Skip to Main Content

COGIS

Facility Detail

COGIS - WELL SCOUT CARD
Click image to view related facilities. Related  Click image to view inspection information. InspClick image to view MIT information. MITClick image to access interactive map at well/facility location. GISClick image to view imaged documents for this well/facility. DocClick image to view imaged documents for this well/facility. COAClick image to view wellbore completion diagram. WellboreClick image to search for orders within this facility's section. OrdersClick image to view bradenhead scoutcard data. Bradenhead
 Surface Location
 API# 05-123-37340		Well Classification: OW Status: SI - 7/1/2025
Well Name/No:LaSalle #25F-332
(Click Well Name for Production Data)		Click Here for Transporter Gatherer Info
Operator:PDC ENERGY INC - 69175
(Click Operator Name for Company Detail Report)		Federal Or State Lease #:
Facility Status:SIStatus Date7/1/2025
FacilityID:432890LocationID:432889
County:WELD #123Location:SWNW 25 5N65W 6
Field:WATTENBERG - #90750Elevation:4640 ft.
Basin:DENVER (DJ) BASIN  
Planned Location:1360FNL  245 FWLLat/Long: 40.373720 / -104.620170Lat/Long Source: Field Measured
As Drilled Location:Footages Not AvailableLat/Long: 40.373717 / -104.620130Lat/Long Source: Field Measured
 
FracFocus
Disclosure: Sidetrack #00
Start Date: 2/16/2014
End Date: 2/17/2014
Reported: 2/21/2014
Days to report: 4
 Wellbore And Formation Details -- select either a wellbore Or formation to expand.
 

Wellbore #00             Wellbore Classification: OW             Status: SI - 7/1/2025             Measured TD: 11314 ft.    Vertical TD: 6810 ft.

 Wellbore Data for Original WellboreWellbore Classification: OW        SI - 7/1/2025
Wellbore PermitHORIZONTAL
Permit #: Expiration Date:5/16/2015
Proposed Depth/Form:11319 ft.
Surface Mineral Owner Same:No
Mineral Owner:FEESurface Owner:FEE
Unit: Unit Number:
Formation And Spacing:Code: NBRR , Formation: NIOBRARA , Order: , Unit Acreage: 320, Drill Unit: GWA
Casing:String Type: SURF, Hole Size: 12.25 in., Size: 9.625 in., Top: 0 ft., Depth: 875 ft., Weight: 36 , Citings Type: PLANNED
Cement:Sacks: 830, Top: 0 ft., Bottom: 875 ft.
Casing:String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 7337 ft., Weight: 26 , Citings Type: PLANNED
Cement:Sacks: 650, Top: 500 ft., Bottom: 7337 ft.
Casing:String Type: 1ST LINER, Hole Size: 6.125 in., Size: 4.5 in., Top: 6124 ft., Depth: 11319 ft., Weight: 11.6 , Citings Type: PLANNED
Cement:Sacks: , Top: , Bottom:
Wellbore Completed
Completion Date:12/16/2013
Spud Date:12/7/2013Spud Date Is:ACTUAL
Measured TD:11314 ft.Measured PB depth:11300 ft.
True Vertical TD:6810 ft.True Vertical PB depth:6810 ft.
Log Types:CBL, MWD
Casing:String Type: SURF, Hole Size: 13.75 in., Size: 9.625 in., Top: 0 ft., Depth: 951 ft., Weight: 36 , Citings Type: ACTUAL
Cement:Sacks: 770, Top: 0 ft., Bottom: 951 ft., Determination Method: VISU
Casing:String Type: 1ST, Hole Size: 8.75 in., Size: 7 in., Top: 0 ft., Depth: 7264 ft., Weight: 26 , Citings Type: ACTUAL
Cement:Sacks: 610, Top: 110 ft., Bottom: 7264 ft., Determination Method: CBL
Casing:String Type: 1ST LINER, Hole Size: 6.125 in., Size: 4.5 in., Top: 7096 ft., Depth: 11304 ft., Weight: 13.5 , Citings Type: ACTUAL
Cement:Sacks: , Top: , Bottom: , Determination Method:
FormationInterval TopLog BottomCoredDSTs
PARKMAN3554 ft.
SUSSEX4070 ft.
SHARON SPRINGS6605 ft.
NIOBRARA7295 ft.
FORT HAYS8304 ft.

Formation FTHYS                   Formation Classification:  OW                   Status:  CM - 6/20/2019                 Interval Top: 8304 ft.    Interval Bottom: 9285 ft.

 Completed Information for Formation FORT HAYS
1st Production Date:N/AChoke Size: 
Formation Name:FORT HAYSCommingled:Yes
Production Method:
Open Hole Completion:Yes
Formation Treatment
Treatment Type:
Treatment Date:6/20/2019Treatment End Date:N/A
Treatment Summary:Completed Depths: 8,304'-9,285'
Total fluid used in treatment (bbls):Max pressure during treatment (psi):
Total gas used in treatment (mcf):Fluid density (lbs/gal):
Type Of gas:Number Of staged intervals:
Total acid used in treatment (bbls):Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Tubing Size:Tubing Setting Depth:
Tubing Packer Depth:Tubing Multiple Packer:
Open Hole Top:Open Hole Bottom:
No Initial Test Data was found for formation FTHYS.
Perforation Data:
Interval Top:8304 ft.# Of Holes:
Interval Bottom:9285 ft.Hole Size:

Formation NB-FH                   Formation Classification:  OW                   Status:  SI - 7/1/2025                  Interval Top: 7295 ft.    Interval Bottom: 11314 ft.

 Completed Information for Formation NIOBRARA-FT HAYS
1st Production Date:3/11/2014Choke Size: 
Formation Name:NIOBRARA-FT HAYSCommingled:No
Production Method:
Open Hole Completion:Yes
Formation Treatment
Treatment Type:FRACTURE STIMULATION
Treatment Date:2/16/2014Treatment End Date:2/17/2014
Treatment Summary:16 Stage sliding sleeve, Swell Packer set at 7,295' Total Fluid: 56,684 bbls Gel Fluid: 44,125 bbls Slickwater Fluid: 12,535 bbls 15% HCl Acid: 24 bbls Total Proppant: 3,265,380 lbs Silica Proppant: 3,265,380 lbs Method for determining flowback: measuring flowback tank volumes.
Total fluid used in treatment (bbls):56684Max pressure during treatment (psi):4390
Total gas used in treatment (mcf):Fluid density (lbs/gal):8.34
Type Of gas:Number Of staged intervals:16
Total acid used in treatment (bbls):24Min frac gradient (psi/ft):0.95
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):2485
Fresh water used in treatment (bbls):56660Disposition method For flowback:DISPOSAL
Total proppant used (lbs):3265380Green completions techniques utilized:Yes
Reason green techniques Not utilized: 
Tubing Size:2.375 in.Tubing Setting Depth:6921 ft.
Tubing Packer Depth:Tubing Multiple Packer:
Open Hole Top:Open Hole Bottom:
Initial Test Data:
Test Date:4/11/2014Test Method:Flowing
Hours Tested:24Gas Type:WET
Gas Disposal:SOLD
Test TypeMeasure
BBLS_H2O 43
BBLS_OIL 170
BTU_GAS 1223
CALC_BBLS_H2O 43
CALC_BBLS_OIL 170
CALC_GOR 6400
CALC_MCF_GAS 1088
CASING_PRESS 1481
GRAVITY_OIL 56
MCF_GAS 1088
TUBING_PRESS 1155
Perforation Data:
Interval Top:7295 ft.# Of Holes:
Interval Bottom:11314 ft.Hole Size:

Formation NBRR                     Formation Classification:  OW                     Status:  CM - 6/20/2019                 Interval Top: 7295 ft.    Interval Bottom: 11314 ft.

 Completed Information for Formation NIOBRARA
1st Production Date:N/AChoke Size: 
Formation Name:NIOBRARACommingled:Yes
Production Method:
Open Hole Completion:Yes
Formation Treatment
Treatment Type:
Treatment Date:6/20/2019Treatment End Date:N/A
Treatment Summary:Completed Depths: 7,295'-8,304' 9,285'-11,314'
Total fluid used in treatment (bbls):Max pressure during treatment (psi):
Total gas used in treatment (mcf):Fluid density (lbs/gal):
Type Of gas:Number Of staged intervals:
Total acid used in treatment (bbls):Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):Disposition method For flowback:
Total proppant used (lbs):Green completions techniques utilized:--
Reason green techniques Not utilized: 
Tubing Size:Tubing Setting Depth:
Tubing Packer Depth:Tubing Multiple Packer:
Open Hole Top:Open Hole Bottom:
No Initial Test Data was found for formation NBRR.
Perforation Data:
Interval Top:7295 ft.# Of Holes:
Interval Bottom:11314 ft.Hole Size:
Primary Well Designation:
None      i
            All DesignationsDate
Reported PluggedN 
Out Of Service RepurposedN 
Out Of ServiceN 
Inactive ExceptionN 
Noticed InactiveN 
Defined InactiveN 
Low ProducingN 

BOE/MCFE/GOR Calculations
Production for Previous 12 Months
November 2024 - October 2025i
Total Oil Produced (Barrels)394
Total Gas Produced (MCF)10636
GOR26994
GOR DeterminationMCFE
Average BOE per Day6.078
Average MCFE per Day35.263

 Federal Financial Assurance  i 

 Tribal Well  i No