Digital Petroleum Atlas
Greenwood Gas Area Field
General Information
Greenwood Gas Area Field Oil & Gas Data

General Field Information

Produces Oil: Yes Produces Gas: Yes
Exploration Method: Gas was discovered in the Pennsylvanian Virgil limestones in Cities Service, Boehm A-1, NE NE NW, 33S-42W-11, on Dec. 3, 1952. This test was a development well in the Keyes sandstone in Boehm field, which was then known as the Greenwood field. It failed to produce in the Keyes, and was successfully plugged back for a gas gauge of 16,000 MCF from the "Greenwood" limestone zones, at a depth of 2988-3158. This well was structurally low on the Keyes sandstone, accounting for the failure in this objective. Gas detecting equipment was used on the well, which logged good gas shows in what is known as the "Greenwood pay". Drill stem tests of this shallow zone were run, which confirmed the recorded gas shows. It is confusing that the Boehm (Morrow) field was discovered by the drilling of a test well named the "Greenwood B-1" and that the Greenwood field was discovered by a well named "Boehm A-1". Other oddities are that the discovery of the wholly stratigraphic Greenwood field resulted from the drilling of a structural field and that seven tests penetrated the Greenwood limestone section prior to the discovery, all of which are within the present confines of the field. The later use of gas detecting equipment undoubtedly played a major role in the discovery and development of this field, whose initial recoverable reserves have been estimated in excess of one trillion cubic feet of gas. Seven other fields are recognized within the Greenwood gas area. All produce from pre-Virgil ("pre-Greenwood" formations) and are set apart from the Greenwood field on the basis of separate producing formations.
Drilling Casing Practices: All wells are drilled with rotary drilling equipment and are cased, usually with 5 1/2", through all potential pay zones. The gas zones are selected from electric logs, perforated and acidized, usually in groups of porous beds. This results in several separate zones of treatment, each of which is blown dry of acid water, taking one or two weeks of cable tool completion work. Rarely are the pays fracture treated.

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
03 DEC 1952 BOEHM 'A' 1
No Oil Production
No Core Images No Core Data
Well Location: NE NE NW 11-T33S-R42W
Rotary Total Depth: 5150
Production Zone: WABAUNSEE AND SHAWNEE GAS
Data Source: DISCOVERY 2608
Discovery Date Well Name Available Well Data Oil Production Gas Production LAS File Viewer with Core Data Plots Core Image Core Data Table
20 FEB 1961 CRAWLEY 'B' 3
No Oil Production
No Digital LAS Files No Core Images No Core Data
Well Location: C NW NE 4-T35S-R41W
Rotary Total Depth: 5340
Production Zone: SHAWNEE OIL (TOPEKA)
Data Source: DISCOVERY 6541

Summary Production Information

Field Size: 243840 acres
Total Wells: 646
Productive Oil Wells: 7 as of July 2021
Productive Gas Wells: 277 as of March 2024
Abandoned Wells: 67
Cumulative Oil: 331,954.15 bbls as of July 2021
Cumulative Gas: 1,239,511,533.00 mcf as of March 2024

Producing Formation:


TOPEKA
(Topeka Limestone Formation)
Depth Top: 3069 feet
Trap Type: Gas occurs in about 17 separate porous limestone beds, whose thicknesses range from one foot to about 30 feet each. These reservoirs, considered a common source of supply, occur from the top of the Wabaunsee group to near the base of the Shawnee group. The reservoir reaches a maximum gross thickness of 500 feet, and averages a net productive thickness of about 65 feet, a sum of the many separate porous beds. Depth to the producing zones is from 2600 to 3400 feet. Accumulation is wholly stratigraphic, occurring on a northeast dipping monocline, the northeast terminus of the Cimarron uplift, which in turn trends south and eastward into the buried Amarillo uplift of the Texas Panhandle. Regional dip on Virgil beds is about 20 feet per mile northeastward, although many local structural irregularities are present that account for as much as 200 feet of dip in less than one mile. Such severe irregularities are peculiar to the eastern flank of the field. The trap is caused by the updip west and southward thinning of the porous beds, due primarily to facies change rather than truncation. Individual beds maintain their identity across the field, but with a noticeable thinning of their porous constituents, and with a southwestward decrease of permeability within those few porous beds that continue uninterrupted, although thinned, across the trap. Permeability adjacent to the west side of the trap is qualified as poor from small fluid recoveries and low flow pressures encountered in drill stem tests run in Baca County, Colorado. An increase of microscopic insolubles within the reservoir, and an increase of red, terrigenous shale is noticed as the west and south limits of the field are approached. These changes are subtle, not apparent in offset wells, and are a problem of regional scope. The downdip occurrence of water in the reservoir beds is related to a structurally controlled gas-water contact, but a common gas-water contact for the field does not suffice to define all reservoirs. To further complicate this problem, water contacts move updip in almost all of the individual reservoirs proceeding northward from the east edge of T33S, R42W, at the rate of about 10 feet per mile. This upward transgression of water joins poor reservoir characteristics at about the southwest corner of T31S, R43W, and forms the northern terminus of the field. This transgression of structure contours has been considered by some students of the field as being due to the recent regional northward tilting. Operating under this theory, the late increase in north dip has moved the gas south, crowding the now structurally highest southwest corner of the field at the expense of the north end of the field, resulting in water-wet gas wells or dry holes along the north end of the field. Entrapment under hydrodynamic conditions has been suggested as an explanation for the presence of water in the extreme updip limit of the field, but it is difficult to apply this theory, since water movement from the west, the impermeable side of the field, would have to be supposed.

TOPEKA (Topeka Limestone Formation)
Oil & Gas Production Information
Produces Oil: Yes Produces Gas: Yes
Drive Mechanism: Gas expansion
Initial Pressure: 435 Data Source of Initial Pressure: KOGF, Vol. II
Proven Production: 160000 acres

TOPEKA (Topeka Limestone Formation)
Gas Chemistry
Minimum BTU: 958 Maximum BTU: 965
Carbon Dioxide: .03 % Nitrogen: 21.09 %
Methane: 67.15 % Butane: 1.1 % Ethane: 5.86 %
Propane: 3.48 % Pentane: .34 % Hextane: .27 %
ISO Pentane: .24 % ISO Butane: .44 %

Producing Formation:


LANS.-K.C.
(Lansing - Kansas City Supergroup)
Depth Top: 3534 feet

LANS.-K.C. (Lansing - Kansas City Supergroup)
Oil & Gas Production Information
Produces Gas: Yes
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