|---|---|---|
|
|
|
|
General Field Information | |
| Geologic Province: | Northern Extension of the Hugoton Embayment, east of the Las Animas Arch |
|---|---|
| Exploration Method: | Subsurface geologic control & seismic (CDP) |
| Surface Formation: | Pleistocene Loess with Pliocene Ogallala outcrops in stream beds |
| Oldest Formation Penetrated: | Granite Wash at 5332' |
| Drilling Casing Practices: | 1. Drill to 500' and set 8 5/8' surface casing. 2. 1-man logging unit used on some wells at 3000' to TD. 3. Circulate significant drilling breaks and/or shows and catch 30 and 45 minute circulation samples. 4. DST as so indicated by shows and drilling breaks. 5. Run log suite at TD and evaluate. 6. Run 5 1/2' casing and perforate. Complete natural, or acidize if required. |
| Electric Logging Practices: | Dual Induction: Surface to TD Neutron-Density: Surface to TD BHC Sonic: Surface to TD EPT: Surface to TD |
| Comments: | Other Shows: Topeka, Oread, Lansing "A", Lansing "C", Lansing "E", Lansing "F", Pawnee, Fort Scott |
| Discussion: | The prospect was generated by subsurface structural and isopach mapping and later confirmed by seismic. CDP seismic through the center of Section 28 indicates an anticlinal feature with 40 feet of thinning from the Stone Corral to the Mississippian unconformity. Area extent of this structure was approximately 640 acres, with a structural closure of 15-20 feet. Subsequent drilling has expanded the limits of the field to 1160 acres, with a minimum of 25 feet of closure. As of 1985, every well drilled with Cherokee porosity has proven productive, with no apparent water. Two pay zones exist within the Celia South Field - the Lansing "B" Horizon and the Cherokee Lime. The Lansing "B" zone produces in the Clark & Cahoj, Cahoj 1, C NE NW, T3S-R36W-28. This well was completed in December 1979, for 7 BO and 100 BW from perforations at 4268'-4272'. This initial potential is misleading due to the nature of the equipment on the well at the time. New, larger diameter pump and equipment later increased the volume of fluid being moved. Total cumulative production for the Cahoj 1 is 62,000 BO and 538,000 BW from December 1979 thru December 1984. The Lansing "B" is an oolitic, fractured brown lime with an average thickness of 4 feet, porosities ranging from 14-18%. The Coastal Oil & Gas Hubbard 7, NE SW SW, T3S-R36W-28 was the only other well in the area in 1985 producing from the Lansing "B" and was commingled with the Cherokee Lime from 4690'-4696' and the Pawnee Lime from 4568'-4572' for 100 BO and 6 BWPD. The Cherokee Lime reservoir of the Celia South Field was discovered by Coastal Oil & Gas in June of 1983, with the drilling of the Coastal Oil & Gas Hubbard 1, SE NE SW, T3S-R36W-28. The Cherokee was tested from 4640'-4664' and recovered 1910' clean oil and 112' OCM. Flow pressures were 392-807# and shut-in pressures were 1300-1292#. The Hubbard 1 was perforated from 4650'-4657' and completed for 138 BOPD pumping. The Murfin Cahoj 1, C SW NW was drilled in October 1962. This well penetrated the Cherokee reservoir but was not tested. Sonic log through the Cherokee indicated 15% porosity in the top 4' of the Cherokee reservoir. Average net pay for the Cherokee reservoir is approximately 6', with porosities ranging from 18-12%. Coastal Oil & Gas cored the Cherokee pay zone in two wells - the Hubbard 3, C NW SE, Sec. 28, and Hubbard 4, C SE SW, Sec. 28. Lithology description from the cores shows the top of the pay zone is composed almost entirely of calcareous skeletal grains. These grains are medium to coarse sand-sized, well sorted algal fragments with minor forams, brachiopod and crinoid fragments also present. Porosity is excellent (approximately 25%) and is primarily interparticle, contained between skeletal grains. Small amounts of pore filling microspar calcite cement are present. The center of the pay zone is composed of bioclastic material including crinoid, echinoid, brachiopod, and algal fragments, ostracods and forams. This zone has excellent primary interparticle porosity (approximately 20%). Some secondary pores have been created by partial dissolution of the matrix (micrite). Cementing, primarily by microspar calcite, is more apparent. The bottom of the pay zone has an extensive micrite matrix. Bioclasts include forams, ostracods, gastropods, and brachiopod fragments. This zone is laminated and may represent an algal bioherm. Porosity is poor with most pores filled by sparry and microspar calcite. Fossil fragments are less abraded than in the upper 4 feet. The core data studied indicates a marine setting where sediments may have been deposited as part of a carbonate bank or shoal. The higher porosities can be directly related to removal of detrital muds by wave action. The lower porosities developed where detrital mud (micrite) deposition was more extensive. |
Discovery Well(s) |
|---|
| Discovery Date | Well Name | Available Well Data | Oil Production | Gas Production | LAS File Viewer with Core Data Plots | Core Image | Core Data Table |
|---|---|---|---|---|---|---|---|
| 04 AUG 1983 | HUBBARD 1-28V | 
|
|
No Gas Production | 
|
No Core Images | No Core Data |
| Well Location: | S2 SE NE SW 28-T3S-R36W |
|---|---|
| Rotary Total Depth: | 5361 |
| Production Zone: | Cherokee Group |
| Initial Oil Potential: | 138 BOPD pumping |
| Casing: | 8 5/8" @ 370' 5 1/2" @ 5361' |
| Perforations: | 4650'-4657' |
| Treatments: | Natural, subsequently acidized |
| Comments: | 5355 Log Total Depth Initial Formation Pressure: IF 392# / FF 807# / ISI 1300# / FSI 1291# |
| Data Source: | KOGF, Vol. V; DISCOVERY 3131 |
| Discovery Date | Well Name | Available Well Data | Oil Production | Gas Production | LAS File Viewer with Core Data Plots | Core Image | Core Data Table |
|---|---|---|---|---|---|---|---|
| 04 NOV 1985 | Kehlbeck 1-D |
|
|
No Gas Production | No Digital LAS Files | No Core Images | No Core Data |
| Well Location: | C NW NE 5-T4S-R36W |
|---|---|
| Rotary Total Depth: | 4762 |
| Production Zone: | Marmaton Group |
| Data Source: | DISCOVERY 7670 |
Summary Production Information | |
| Field Size: | 1600 acres |
| Total Wells: | 47 |
| Productive Oil Wells: | 34 as of July 2024 |
| Abandoned Wells: | 10 |
| Cumulative Oil: | 2,307,435.36 bbls as of July 2024 |
Producing Formation:CHEROKEE |
| Depth Top: | 4621 feet |
| Geological Age: | Pennsylvanian |
| Depositional Environment: | Environment of deposition based on core analysis suggests a mound or bank of lime sediments deposited in a shallow near shore environment with organic build-up of skeletal remains providing the nucleus for bank development. |
| Formation Lithology: | Top of the pay zone is composed almost entirely of calcareous skeletal grains, medium to coarse sand-sized, well sorted algal fragments with forams, brachiopod and crinoid fragments. Excellent interparticle porosity. Small amounts of microspar calcite present. Center of pay zone also composed of bioclastic material with excellent interparticle porosity with secondary porosity the result of partial dissolution of the matrix (micrite). Bottom of pay zone has extensive micrite matrix with bioclasts including forams, ostracods, gastropods and brachiopod fragments. Porosity is poor, with pore filling by sparry and microspar calcite. |
| Formation Geometry: | A thin limestone bed deposited regionally with porosity developed locally on a structural high, average thickness 6-8 feet. |
| Trap Type: | Structural/Stratigraphic |
CHEROKEE (Cherokee Group) |
| Thickness: | 7 feet | Maximum Thickness: | 8 feet |
CHEROKEE (Cherokee Group) |
| Produces Oil: | Yes |
| Maximum Net Pay: | 8 feet | Average Net Pay: | 6 feet |
| Average Oil Column: | 51 |
| Gas Oil Ratio: | 18 Standard Cubic Ft./BBL | Drive Mechanism: | Rock and fluid expansion to 125#, then expanding gas solution drive |
| Initial Pressure: | 1314 | Data Source of Initial Pressure: | KOGF, Vol. V |
| Pressure Maintenance or EOR: | 1985: Anticipated water flood |
| Proven Production: | 1160 acres | Production Well Spacing: | 40 acres |
CHEROKEE (Cherokee Group) |
| Specific Gravity: | 1.097 |
CHEROKEE (Cherokee Group) |
| Oil Color: | Black % |
| Oil Base: | 4.15% asphalt @ 60 degrees F, 1.22% paraffin % |
| Average Oil API Gravity: | 27.5 |
CHEROKEE (Cherokee Group) |
| Maximum Porosity: | 25 % | Average Porosity: | 12 % |
CHEROKEE (Cherokee Group) |
| Maximum Horizontal: | 624 md | Average Horizontal: | 294 md |
Producing Formation:MARMATON |
| Depth Top: | 4617 feet |
MARMATON (Marmaton Group) |
| Thickness: | 4 feet |
MARMATON (Marmaton Group) |
| Produces Oil: | Yes |
|
This web page generated by ORACLE PLSQL Stored Procedure gemini.dpa_general_pkg.build_general_web_page()
Comments to webadmin@kgs.ku.edu |