Facility Detail

COGIS WELL SCOUT CARD

Insp

Surface Location
API# 05-123-37495

Well Classification: DSPW

Status: IJ - 12/16/2015

Well Name/No:

Razor #26J-2633L
(Click Well Name for Production Data)

Click Here for Transporter Gatherer Info

Operator:

TALLGRASS WATER WESTERN LLC - 10608
(Click Operator Name for Company Detail Report)

Federal Or State Lease #:

Facility Status:

Status Date

12/16/2015

FacilityID:

433132

LocationID:

433131

County:

WELD #123

Location:

NWSE 26 10N58W 6

Field:

UNNAMED - #85251

Elevation:

4728 ft.

Basin:

DENVER (DJ) BASIN

Planned Location:

2251FSL 2047 FEL

Lat/Long: 40.808550 / -103.829978

Lat/Long Source: Field Measured

As Drilled Location:

Footages Not Available

Lat/Long: 40.808551 / -103.829968

Lat/Long Source: Field Measured

Disclosure: Sidetrack #00
Start Date: 7/3/2014
End Date: 7/3/2014
Reported: 8/19/2014
Days to report: 47

Wellbore Data for Original Wellbore		Wellbore Classification: DSPW IJ - 12/16/2015 Measured TD: 9422 ft. Vertical TD: 9412 ft.
Wellbore Permit			DIRECTIONAL
Permit #:		Expiration Date:	5/28/2015
Proposed Top PZ Location:	Sec:26 Twp: 10N 58W	Footage: 1988 FSL 1959 FEL
Bottom Hole Location:	Sec:26 Twp: 10N 58W	Footage: 1938 FSL 2013 FEL
Prop Depth/Form:	9508 ft.
Surface Mineral Owner Same:	Yes
Mineral Owner:	FEE	Surface Owner:	FEE
Unit:		Unit Number:
Formation And Spacing:	Code: AMZN , Formation: AMAZON , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: LYNS , Formation: LYONS , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: MRRW , Formation: MORROW , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: NBRR , Formation: NIOBRARA , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: PCMB , Formation: PRECAMBRIAN , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: PNATK , Formation: PENNSYLVANIAN-ATOKA , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: WFCMP , Formation: WOLFCAMP , Order: , Unit Acreage: , Drill Unit:
Casing:	String Type: CONDUCTOR, Hole Size: 20.167 in., Size: 20 in., Top: 0 ft., Depth: 80 ft., Weight: 68 , Citings Type: PLANNED
Cement:	Sacks: , Top: , Bottom:
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 1550 ft., Weight: 36 , Citings Type: PLANNED
Cement:	Sacks: 716, Top: 0 ft., Bottom: 1550 ft.
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 5.5 in., Top: 0 ft., Depth: 9500 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: 1076, Top: 0 ft., Bottom: 9500 ft.

Wellbore Completed
Completion Date:	8/10/2013
Spud Date:	7/23/2013	Spud Date Is:	ACTUAL
Measured TD:	9422 ft.	Measured PB depth:	8297 ft.
True Vertical TD:	9412 ft.	True Vertical PB depth:	8288 ft.
Top PZ Location:	Sec:26 Twp: 10N 58W	Footage: 1988 FSL 1959 FEL
Bottom Hole Location:	Sec:26 Twp: 10N 58W	Footage: 1938 FSL 2013 FEL
Log Types:	Mud, Triple Combo, Resistivity, FMI, RCBL
Log Types:
Casing:	String Type: CONDUCTOR, Hole Size: 24 in., Size: 16 in., Top: 0 ft., Depth: 80 ft., Weight: 75 , Citings Type: ACTUAL
Cement:	Sacks: , Top: 0 ft., Bottom: 80 ft., Determination Method: VISU
Casing:	String Type: SURF, Hole Size: 13.5 in., Size: 9.625 in., Top: 0 ft., Depth: 1600 ft., Weight: 36 , Citings Type: ACTUAL
Cement:	Sacks: 742, Top: 0 ft., Bottom: 1600 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 8.75 in., Size: 5.5 in., Top: 0 ft., Depth: 9404 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 1263, Top: 150 ft., Bottom: 9404 ft., Determination Method: CALC
Casing:	String Type: 1ST LINER, Hole Size: 4.875 in., Size: 4.75 in., Top: 5642 ft., Depth: 5684 ft., Weight: 16.4 , Citings Type: ACTUAL
Cement:	Sacks: 0, Top: , Bottom: , Determination Method: CALC
Additional Cement:	String Type: 1ST , Top: 5661, Depth: 5664, Bottom: 5664, Sacks: 52, Method: SQUEEZE

Formation	Interval Top	Log Bottom	Cored	DSTs
PIERRE	1607 ft.		N	N
HYGIENE	3270 ft.		N	N
SHARON SPRINGS	5565 ft.		N	N
NIOBRARA	5568 ft.		Y	N
SKULL CREEK	6508 ft.		Y	N
DAKOTA	6695 ft.		Y	N
MORRISON	6791 ft.		Y	N
ENTRADA	6976 ft.		Y	N
LYONS	7538 ft.		Y	N
WOLFCAMP	7818 ft.		N	N
AMAZON	7905 ft.		N	N
PENNSYLVANIAN	8263 ft.		N	N
MORROW	9035 ft.		N	N
PRECAMBRIAN	9279 ft.		N	N

Completed Information for Formation PRECAMBRIAN Formation Classification: DSPW Status: AB - 10/28/2013

1st Production Date:	10/24/2013	Choke Size:
Formation Name:	PRECAMBRIAN	Commingled:	No
Production Method:
Open Hole Completion:	No
Formation Treatment
Treatment Type:
Treatment Date:	10/28/2013	Treatment End Date:	N/A
Treatment Summary:	160 bbls 3% KCl water
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:

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92

Perforation Data:
Interval Top:	9372 ft.	# Of Holes:	61
Interval Bottom:	9382 ft.	Hole Size:	0.375 in.

Completed Information for Formation AMAZON Formation Classification: DSPW Status: CM - 10/2/2015

1st Production Date:	N/A	Choke Size:
Formation Name:	AMAZON	Commingled:	Yes
Production Method:
Open Hole Completion:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/30/2014	Treatment End Date:	9/30/2014
Treatment Summary:	Drill out cemented BP @ 7938', perform acid job with 5000 gals acid and step rate injection test
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:

Formation Treatment

Treatment Type:

Treatment Date:

11/1/2013

Treatment End Date:

N/A

Treatment Summary:

Swabbed. No treatment performed.

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:

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92
BBLS_H2O	205
CALC_BBLS_H2O	205
CASING_PRESS	650

Perforation Data:
Interval Top:	7948 ft.	# Of Holes:	85
Interval Bottom:	7962 ft.	Hole Size:	0.375 in.

Completed Information for Formation LYONS Formation Classification: DSPW Status: CM - 10/2/2015

1st Production Date:	N/A	Choke Size:
Formation Name:	LYONS	Commingled:	Yes
Production Method:
Open Hole Completion:	No
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/30/2014	Treatment End Date:	9/30/2014
Treatment Summary:	Drill out cemented BP @ 7530', perform acid job with 5000 gals acid and Step Rate Test for injection test
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:

Formation Treatment

Treatment Type:

Treatment Date:

11/12/2013

Treatment End Date:

N/A

Treatment Summary:

No treatment performed in Lower Lyons. Swabbed. Pump 54 bbls 3% KCl water on Upper Lyons. Swabbed.

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:

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92
BBLS_H2O	205
CALC_BBLS_H2O	205
CASING_PRESS	650
BBLS_H2O	155
CALC_BBLS_H2O	155

Perforation Data:
Interval Top:	7544 ft.	# Of Holes:	219
Interval Bottom:	7628 ft.	Hole Size:	0.375 in.

Completed Information for Formation DENVER BASIN COMBINED DISPOSAL ZONE Formation Classification: DSPW Status: IJ - 12/16/2015

1st Production Date:	10/2/2015	Choke Size:
Formation Name:	DENVER BASIN COMBINED DISPOSAL ZONE	Commingled:	No
Production Method:
Open Hole Completion:

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 DJINJ.

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92
BBLS_H2O	205
CALC_BBLS_H2O	205
CASING_PRESS	650
BBLS_H2O	155
CALC_BBLS_H2O	155

Perforation Data:
Interval Top:	6976 ft.	# Of Holes:	438
Interval Bottom:	7962 ft.	Hole Size:	0.375 in.

Completed Information for Formation ENTRADA Formation Classification: DSPW Status: CM - 10/2/2015

1st Production Date:	N/A	Choke Size:
Formation Name:	ENTRADA	Commingled:	Yes
Production Method:
Open Hole Completion:	No
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	9/30/2014	Treatment End Date:	9/30/2014
Treatment Summary:	Perform acid job with 5000 gals acid and step rate injection test
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:

Formation Treatment

Treatment Type:

Treatment Date:

11/18/2013

Treatment End Date:

N/A

Treatment Summary:

No treatment performed. Swabbed.

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:

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92
BBLS_H2O	205
CALC_BBLS_H2O	205
CASING_PRESS	650
BBLS_H2O	155
CALC_BBLS_H2O	155
BBLS_H2O	231
CALC_BBLS_H2O	231

Perforation Data:
Interval Top:	6976 ft.	# Of Holes:	134
Interval Bottom:	7002 ft.	Hole Size:	0.375 in.

Completed Information for Formation NIOBRARA Formation Classification: SI Status: AB - 9/12/2014

1st Production Date:	N/A	Choke Size:
Formation Name:	NIOBRARA	Commingled:	No
Production Method:
Open Hole Completion:	No
Formation Treatment
Treatment Type:	FRACTURE STIMULATION
Treatment Date:	7/3/2014	Treatment End Date:	7/3/2014
Treatment Summary:	1 Stage 20# XL Gel frac pumped with 1310# 40/70 and 65061# 20/40 sand, 24 bbls 15% HCl, 1513 bbls slickewter pumped.
Total fluid used in treatment (bbls):	1587	Max pressure during treatment (psi):	2705
Total gas used in treatment (mcf):	0	Fluid density (lbs/gal):	8.33
Type Of gas:		Number Of staged intervals:	1
Total acid used in treatment (bbls):	24	Min frac gradient (psi/ft):	0.80
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):	50
Fresh water used in treatment (bbls):	1513	Disposition method For flowback:	DISPOSAL
Total proppant used (lbs):	66371	Green completions techniques utilized:	Yes
Reason green techniques Not utilized:

Tubing Size:		Tubing Setting Depth:
Tubing Packer Depth:		Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:

Initial Test Data:
Test Date:	10/26/2013	Test Method:	Swabbing
Hours Tested:	24	Gas Type:
Gas Disposal:

Test Type	Measure
BBLS_H2O	92
CALC_BBLS_H2O	92
BBLS_H2O	205
CALC_BBLS_H2O	205
CASING_PRESS	650
BBLS_H2O	155
CALC_BBLS_H2O	155
BBLS_H2O	231
CALC_BBLS_H2O	231
BBLS_H2O	50
CALC_BBLS_H2O	71
CASING_PRESS	800

Perforation Data:
Interval Top:	5661 ft.	# Of Holes:	18
Interval Bottom:	5664 ft.	Hole Size:	0.375 in.

All Designations		Date
Primary Well Designation: None i
Reported Plugged	N
Out Of Service Repurposed	N
Out Of Service	N
Inactive Exception	N
Noticed Inactive	N
Defined Inactive	N
Low Producing	N

April 2025 - March 2026	i
BOE/MCFE/GOR Calculations Production for Previous 12 Months
Total Oil Produced (Barrels)	0
Total Gas Produced (MCF)	0
GOR
GOR Determination
Average BOE per Day	0.000
Average MCFE per Day	0.000

Federal Financial Assurance

Tribal Well