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

General Field Information

Produces Oil: Yes Produces Gas: Yes
Drilling Casing Practices: Hydrochloric acid, 1000 to 8000 gallons per zone, had been the customary completion treatment in the field from 1938  1959. In the late 1950s, acid-sand fracturing treatments became increasingly popular.
Comments: In the central part of the field where the Ft. Riley through the Herington are productive, total pay thickness exceeds 100 feet. The overall average is estimated to fall in the range of 50 to 60 feet.

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
20 DEC 1922 Boles (was 1) 2-3
No Oil Production
No Digital LAS Files No Core Images No Core Data
Well Location: NW NE NW 3-T35S-R34W
Rotary Total Depth: 2919
Production Zone: Chase Group
Initial Gas Potential: 5000 MCF natural
Comments: The well is 3 miles west of Liberal in Seward County. The well was plugged back to 2758 feet.
Data Source: KOGF, Vol. II; DISCOVERY 1341
Discovery Date Well Name Available Well Data Oil Production Gas Production LAS File Viewer with Core Data Plots Core Image Core Data Table
01 OCT 1927 CRAWFORD 1
No Oil Production No Gas Production No Digital LAS Files No Core Images No Core Data
Well Location: C SW 31-T33S-R37W
Rotary Total Depth: 3502
Production Zone: CHASE
Initial Gas Potential: 6000 MCF
Initial Formation Pressure: 435
Comments: The well was plugged back to 2620 feet. This well is regarded by many as the discovery well of the Hugoton field, since development occurred at a much faster pace from this well than from the BOLES 1, 15-175-00548 in T35S-R34W-Section 3. The BOLES 1, and a few wells around it, comprised the Liberal field until 1950 when the steadily growing Hugoton field joined the Liberal field.
Data Source: KOGF, Vol. II
Discovery Date Well Name Available Well Data Oil Production Gas Production LAS File Viewer with Core Data Plots Core Image Core Data Table
06 JUL 1977 M. MAUNE 1
No Oil Production
No Digital LAS Files No Core Images No Core Data
Well Location: C NE NE 22-T21S-R38W
Rotary Total Depth: 5636
Production Zone: CHASE GAS
Data Source: DISCOVERY 7527

Summary Production Information

Field Size: 3060480 acres
Total Wells: 10463
Productive Oil Wells: 157 as of December 2023
Productive Gas Wells: 7711 as of December 2023
Abandoned Wells: 471
Cumulative Oil: 4,035,411.68 bbls as of December 2023
Cumulative Gas: 27,131,383,059.93 mcf as of December 2023

Producing Formation:


CHASE GROUP
(Chase Group)
Formation Lithology: The overall thickness of the Chase group is relatively constant over most of the field but a slight thinning occurs to the west and north going out of the Hugoton Embayment. Individual formations tend to lose their identity to the north and west as shale and siltstone increase. The total thickness of the reservoir rocks (Herington through Ft. Riley) including shale members is over 200 feet. Dolomite, dolomitic limestone and limestone comprise the pay sections. The texture varies from fine crystalline sub-lithographic to granular or sucrosic. Porosity is chiefly fine vugular and inter-crystalline. Varying amounts of shale and silt to fine sandstone are generally present throughout the section.
Trap Type: Stratigraphic type trap - the result of a facies change causing an up dip pinchout of porosity. Porous limestones and dolomites of the Permian Chase group grade westward and up dip into relatively impermeable red shale and siltstone. The overlying Wellington shale formed the seal and basinward tilting positioned the low porosity clastic facies up dip from the carbonates.

CHASE GROUP (Chase Group)
Thickness
Maximum Thickness: 200 feet

CHASE GROUP (Chase Group)
Oil & Gas Production Information
Maximum Net Pay: 100 feet Average Net Pay: 55 feet
Drive Mechanism: A water drive is indicated by the large amount of water tested from some wells that were drilled through the gas column. As much as 30 to 40 barrels of water per hour have been tested from wells that penetrated the water table in the central part of the field. Further evidence of a water drive is the fact that the reservoir pressure has decreased so slowly relative to the amount of gas produced. A rock pressure of 435# psi was reported in the discovery well that was completed in 1927. In 1958, shut in pressures from several wells scattered throughout the field averaged 350# psi with a range of 42# psi between the lowest and highest pressures. The shut in pressures were recorded from wells shut in 14 days or longer.
Water Production: Producing wells completed appreciably above the water table generally produce only a trace of water. In most instances, when water was encountered on completion tests, it was possible to plug back to the next zone above and achieve a water free completion. In the overall picture of the field, water production is a minor problem. On the east and northeast margins of the field, however, where there is not much pay above the water table, water free completions cannot always be achieved. Wells in these areas are often small producers that will not blow out much water and are therefore susceptible to loading up. Before 1959, there was evidence that the water table has risen 15 to 20 feet in T31S, R35W. It is possible that other areas with reasonable permeability extending down to the vicinity of the water table also experienced a rise in the water table in that era.

CHASE GROUP (Chase Group)
Gas Chemistry
Minimum BTU: 1008 Maximum BTU: 1008
Carbon Dioxide: .02 % Nitrogen: 14.9 %
Methane: 72.77 % Butane: 1.09 % Ethane: 6.47 %
Propane: 3.31 % Pentane: .56 % Hextane: .11 %
ISO Butane: .34 %

CHASE GROUP (Chase Group)
Porosity
Porosity Type: Porosity is chiefly fine vugular and inter-crystalline.
This web page generated by ORACLE PLSQL Stored Procedure gemini.dpa_general_pkg.build_general_web_page()
Comments to webadmin@kgs.ku.edu