Facility Detail

COGIS - WELL SCOUT CARD

Insp

Surface Location
API# 05-121-11065

Well Classification: OW

Status: PA - 7/15/2022

Well Name/No:

RIO LOBO #1-30
(Click Well Name for Production Data)

Click Here for Transporter Gatherer Info

Operator:

GRAND MESA OPERATING CO - 35080
(Click Operator Name for Company Detail Report)

Federal Or State Lease #:

Facility Status:

Status Date

7/15/2022

FacilityID:

450630

LocationID:

450631

County:

WASHINGTON #121

Location:

SWNW 30 5S53W 6

Field:

WILDCAT - #99999

Elevation:

5138 ft.

Planned Location:

2474FNL 610 FWL

Lat/Long: 39.586820 / -103.366370

Lat/Long Source: Field Measured

As Drilled Location:

Footages Not Available

Lat/Long: 39.586820 / -103.366370

Lat/Long Source: Field Measured

Disclosure: Sidetrack #00
Start Date: 10/22/2019
End Date: 10/22/2019
Reported: 12/4/2019
Days to report: 43

Wellbore And Formation Details -- select either a wellbore Or formation to expand.

Wellbore #00 Wellbore Classification: OW Status: PA - 7/15/2022 Measured TD: 8099 ft.

Wellbore Data for Original Wellbore		Wellbore Classification: OW PA - 7/15/2022
Wellbore Permit
Permit #:		Expiration Date:	5/14/2019
Prop Depth/Form:	8200 ft.
Surface Mineral Owner Same:	No
Mineral Owner:	FEE	Surface Owner:	FEE
Unit:		Unit Number:
Formation And Spacing:	Code: MSSP , Formation: MISSISSIPPIAN , Order: , Unit Acreage: , Drill Unit:
Formation And Spacing:	Code: PENN , Formation: PENNSYLVANIAN , Order: , Unit Acreage: , Drill Unit:
Casing:	String Type: SURF, Hole Size: 11 in., Size: 8.625 in., Top: 0 ft., Depth: 350 ft., Weight: 24 , Citings Type: PLANNED
Cement:	Sacks: 200, Top: 0 ft., Bottom: 350 ft.
Casing:	String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 8200 ft., Weight: 17 , Citings Type: PLANNED
Cement:	Sacks: 300, Top: 6000 ft., Bottom: 8200 ft.
Casing:	String Type: STAGE TOOL, Hole Size: , Size: , Top: , Depth: 5200 ft., Weight: , Citings Type: PLANNED
Cement:	Sacks: 200, Top: 3740 ft., Bottom: 5200 ft.

Wellbore Completed
Completion Date:	7/6/2017
Spud Date:	6/24/2017	Spud Date Is:	ACTUAL
Measured TD:	8099 ft.	Measured PB depth:	7985 ft.
True Vertical TD:		True Vertical PB depth:
Log Types:	CBL, Sonic, Induction, Density/Neutron, Triple Combo, Microlog, Caliper
Casing:	String Type: SURF, Hole Size: 12.25 in., Size: 8.625 in., Top: 0 ft., Depth: 386 ft., Weight: 24 , Citings Type: ACTUAL
Cement:	Sacks: 275, Top: 0 ft., Bottom: 386 ft., Determination Method: VISU
Casing:	String Type: 1ST, Hole Size: 7.875 in., Size: 5.5 in., Top: 0 ft., Depth: 8022 ft., Weight: 17 , Citings Type: ACTUAL
Cement:	Sacks: 242, Top: 5700 ft., Bottom: 8022 ft., Determination Method: CBL
Casing:	String Type: S.C. 1.1, Hole Size: , Size: , Top: , Depth: 5267 ft., Weight: , Citings Type: ACTUAL
Cement:	Sacks: 250, Top: 2987 ft., Bottom: 5267 ft., Determination Method: CALC
Formation	Interval Top	Log Bottom	Cored	DSTs
DAKOTA	4515 ft.		N	N
CHEYENNE	4860 ft.		N	N
STONE CORRAL	5928 ft.		N	N
MARMATON	7251 ft.		N	Y
MORROW	7851 ft.		N	N
MISSISSIPPIAN	8042 ft.		N	Y

Formation MRTN Formation Classification: OW Status: AB - 7/15/2022 Interval Top: 7286 ft. Interval Bottom: 7292 ft.

Completed Information for Formation MARMATON

1st Production Date:	9/22/2017	Choke Size:
Formation Name:	MARMATON	Commingled:	No
Production Method:
Open Hole Completion:	No

Formation Treatment
Treatment Type:
Treatment Date:	11/22/2021	Treatment End Date:	N/A
Treatment Summary:	10/29/2021 MIRU PEAK WIRELINE perforated Marmaton 11/2/2021 Set CIBP @ 7298' 11/3-11/20/21 Waiting on new heater treater. Replaced 11/21/21 Started pumping unit.
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):	0
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:	ACID JOB
Treatment Date:	5/18/2021	Treatment End Date:	5/19/2021
Treatment Summary:	4/14/21 Knocked out CIBP 4/15/21 Set RBP @ 7369' 5/18/21 Prostim pumped 2000galsof 15% NEFE Acid w/22bbls Produced water from The Undefeated well 5/19/21 Reset RBP @ 7343' then Prostim pumped 2000gals of 15% NEFE Acid w/22bbls Produced water from the Undefeated well 5/26/21 Released RBP pull out of hole
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:	ACID JOB
Treatment Date:	11/2/2020	Treatment End Date:	11/2/2020
Treatment Summary:	11/2/2020 ProStim pumped 12bbls 15% NEFE with mutual solvent and flushed with 40bbls of production oil. Never caught pressure while treating the well.
Total fluid used in treatment (bbls):	12	Max pressure during treatment (psi):	0
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	12	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):	0
Fresh water used in treatment (bbls):	0	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	--
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	FRACTURE STIMULATION
Treatment Date:	10/22/2019	Treatment End Date:	10/22/2019
Treatment Summary:	10/18/19 Set a CIBP @ 7343 w/2sxs cmt on top. 10/22/19 Pumped Frac job 714 bbls of 15% HCl Acid, 12,500# of 100 Mesa White Sand, 51,000# of 40/70 Mesa White Sand and 1974bbls of slick water. Treating pressure was 3222 PSI.
Total fluid used in treatment (bbls):	2688	Max pressure during treatment (psi):	3222
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	714	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):
Fresh water used in treatment (bbls):	1974	Disposition method For flowback:
Total proppant used (lbs):	63500	Green completions techniques utilized:	Yes
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	1/17/2019	Treatment End Date:	1/24/2019
Treatment Summary:	1/17/19 Prostim pumped 250gals 7.5% MCA acid with 43bbls 2% KCL flush. 1/18/19 Prostim pumped 1000gals 20% MCA acid with 10gal of RAS 92 and 43bbls 2% KCL water 1/21/19 Prostim pumped 5000gals 20% SGA 2010 acid 1/24/19 Pumped 55bbls 2% KCL wtr down tubing.
Total fluid used in treatment (bbls):	290	Max pressure during treatment (psi):	4400
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	149	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	0	Total flowback volume recovered (bbls):	0
Fresh water used in treatment (bbls):	141	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	Yes
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	10/26/2017	Treatment End Date:	10/27/2017
Treatment Summary:	10/26/17 Pumped 250 gals 7.5% MCA acid w/additives then pumped 1,000 gals 15% HC1 acid w/additives & 98bbls 2% KCL Biocide. 10/27/17 Pumped 3,000gals 15% HC1 acid, w/additives & 44 bbls 2% KCL Biocide.
Total fluid used in treatment (bbls):	243	Max pressure during treatment (psi):	700
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	101	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):		Total flowback volume recovered (bbls):	0
Fresh water used in treatment (bbls):	142	Disposition method For flowback:
Total proppant used (lbs):		Green completions techniques utilized:	Yes
Reason green techniques Not utilized:
Formation Treatment
Treatment Type:	ACID JOB
Treatment Date:	8/8/2017	Treatment End Date:	8/9/2017
Treatment Summary:	8/07/17 Perfed from 7348-7362, 4shots/ft. 8/08/17 Pumped 250gals 7.5 MCA acid, 38bbls KCL Biocide. 8/09/17 Pumped 750gals 15% HC1 acid, 27gals RAS-10; 3gals CIA-165, 3gals IC-75, 1gal SI-4, 42bbls KCL Biocide 2%.
Total fluid used in treatment (bbls):	104	Max pressure during treatment (psi):	500
Total gas used in treatment (mcf):		Fluid density (lbs/gal):
Type Of gas:		Number Of staged intervals:
Total acid used in treatment (bbls):	24	Min frac gradient (psi/ft):
Recycled water used in treatment (bbls):	80	Total flowback volume recovered (bbls):	70
Fresh water used in treatment (bbls):	0	Disposition method For flowback:	RECYCLE
Total proppant used (lbs):		Green completions techniques utilized:	Yes
Reason green techniques Not utilized:

Test Type	Measure
Tubing Size:	2.875 in.	Tubing Setting Depth:	7278 ft.
Tubing Packer Depth:		Tubing Multiple Packer:
Open Hole Top:		Open Hole Bottom:
Initial Test Data:
Test Date:	11/22/2021	Test Method:	Pumping
Hours Tested:	24	Gas Type:
Gas Disposal:
BBLS_H2O	58
BBLS_OIL	2
CALC_BBLS_H2O	58
CALC_BBLS_OIL	2
CASING_PRESS	20
GRAVITY_OIL	36
TUBING_PRESS	40

Perforation Data:
Interval Top:	7286 ft.	# Of Holes:	24
Interval Bottom:	7292 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

August 2023 - July 2024	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