HomeMy WebLinkAbout20240932.tiffCIVITAS
Bonanza Creek Energy Operating Company, LLC
March 13, 2024
WA CERTIFIED MAIL - RETURN RECEIPT REQUESTED
Re:
Notice of Completeness Determination
Pronghorn OGDP Application — Docket No. 211100228
Township 5 North, Range 61 West. 6th P.M.
Section 4: SENNSENN
Section 10: NE1ANEA
Section 16: NWANWN
Section 22: NENNNE'.4
Wattenberg Field, Weld County, Colorado
Dear Interested Party,
RECEIVED
MAR 222024
WELD COUNTY
COMMISSIONERS
The purpose of this letter is to formally notify you that in compliance with the Colorado
Energy and Carbon Management Commission ("ECMC" or "Commission") Rule 303.e.,
Bonanza Creek Energy Operating Company, LLC (Operator No. 8960) ("BCEI" or
"Applicant") filed the Pronghorn Oil and Gas Development Plan Application ("Pronghorn
OGDP") with the Commission, and the Director made a completeness determination for the
Pronghorn OGDP pursuant to Rule 303.b. on March 8, 2024.
This Notice of Completeness Determination letter includes the following information
relevant to the Pronghorn OGDP Application and associated completeness determination:
i. The Operator's contact information including its electronic mail address, phone number,
and physical addresses to which the public may direct questions and comments:
Bonanza Creek Energy Operating Company, LLC
A Wholly Owned Subsidiary of Civitas Resources, Inc.
Attn: Jeff Annable, Manager, Well & Location Permitting
555 17th Street, Suite 3500
Denver, CO 80202
Tel: 303-312-8529
Email: jannabteleciviresources.com
Co .&Ru n i co., -1 ; o.1 S
01-1/2.2./.2.1-1
cc: cTh CSR), CA (BB), OG (SM)
0y/ ll/21i
2024-0932
� CIVITAS
Bonanza Creek Energy Operating Company, LLC
ii. The contact information for the Relevant Local Government:
Weld County Oil & Gas Energy Dept
Attn: Kelly Holliday, Lead Regulatory Analyst
1402 N 17th Ave
Greeley, CO 80631
Ted: 970-400-3582
Email: ogedOwetdgov.com
iii. The Commission's website address, main telephone number and email address:
Colorado Energy and Carbon Management Commission (formerly COGCC)
1120 Lincoln Street, Suite 801
Denver, Colorado, 80203
https://ecmc.state.co.us/#/home
Phone: 303-894-2100
Email: Dnr.ecmc@state.co.us
iv. The location of the Oil and Gas Locations (please see map below):
Amended Expanded Pronghorn P-22 Pad (Location ID 432611): NE'/4NE'A4 of Section
22, Township 5 North, Range 61 West, 6th P.M., Weld County, Colorado.
Amended Expanded Pronghorn T-4 Pad (Location ID 431481): SE'/4SE1A of Section
4, Township 5 North, Range 61 West, 6th P.M., Weld County, Colorado
Amended Expanded Pronghorn P-10 Pad (Location ID 436242): NE'/4NE'/4 of Section
10, Township 5 North, Range 61 West, 6th P.M., Weld County, Colorado.
Amended Expanded Pronghorn F-16 Pad (Location ID 431197): NW'/4NW'/4 of
Section 16, Township 5 North, Range 61 West, 6th P.M., Weld County, Colorado.
Nearby Public Crossroads: C.R. 58 & C.R. 89
CIVITAS
Bonanza Creek Energy Operating Company, LLC
v. The anticipated dates that each phase of operations will commence (by month and year)
is summarized below:
P ronghorn P-22 Pad
Construction: Oct 2025
Drilling: Dec 2025
Completion: Feb 2026
Production: April 2026
Interim Reclamation: Jun 2026
Pronghorn T-4 Pad
Construction: July 2025
Drilling: Sept 2025
Completion: Nov 2025
P roduction: Feb 2026
Interim Reclamation: May 2026
P ronghorn P-10 Pad
Construction: Aug 2025
Drilling: Oct 2025
Completion: Nov 2025
Production: Feb 2025
Interim Reclamation: May 2026
CIVITAS
Bonanza Creek Energy Operating Company, LLC
Pronghorn F-16 Pad
Construction: Sept 2025
Drilling: Nov 2025
Completion: Jan 2026
Production: Mar 2026
Interim Reclamation: Jun 2026
In addition, this Notice of Completeness Determination letter contains the following details
regarding the proposed Pronghorn OGDP development:
How many Wells and Locations are proposed:
BCEI seeks approval of an approximate 6,540 -acre OGDP for the development
and production of 26 new horizontal wells and 6 existing horizontal wells, for a
total of 32 horizontal wells, to be developed from a total of four amended
expanded Oil and Gas Locations. BCEI proposes to drill 7 new horizontal wells
from the Pronghorn P-22 Oil and Gas Location, 7 new horizontal wells from the
Pronghorn T-4 Oil and Gas Location, 4 new horizontal wells from the Pronghorn
P-10 Oil and Gas Location and 8 new horizontal wells from the Pronghorn F-16 Oil
and Gas Location.
ii. The proposed construction schedule by quarter and year is summarized below:
Q4 Quarter, 2025: Construction Phase for the Pronghorn P-22 Pad
Q3 Quarter, 2025: Construction Phase for the Pronghorn T-4 Pad
Q3 Quarter, 2025: Construction Phase for the Pronghorn P-10 Pad
Q3 Quarter, 2025: Construction Phase for the Pronghorn F-16 Pad
iii. A description of each operational phase of development and what to expect during
each phase.
See Attachment A - Description of Operational Phases.
iv. Proposed haul routes and traffic volume associated with each phase of operations.
See Attachment B - Estimated Traffic during Active Operations.
v. A description of any variances requested pursuant to Rule 502:
BCEI is not seeking any Rule 502 variances for the Pronghorn OGDP Application.
Q CIVITAS
Bonanza Creek Energy Operating Company, LLC
Furthermore, with this letter BCEI is including the following information from the
Commission:
1. The issued Notice of Hearing for a May 15, 2024 ECMC Hearing Date for the
Pronghorn OGDP;
2. The Pronghorn OGDP Hearing Application and Exhibits;
3. The Commission's information sheet about the procedural steps involved with the
Director's and Commission's review of Oil and Gas Development Plans;
4. The Commission's information sheet about the Commission's public comment
process and the relevant deadlines;
5. The Commission's information sheet about hydraulic fracturing treatment; and
6. The Commission's information sheet about how the public mayviewthe status of the
proposed Oil and Gas Development Plan application on the Commission's website.
Please note that the ECMC Director did not identify any additional information to include in
this notice in her completeness determination. To learn more details about the Pronghorn
OGDP and ask questions about the Oil and Gas Development Plan prior to the closure of
the public comment period, please contact me at 303-312-8529 or
jannable@civiresources.com.
Sincerely,
Jeff Annable
Manager, Well & Location Permitting
Bonanza Creek Energy Operating Company, LLC
A Wholly Owned Subsidiary of Civitas Resources, Inc.
Enclosures
Phases of Operations & What to Expect
Attachent A
Well Pad Construction
• Initial construction includes clearing the access and pad site construction areas of vegetation and grading the
surface. Once the surface has been graded, construction crews will install the base material to provide for the
construction of the well pad. Final dressing of the working pad surface and seeding and stabilization of the topsoil
stockpiles and stormwater controls will occur prior to final inspection. Prior to the arrival of the drilling rig, additional
preparation for operational BMPs (i.e., noise mitigation) will be installed. Construction operations are limited to
daylight hours only.
Drilling
• Initial operations include the mobilization of rig equipment to site, assembly of the drill rig to include the installation
of the rig derrick, and the setting of surface casing per the issued drilling permits. Following the installation of
surface casing on all wells, the rig then drills the remaining portions of each well. When total depth has been
reached on all wells, the rig will be taken apart and mobilized from the site. Drilling operations occur 24 hours/day.
Completions
Initial operations include the mobilization of completions fleet to site, arrival of wireline vehicles, and spotting of the
pumps, support vehicles, cranes, and operations command trailer. Once the equipment has been sited, operations
begin by preparing the wellbore(s) for hydraulic stimulation. Once prepped, the stimulation starts by pumping fluid
downhole for a pre -determined period of time. Once the stimulation is over, a plug is pumped downhole and the
next wellbore is stimulated until all stages have been pumped. Completion operations occur 24 hours/day.
Facility Construction
• All access and facility assembly activities will be contained within the approved well pad; contractors will follow the
Town -approved transportation route. Activities will include transportation of facility equipment to the well site,
followed by assembly, and testing the functionality of the equipment prior to approving it for service. Facility
construction occurs during daylight hours only.
Production
In preparation for production, the wellbore is cleaned out using a Coiled -tubing unit and production tubing is
installed in each well. Following the installation of tubing, production is initiated from each well in sequential order.
Initial production may flow through temporary or permanent equipment then into pipeline to be sold. Once a pad is
in the production phase, there will be occasional well/equipment maintenance requiring equipment to be brought on
location; otherwise, routine traffic will be pickup trucks and water trucks to remove produced water from location.
Production operations occur 24 hours/day.
Q CIVITAS
100% of Traffic on
CR89, South of
Access Points
CIVITAS
Bonanza Creek Energy Operating Company, LLC
Pronghorn F-16 Pad
Average Daily Roundtrip Activity
Pad
Construction
Facility
Construction
Drilling
Completions
Flowback
Interim
Reclamation
On Going
Production
Duration
20
60
48
39
6
20
On Going
Operating
Hours
Daylight
Hours
Daylight Hours
24 hours
24 hours
24 hours
Daylight
24 hours
Truck
Traffic
5
1
9
68
6
5
0
Employee
Traffic
5
5
18
27
4
5
1
Table 1: Average Number of Roumdtrips per Dray during Drilling and Completions Operations
Pronghorn P-10 Pad
Average Daily Roundtrip Activity
Pad
Construction
Facility
Construction
Drilling
Completions
Flowback
Interim
Reclamation
On Going
Production
Duration
20
60
34
29
4
20
On Going
Operating
Hours
Daylight
Hours
Daylight Hours
24 hours
24 hours
24 hours
Daylight
24 hours
Truck
Traffic
5
1
7
60
3
5
0
Employee
Traffic
5
5
18
22
4
5
1
Table 2: Average Number of Roundtriplsper Dray during Drilling and Completions Operations
Suite 3700 - 55517th St, Denver, CO 80202
www.civitasresources.com
(Bonanza Creek Energy Operating Company, LLC is a wholly owned subsidiary of Civitas Resources, Inc)
0 CIVITAS
Bonanza Creek Energy Operating Company, LLC
Pronghorn P-22 Pad
Average Daily Roundtrip Activity
Pad
Construction
Facility
Construction
Drilling
Completions
Flowback
Interim
Reclamation
On Going
Production
Duration
20
60
49
43
6
20
On Going
Operating
Hours
Daylight
Hours
Daylight Hours
24 hours
24 hours
24 hours
Daylight
24 hours
Truck
Traffic
5
1
8
63
5
5
0
Employee
Traffic
5
5
18
24
4
5
1
Table 3: Average Number of Roundtrips per Day during Drilling and Completions Ope►ations
Pronghorn T-4 Pad
Average Daily Roundtrip Activity
Pad
Construction
Facility
Construction
Drilling
Completions
Flowback
Interim
Reclamation
On Going
Production
Duration
20
60
49
43
6
20
On Going
Operating
Hours
Daylight
Hours
Daylight Hours
24 hours
24 hours
24 hours
Daylight
24 hours
Truck.
Traffic
5
1
8
63
5
5
0
Employee
Traffic
5
5
18
24
4
5
1
Table 4: Average Number of Roundtrips per Day during Drilling and Completions Operations
Suite 3700 - 55517th St, Denver, CO 80202
www.civitasresourcess.com
(Bonanza Creek Energy Operating Company, LLC is a wholly owned subsidiary of Civitas Resources, Inc.)
BEFORE THE ENERGY AND CARBON MANAGEMENT COMMISSION
OF THE STATE OF COLORADO
IN THE MATTER OF THE PROMULGATION
AND ESTABLISHMENT OF FIELD RULES TO
GOVERN OPERATIONS FOR THE NIOBRARA,
FORT HAYS, CODELL, AND CARLILE
FORMATIONS, WATTENBERG FIELD, WELD
COUNTY, COLORADO
NOTICE OF HEARING
CAUSE NO. 407
DOCKET NO. 211100228
TYPE: OIL & GAS
DEVELOPMENT PLAN
Bonanza Creek Energy Operating Company, LLC (Operator No. 8960) ("BCEI" or
"Applicant"), a wholly owned subsidiary of Civitas Resources, Inc., filed an Application with the
Commission for an order to establish an Oil & Gas Development Plan ("OGDP") on the lands
identified below. Generally, an Oil & Gas Development Plan is the process whereby an applicant
obtains approval to develop oil or gas resources at one or more oil and gas location by drilling a
specific number of wells. Importantly, an OGDP is not a pooling application.
This Notice was sent to you because the Applicant believes you may: 1) be an Owner of
oil and/or gas ("mineral") interests to be developed by the proposed OGDP; 2) own, reside, or
operate a first responder agency on property within 2,000 feet of a working pad surface included
in the OGDP; or 3) be otherwise entitled to notice pursuant to Commission Rule 303.e.(1).
APPLICATION LANDS
Township 5 North, Range 61 West, 6th P.M.
Section 3: All
Section 4: All
Section 5: E%
Section 8: E%
Section 9: All
Section 10: 9%; W%W%2
Section 15: E%; W%W%; S%SE%SW%
Section 16: All
Section 17: All
Section 21: N%N%N%
Section 22: EA; N%2N%NW%
Township 6 North, Range 61 West, 6th P.M.
Section 33: All
Section 34: All
Surface Location No. 1 Amended Expanded Pronghorn P-22 Pad
Lands:
Township 5 North, Range 61 West, 6th P.M.
Section 22: NE%NE%
1211100220141
Surface Location No. 2 Amended Expanded Pronghorn T-4 Pad
Lands:
Township 5 North, Range 61 West, 6th P.M.
Section 4: SE%SE%
Surface Location No. 3 Amended Expanded Pronghorn P-10 Pad
Lands:
Township 5 North, Range 61 West, 6th P.M.
Section 10: NE'%NE'/4
Surface Location No. 4 Amended Expanded Pronghorn F-16 Pad
Lands:
Township 5 North, Range 61 West, 6th P.M.
Section 16: NW%NW%
DATE, TIME, AND LOCATION OF HEARING
(Subject to change)
The Commission will hold a hearing only on the above -referenced docket number at the
following date, time, and location:
Date: May 15, 2024
Time: 9:00 a.m.
Place: Colorado Energy and Carbon Management
Commission
The Chancery Building
1120 Lincoln Street, Suite 801
Denver, CO 80203
Parties to this hearing will be notified if this date, time, or place changes. For the most up-
to-date information regarding the Commission's hearing schedule, please visit
https://ecmc.state.co.us/+/home, click on "Commission Hearings," and click on "Preliminary
Agendas."
PUBLIC COMMENT
Any party may file a public comment for the review of Commission Staff related to the
above -described OGDP. All public comments will be included in the administrative record for the
OGDP proceeding. Parties wishing to file a public comment on the above -described OGDP may
follow the instructions at
https://ecmc.state.co.us/documents/sb19181/Guidance/Mission Change Guidance/Info%20Sh
eet 303.e.(2).D%20Public%20Comment 20210309.pdf, or may use the eFiling system outlined
below.
PETITIONS
2
(211100228)
DEADLINE FOR PETITIONS BY AFFECTED PERSONS: April 15, 2024
Any interested party who wishes to participate formally in this matter must file a written
petition with the Commission no later than the deadline provided above. Please see Commission
Rule 507 at https://ecmc.state.co.us, under "Regulation," then select "Rules." Please note that,
under Commission Rule 510.1, the deadline for petitions may only be continued for good cause,
even if the hearing is continued beyond the date that is stated above. Pursuant to Commission
Rule 507, if you do not file a proper petition, the Hearing Officer will not know that you wish to
formally participate in this matter and the date and time of the hearing may change without
additional notice to you. Parties wishing to file a petition must register online at
https://oitco.hvlandcloud.com/DNRCOGExternalAccess/Account/Looin.aspx and select "Request
Access to Site." Please refer to our "eFiling Users Guidance Book" at
https://ecmc.state.co.us/documents/reg/Hearings/Extemal Efiling System Handbook Decemb
er 2021 Final.pdf for more information.
Any Affected Person who files a petition must be able to participate in a prehearing
conference during the week of April 15, 2024, if a prehearing conference is requested by the
Applicant or by any person who has riled a petition.
ADDITIONAL INFORMATION
For more information, you may review the Application, which was sent to you with this
Notice. You may also contact the Applicant at the phone number or email address listed below.
In accordance with the Americans with Disabilities Act, if any party requires special
accommodations as a result of a disability for this hearing, please contact Margaret Humecki at
Dnr ECMC Hearings Unit(@,state.co.us, prior to the hearing and arrangements will be made.
Dated: March 12, 2024
ENERGY AND CARBON MANAGEMENT COMMISSION
OF THE STATE OF COLORADO
I
Jon Peskin, Acting Secretary
Applicant
Bonanza Creek Energy Operating Company, LLC
c/o Jamie L. Jost
Kelsey H. Wasylenky
Jost Energy Law, P.C.
3511 Ringsby Court, Unit 103
Denver, CO 80216
720-4465620
jjost(@lostenergylaw.com
kwasylenky@jostenergylaw:cow
BEFORE THE ENERGY AND CARBON MANAGEMENT COMMISSION
OF THE STATE OF COLORADO
IN THE MATTER OF THE PROMULGATION ) CAUSE NO. 407
AND ESTABLISHMENT OF FIELD RULES TO )
GOVERN OPERATIONS FOR THE NIOBRARA, ) DOCKET NO. 211100228
FORT HAYS, CODELL AND CARLILE )
FORMATIONS, WATTENBERG FIELD, WELD ) TYPE: OIL AND GAS
COUNTY, COLORADO ) DEVELOPMENT PLAN
FOURTH AMENDED APPLICATION
COMES NOW Bonanza Creek Energy Operating Company, LLC (Operator No. 8960)
(°BCEI" or "Applicant"), a wholly owned subsidiary of Civitas Resources, Inc., by and through its
attorneys Jost Energy Law, P.C., respectfully submits this Application to the Colorado Energy and
Carbon Management Commission (the "Commission" or the "EMC") for an Oil and Gas
Development Plan ("OGDP"). In support of its Application, Applicant states as follows:
1. The Applicant is a limited liability company and is a registered operator in good
standing with the Commission.
2. Applicant seeks approval of an approximate 6,540 -acre OGDP for the development
and production of 26 new horizontal wells and six existing horizontal wells, for a total
of 32 horizontal wells, to be developed from a total of four amended expanded Oil and
Gas Locations on the below -described lands ("Application Lands") (the "Pronghorn
OGDP"):
Township 5 North, Range 61 West, 6th P.M.
Section -3: All
Section 4: All
Section 5: E'/2
Section 8: E%
Section 9: All
Section 10: E%2; W1 WY2
Section 15: E%2; W%W'/2; SYSE'/%SW'/a
Section 16: All
Section 17: All
Section 21: N'A2N'%NY2
Section 22: EA; NVNY2NW%
Township 6 North, Range 61 West, 6th P.M.
Section 33: All
Section 34: All
Surface Locations:
Amended Expanded Pronghorn P-22 Pad (Location ID 432611): NE'/%NE%
of Section 22, Township 5 North, Range 61 West, 6th P.M., Weld County,
Colorado.
(211100228/407-XXXX)
Amended Expanded Pronghorn T-4 Pad (Location ID 431481): SE%SE'/4
of Section 4, Township 5 North, Range 61 West, 6th P.M., Weld County,
Colorado
Amended Expanded Pronghorn P-10 Pad (Location ID 436242): NE%NE'/4
of Section 10, Township 5 North, Range 61 West, 6th P.M., Weld County,
Colorado.
Amended Expanded Pronghorn F-16 Pad (Location ID 431197):
NW'/NW'/4 of Section 16, Township 5 North, Range 61 West, 6th P.M.,
Weld County, Colorado.
Nearby Public Crossroads: CR 58 & CR 89
A reference map of the Application Lands is attached hereto as Exhibit A.
3. With this Application, BCEI is providing a copy of an Oil and Gas Lease and associated
Assignment, Bill of Sale and Conveyance into BCEI for at least one portion of a mineral
tract within the Application Lands showing the Applicant's status as an Owner in
accordance with ECMC Rule 303.a.(1). See Exhibit B, attached and made a part
hereto.
4. With this Application, BCEI submits an application for six new Drilling and Spacing
Units, three amended Drilling and Spacing Units, and two new Wellbore Spacing Units.
See Exhibit C.
5. With this Application, BCEI submitted a Form 2A for the development of seven new
horizontal wells within the Application Lands from the proposed amended Pronghorn
P-22 Oil and Gas Location (Location ID 432611) pursuant to Rule 303.a.(2) and Rule
304, Document No. 402766972. The Pronghorn P-22 Oil and Gas Location (Location
ID 432611) has one active well that will be included in this OGDP, for a total of eight
wells on this Location. BCEI attached the approved Weld County Pronghorn
Comprehensive Development Plan approving the siting and the related surface
disturbance as an Exhibit to the Form 2A, in accordance with Rule 303.a.(6).B.
6. With this Application, BCEI submitted a Form 2A for the development of seven new
horizontal wells within the Application Lands from the proposed amended Pronghorn
T-4 Oil and Gas Location (Location ID 431481) pursuant to Rule 303.a.(2) and Rule
304, Document No. 402766986. The Pronghorn T-4 Oil and Gas Location (Location
ID 431481) has one shut in well that will be included in this OGDP, fora total of eight
wells on this Location. BCEI attached the approved Weld County Pronghorn
Comprehensive Development Plan approving the siting and the related surface
disturbance as an Exhibit to the Form 2A, in accordance with Rule 303.a.(6).B.
7. With this Application, BCEI submitted a Form 2A for the development of four new
horizontal wells within the Application Lands from the proposed amended Pronghorn
P-10 Oil and Gas Location (Location ID 436242) pursuant to Rule 303.a.(2) and Rule
304, Document No. 402766991. The Pronghorn P-10 Oil and Gas Location (Location
ID 436242) has one active well that will be included in this OGDP, for a total of five
wells on this Location. BCEI attached the approved Weld County Pronghorn
(211100228/407-XXXX)
Comprehensive Development Plan approving the siting and the related surface
disturbance as an Exhibit to the Form 2A, in accordance with Rule 303.a.(6).B.
8. With this Application, BCEI submitted a Form 2A for the development of eight new
horizontal wells within the Application Lands from the proposed amended Pronghorn
F-16 Oil and Gas Location (Location ID 431197) pursuant to Rule 303.a.(2) and Rule
304, Document No. 402766921. The Pronghorn F-16 Oil and Gas Location (Location
ID 431197) has three active wells that will be included in this OGDP, for a total of
eleven wells on this Location. BCEI attached the approved Weld County Pronghorn
Comprehensive Development Plan approving the siting and the related surface
disturbance as an Exhibit to the Form 2A, in accordance with Rule 303.a.(6).B.
9. With this Application, BCEI submitted a Form 2B Cumulative Impact Data Identification
pursuant to Rule 303.a.(5), Document No. 402766937.
10. With this Application, BCEI submitted a Form 2C OGDP Certification pursuant to Rule
303.a.(7), Document No. 402766995.
11. With this Application BCEI submitted its required Rule 505 testimony.
12. BCEI certifies that pursuant to Rule 302.e, it notified Weld County as the Relevant
Local Government that it planned to submit the Pronghorn OGDP Application no less
than 30 days prior to submitting this Pronghorn OGDP Application. There are no
Proximate Local Governments within 2,000 feet of the Working Pad Surface for the
Pronghorn P-22 Pad, the Pronghorn T-4 Pad, the Pronghorn P-10 Pad or the
Pronghorn F-16 Pad. The Rule 302.e 30 -day notice letter to Weld County is attached
and made a part hereto as Exhibit D. The 30 -day pre -notice complied with the
procedural and substantive requirements of Rules 303.e.(2) and (3).
13. BCEI certifies that copies of this Application and the Notice of Hearing will be served
on each interested party as required by Rule 504.a, Rule 504.b.(1), Rule 504.b.(2),
504.b.(5) and Rule 303.e. The Interested Parties list is attached hereto and submitted
with this Application as Exhibit E.
14. BCEI certifies that upon completeness determination by the Director of the Pronghorn
OGDP, BCEI will provide notice of the Director's Completeness Determination to each
interested party required by Rule 303.e.
15. The granting of this Application is in accord with the Oil and Gas Conservation Act,
found at C.R.S. §§ 34-60-101 et seq., and the Commission Rules.
16. Applicant requests that relief granted under this Application should be effective on oral
order by the Commission, and Applicant hereby agrees to be bound by said oral order.
WHEREFORE, BCEI respectfully requests that this matter be set for hearing in
accordance with applicable Commission Rules, that notice be given as required by law, and that
upon such hearing this Commission enter its order to:
A. Approve the approximate 6,540 -acre OGDP for the development of 26 new horizontal
wells and six existing horizontal wells, for a total of 32 horizontal wells, within eleven
Drilling and Spacing Units for the Application Lands;
(211100228/407-XXXX)
B. Provide that the subject wells shall be located on the amended expanded Pronghorn P-
22 Pad, Pronghorn T-4 Pad, Pronghom P-10 Pad and Pronghorn F-16 Pad within the
Application Lands and approve the associated Form 2A(s) for the Pronghorn P-22 Pad,
the Pronghorn T-4 Pad, the Pronghorn P-10 Pad and the Pronghorn F-16 Pad where
applicable;
C. Find that the Pronghorn OGDP will protect and minimize adverse impacts to public health,
safety, and welfare, the environment, and wildlife resources and will protect against
adverse environmental impacts on any air, water, soil or biological resource in compliance
with C.R.S. § 34-60-106(2.5)(a);
D. For such other findings and orders as the Commission may deem proper or advisable in
this matter.
Dated this 22nd day of November, 2023.
Bonanza Creek Energy Operating Company,
LLC
By
Jamie L. Jost
Kelsey H. Wasylenky
Jost Energy Law, P.C.
Attorneys for Applicant
3511 Ringsby Court, Unit 103
Denver, Colorado 80216
(720) 446-5620
Jiosttmiostenergvlaw.com
KwasvlenkytBtlostenergvlaw.com
Applicant's Contact Information:
Bonanza Creek Energy Operating Company, LLC
A Wholly Owned Subsidiary of Civitas Resources, Inc.
ATTN: Jeff Annable
Manager, Well & Location Permitting
Direct: 303-312-8529
jannable(civiresources.com
555 17th Street, Suite 3500
Denver, CO 80202
(211100228/407-)OOOQ
VERIFICATION
Jeff Annable, of lawful age, being first duly sworn upon oath, deposes and says that he is the
Manager, Well & Location Permitting for Civitas Resources, Inc., and that he has read the foregoing
Amended Application and that the matters therein contained are true to the best of his knowledge,
information and belief.
Dated November 22, 2023.
Jeff Annable
Manager, Well & Location Permitting
Civitas Resources, Inc.
(211100228/4074OOOQ
Exhibit A
Reference Map Legd Desatpti on
Wattenbeg Field, Weld County
Township 5 Noth, Range 61 West, 6th P.M.
Sell on 3: All
Secti on 4: All
Secti on 5: E',4
Secti on 8: E%
Secti on 9: All
Secti on 10: Eth; WY2W1/2
%z
Sell on 15: E%; W' W'/) S'/4SE'/aSW%
Sedi on 16: All
Sedi on 17: All
Secti on 21: N%N'YN%
Sedi on 22: E'/2; N%N%NW %
Tow nshb 6 Noth, Range 61 West, 6th P .M.
Sell on 33: All
Sear on 34: All
Surface Locations:
Amended Expanded P onghon P -22P a i(Loati on ID 432611): NE% NE%
of Sedi on 22, Townshp 5 Noth, Range 61 West, 6th P .M.,Weld County,
Colotedo.
Amended Ex panded P onghon T-4 P ad(Locli on ID 431481): SE' SE%
of Sedi on 4, Township 5 Noth, Range 61 West, 6th P .M.,Weld County,
Colorado
Amended Ex paned P onghon P -10P ad(Locsi on ID 436242): NE' NE%
of Sedi on 10, Townshp 5 Noth, Range 61 West, 6th P .M.,Weld County,
Coloedo.
Amended Expanded P onghon F-16 P at (Local on ID 431197):
NW% N1/1/1,44 Secti on 16, Townshp 5 Noth, Range 61 West, 6th P .M.,
Weld County, Coloab.
Nearby Public Crossroads: CR 58 & CR 89
Exhibit A
Ref eience Map
W atten berg Reid, Weld County
IIIII IIII l INt.1 IIIII IIIII II IIIII IIII IIII
1r 3124160 1110612013 09:4611 Weld County, CO
1 of 6 R 31.00 0 0.00 Steve Moreno Clerk & Recorder
SLB 193-6
Rev. 8/89
STATE OF COLORADO
BOARD OF LAND COMMISSIONERS
OIL AND GAS LEASE NO. 77993
Containing 640.00 acres, more or less: Land Fund Schoo
THIS LEASE AGREEMENT, Dated this la,day of February. 2003 made and entered into by and
between the STATE OF COLORADO, acting by and through the STATE BOARD OF L 5ND COMMISSIONERS.
hereinafter called Lessor, and CFG Energy. In.
1846 Frontier Road. Greeley. C080634 hereinaflercalledLessee:
ASSIGNED
Exhibit B
WITNESSETH
WHEREAS, Said Lessee has applied to Lessor for an oil and gas lease covering the land herein described,
and has paid a filing fee in the amount of $ ALL, plus a bonus consideration of1J121_0.00 10 40.00 fixed by Lessor as an
additional consideration for the granting of this lease, and Lessee agrees to pay an annual rental of S 960.00
computed at the rate of $ 1.50 , per acre or fraction thereofper year.
WHEREAS, All the requirements relative to said application have been duly complied with and said
application has been approved and allowed by Lessor•,
THEREFORE, In consideration of the agreements herein, on the part of Lessee to be paid, kept and
performed, Lessor does lease exclusively to Lessee for the sole and only purpose of drilling for, development of and
production of oil and gas, or either of them, thereon and therefrom with the right to own, except as set forth in the
METHANE FROM COAL SEAMS paragraph herein, all oil and gas so produced and saved therefrom and not
reserved as royalty by Lessor under the terms of this lease, together with rights -of -way, easements and servitudes for
pipelines, telephone and telegraph lines, tanks and fixtures for producing and caring for such products, and any and
all rights and privileges necessary for the exploration and operation of said land for oil and gas, the following
described land situated in the County of Weld, State of Colorado, and more particularly described as foi our:
DESCRIPTION OF LAND TOWNSHIP RANGE SEC!. ION
All 5N
Surface Patents: Yes X No _
61W 16
TO HAVE AND TO HOLD Said land, and all the rights and privilegesgranted hereunderto Lessee until the
hour of twelve o'clock noon on the 13th day of Februarv.2008 , as primary term, and so long thereafter as oil and
gas, or either of them, is produced in paying quantities from said land or Lessee is diligently engaged in bona fide
drilling or reworking operations on said land, subject to the terms and conditions herein. Drilling or reworking
operations shall be deemed to be diligently performed if there is no delay or cessation thereof fora period greater
than 60 consecutive days unless an extension in writing is granted by Lessor, provided that such drilling or
reworking operations are commenced during said primary tens or any extension thereof or while this lease is in
force by reason of production of oil and gas or either of them, or that such reworking is commenced within 60 days
upon cessation of production for the purpose of re-establishingthe same, and provided further that such production is
anntnrncred during such primrn• tern, or any .\tendon thereof, or while this leeon ig in lured by reacon of such
drilling or reworking operations or other production.
METHANE FROM COAL SEAMS - Coalbed methane may be produced, saved and/or sold by a coal
mining lessee from mineable coal measures and from roofs and floors of mineable coal measures and the gas shall be
the property of that lessee provided that the gas is removed only as a mining safety procedure prior to or during
mining. Gas that is uneconomical to produce maybe vented or flared provided that such venting or faring complies
with all Federal and State requirements. Gases produced by the oil and gas lessee from the mineable coal measures
and from roofs and floors of mineable coal measures prior to, during, or alter mining shall be the property of the oil
and gas lessee under the terms of this lease. Oil and gas operation shall not render coal seams unmineable.
EXPLORATION - Lessor reserves the right to conduct exploration on the leased land provided such
exploration does not interfere with rights granted herein.
1 111111 11111 MI 1111111 11111;41,1M Milli 101
3124155 11/0612003 09::455 Weld County, CO
2 of 6 R 31.00 0 0.00 Steve Moreno Clerk & Recorder
In consideration of the premises, the parties covenant and agree as follows:
1. RENTAL - If lease is extended for any reason beyond primary tern rental will be determined by Lessor.
The rental in effect at the time production is established shall not be increased due to the term of this lease being
extended by such production. Rentals set at the time of established production shall be paid during the remaining life
of this lease, annually, in advance. on or before each anniversary date hereof. There shall he no refuted of unused
rental.
2. ROYALTY - Lessee shall account for any and all substances produced on the leased land and Lessee
shall pay to Lessor a royalty on same in addition to the rentals provided. Products used on the leased laced,
unavoidablylost or flared on the leased land, may be exempt with approval of Lesson
(a)
On oil, one -eighth of the oil produced and saved from the leased land.
At the opteatfakah and with 60 days notice to Lessee, Lessor may take its royalty oil in kind.
:vhich event Lessee shalt deliver such royalty oil to Lessor on the leased land, free of cost or
deduction. into the pipelines or storage tanks designated by Lessor. but Lessee shall not in such case
be required to provide free tankage for any such oil for a longer period than 1 month after the same
is run into tanks. With 60 days notice to Lessee, Lessor may cease iakingoil royalty in kind. When
paid in cash, the royalty shall be calculated upon the fair market value of the oil at the well which
shall not be deemed to be less than the price actually paid to Lessee at the well by the purchaser
thereof; and in no event shall the royalties be based upon a market value at the well less than the
posted price in the field for such oil. or in the absence of a posted price in the field far such oil, upon
a market value at the well less than the prevailing price received by other producers in the field for
oil of like grade and gravity at the time such oil is nm into pipelines or storage tanks.
(b) On gas, including casingheadgas or other gaseous substance. one -eighth of the fair market value at
the well or of the price received by Lessee at the well, whichever is greater, of all has produced and
sold from the leased land or utilized off the land by Lessee. A copy of all contracts for sale of gas
shall be furnished to Lessor. Where gas is sold under a contract that has been approved by Lessor,
the fair market value of such gas for determining the royalties payable lieretinder shall be the price
at which such gas is sold under such contract. No approval by Lessor of the teeen of any such
agreement shall operate to make Lens to n party thereto ne obligate it thereunder in any way. At the
option of Lessor, and with 60 days' notice to. Lessee, Lessor eeey take its royalty in kind. With 60
days' notice to Lessee, Lessor may cease taking gas royalty in kited.
(c)
All costsof marketing the oil and'or gas produced shall be borne by Lessee and such costs shall not
directly or indirectly reduce the royalty payments to Lessor. except that marketing costs for Lessor's
in -kind royalty shall be borne by Lessor.
(d) If Lessor owns a lesser interest in the oil and gas deposits of the above described land than the entire
and undivided fee simple estate, then the royalties and rentals herein provided shall be paid to
Lessor only in the proportion which its interest bears to the :thole and undivided fee.
3. RECORDS - Lessee agrees to keep and to have in possession complete and accurate boots and records
showing the production and disposition of any and all substances produced on the leased land and to permit Lessor,
at all reasonable hours, to examine the saute, or to furnish copies of same to Lessor upon request along with
purchaser's support documentation. Lessor will not be unreasonable with requests. All said books and records shall
be retained by Lessee and made available in Colorado to Lessor fora period of not less dean 5 years. A8s
contracts and subsequent agreements and amendments shall be submitted to Lessor within 60 days of execution.
4. MEASUREMENTS - All production shall be accurately measured using standards established by the
American Gas Assee(neien (AGA) antthe-t!te Aeeer3can Petroleum 4tta!•e to (Apt) amt al. epee *leg L' u en sttet bet
tamperproof as nearly as possible. Oil royalties due within the tenets of this lease shall be calculated on actual and
accurate measurements within API standards unless a different means ot'measurement. subject to Lessor's approval,
is provided.
e. PAYMENTS S. REPORTS - All payments and reports due hereunder shall be made on or before the day
such payments and reports are due. Nothing in this paragraph shall be construed to extend the expiration of the
primary term hereof
Page 2 of 6
11111111!1111111111111111►'':IIliflits1101111
31241W 1110612003 09:4M Weld County, CO
3 of 0 R 31.00 D 1.00 Steve Moreno dirk d Recorder
Oil royalty payments and supporting documents shall be submitted prior to the last day of the calendar
month following each month's sale of production, and gas royalty payments and supporting documents shall be
submitted prior to the last day of the second calendar month following each month's sale of production. Payments
and supporting documents for new wells shall be submitted prior to the last day of the third calendar month
following fast month's sale of production.
All payments shall be made by cash, check, certified check or money order. Payments having restrictions,
qualifications, or encumbrances of any kind whatsoever shall not be accepted by Lessor. A penalty for a late
payment shall be charged as set forth in the PENALTIES paragraph herein.
6. PENALTIES - A penalty shall be imposed for, but not limited to, late payments, improper payments,
operational deficiencies, violation of any covenant of this lease. or false statements made to Lessor. Penalties shall
be determined by Lessor unless otherwise provided for by law and may be in the form of, but not limited to, interest,
fees, fines, and/or lease cancellation.
7. LAW - The terms and conditions of this lease shall be performed and exercised subject to all laws, rules,
regulations, orders, local ordinances or resolutions applicable to and binding upon the administrationof lands owned
by the State of Colorado, and to laws, rules and regulationsgovemingoil and gas operations in Colorado. Violations
shall result in penalties as provided for by law or as set forth in the aforementioned schedule or shall, at the option of
Lessor, result in default as provided hereinafter.
8. SURRENDER - Lessee may at any time, by paying to Lessor all amounts then due as provided herein,
surrender this lease insofar as the same covers all or any portion of the land herein leased and be relieved from
further obligations or liability hereunder with respect to the land so surrendered; provided that no partial surrender or
cancellation of this lease shall be for less than contiguous tracts of approximately 40 acres or Governmental lot
corresponding to a quarter -quarter section; provided further that this surrender clause and the option herein reserved
to Lessee shall cease and become absolutely inoperative immediately and concurrently with the institution of any
suit in any court of law by Lessee, Lessor or any assignee of either to enforce this lease, or any of its tens express or
implied. in no case shall any surrender be effective until Lessee shall have made full provision for conservation of
the leased products and protection of the surface rights of the leased land.
9. ASSIGNMENTS -
(a) Lessee, with written consent of Lessor, shall have the right to assign the entire leasehold interest of
said Lessee in all or part of the land covered hereby, but not less however, than contiguous tracts of
approximately 40 acres or Governmental lot corresponding to a quarter -quarter section for any
partial assignment, and for approval of such assignment Lessor shall make an assignment charge in
an amount to be determined by Lessor. Prior to written approval by Lessor of assignment of this
lease, Lessee (assignor) shall not be relieved of its obligations under the tens and conditions
herein. An assignment shall not extend the ten of this lease.
(b) if any assignment of a portion of the land covered hereby shall be approved, a new lease shall be
issued to the assignee covering the assigned land, containing the same terms and conditions as this
lease, and limited as to term as this lease is limited, and the assignor shall be released and
discharged from all further obligationsand liabilitiesas to that portion so assigned.
(C)
Lessee shall notify Lessor of all assignments of undivided percentage or other interests. Said
interests will not be recognized or approved by Lessor, and the effect of any such assignments will
be strictly and only between the parties thereto, and outside the terms of this lease; and no dispute
between parties to any such assignment shall operate to relieve Lessee from performance of any
terms or conditions hereof or to postpone the time therefor. However, if Lessee assigns 100 percent
of said interest in this manner. a leasehold assignment must be received and approved by lessor to
assure that a leasehold interest is maintained by the record lessee. Lessor shall at all times be
entitled to look solely to Lessee or his assignee shown on its books as being the sole owner hereof,
and for the sending of all notices required by this lease and for the performance of all tens and
conditions hereof.
(d) Although not binding on Lessor, all instrnments of every kind and nature whatsoever affecting this
lease shall be filed in the records of the Mineral t!cpartment of Lessor.
10. OVERRIDING ROYALTY - Any and all onset :siytntentsof overriding royalties shall not
exceed 5 percent, includingany overriding royalties pre, iousl din:. In the event that production drops to an
amount that would cause the well to be shut-in or to be ptugge,:. dtci • ,verriding royalties based on last in fast
Page 3of6
IIII111IIIIII11II11III11III111I0IIIII1IIIIIIIII f
3124155 1110612003 09:461 Moms*, Co
4 of 6 R 31.00 D 0.00 Stove Moreno Clerk & Recorder
out, or prorated, maybe suspended to allow the well, if possible, to be economic. A reservation or assignment ofan
overriding royalty inteest shall not relieve Lessee of any of its obligations for payment of royalties to Lessor as
provided by ROYALTY paragraph herein.
11. OFFSET WELLS - Lessee agrees to protect the leased land from drainage by offset wells located on
adjoining lands not owned by Lessor, when such drainage is not compensated for by counter -drainage. It shall be
presumed that the production of oil and gas from offset wells results in drainage from the leased land, unless Lessee
demonstrates to Lessor's satisfaction by engineering, geological, or other data that production from such offset well
does not result in such drainage, or that the drilling of a well or wells on the leased land would not accomplish the
purposes of protectingthe deposits under the leased land. Lessor'sdecision as to the existence of such drainage shall
be final, and Lessee shall comply with Lessor's order thereon or surrender this lease as to any such undeveloped
acreage as designated by Lessor.
12. DEVELOPMENT - Upon discovery of oil and gas or either of them on the leased land Lessee shall
proceed with reasonable diligence to develop said land at a rate and to an extent commensurate with the economic
development of the field in which the leased land lies.
13. UNITIZATION - COMMUNITIZATION - In the event Lessor permits the land herein leased to be
included within a cornmunitiestionor unitization agreement, the terms of this lease may be deemed to be modified to
conform to such agreement. When only a portion of the land under this lease is committed by an agreement, Lessor
may segregate the land and issue a separate lease for each portion not committed thereunder, the term of such
separate lease shall be limited as to the original term of this lease. The terms of the lease on that portion remaining
in the unit shall be deemed to be modified to conform to such agreement. Nonproducing leases shall terminate on
the first anniversary date of the lease following the termination date of the unit or part thereof modifying the lease.
but in no evert prior to the end of the primaryte a of the lease or the extension tern of the lease.
14. DISPOSAL WELLS - No well on State land shall be used as a disposal or injection well without a
Disposal Well Lease approved by Lessor.
15. PRODUCTION - Lessee shall, subject to applicable laws, regulations and orders binding upon the
administration of state lands, operate and produce all wells upon the leased land so long as the same are capable of
producing in paying quantities, and shall operate the same so as to produce at a rate commensurate with the rate of
production of wells on adjoining lends within the same field and within the limits of good engineering practice.
except for such times as there exist neither market nor storage therefor, and except for such limitations on or
suspensions of production as may be approved m writing by Lessor. Lessee shall be responsible for adequate site
security on all producing properties.
16. SHUT-IN WELLS - If Lessee shall complete a well on the leased land productive of oil and/or gas and
Lessee is unable to produce such oil and/or gas due to a lack of suitable market therefor, Lessor may grant Lessee
suspension of his obligations to produce hereunder until a suitable market for such oil and/or gas can be found, and
during any such suspension period, it shall be deemed that oil and/or gas is being produced hereunder in paying
quantities. Except, however, that beginning on the anniversary date next, of the year of an extension of the lease by
reason of a shut-in well, Lessee shall pay to Lessor a shut-in royalty equal to S2 per acre of the lease per annum in
addition to the annual rental. The minimum amount of such shut-in royalty payment shall be S320. Each year's
shut-in royalty shall be forfeited to Lessor except for the shut-in royalty paid for the year during which the well
begins production. The maximum extension of the lease, due to the existence of a shut-in well, shall be 5 years
beyond the extension term as described in the EXTENSION paragraph herein. The granting of any further
extensions shall be at the sole option of Lessor.
17. OPERATIONS - No exploration, drilling or production operation, including permanent installations,
shall be within 200 feet of any existing building or other improvement, including water well or reservoir, without the
written permission of the owner of said improvements. Lessee shall keep a correct log of each well drilled
hereunder, showing by name or description the fermatieas passed through, the depth at which each fa:nation was
reached the number of feet of each she casing set in each well, where set, and the total depth of each well drilled.
Lessee, within 30 days after the completion or abandonment of any well drilled hereunder, shall file in the office of
Lessor a complete and correct log of such well, together with a copy of the electric log and the radioactivity log of
the well when such logs, or either of them, are run; and also a copy of all drill stem test results, core records and
analyses, record of perforations and initial production tests, if any. If any of the information required by this
paragraph is contained in reports required to be filed with the Oil and Gas Conservation Commission of Colorado,
the requirements of this paragraph for such information may be satisfied by such filing with said Commission,
except for copies of the repots as are required by the following paragraph, and provided that all such information is
immediately available to Lessor. Any proprietary information so submitted shall not be subject to public inspection
onderColorado law.
Page 4 of 6
gyillosttaliggint
� is{�r�i� Duily, CO
5 of 0 R 31.00 0 0.00 Stove Moreno Clerk dr Remitter
Lessee shall bury pipelines below plow depth. Lessee shall set and cement sufficient surface casing to
protect the fresh water wells of the area.
18. NOTIFICATION - Lessee shall notify Lessor and the surface lessee or surface owner of the location of
each drill site at least two weeks prior to commencing drilling operations thereon. Lessee shall notify Lessor before
commencing to plug and abandon any well by copy of Lessee's request for approval or sundry notice of intent to plug
and abandon.
19. BONDS - Lessee shall be liable for all damages to the surface of the land, livestock, growing crops,
water wells, reservoirs, or improvements caused by Lessee's operations on said land. No operations shall be
commenced on the land hereinabove described unless and until Lessee shall have filed a good and sufficient bond
with Lessor, in an amount to be fixed by Lessor, to secure the payment for such damages as may be caused by
Lessee's operations on said land and to assure compliance with all the terms and provisions of this lease, the laws of
the State of Colorado, and the rules and regutationsthereto appertaining. A bond maybe held in effect for the life of
production of any well.
20. SETTLEMENT - Lessee shall not remove any machinery, equipment or fixtures placed on said land,
other than drilling equipment, nor draw the casing from any well unless and until all payments and obligations
currently due Lessor under the terns of this lease shall have been paid or satisfied. My machinery, equipment or
fixtures left on this land fora period of more than 6 months after the expiration hereof, shall automatically become
the property of Lessor.
21. OTHER DISCOVERY - Should Lessee discover any valuable products other than oil and gas, on or
within the leased land, Lessee shall within 7 days report such discovery to Lessor, in which event Lessee and Lessor
may negotiate a provision for production of such discovery.
22. WATER - This lease does not grant pemtission, express or implied, to Lessee for water exploration,
drilling or establishing water wells without written permission of the surface owner and other required state permits.
If Lessee desires to establisher adjudicate any water right for beneficial use on the leased land in direct relationship
to lease operations this adjudication or application shall be in the name of Lessor if lessor is the surface owner.
Water for use off the lease may only be used with permission of the surface owner and a charge maybe imposed for
this use.
23. DEFAULT - Upon failure or defauit of Lessee to comply with any of the terms and provisions hereof,
including but not limited to the failure to comply with laws, rules and regulations governing Colorado oil and gas
operations and including Lessor's policy now or hereafter in force relative to this lease, provided that no policy made
after the execution of this lease affecting either the length of the term hereof, the rate of royalty, or payment
hereunder, or the assignment hereof, shall operate to alter the terms and conditions of this lease, Lessor is hereby
authorized upon notice and hearing, as hereinafter provided, to cancel this lease as to all of the leased land so
'claimed ors possessed by Lessee hereunder. In the event of any such default or failure, Lessor shall, before making
any such' cancellation, send to Lessee by certified mail, to the post office address of said lessee as shown by the
records bf Lessor, a notice of intention to cancel for such failure or default, specifyingthe same, stating that if within
30 days froth the date of mailing said notice, Lessee shall correct such failure or default to the satisfaction of Lessor,
no cancellation will be made. If such failure or default is not corrected within 30 days after the mailing of such
notice, and if Lessee does not request a hearing on such notice within 30 days, this lease will terminate and be
cancelled by operation of this paragraph without further action by Lessor, or further notice to Lessee.
24. EXTENSION - If, at the expiration of the primary term of this lease, production of oil or gas has not
been obtained on the leased premises but drilling operations are being conducted thereon in good faith and in a good
and workmanlike manner, Lessee may, on or before the expiration of the primary term, make written application to
Lessor for an extension of this lease fora term equal to one year. Such application must be accompanied by a
payment of $10 per acre or portion thereof. This lease shall not be extended for more than one year past the primary
term unless production in paying quantities has been obtained or unless extended by some other provision hereof.
25. HOLD HARMLESS - Lessee shall indemnify Lessor against all liability and loss, and against all claims
and actions, including the defense of such claims or actions, based upon or arising out of damage or injury, including
death, to persons or property caused by or sustained in connection with operations on this leased land or by
conditions created thereby, or based upon any violation of any statute, ord inane, or regulation.
26. CONDEMNATION -lf the leased lam! olotl lie t^' st in any condemnation procegding,tltis lease shall
automatically terminate as of the date of taking. 7 I • nrd lin such condemnation shall bt`{ta tl'f6 Istssbc, except
for any specific award(s) paid to Lessee for severed d r:rs reserves, in which event a ttert:edtoge osrioIs specific
awards equal to royalty as specified under Item 2 (Rs, alty)shall be paid to Lessor in lieu of ioyalty lost by
Page 5 of 6
IIl�ttttlliltllttllltNttlItttlltlllll�I � -
3124155 11/0612003 09:45A Weld Courtly. CD
Oct 6 R 31.00 D 0.00 Steve Moreno Clerk d Recorder
virtue of the condemnation. lmprovementsshall be removed by Lessee perr terms in the SETTLEMENT paragraph
herein. If only a portion of the leased land is taken by condemnation, Lessee may, at its option, terminate this lease
or terminate only that portion of the lease so taken.
27. ERRORS- Every effort is made by Lessor to avoid errors in all procedures including butnot limited to
auction listings and lease preparation. Lessor shall not be liable for any inconvenience or loss caused by errors
which may occur. Lessee shall notify Lessor immediately upon discovery of any errors or discrepancy whatever.
28. ARCHAEOLOGY- Lessee shall not destroy, disturb, mar, collect, remove or alter any prehistoric or
historic resources of any kind on state lands as provided by law. These resources include but are not limited to all
artifacts of stone, wood or metal, pictographs, structures, and bones. A discovery of anything of prehistoric or
historic nature shall be reportedto Lessor or the State Archacologistimmediately.
29. DEFINITIONS -
A. "Gas" as used herein shall mean all gases (combustible and noncombustible), including but not
limited to all gaseous hydrocarbons, gaseous compounds, carbon dioxide, and helium.
B. "Oil and gas" as used herein shall include all substances produced as: by-products therewith,
includingbut not limitedte sulfur.
C. "Paying quantities" as used herein shall mean and refer to quantities of oil and gas or of either of
them sufficient to return to Lessor an amount_ equal to the shut-in royalty.
30. TAXES - Lessee shall pay all property taxes, or payments in lieu of taxes, lawfully assessed for the
leased premises or improvements thereon.
3]. HEIRS AND ASSIGNS The benefits and obligations of this lease shall inure to and be binding upon
the heirs, legal representatives, successors or assigns of Lessee; but no sublease or assignment hereof, or of any
interest herein, shall be binding upon Lessor until the same has been approved by Lessor as explained in the
ASSIGNMENTS paragraph provided.
32. IN WITNESS WHEREOF, Lessor has hereunto signed and caused its name to he signed by the STATE
BOARD OF LAND COMMISSIONERS, with the seal of the office affixed, and Lessee has ei . , ,,; cement,
the day and year first above written.
Recommended:
Mark W. Davis, MineralsDirector
ATTEST
State of COLORADO
County of WILD
The foregoing instrumentcvas acknowledgedbefore me this 2ND day of APRIL 2003 by
Tt5O0AS B 00000 as being authorized to execute same.
ST s TE BOARD OF LAND
Diane
C tnstoy ` `rJ. Cast lian, Division
LESSEE
CFt //F. if c y,/�Nffe3 .
byy I/l-r0 0,
SFal or Authority
. C,11 4`.4*.
Notary Public
My Commission Expires v7aa3
Page 6of6
3UTam Crete
]3F5 FmnticrRl)
Gresfcy,CO5s 0
43?
RECORDING REQUESTED BY
& WHEN RECORDED MAIL TO:
BONANZA CREEK OPERATING COMPANY, LLC
4900 CALIFORNIAAVE, SUITE 3508
BAKERSFIELD, CA 93309
IIIIIIIIIIIIIIIIIlIIIlIIIIf'1'411 V1!IIffI 111 11113318437 1111
CO
1 of 22 08/31/2005
111p 001 iMereno County,
Recorder
ASSIGNMENT, BILL OF SALE AND CONVEYANCE
THIS ASSIGNMENT, BILL OF SALE AND CONVEYANCE ("Assignment") is
dated effective July 1, 2005, andis made from CFG Energy, Inc. ("CFG'), a Colorado
corporation whose address is 3932 West 18th Street Lane, Greeley, Colorado 80634; Thomas B.
Croke, HE, and Laura L. Croke, husband and wife, whose address is also 3932 West 18th Street
Lane Greeley, Colorado 80634; RAAM Production, LLC, a Colorado limited liability company,
P.O. Box 269, Sterling, Colorado 80751; Ronald E. Yetter and Tonle E. Yetter, husband and
wife, 20037 Highway 52, Fort Morgan, Colorado 80701; and Albert E. Yetter, 1020 Seventh
Avenue; Sidney, Nebraska 69162 (collectively, the "Assignors") to Bonanza Creek Operating
Company, LLC ("Bonanza Creek"), a California limited liability company whose address is 4900
California Avenue, Suite 350-B, Bakersfield, California 93390, as Assignee.
For $100.00 and other good and valuable consideration, the receipt and sufficiency of
which are hereby acknowledged, the Assignors hereby sell, assign, transfer, grant, bargain and
convey all of their right, title and interest in and to the Assets to Bonanza Creek.
As used in this Assignment, the term "Assets" means the following real and personal
property interests:
the wells (the 'Wells") described in Exhibit A;
the oil and gas leases (the "Leases") listed in Exhibit B attached hereto, but only insofar
as they cover the lands (the "Lands") specifically described in Exhibit B;
the personal property and fixtures located on, in and under the Lands, including without
limitation the equipment shown in Exhibit C;
the surface owner agreements, operating agreements, marketingagreements, pooling
agreements, rights of way, easements, surface agreements, gas sale contracts, gas
processing contracts, and other contracts and agreements that benefit or burden the Wells,
Leases or Lands, including without limitation the particular agreements identified in
Exhibit D;
the oil, gas, casinghead gas, condensate, distillate, liquid hydrocarbons, gaseous
hydrocarbons, products refined and manufactured therefrom, and other minerals,
produced from the Wells and the accounts and proceeds from the sale of the foregoing
and
Assignment, Bi11 of Sale and Conveyance dated effective July 1.2005 between CFG Energy. Inc.. et al. Assignors and Bonanza Creek Operating
Company, LLC, Assignee.
6.0i+taio•000
.z
1)111111 11111 nin III Ili1I lo 1111 n Lei
08/31/2005 02:41P Wel. county, CO
2 of 22 R 111.00 D 0.00 Steve Moreno Clerk & Recorder
the files, records, seismic, seismic interpretation, electronic databases and seismic
licensing and other documentary information (the "Information") relating to the Leases
and Lands, but only to the extent that are in Assignors' possession and are not subject to
third party confidentiality restrictions.
Assignors hereby except and reserve an overriding royalty interest (subject to proportionate
reduction based both on .the percentage leasehold interest being assigned to Bonanza Creek and on
the percentage of the fee oil and gas estate covered by such Lease) on all oil, gas and other
hydrocarbon substances produced, saved and sold under the terms of each Lease equal to the
difference between 19% and all landowner royalties, overriding royalties and other burdens on
production that are of record at the date hereof. The overriding royalty interest in each particular
Lease is being reserved by each Assignor in the same manner and in the same proportion that it held
its undivided leasehold interest in such Lease immediately prior to this Assignment, so that i.f for
example, CFG owned a 50% leasehold interest in a Lease and Ronald E. Yetter and Tonic E. Yetter,
as joint tenants, owned the rernaining 50% interest, and if the other Assignors had no interest, then
the entire overriding royalty interest reserved hereby in. such Lease would be owned 50% by CFG
and 50% by Ronald E. Yetter and Tonle E. Yetter, as joint tenants. No reservaticm to a stranger is
intended. Overriding royalties due under this reservation in respect of production under a particular
Lease shall be determined and calculated (for example, but not by way of limitation, in respect of
value or proceeds and in. respect of permissible deductions) in the same manner as the landowner's
royalty under that same Lease. Finally, these reserved overriding royalties shall burden all renewals,
extensions, new leases and other similar arrangements in respect of a Lease that maybe obtained by
Bonanza Creek before the expiration of such Lease or within six months after expiration of such
Lease.
TO HAVE AND TO HOLD the Assets unto Bonanza Creek and its successors and
assigns forever.
This Assignment is made subject to the following terms and conditions:
A. This Assignment is being made pursuant to the termsofthe Purchase and Sale
Agreement dated as of July 1, 2005, among Assignors and Bonanza Creek (the "PSA").
B. ASSIGNORS WARRANT TITLE TO THE ASSETS FROM AND
AGAINST ALL PERSONS CLAIMING BY, THROUGH, AND UNDER ASSIGNORS
BUT NOT OTHERWISE. EXCEPT FOR THIS FOREGOING SPECIAL WARRANTY
OF TITLE, THE ASSIGNMENT IS MADE WITHOUT WARRANTY OF ANY KIND,
EXPRESS, IMPLIED OR STATUTORY.
C. ASSIGNORS EXPRESSLY DISCLAIM AND NEGATE ANY WARRANTY
AS TO THE CONDITION OF ANY PERSONAL PROPERTY, EQUIPMENT,
FIXTURES AND ITEMS OF MOVABLE PROPERTY COMPRISING ANY PART OF
THE ASSETS, INCLUDING (I) ANY IMPLIED OR EXPRESS WARRANTY OF
MERCHANTABILITY, (ii) ANY IMPLIED OR EXPRESS WARRANTY OF FITNESS
2
Assignment. BID of Sale anti Conveyance dated effective July 1, 2005 between CPO Energy, fne., et al, Assignors and Banana Creek Operating
Company, LLC, Assignee.
:A INI11111 Ni111111111111I1111 ll" IIII lilt
3318437 08(3112005 02:41P Weld County, CO
3 of 22 R 111.00 D 0.00 Steve Moreno Clerk 8t Recorder
FORA PARTICULAR PURPOSE, (iii) ANY IMPLIED OR EXPRESS WARRANTY OF
CONFORMITY TO MODELS OR SAMPLES OF MATERIALS, (iv) ANY RIGHTS OF
BONANZA CREEK UNDER APPLICABLE STATUTES TO CLAIM DIMINUTION OF
CONSIDERATION, AND (v) ANY CLAIM BY BONANZA CREEK FOR DAMAGES
BECAUSE OF DEFECTS, WHETHER KNOWN OR UNKNOWN. BONANZA CREEK
ACKNOWLEDGES THAT SAID PERSONAL PROPERTY, FIXTURES, EQUIPMENT
AND ITEMS ARE BEING CONVEYED TO IT "AS IS, WHERE IS," WITH ALL
FAULTS AND IN THEIR PRESENT CONDITION AND STATE OF REPAIR
D. To -the extent permitted by law, Bonanza Creek shall be subrogated to Assignors'
rights in and to representations, warranties and covenants given with respect to the Assets.
Assignors hereby grant and transfer to Bonanza Creek, its successors and assigns, to the extent so
transferable and permitted by law, the benefit of and the right to enforce the covenants,
representations and warranties, if any, which Assignors maybe entitled to enforce with respect to
the Assets.
E. The PSA contains an indemnification by Bonanza Creek for the benefit of
Assignors and an indemnification by Assignors for the benefit of Bonanza Creek, which
indemnifications are incorporated herein and which shall survive execution and delivery of this
Assignment
F. Separate governmental form assignments -of the Assets maybe executed on
officially approved forms by the Assignors to Bonanza Creek, in sufficient counterparts to satisfy
applicable statutory and regulatory requirements. Those assignments shall be deemed to contain
all of the exceptions, reservations, warranties, rights, titles, power and privileges set forth herein
as fully as though they were set forth in each such assignment. The interests conveyed by such
separate assignments are the same, and not in addition -to, the Assets conveyed herein.
G. This Assignment binds and inures to the benefit of Assignors and Bonanza Creek,
together with their respective successors and assigns.
IN WITNESS. WBEREOF, the parties have executed this Assignment, Bill of Sale and
Conveyance as of the date first set forth above.
ASSIGNORS:
ASSIGNEE:
CFG ENERGY, INC. BONANZA CREEK OPERATING
COMPANY, LLC •
B A /1 IL.. .s. By:y: ;�Thomas B. Croke, Ili, President ]Vfichael R. tarzer, President
3
Assignment, sill of Side and Carver= dated effective July I, 2005between CFO iasetgy, Inc., et al, Assignors and Bonanza Creek Opetatmg
Company, LLC, Assignee.
111l1I1III1JIIIIIIIII1II Bl IIIIIII IIII l�I IIII
31/2005 02:41P Weld Cot , CL
4 of 22 R 111.00 D 0.00 Steve Moreno Clerk & Recorder
/
Thomas B. Croke, III, individually
RAAM PRODUCTION, LLC
Ronald E. Yetter, Mpeager
Ronald E. Yetter, in " dually
Tonle E. Yetter, individv
Albert E. Yetter, indi ldually
L. Croke, in vidually
STATE OF COLORADO )
)ss.
COUNTY OF WELD )
The foregoing instrument was acknowledged before me thisa .day of August, 2005, by
Thomas B. Croke, III, both individually and as President of CFG En gy, Inc., a Colorado
corporation, and also by Laura L. Croke, individually.
My commission expires:
Witness my hand and official seal.
Notary Public
4
Assignment, Belt of Sale and Conveyance dated effective July 1, 2005 between CFG Energy, Inc., et al, .Assignors and Bonanza Creek Operas.
Canpany. LLC, Assignee.
f. 11 11111111111111111111III Ills 111 C:;I 11111111
3318437 08/31/2005 02:41P Weld County, CO
5 of .22 R 111.00 0 0.00 Steve Moreno Clerk & Recorder
STATE OF COLORADO )
) ss
COUNTY OF /IIJIJ)
The foregoing instrument was acknowledged before me this .31 day of August , 2005,
by Ronald E. Yetter, individually and as Manager of RAAM Production, LLC, a Colorado
limited liability ccanpany, and also by Tonne E. Yetter, individually.
Witness my hand and official seal.
My commission expires: it- /c -
STATE OF COLORADO )
) ss.
COUNTY OF aLd
)
The foregoing instrument was ac;: t' ged before me this ...... day of August, 2005, by
Albert E. Yetter.
My commission expires: `1-%
State of California
County of Kern
se'µ •. ••- ��
DARELLA L
BL0CH .o
Public
On 4by t..6, 29 2005 before me, 1. . , Notary Public,
personal ppeared . , personally known to ale • —O —
riavC tl tv arc on the basis of catisfaetoryy evideaoe io be the personle)'whose name(,sr) islanrsubscribed to
the within instrument and acknowledge to me that heishel4herexecuted the same in hisihen'diei authorized
capacity000, and that by hissfren4heirsignature on the instrument the persons or the entity upon
fehalf of which the oesso kt aacted, red the instalment.
MONICA L WARD-KLL.ER
Commtsalon g 1514772
NoblyCalifornia is S my d and official seal.
Kam County
comm,r�aoa2o.zoos
My
My commission expires: . z0,Cob Notary Public
5
Assignment. BM of Sale and Conveyance dated effective July 1.2005 between CFG Energy, lac., et al, Assignors and Bonanza Creek Operating
Company. LLC, Assignee.
• I1JIIIiI1RiIII.iJIIjii IIIIIII 1 11ICioi
3318437 01/3112005 02:41P Weld County, CO
6 of 22 0 111.00 0 0.00 Steve Moreno Clerk & Recorder
Exhibit "A"
Attached to and made a part of that certain Assignment, Bill of Sale and
Conveyance dated effective Jnly 1, 2005 between CFG Energy, Inc., Thomas
B. Croke, III and Laura L. Croke, RAAM Production, LLC, Ronald E.
Yetter and Tonle E. Yetter, and Albert E. Yetter, Assignors and Bonanza
Creek Operating Company, LLC, Assignee.
WELLS
North Riverside Project (Developed)
Weld County, Colorado
Well I API Field
Location
WI
NRI
MGF Williams 8-1
05-123-
10129
North
Riverside
NESW S8 T5N
R61W
1.00000
0.77500
Pronghorn 14-4
05-123-
22430
North
Riverside
SWSW S4 T5N
R61W
1.00000
0.81000
Pronghorn 32-8
05-123-
22052
North
Riverside
SWNE S8 T5N
R61W
• 1.00000
0.76250
Pronghorn 12-9
05-123-
22050
North
Riverside
SWNW S9 TSN
R61W
1.00000
0.81000
Weld County 22-15
05-123-
19630
North
Riverside
SENW S15 TSN
R61W
1.00000
0.81000
Pronghorn 41-16
05-123-
22768
North
Riverside
NENE S16 TSN
R61W
1.00000
0.81000
Pronghorn 31-17
05-123-
22765
North
Riverside
NWNE S17 T5N
R61W
1.00000
0:81000
Pronghorn 11-17
05-123-
22547
North
Riverside
NWNW S17 TSN
R61W.
1.00000
0.81000
6
Assignment, Bill of Sale and Conveyance dated effective July 1, 2005 between CFO Energy, Inc., et al. Assignors and Bonanza Creek Operating
Company, LLC, Assignee.
1.IIIiJ'IIIIIIIIIIillII IIIIIII III IIIIIII ►;MITI leal 1111
3318437 7 of � 08/3112,..
11100 D 0 001 Steve,Morreno Clerk & Recorder
Exhibit "B"
Attached to and made a part of that certain Assignment, Bill of Sale and
Conveyance dated effective July 1, 2005 between CFG Energy, Inc., Thomas
B. Croke, III and Laura L. Croke, RAAM Production, LLC, Ronald E.
Yetter and Tonic E. Yetter, and Albert E. Yetter, Assignors and Bonanza
Creek Operating Company, LLC, Assignee.
The Lands
North Riverside Project (Developed)
Weld County, Colorado
Spot Section Township Range WI NRI
W/2 3 5N 61W 1.00000 0.81000
W/2 10 SN 61W 1.00000 0.81000
W/2 15 SN 61W 1.00000 0.81000
All 4 SN 61W 1.00000 0.81000
All 5 5N 61W 1.00000 0.81000
All 6 SN 61W 1.00000 0.81000
All 7 5N 61W 1.00000 0.81000
All 9 SN 61W 1.00000 0.81000
All 16 5N 61W 1.00600 0.81000
All 17 5N 61W 1.00000 0.81000
All 18 SN 61W 1.00000 • 0.81000
SW/4 8 SN 61W 1.00000 0.76250
NE/4 8 SN 61W 1.00000 0.76250
7
Assignment, BM of Sale and Conveyance dated effective July 1, 2005 between CFO Energy, Inc., et al, Assignors and BacemaCreek Operating
Company, LLC. Assignee.
Lessor
Nancy Ann Blotter, a married
woman dealing in tier sole and
separate property
Lessee
CFG Energy, Inc.
Dean N. Davis and CFG Energy, Inc.
Lillian E. Davis, husband and wife
Mary Evelyn Davis, a widow CFG Energy, Inc.
Patricia Sue Fickes and CFG Energy, Inc.
John Robert Fickes, Wife and husband
Alice M. Flanagan, formerly
known as Alice M. Mandelko and
Donald J. Flanagan, her husband
CFG Energy, Inc.
George Richard Foreman and CFG Energy, Inc.
Jessie M. Foreman, husband and wife
James R. Harrison and CFG Energy, Inc.
Janice A. Harrison, husband and wife
Vicky L. Higginbotham, CFG Energy, Inc.
Attorney -in -Fact for,
Frances Irene Sublett
H. Loraine Mandelko, CFG Energy, Inc.
a single woman
Recording
Date
Rec. No. Description
o .a..
11/19/2004 3236991 Township 5 North, Range 61 West, 6"' P.M. s
Section 3: W1/2
t.ts
10/15/2004 3227722 Township 5 North. Range 61 West. 6"' P.M.
Section 3: W1/2 5 =—
11/19/2004 3236992 Towgghip 5 North. Range 61 West 6° P.M.
Section 3: W1/2 pa at.
10/15/2004 3227/21 Township 5 North. Range 61 West. 6'" P.M. a.
Section 3: W1/2 9
10/15/2004 3227123 Township 5 North. Ranee 61 West. 6° P.M.
Section 3: W1/2
11/19/2004 3236993 Township 5 North. Range 61 West. 6"' P.M.
Section 3: W1/2
01/14/2005 32p018
11/19/2004 3236994 Township 5 North. Range 61 West. 6"' P.M,
Section 3: W1/2
e6
Section 3: W1/2
01/14/2004 3293017 Township 5 North. Range 61 West. 6' P.M.
Section 3: W1/2
8
Assignment, Bill of Sale and Conveyance dated effective July I, 2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
Penny Lee Reid, a married woman
dealing in her sole and separate
property
Ann E. Armit as Custodian
for Jolm E. Armit u/cutma
Ann E. Annit as Custodian
for Julia Ann Armit u/cutma
James Foster and Karen Foster,
husband and wife •
Jolm Foster and Sylvia Foster,
his wife
Norman A. Foster and
Dean F. Foster
Robert P. Foster mid
Treys Foster his wife
Dennis W. Grotheer and
Debra A. Grotheer, CO -Trustees
of the Dennis W. Grotheer
Living Trust
K. S. Properties, LLC
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc
CFG Energy, Inc.
CFG Energy, Inc.
•
11/19/2004 3236990 Township 5 North. Range 61 West. 6d' P.M. •
Section 3: W1/2
11/05/2003 3124100 Township 5 North. Range 61 West, 6'h P.M.
Section 4: W1/2NW1/4, 1/4, NE1/4
Section 5: Lot 1 (39.44), SE1/4NEl/4
11/05/2003 3124099 Township 5 North. Range 61 West. 6" P.M.
Section 4: W1/2NW1/4, NE1/4
Section 5: Lot 1(39.44), SE1/4NE1/4
11/05/2003 3124093 Township 5 North. Range 61 West. 6'h P.M.
Section 4: SE1/4
11/05/2003 3124097 Township 5 North. Range 61 West. el P.M.
Section 4: SE1/4
03/08/2004 3160053 Township 5 North. Range 61 West. 6* P&L .
Section 4: SE1/4
j
ee s
o e
ea
06/02/2005 3291075 Township 5 North. Range 61 West. 6`h P.M. =
Section 4: SEl/4
11/18/2003 3127857 Township 5 North. Range 61 West. 6" P.M. --!,',A=.;;
Section4: W1/2SW1/4-
c
Section 9: E1/2
amm
e �
!rime
3' n
12/19/2003 3137006 Township 5 North. Range 61 West. 6W 1 P.M. g aa_
gam=
o aaa�
moots
R
9 &u-
p:
a
Section 4: SEl/4
Assignment, Bill or Sale and Conveyance dated effective July 1.2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, I.tC, Assignee.
Alvin L. Sall and Marilyn A. Sall,
husband and wife
Brenda Fay Sall, a single woman
Clarence Pierce Sall and
Doris Darlene Sall, husband and wife
Lillian II. Slolarczyk Smith,
a married woman dealing in her
sole and separate properly
Weld County, Colorado, a
political subdivision of the
State of Colorado, acting by
and through the Board of County
Commissioners of the County of
Weld, for its respective interests,
c/o Board of County Commissioners
Lloyd Linnebur acid
Shirley A. Linnebur
husband and wife
Ruth Cabelka a married woman
dealing in her sole and separate
property
CFO Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFO Energy, Inc.
CFO Energy, Inc.
CFO Energy, Inc.
CFO Energy, Inc.
08/11/2003 3093790 Township 5 North, Range 61 West. 6"IP.M. cc, -v_,
Section 4: SE1/4
11/05/2003 3124095 Township 5 North. Range 61 West, 6° P.M. M =
Section 4: SE1/4 •• �" Ems
MN
j.2"
11/05/2003 3124096 Township 5 North. Range 61 West. 6s' P.M. g g!
Section4: SE1/4 p1•
11/05/2003 3124094 Township 5 North. Range 61 West, 6° P.M. o
Section 4: SE1/4 en
1
3"�
01/12/2004 3143332 Township 5 North. Range 61 West, 6tb P.M. a
Section 4: Lot 3 and SE1/4NW 1/4; o
El/2SW1/4
mom®
Ae
03/03/2004 3158466 Township 5 North. Range 61 West. 6d' P.M.
Section 5: Lots 1(39.44), 2 (39.45),
3 (39.49), and 4 (39.52), S1/21,11/2,
S1/2
Section 6: SE1/4SW1/4, SW1/4SE1/4,
NEl/4SW1/4, NW1/43E1/4,
El/2SE1/4
Section 7: Lots 3 (39.51), 4 (39.57),
E1/2W1/2, 01/2
11/05/2003 3124101 Towns p 5 North. Range 61 West. 6° P.M.
Section 5: Lots 2 (39.45), SW1/4NE1/4
W1/2SE1/4
10
Assignment, Bill orSale and Conveyance dated effective July l , 2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
•a partnership
Thomas Marvin Thompson, CFG Energy, Inc.
a single man
The American National Red Cross CFG Energy, Inc.
Joan Brodie, a widow CFG Energy, Inc.
Elmer Willis Ealey CFG Energy, Inc.
Ism
McGhee Investment Company, CFO Energy, Inc. 06/30/2003 3078350 Township 5 North, Range 61 West, 6'h P.M. oa,,
Section 5: Lots 1(39.42), 2 (39.45),
3 (39.49), 4 (39.52), S1/2N1/2,
S1/2
Section 6: SE1/4SW1/4, SW1/4SE1/4,
EI/2SEI/4
Section 7: Lots 3 (39.51), 4 (39.57),
E1/2W1/2, E1/2
Section 17: W1/2, SE1/4 •
Section 18: Lots 1(39.62), 2 (39.62),
3 (39.72), 4 (39.78), E1/2W1/2,
E1/2
a
11/05/2003 3124102 Township 5 North. Range 61 West. 6a' P.M. •
Section 5: Lot 2 (39.45), SW 1/4NE1/4,
W1/2SE1/4 •
03/08/2004 3160051 Township 5 North, Range 61 West. 6a' P.M.
Section 6: Lots 3 (39.83), 4 (39.16),
5 (39.26), 6 (39.30), 7 (39.34),
SEl/4NW1/4
Section 7: Lots 1(39.39), 2 (39.16)
11/05/2003 3124103 Township 5 North. Range 61 West. 6° P.M.
Section 6: Lots 3 (39.83), 4 (39.16),
5 (39.26), 6 (39.30), 7 (39.34),
SE1/4NW1/4
Section 7: Lots 1 (39.39), 2 (39.16)
04/22/2004 3172711 Township 5 North. Range 61 West. 6s' P.M.
Section 6: SE1/4SW1/4, SW1/4SE1/4
Section 7: NE1/4NW1/4, NE1/4,
11
Assignment, Dili of Sale and Conveyance dated effective July 1, 2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
SEl/4NW 1/4
Gina M. Janak and
David W. Janak,
wife and husband
CFG Energy, Inc.
Gene F. Keyser Jones, CFG Energy, Inc.
as Agent and Attorney -in -Fact
for the Funkhouser Family
Partnership
G. N. Rupe CFO Energy, Inc.
Joann L. Eisenbrandt CFG Energy, inc.
Gene F. Keyser Jones, as Agent CFG Energy, Inc.
and Attomey-In Fact for the
Funkhouser Fatuity Partnership
Theron Vannest, a single man CFG Energy, Inc.
08/22/2003 3098923 Township 5 North. Range 61 West. 6° P.M.
Section 6: Lots 3 (39.83), 4 (39.16),
5 (39.26), 6 (39.30), 7 (39.34),
SE1/4NW1/4
Section 7: Lots 1 (39.39), 2 (39.45)
o
02/17/2005 3261726 Township 5 North. Range 61 West. 6° P.M, $ P
Section 6: Lots 3 (39.83), 4 (39.16),
5 (39.26), 6 (39.30), O pi
7 (39.34), SE1/4NW1/4 0-
06/02/2004 3185887 Township 5 North. Mange 61 West. 6'h P.M Its
• Section 6: Lots 3 (39.83), 4 (39.16),
5 (39.26), 6 (39.30), 7 (39.34), o
SEI/4NW1/4
Section 7: Lots 1(39.39), 2 (39.16) o»
11/18/2003 3127856 Township 5 North,Range 61 West. 6d' P.m a =
Section 7: Lots 3 (39.51), 4 (39.57), ttttttt�
E1/2SW 1/4, SE1/4, also described g
a.
as the entire S1/2
03/08/2004 3160049 Township 5 North, Range 61 West. 6° P.M.
Section 7: Lots 1(39.39), 2 (39.16)
02/07/2005 3259230 Township 5 North, Range 61 West, 6° P.M.
Section 7: NE1/4, E1/2NW1/4
12
Assignment, Bill of Sale and Conveyance dated effective July I , 2005 between CFG Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
The Salvation Army National
Corporation
CFG Energy, Inc.
Nancy Ann Blotter, a married CFG Energy, Inc.
woman dealing in her sole and
separate property
Dean N. Davis
Mary Evalyn Davis, a widow
Patricia Sue Fickes
Alice M. Flanagan,
formerly Alice M. Mandelko
George Richard Foreman
James R. Harrison and
Janice A. Harrison,
husband and wife
H. Loraine Mandelko
CFG Energy, Inc.
CFG Energy, inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
03/08/2004 3160050 Township 5 North, Range 61 West. 6° P.M. i°
Section 6: Lots 3 (39.83), 4 (39.16);
5 (39.26), 6 (39.30), 7 (39.34),
SE1/4NW1/4
Section 7: Lots 1 (39.39), 2 (39.16)
' 03/08/2004 3160054 Township 5 North. Range 61 West. 6'" P.M,
Section 9: SWI/4
Section 10: W/2 0{
10/21/2003 3119293 Tovoship 5 North. Range 61 West, 6'" P.M. M
Section 9: SW 1/4
Section 10: W/2
10/28/2003 3121340
11/03/2003 3123152
11/06/2003 3124260,
5.2
Section 10: W/2 �'�
a� asss�
11/18/2003 3127855 T4}lpaship�5 North. Range 61 West. 6'" P.M g
Section 9: SW1/4 • a
. Section 10: W/2
TQ}laship 5 North. Range 61 West, 6° P.M. tfi'4°11-
Section 9: SW 1/4 v
MINIM
Section 10: W/2 or.
Township 5 North. Range 61 West. 6° P.M. * =
Section 9: SW1/4 =N""
Section 10: W/2 1 �a
Township 5 North. Range 61 West. 6th P.M
Section 9: SW1/4
03/08/2004 3160052 Township 5 North. Range 61 West. 6a' P.M.
Section 9: SW1/4
Section 10: W/2
12/08/2003 3133382 Township 5 North. Range 61 West. 6° P.M.
Section 9: SW 1/4
13
Assigment, Bill of Sale and Conveyance dated effective July t, 2005 between CFO Energy, Inc„ et al. Assignors and Bonanza Creek Operating Company, U C, Assignee.
Penny Lee Reed, a married CFG Energy, Inc.
woman dealing in her sole and
separate property
Frances Irene Sublett CFG Energy, Inc.
Weld County, Colorado, a CFG Energy, Inc.
political subdivision of the
State of Colorado, acting by
and through the Board of County
Commissioners of the County of
Weld, for its respective interests,
c/a Board of County Commissioners
Nancy Lee Aston, a widow CFG Energy, Inc.
James W. Heckman, a single man CFG Energy, Inc.
Robert S. McLandress, a married CFG Energy, Inc.
man dealing in his sole and separate
property
Katherine S. Shannon, a widow CFG Energy, Inc.
Weld County, Colorado
Section 10: W/2
nIza
04/22/2004 3172710 Township 5 North. Range 61 West. 6th P.M. 81 1
Section 9: SW 1/4 c7
Section 10: W/2
10/28/2003 3121341 Township 5 North, Range 61 West. 6°i P.M. if "4 Section 9: SW1/4
Section 10: W/2 0 e
01/06/2004 3141448 ' Township 5 North. Range 61 West, 6° P.M.
Section 9: NW 1/4
a•
11/05/2003 3124098 Township 5 North. Range 61 West. 6°i P.M.
Section 10: Wl/2
11/05/2003 3124105 Township 5 North Range 61 West, 6°i P.M.
Section 10: W1/2
11/05/2003 3124106 Township 5 North. Range 61 West. 6th P.M.
Section 10: W1/2
11/05/2003 3124104 Township 5 North. Range 61 West. 6th P.M. •
Section 10: W1/2
El Camino Resources/ 08/18/2003 3096555 Township S North. Range 61 West, 6"IP.M.
Raymond A. Tonella Section 15: NW/4
14
rms
J
Assignment, Hill or Sale and Conveyance dated effective July 1, 2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating.Company, LLC, Assignee.
Geo. A. Henderson Co., a
Colorado Corporation
Wells Fargo Bank, N.A.,
as Successor Trustee of the
Mildred H. Robbins Trust
FBO Nancy R. Schrader
Wells Fargo Bank, NA.,
as Successor Trustee of the
Mildred H. Robbins Trust
FBO Suzanne R. Oeklaus
Wells Fargo Bank, N.A.,
as Successor Trustee of the
Mildred H. Robbins Trust
FBO George H. Robbins
Wells Fargo Bank, N.A.,
as Successor Trustee of the
Mildred H. Robbins Trust
F13O Patricia Ann Robbins
Wells Fargo Bank, N.A.,
as Successor' Trustee of the
Mildred H. Robbins Trust
IMO Holden Erie Shannon
CFG Energy, Inc
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CFG Energy, Inc.
CPU Energy, Inc.
State of Colorado, acting by and CFG Energy, Inc.
through the State Board of
Land Commissioners (#7799.3)
Roy & Beverly Carlson & Co., CFG Energy, Inc.
a partnership
01/14/2005
03/28/2005
03/28/2005
03/28/2005
03/28/2005
03/28/2005
11/06/2003
06/04/2003
15
3253016
3271961
Township 5 NorthLRange 61 West, 6th P.M.
Section 15: SW1/4
Township 5 North, Range 61 West, 6th P.M.
Section 15: SW/4
3271962 Township 5 North, Range 61 West, 6th P.M.
Section 15: SW/4
3271963
3271964
3271965
3124155
3069522
r
Township 5 North, Range 61 West, 6th P.M;
o
Section 15: SW/4
Is
Township 5 North. Range 61 West, 6111 P.M.
Section 15: SW/4
Township 5 North, Range 61 West, 6th P.Mcn
a
Section 15: SW/4
Township 5 North. Range 61 West, 6th P.M.
Section 16: All
Township 5 North, Range 61 West, 6th' P.M.
Section 17: NE 1/4
Erne
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Assignment, Bill of sale and Conveyance dated effective July 1, 2005 between CFG Energy, inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
1 111111 11111 11111 1111111 III I�IIIII III IIIIII III IIII'•
County, CO
16 of 22 R 111.00 D 0.00 Steve Moreno Clerk &'Recorder
Wells Fargo Bank of Denver
of Denver Colorado, successor by
merger to United Bank of Denver,
Trustee under the Will of C.A.
Bresnahan
Carol L. Ritchie and
A. Scott Ritchie as Trustees
of the Carol L. Ritchie Revocable
Living Trust Under Ded of Tust
dated 3/31/92
James E. Thom, a single man
Velma R. Wallace, a single woman
The William E. Walker
Living Trust, William E. Walker,
Trustee
Nobelene Jay French,
a married woman dealing in
her sole and separate property
Robert H. Hamilton,
a married man dealing in
his sole and separate property
Thomas 13. Croke, Ili and
Laura L. Croke
Tom Croke, lll and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, III and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke,111 and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, III and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, III and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, 131 and
Laura L. Croke,
husband and wife, JTWROS
07/09/2004 3197220
08/19/2004 3210917
09/02/2004 3215087
08/02/2004 3204448
06/02/2004 3185888
08/19/2004 3210914
08/02/2004 3204449
16
Township 5 North. Range 61 West. 61e P.M. '
Section 3: Wl/2
Section 9: SW 1/4
Section 10: W/2
Township 5 North, Range 61 West, 6°i P.M.
Section 6: Lots 3 (39.83), 4 (39.16), 5 (39.26),
6 (39.30), 7 (39.34), SE1/4NW 1/4
Section 7: Lots 1 (39.39), 2 (39.16)
Township 5 North. Range 61 West, 66 PM,
Section 6: Lots 3 (39.83), 4 (39.16), 5 (39.26),
6 (39.30), 7 (39.34), SE1/4NW1/4
Section 7: Lots 1 (39.39), 2 (39.16)
Township 5 North. ' - ge 61 West: 6'" P.M.
Section 6: Lots ) (39.83), 4 (39.16), 5 (39.26),
6 (39.30), 7 (39.34), SE1/4NW 1/4
Section 7: Lots 1 (39.39), 2 (39.16)
Township 5 North. Rance 61 West. 6'a P.M.
Section 6: Lots 3 (39.83), 4 (39.16), 5 (39.26),
6 (39.30), 7 (39.34), SEl/4NW 1/4
Section 7: Lots 1 (39.39), 2 (39.16)
Township 5 North. Range 61 West. 6°i P.M.
Section 7: NE1/4, E1/2NW1/4
Township 5 North. Range 61 West. 6°i P.M.
Section 7: NE1/4, E1/2NW 1/4
Assignment, Bill of Sale and Conveyance dated effective July I, 2005 between CEO Energy, Inc., et al, Assignors and Bonanza Creek Operating Company, LLC, Assignee.
n3318437 um 11011111111111111111111111111111III1111111111111
17 oh 22 R 111.00 D 0.8131/2006 00P StteevedMoreno'Cterk dt Recorder
Josette Henry, a widow
Stanley Buford Henry and
Florence Henry, husband and wife
Patricia Louise Hocke,
a married woman dealing in her
sole and separate property
John Bob Johnson, a married
man dealing in Isis sole and
separate property
Shirley June Jolutson and
Roy K. Johnson, wife
and husband
David Dean Klingenberg and
Janice K. Klingenberg
husband and wife
Bonnie Jean Mascarenas,
a married woman dealing in
her sole and separate property
Sharon L. McGee and
Jansen M. McGee wife and husband
Laura Mix and Duane Mix
Tom Croke, lll and
Laura L. Croke,
husband and 'wife, JTWROS
Tom Croke, ill and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke,131 and
Laura L. Croke,
husband and wife, JTWROS
Tote Croke, III and
Laura L. Croke
husband and wife, JTWROS
Tom Croke, III and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, III and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, 111 and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke III and
Laura L. Croke, husband and
wife, JTWROS
Tom Croke 11I and
Laura L. Croke, husband and
wife, J1'WROS
08/02/2004 3204451 Township 5 North. Range 61 West. 6th P.M. •
Section 7: NE1/4, E1/2NW1/4
08/02/2004 3204452 Township 5 North. Range 61 West. 6"' P.M.
Section 7: NE1/4, E1/2NW1/4
08/02/2004 3204450 Township 5 North. Range 61 West. 6th P.M.
Section 7: NE1/4, E1/2NW1/4
10/15/2004 3227718 Township 5 North. Range 61 West. 6a' P.M.
Section 7: NE1/4, E1/2NW 1/4
09/02/2004 3215085 Township 5 North. Range 61 West. 6th P.M.
Section 7: NE1/4, E1/2NW1/4
08/19/2004 3210916 Township S North. Range 61 West. 6s' P.M,
Section 7: NE1/4, E1/2NW1/4
08/02/2004 3204447 Township. North. Ranee 61 West. 6th P.M,
Section 7: NE1/4, E1/2NW1/4
10/15/2004 3227720 Township 5 North. Range 61 West. 6t P.M.
Section 7: NE1/4, E1/2NW 1/4
10/15/2004 3227719 Township 5 North. Ranee 61 West. 6°i P.M.
Section 7: NE1/4, E1/2NW1/4
17
Assignment, Bill of Sale and Conveyance dated effective July I, 2005 between CFO Energy, Inc., et al, Assignors and Romans Creek Operating Company, LLC, Assignee.
Debbie Marie Phillips and
Jay Phillips
wife and husband
Donald Lee Wilhelm, Sr. and
Rose Anne Wilhelm
husband and wife
Guy Dean Wilhelm,
a single man
Phillip Wayne Hamilton and
Julie M. Hamilton
husband and wife
U.S. AgBank, FCB fka
Farrar Credit Bank of Wichita
Wichita, Kansas, a corporation
U.S. Agltank, FCB lka
Farm Credit Bank of Wichita
Wichita, Kansas, a corporation
U.S. AgBank, FCB fka
Farm Credit Bank of Wichita
Wichita, Kansas, a corporation
Ellen Rae Rubenstein, Era
Ellen Rae Bergreen, !Ica
Ellen Rae Dodge
Tom Croke, III and
. Laura L. Croke,
husband and wife, JTWROS
Tom Croke, Ill and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, Ill and
Laura L. Croke,
husband and wife, JTWROS
Tom Croke, Ill and
Laura L. Croke
husband and wife, JTWROS
Thomas B. Croke, III and
Laura L. Croke
Thomas B. Croke, Ill and
Laura.L. Croke
Thomas B. Croke, BI and
Laura L. Croke
Thomas B. Croke, III and
Laura L. Croke, as joint tenants
• 1111111111111111111111111111 Ili 111111111111011 III IIII
3318437 08/3112005 02:41P Weld County, CO
18 of 22 R 111.00 D 0.00 Steve Moreno Clerk & Recorder
09/02/2004 3215086 Township 5 North. Range 61 West. 6°i P.M.
Section 7: NE1/4, El/2NW1/4
08/19/2004 3210915 Township 5 North, Range 61 West, 6° P.M.
Section 7: NE1/4, E1/2NW1/4
08/02/2004 3204446 Township 5 North, Range 61 West. 6°i P.M.
Section 7: NEl/4, El/2NW1/4
02/07/2005 3259231 Township 5 North, Ranee 61 West, 6°i P.M.
Section 7: NEI/4, E1/2NW1/4
04/06/2004 3167983 Township 5 North. Range 61 West, 6° P.M.
Section 17: SW
04/06/2004 3167984 Township 5 North. Range 61 West. 6'" P.M.
Section 17: SE
04/06/2004 3167985 Township 5 North. Range 61 West, 6°i P.M.
Section 17: NW
05/25/2004 3183161 Township 5 North. Range 61 West, 6°i P.M.
Section 18: Lots 1(39.62), 2 (39.58),
3(39.12), 4 (39.78), SEl/4NE1/4,
SW 1/4NE1/4, NW 1/4SE1/4,
NE 1/4SW 1/4
18
Assignment, Bill of Sale and Conveyance dated effective July 1, 2005 between CFG Energy, Inc., et al, Assignor: and Bonanza Creek Operating Company, LLC, Assignee.
1.11111111111111111111111111111111111111 III 111111 Ill1111
3318437 0813112005 02:41P Weld County, CD
19 of 22 R 111.00 D 0.00 Steve Moreno Clerk & Recorder
Michael Campbell
Charles S. Williams and
Margaret Williams
CFG Energy, Inc. 08/17/2005 3313827 Township S North. Ranee 61 West. 6`h P.M,
Section 3: W1/2 •
Section 9: SW1/4
Section 10: W/2
Seaver Mesa 05/14/1976 1854504 Township 5 North, Range 61 West, 6* P.M.
Section 8: SW/4, NE/4
19
Assigmnent, Bill of Sale and Conveyance dated effective July 1, 2005 between CFO Energy, lnc., el al, Assignors and Bonanza Creek Operating Company, LLC. Assignee.
:be
Exhibit "C"
Attached to and made a part of that certain Assignment, Bill of Sale and
Conveyance dated effective July 1, 2005 between CFG Energy, Inc., Thomas
B. Croke, III and Laura L. Croke, RAAM Production, LLC, Ronald E.
Yetter and Tonie E. Yetter, and Albert E. Yetter, Assignors and Bonanza
Creek Operating Company, LLC, Assignee.
EOUIPMENT DESCRIPTION
North Riverside Project (Developed)
Weld County, Colorado
• 250 psi Vertical, 2 Phase Separator
■ 300 psi Horizontal, 3 Phase Separator
• 2 — 400 Bbls Tanks with Landing/Stairs
■ 2 — 300 Bbls Tanks with Landing/Stairs
• 6' x 20' Nelco 50 psi Heater-Treator
• 6' x 20' Nelco 50 psi Heater-Treator (Bad Bottom — subject to repair)
• @2,300' IPSCO I80, 4'h" Casing (New, retested to 6,500 psi)
• 2 —12'x15' — 300 bbl Steel Tanks (Nelco) — SN 228781 (50888) & 228881 (7678)
• 2 -12'x20' - 400 bbl Steel Tanks (Eaton Metal) — SN 0017 & 0036
20
Assignment. Bill of Sale and Conveyance dated effective July 1, 2005 between CFO Energy, Inc., et al, Assignors and Bonanza Creek Operating
Company, LLC, Assignee.
Exhibit "D"
Attached to and made a part of that certain Assignment, Bill of Sale and
Conveyance dated effective July 1, 2005 between CFG Energy, Inc., Thomas
B. Croke, III and Laura L. Croke, RAAM Production, LLC, Ronald E.
Yetter and Tonle E. Yetter, and Albert E. Yetter, Assignors and Bonanza
Creek Operating Company, LLC, Assignee.
74r
er'
Surface Agreements
� era r
_ CM
CONTRACTS
North Riverside Project (Developed)
. Weld County, Colorado
1) Grant of Road and Pipeline Easement dated July 13, 2005 between Dennis W. Grotheer,
as Trustee of the Dennis W. Grotheer Living Trust, Grantor and CFG Energy, Inc.,
Grantee, recorded July 13, 2005 #3302769, Weld County Records.
2) Surface Damage Agreement dated February 27, 2005 between Dennis W. Grotheer
Living Trust, Surface Owner and CFG Energy, Inc., recorded March 3, 2004 #3158465,
Weld County Records.
3) Surface Damage Agreement dated July 23, 2005 between Dewey K. Ankeney, also
known as Dewey Ankeny and Orlene M. Ankeney, also known as Orlene Ankeney,
Surface Owner and Thomas B. Croke III and Laura L. Croke, Operator, recorded August
19, 2004 #3210930, Weld County Records.
4) Surface Use Agreement dated February 26, 2004 between Lloyd Linnebur and Shirley A.
Linnebur and CFG Energy, Inc., recorded March 3, 2004 #3158468, Weld County
Records.
5) Surface Damage Agreement dated February 4, 2005 between Roy & Beverly Carlson &
Co., Surface Owner and CFG Energy, Inc., recorded February 7, 2005 #3259229, Weld
County Records. •
6) Surface Damage Agreement dated July22, 2005 between Dennis W. Grotheer Living
Trust, Surface Owner and CFG Energy, Inc., recorded July 22, 2005 #3305509, Weld
County Records.
Contracts
1) Frontier Contract No. P0506007 -CH dated June 23, 2005 between Frontier Oil and
Refining Company, Buyer and CFG Energy, Inc., Seller.
2) Duke Gas Purchase and Processing Agreement #WEL0317 dated , 2005
between Duke Energy Field Services, LP, Buyer/Processor and CFG Energy, Inc., Seller.
21
Assignment Bill of Sale and Conveyance dated effective July 1, 2005 between CFG Energy, Inc., et al. Assignors and Bonanza Creek opaaung
Company, U.C, Assignee.
.
•
� s m
°g Pooling Agreements
-'- mss
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m
- o
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� � T
�lr9N
N
1) Declaration of Pooling dated April 7, 2005 between CFG Energy, Inc., Albert E. Yetter,
RAAM Production, LLC, Ronald E. Yetter and Tonle E. Yetter, covering the S/2 SW/4
of Section 4, T -5N, R -61W, W, Weld County, and recorded April 11, 2005 #3276054, Weld
County Records.
22
i. its 1Tr
Assignment, Bill of Sale and Conveyance dated effective July 1, 2005 between CFG Energy, Inc., at al, Assiglom rld Banaozi'iteek Operating
Company, ILC, Assignee.
•
Amended Exhibit C
To BCEI Pronghorn OGDP Application
BEFORE THE ENERGY AND CARBON MANAGGEMENT COMMISSION
OF THE STATE OF COLORADO
IN THE MATTER OF THE APPLICATION OF BONANZA
CREEK ENERGY OPERATING COMPANY, LLC FOR AN
ORDER TO ESTABLISH SIX NEW DRILLING AND SPACING
UNITS, AMEND THREE EXISTING DRILLING AND
SPACING UNITS, AND ESTABLISH TWO NEW WELLBORE
SPACING UNITS FOR CERTAIN LANDS IN TOWNSHIP 5
NORTH, RANGE 61 WEST, 6T" P.M. AND TOWNSHIP 6
NORTH, RANGE 61 WEST, 6TH P.M., FOR THE
DEVELOPMENT OF 26 NEW HORIZONTAL WELLS FROM
FOUR AMENDED EXPANDED OIL AND GAS LOCATIONS
WITHIN AN APPROXIMATE 6,540 -ACRE "PRONGHORN"
OIL AND GAS DEVELOPMENT PLAN FOR THE NIOBRARA,
FORT HAYS, CODELL AND CARLILE FORMATIONS,
WATTENBERG FIELD, WELD COUNTY, COLORADO
CAUSE NO. 407
DOCKET NO. 211100228
TYPE: SPACING
FIFTH AMENDED APPLICATION
COMES NOW Bonanza Creek Energy Operating Company, LLC (Operator No. 8960)
("BCEI" or "Applicant"), a wholly owned subsidiary of Civitas Resources, Inc., by and through its
attorneys Jost Energy Law, P.C., respectfully submits this Application to the Colorado Energy and
Carbon Management Commission (the "Commission" or the "ECMC") for an order to establish six
new Drilling and Spacing Units (DSU), amend three existing DSUs, and establish two new
Wellbore Spacing Units (WSU), as described below, for the production of oil, gas and associated
hydrocarbons from the Niobrara, Fort Hays, Codell and Carlile Formations within the below -
described Application Lands. In support of its Application, Applicant states and alleges as follows:
1. Applicant is a limited liability company duly organized and authorized to conduct
business in the State of Colorado and is a registered operator in good standing with the
Commission.
2. Applicant is an "Owner" as defined by the Oil and Gas Conservation Act and ECMC
Rules, and owns leasehold interests or holds the right to operate on the following lands (hereafter
"Application Lands"), to be developed by the following amended expanded Oil and Gas Locations:
Pronghorn P-22 Pad: NE'/4NE% of Section 22, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #1 — 2 Wells:
Pronghorn T34-15-10XRLN
Pronghorn Y44-15-10XRLN
Township 5 North, Range 61 West, 6th P.M.
Section 10: E%
Section 15: EA
Page 1 of 24
Approximately 640 -acres.
DSU #2 — 2 Wells:
Pronghorn 31-34-22HN
Pronghorn 41-44-22HN
Township 5 North, Range 61 West, 6th P.M.
Section 22: EYz
Approximately 320 -acres.
DSU #3 — 2 Wells:
State Pronghorn E-15-10XRLN
Pronghorn 14-15-10XRLN
Township 5 North, Range 61 West, 6th P.M
Section 9: EIAEYZE/2
Section 10: W,4WYO
Section 15: W'/ZWY%
Section 16: E,4E%E'/z
Approximately 480 -acres.
WSU #1 - State Pronghorn Y-15-16XRLN Well:
Township 5 North, Range 61 West, 6th P.M.
Section 15: S'/%S'/%S'/z
Section 16: S'%S'%SY0
Section 21: N'%N14NY2
Section 22: NYON%NYz
Approximately 320 -acres.
Pronghorn T-4 Pad: SEIASEY4 of Section 4, Township 5 North, Range 61 West,
6th P.M., Weld County, Colorado:
Amended DSU #4 (Order Nos. 407-380 and 407-633) — 2 Additional Wells:
Pronghorn V-B-9HN
Pronghorn 42-12-9HN
Township 5 North, Range 61 West, 6th P.M.
Section 9: All
Approximately 640 -acres.
DSU #5 — 4 Wells:
Pronghorn Y44-4-33XRLN
Pronghom O34-4-33XRLN
Pronghorn O24-4-33XRLN
Pronghorn J-4-33XRLN
Page 2 of 24
Township 5 North, Range 61 West, 6th P.M.
Section 4: All
Township 6 North, Range 61 West, 6th P.M.
Section 33: All
Approximately 1,280 -acres.
Pronghorn P-10 Pad: NE'/NE' of Section 10, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #6 — 5 Wells:
Pronghorn 44-3-34XRLN
Pronghorn O34-3-34XRLN
Pronghorn O24-3-34XRLN
Pronghorn J-3-34XRLN
Pronghorn E14-3-33XRLN — to produce from the Pronghorn T-4 Pad
Township 5 North, Range 61 West, 6th P.M.
Section 3: All
Township 6 North, Range 61 West, 6th P.M.
Section 34: All
Approximately 1,280 -acres.
Pronghorn F-16 Pad: NWIANWIA of Section 16, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
Amended DSU #7 (Order No. 407-768) — 2 Additional Wells:
Pronghorn P31-T34-17HN
Pronghorn 41-44-17HN
Township 5 North, Range 61 West, 6th P.M.
Section 17: All
Approximately 640 -acres.
DSU #8 — 2 Wells:
Pronghorn 34-8-5XRLN
Pronghorn 44-8-5XRLN
Township 5 North, Range 61 West, 6th P.M.
Section 5: E)6
Section 8: E%
Approximately 640 -acres.
Amended DSU #9 (Order Nos. 407-380 and 407-633) — 3 Additional Wells:
State Pronghorn 21-24-16HN
State Pronghorn K-O-16HN
Page 3of24
State Pronghorn P-T-16HN
Township 5 North, Range 61 West, 6th P.M.
Section 16: All
Approximately 640 -acres.
WSU #2 — Pronghorn Y-8-5XRLN Well:
Township 5 North, Range 61 West, 6th P.M.
Section 4: W%W%W'/2
Section 5: EY2E14E'/2
Section 8: EYE'/2E'h
Section 9: W'A2W%W%2
Approximately 320 -acres.
Nearby Public Crossroads: CR 58 & CR 89
Reference maps of the Application Lands are attached hereto.
3. With this Application, BCEI is providing a copy of an Oil and Gas Lease and
associated Assignment, Bill of Sale and Conveyance into BCEI for at least one portion of a mineral
tract within the Application Lands showing the Applicant's status as an Owner in accordance with
ECMC Rule 303.a.(1). See Exhibit B, submitted with the Pronghorn OGDP Application.
4. Rule 401.a. provides that a Well completion 2,500 feet or greater below the surface
will be located not less than 600 feet from any lease line and not less than 1,200 feet from any
other existing or permitted Well completion in the same common source of supply, unless
authorized by order of the Commission or an exception under Rule 401.c is obtained.
5. On April 27, 1998, the Commission adopted Rule 318A, the Greater Wattenberg
Area Special Well Location, Spacing and Unit Designation Rule. The Application Lands are
subject to this Rule for the Niobrara and Codell Formations. Effective January 15, 2021,
Commission Rule 318A was moved to Rule 402 and modified to have no effect on future
operations and development in the Greater Wattenberg Area. However, Rule 402.c states that
any wellbore spacing units established prior to January 15, 2021 will remain in effect unless the
applicable Form 2s, if any, expire without spud.
6. On November 29, 2010, the Commission entered Order No. 407-380, which
among other things, established 21 approximate 640 -acre drilling and spacing units for various
lands in Township 5 North, Ranges 61 and 62 West, 6th P.M. and Township 6 North, Range 62
West, 6th P.M., and approved one horizontal well within each unit for development of the Codell
and Niobrara Formations. The approximate 640 -acre drilling and spacing unit established for
Section 4, Township 5 North, Range 61 West, 6th P.M. was vacated by Order No. 407-869. The
approximate 640 -acre drilling and spacing unit established for Section 17, Township 5 North,
Range 61 West, 6th P.M. was vacated by Order No. 407-768. Sections 5, 9, 10, 15 and 16,
Township 5 North, Range 62 West, 6th P.M., are subject to Order No. 407-380 for the Niobrara
and Codell Formations.
Page 4 of 24
7. On February 22, 2011 (Corrected April 4, 2013), the Commission entered Order
Nos. 407-779 and 535-4 which, among other things, established 74 approximate 640 -acre drilling
and spacing units, and approved one horizontal well within each unit, for the production of oil, gas
and associated hydrocarbons from the Niobrara Formation. The approximate 640 -acre drilling
and spacing unit established for Section 20, Township 5 North, Range 61 West, 6th P.M. was
vacated by Order No. 407-947. The approximate 640 -acre drilling and spacing unit established
for Section 28, Township 6 North, Range 61 West, 6th P.M. was vacated by Order No. 407-2717.
Section 21, Township 5 North, Range 61 West, 6th P.M. is subject to Order Nos. 407-779 and
535-4 for the Niobrara Formation.
8. On April 16, 2012, the Commission entered Order No. 407-583 which, among other
things, established nine approximate 640 -acre drilling and spacing units for certain lands including
Sections 33 and 34, Township 6 North, Range 61 West, 6th P.M., and approved up to four
horizontal wells within each unit for the production of oil, gas and associated hydrocarbons from
the Niobrara Formation, with the treated interval of the permitted wellbore(s) to be located no
closer than 460 feet from the boundaries of the proposed units, without exception being granted
by the Director. The approximate 640 -acre drilling and spacing units established by Order No.
407-583 for Sections 33 and 34, Township 6 North, Range 61 West, 6th P.M. were vacated by
Order No. 407-2720 for the Niobrara Formation.
9. On May 29, 2012, the Commission entered Order No. 407-633 which, among other
things, approved one or more additional horizontal wells within each existing approximate 640 -
acre drilling and spacing unit established for certain lands in Township 5 North, Ranges 61 and
62 West, 6th P.M., for the production of oil, gas and associated hydrocarbons from the Niobrara
Formation. Order No. 407-869 vacated Order No. 407-633 as it applies to Section 4, Township 5
North, Range 61 West, 6th P.M. Order No. 407-768 vacated Order No. 407-633 as it applies to
Section 17, Township 5 North, Range 61 West, 6th P.M. Sections 5, 9, 10, 15 and 16, Township
5 North, Range 62 West, 6th P.M., are subject to Order No. 407-633 for the Niobrara Formation.
10. On March 25, 2013, the Commission entered Order No. 407-768 which, among
other things, vacated an approximate 640 -acre drilling and spacing unit established by Order Nos.
407-380 and 407-633 for Section 17, Township 5 North, Range 61 West, 6th P.M., and
established an approximate 640 -acre drilling and spacing unit for Section 17, Township 5 North,
Range 61 West, 6th P.M., and approved up to ten horizontal wells within the unit, for the
production of oil, gas and associated hydrocarbons from the Niobrara Formation.
11. On June 17, 2013, the Commission entered Order Nos. 407-795 and 535-361
which, among other things, approved up to eight horizontal wells within an approximate 640 -acre
drilling and spacing unit established for Section 21, Township 5 North, Range 61 West, 6th P.M.,
for the production of oil, gas and associated hydrocarbons from the Niobrara Formation.
12. On July 29, 2013, the Commission entered Order Nos. 407-826 and 535-386
which, among other things, established an approximate 640 -acre drilling and spacing unit for
Section 21, Township 5 North, Range 61 West, 6th P.M. and approved up to four horizontal wells
within the unit for the production of oil, gas, and associated hydrocarbons from the Codell
Formation.
13. On October 28, 2013, the Commission entered Order No. 407-868 which, among
other things, pooled all interests within an approximate 640 -acre drilling and spacing unit
established for Section 21, Township 5 North, Range 61 West, 6th P.M., to accommodate the
Hawkins 5-61-21-3340BH Well (API No. 05-123-37756), Hawkins 5-61-21-4841BH Well (API No.
Page 5 of 24
05-123-37755), Hawkins 5-61-21- 4956BH Well (API No. 05-123-37750), Hawkins 5-61-21-
6457BH Well (API No. 05-123-37751), Kunsemiller 5-61-21-0108BH Well (API No. 05-123-
38211), Kunsemiller 5-61-21-1 609BH Well (API No. 05-123-38212), Kunsemiller 5-61-21-
3225BH Well (API No. 05-123- 38223), and Kunsemiller 5-61-21-172 4BH Well (API No. 05-123-
38224) for the development and operation of the Niobrara Formation.
14. On October 28, 2013, the Commission entered Order No. 407-869 which, among
other things, vacated an approximate 640 -acre drilling and spacing unit established by Order Nos.
407-380 and 407-633 for Section 4, Township 5 North, Range 61 West, 6th P.M., established an
approximate 640 -acre drilling and spacing unit for Section 4, Township 5 North, Range 61 West,
6th P.M. and approved up to four horizontal wells within the unit for the production of oil, gas and
associated hydrocarbons from the Niobrara Formation, with the productive interval of the
horizontal wellbore to be no closer than 460 feet from the unit boundaries, and no closer than 150
feet from the productive interval of any other wellbore located in the unit, without exception being
granted by the Director, and provided that the production from existing vertical and directional
wells, including the existing Pronghorn 31-4 well (API No. 05-123-23929) and the Pronghorn 14-
4 well (API No. 05-123-22430), shall continue to pay in accordance with units established under
Rule 318A or other prior orders of the Commission.
15. On July 28, 2014, the Commission entered Order No. 407-1087 which, among
other things, pooled all interests within an approximate 640 -acre drilling and spacing unit
established for Section 10, Township 5 North, Range 61 West, 6th P.M., and subjected any non -
consenting interests to the cost recovery provisions of §34-60-116(7), C.R.S. for the Pronghorn
K-O-10HNC Well (API No. 05-123-36583) and the Pronghorn F-J-10HNB Well (API No. 05-123-
36582), for the development and operation of the Niobrara Formation.
16. On December 17, 2018, the Commission entered Order No. 407-2720 which,
among other things, 1) vacated two approximate 640 -acre drilling and spacing units established
by Order No. 407-583 for Sections 33 and 34, Township 6 North, Range 61 West, 6th P.M., for
the production of oil, gas and associated hydrocarbons from the Niobrara Formation; and 2)
established an approximate 1,280 -acre drilling and spacing unit for Sections 33 and 34, Township
6 North, Range 61 West, 6th P.M., for the production of oil, gas and associated hydrocarbons
from the Niobrara and Codell Formations.
17. Prior to the date of this Application, the Commission entered various Orders
establishing and/or pooling all interests in wellbore spacing units for development of the Niobrara
and Codell Formations within portions of the Application Lands. These Orders are wellbore-
specific and do not affect the relief requested in this Application.
18. The records of the Commission reflect that the following wells are currently
producing in the Niobrara, Fort Hays, Codell and/or Carlile Formations within Rule 318A horizontal
Wellbore Spacing Units overlapping portions of the Application Lands:
Well Name
API No.
Location ID
Pronghorn # U-Y-18HNB
05-123-45065
431029
Kunsemilller # 5-61-20-0801B2B
05-123-44296
434508
Kunsemiller # 5-61-21-1 609BH
05-123-38212
434508
19. The above -referenced wells will not be included within any of the Drilling and
Spacing Units proposed for the Pronghorn OGDP and will continue to operate in accordance with
Rule 318A.
Page 6 of 24
20. The records of the Commission reflect that the following wells are currently
producing in the Niobrara, Fort Hays, Codell and/or Carlile Formations within portions of the
Application Lands pursuant to Rule 318A or an established Drilling and Spacing Unit, operated
by Applicant, from the following Locations:
Well Name
API No.
Location ID
Pronghorn #T-P-3HNB
05-123-36465
431184
Pronghorn # P-T-8HNB
05-123-37091
432389
Pronghorn # 41-11-9HZ
05-123-35010
427503
Pronghorn # D-X-9HNB
05-123-39286
436843
Pronghorn # C-W-9HNB
05-123-39287
436843
Pronghorn # 13-43-9HNB
05-123-39288
436843
Pronghorn # P-10-15XRLNB
05-123-39005
436242
Pronghorn # O-K-15HNC
05-123-41160
440871
Pronghorn # J24-15-10XRLNC
05-123-41161
440871
Pronghorn # O24-15-10XRLNB
05-123-41162
440871
Pronghorn # 31-34-15HZ
05-123-35276
428205
Pronghorn # F-J-15HNB
05-123-36416
431111
State Pronghorn # F-J-16HNB
05-123-36469
431197
State Pronghorn # 11-1 4-16HNB
05-123-39064
431197
State Pronghorn # A-E-16HNB
05-123-39066
431197
Pronghorn # 31-34-17HZ
05-123-33331
305297
Pronghorn # 11-1 4-17HNB
05-123-39390
437059
Pronghorn # F-J-17HNC
05-123-39392
437059
Pronghorn # 21-24-17HNB
05-123-39393
437059
Pronghorn # P-T-17HNB
05-123-36347
430949
Esterling # 44-33H
05-123-35472
428695
Pronghorn # 21-24-22HNB
05-123-39545
437437
Pronghorn # K-O-22HNB
05-123-39546
437437
Pronghorn # 11-1 4-22HNB
05-123-39547
437437
Pronghorn # F-J-22HNB
05-123-39548
437437
Pronghorn # K21-O24-22HNC
05-123-40607
437437
Pronghorn # F21-J24-22HNC
05-123-40608
437437
Pronghorn # A-E-22HNB
05-123-42204
437437
Pronghorn # K-O-17HNB
05-123-45066
451287
Kunsemiller 5-61-21-3225BH
05-123-38223
434508
Kunsemiller 5-61-21-172 4BH
05-123-38224
434508
Hawkins 5-61-21-33 40BH
05-123-37756
433684
Hawkins 5-61-21- 4841BH
05-123-37755
433684
Hawkins 5-61-21- 4956BH
05-123-37750
433684
Hawkins 5-61-21- 6457BH
05-123-37751
433684
Page 7 of 24
21. BCEI requests that the above -referenced wells not be included within any of the
Drilling and Spacing Units proposed for the Pronghorn OGDP and continue to operate in
accordance with Rule 318A or their respective spacing unit. With respect to the Pronghorn # 31-
34-17HZ Well (API No. 05-123-33331), Applicant separately filed an Application with the ECMC
in Docket No. 23110035 4 to amend Order No. 407-768 to make the Pronghorn # 31-34-17HZ
Well (API No. 05-123-33331) subject to the drilling and spacing unit established by Order No.
407-768.
22. The records of the Commission reflect that the following wells are currently Shut -
In for the production of the Niobrara, Fort Hays, Codell and/or Carlile Formations within portions
of the Application Lands, which have produced pursuant to Rule 318A or an established drilling
and spacing unit, operated by Applicant, from the following Locations:
Well Name
API No.
Location ID
Pronghorn # T-P-4HNB
05-123-36626
431481
Pronghorn # 14-11- 4HNB
05-123-37499
433145
Pronghorn # K-5-8XRLNB
05-123.40087
438694
Pronghorn # 14-44-9HNB
05-123-39289
436843
Pronghorn # F-J-10HNB
05-123-36582
431387
Pronghorn # K-O-10HNC
05-123-36583
431387
State Pronghorn # 41-44-16HZ
05-123-35220
428090
State Pronghorn # 31-34-16HNB
05-123-36470
428090
Pronghorn # P-T-22HNB
05-123-3718 6
432611
23. BCEI requests that the above -referenced wells not be included within any of the
Drilling and Spacing Units proposed for the Pronghorn OGDP. While BCEI acknowledges that
such wells have produced and/or are capable of production, BCEI intends to evaluate all shut-in
wells for potential plug, abandon, return to production while maintaining existing spacing units,
and/or reclamation operations with the Application Lands. With respect to the Pronghorn # T-P-
4HNB Well (API No. 05-123-36626) and the Pronghorn # 14-11-4HNB Well (API No. 05-123-
37499), Applicant separately filed an Application with the ECMC in Docket No. 23110035 4 to
amend Order No. 407-869 to make the Pronghorn # T-P-4HNB Well (API No. 05-123-36626) and
the Pronghorn # 14-11- 4HNB Well (API No. 05-123-37499) subject to the drilling and spacing unit
established by Order No. 407-869.
24. The records of the Commission reflect that the following wells are currently
permitted from the Pronghorn K-5 Pad (Location ID 438694) located within the Application Lands
in Lot 2 located in Section 5, Township 5 North, Range 61 West, 6th P.M., with approved or expired
Applications for Permit to Drill (APDs) within portions of the Application Lands for development of
the Niobrara, Fort Hays, Codell and/or Carlile Formations, to be operated by Applicant in an
adjacent 1,280 -acre drilling and spacing unit established by Order No. 407-2718:
Well Name
API No.
Pronghorn K-5 FED # 32N-12-01
Pronghorn K-5 FED # 32N-20-06
Mule Deer # Y-U-32HNB (expired)
Pronghorn K-5 # 31W-10-07
05-123-51210
05-123-51211
05-123-51212
05-123-51213
Page 8 of 24
Pronghorn K-5 FED # 32N-20-02
Pronghorn K-5 FED # 32N-20-03
Pronghorn K-5 FED # 32N-20-04
Mule Deer # 44-32-29XRLNB (expired)
Pronghorn K-5 FED # 32N-20-05
Pronghorn K-5 # 31W-10-08
Pronghorn K-5 # 31W-10-09
05-123-5121 4
05-123-51215
05-123-5121 6
05-123-51217
05-123-51218
05-123-51219
05-123-51220
25. BCEI requests that the above -referenced APDs not be included within any of the
Drilling and Spacing Units proposed for the Pronghorn OGDP and develop in accordance with
Order No. 407-2718.
26. BCEI will utilize the following four amended expanded Oil and Gas Locations
located within the Application Lands for development of the 26 new horizontal wells within the
Application Lands: the Pronghorn P-22 Pad (Location ID 432611), the Pronghorn T-4 Pad
(Location ID 431481), the Pronghorn P-10 Pad (Location ID 436242), and the Pronghorn F-16
Pad (Location ID 431197). With this Application, BCEI submitted sworn testimony pursuant to
Rule 505 regarding the applicable criteria listed in Rule 304.b.(2).B that apply to the amended
expanded Oil and Gas Locations. The amended expanded Pronghorn P-22 Pad, Pronghorn T-4
Pad, Pronghorn P-10 Pad and Pronghorn F-16 Pad are subject to the Pronghorn OGDP
Application filed concurrently herewith.
27. Based on the locations of the amended expanded Pronghorn P-22 Pad, Pronghorn
T-4 Pad, Pronghorn P-10 Pad and Pronghorn F-16 Pad, Weld County is the jurisdiction with siting
authority. PDC has an approved Pronghorn Comprehensive Development Plan from Weld County
for the siting and the related surface disturbance for the proposed Oil and Gas Locations
(1041WOGLA21-0017 ).
28. BCEI anticipates that it will submit an application to pool all interests, including any
non -consent interests, within the Application Lands at a future date. BCEI currently owns over
45% leasehold interest in the Application Lands, and therefore BCEI may pool the proposed Wells
in the Application Lands pursuant to the requirements of C.R.S. § 34-60-11 6(6)(b)(I), subject to
the requirement to tender a reasonable and good faith lease offer to all unleased mineral interest
owners within the Application Lands in accordance with C.R.S. § 34-60-11 6(7)(d)(I). The mineral
ownership within the Application Lands is in fee.
29. BCEI certifies that the approval of the eleven Drilling and Spacing Units requested
herein for the development of the Application Lands will result in development that will protect and
minimize adverse impacts to public health, safety, and welfare, the environment, and wildlife
resources and will protect against adverse environmental impacts on any air, water, soil or
biological resource in compliance with C.R.S. § 34-60-106(2.5)(a). BCEI certifies that its
operations in the Application Lands will be conducted in a reasonable manner to protect and
minimize adverse impacts to public health, safety, welfare, the environment, and wildlife
resources. With this Application, BCEI submitted sworn testimony pursuant to Rule 505
supporting the protection of public health, safety, welfare, the environment and wildlife resources.
30. BCEI further certifies that the eleven Drilling and Spacing Units requested herein
for the development of the Application Lands prevents waste of oil and gas resources, avoids the
drilling of unnecessary Wells, and protects correlative rights. With this Application, BCEI
Page 9of24
submitted sworn testimony pursuant to Rule 505 supporting the prevention of waste, the
avoidance of drilling unnecessary Wells, and the protection of correlative rights.
31. BCEI requests that the spacing order provide that all horizontal wells will be no
closer than 150 feet from the productive interval of any other wellbore located in the same
formation or common source of supply, unless authorized by Rule 401.c or Rule 408.u.(1) as
applicable, and establish the following subsurface setbacks for each unit:
a. Drilling and Spacing Unit Nos. 1, 2, 3, 5, 6 and 8, Amended Drilling and
Spacing Unit Nos. 7 and 9, and Wellbore Spacing Unit No. 2: 330 -foot productive interval setbacks
from the eastern and western boundaries of the units and 90 -foot productive interval setbacks
from the northern and southern boundaries of the units for the Niobrara, Fort Hays, Codell and
Carlile Formations. All approved Wells in Drilling and Spacing Unit Nos. 1, 2, 3, 5, 6 and 8,
Amended Drilling and Spacing Unit Nos. 7 and 9, and Wellbore Spacing Unit No. 2 will be drilled
from a north -south or south -north lateral orientation.
b. Wellbore Spacing Unit No. 1 and Amended Drilling and Spacing Unit No.
4: 90 -foot productive interval setbacks from the eastern and western boundaries of the units and
330 -foot productive interval setbacks from the northern and southern boundaries of the units for
the Niobrara, Fort Hays, Codell and Carlile Formations. All approved Wells in Wellbore Spacing
Unit No. 1 and Amended Drilling and Spacing Unit No. 4 will be drilled from an east -west or west -
east lateral orientation.
32. The undersigned certifies that copies of this Application and the Notice of Hearing
will be served on each interested party as required by Rules 504.a., 504.b.(2) and 504.b.(6).
33. The granting of this Application is in accord with the Oil and Gas Conservation Act,
found at §§ 34-60-101 et seq., C.R.S., and the Commission Rules.
34. Applicant requests that relief granted under this Application should be effective on
oral order by the Commission, and Applicant hereby agrees to be bound by said oral order.
WHEREFORE, BCEI respectfully requests that this matter be set for hearing in
accordance with applicable Commission Rules, that notice be given as required by law, and that
upon such hearing this Commission enter its order to:
A. Establish DSU #1 (2 Wells), DSU #2 (2 Wells), DSU #3 (2 Wells), DSU #5 (4
Wells), DSU #6 (5 Wells), DSU #8 (2 Wells), WSU #1 and WSU #2 for the production of oil, gas,
and associated hydrocarbons from the Niobrara, Fort Hays, Codell and Carlile Formations;
B. Amend Order Nos. 407-380 and 407-633 to authorize a total of seven horizontal
wells within the approximate 640 -acre drilling and spacing unit established for Section 9,
Township 5 North, Range 61 West, 6th P.M., for the Niobrara, Fort Hays, Codell and Carlile
Formations, and to authorize 330 -foot subsurface setbacks on the northern and southern
boundaries of the unit, 90 -foot subsurface setbacks on the eastern and western boundaries of the
unit, and provide that all horizontal wells will be no closer than 150 feet from the productive interval
of any other well producing in the same formation or common source, for the Niobrara, Fort Hays,
Codell and Carlile Formations;
C. Amend Order No. 407-768 to authorize a total of eight horizontal wells in the
approximate 640 -acre drilling and spacing unit established for Section 17, Township 5 North,
Page 10 of 24
Range 61 West, 6th P.M., for the Niobrara, Fort Hays, Codell and Carlile Formations, and to
authorize 330 -foot subsurface setbacks on the eastern and western boundaries of the unit, 90 -
foot subsurface setbacks on the northern and southern boundaries of the unit, and provide that
all horizontal wells will be no closer than 150 feet from the productive interval of any other well
producing in the same formation or common source, for the Niobrara, Fort Hays, Codell and
Carlile Formations;
D. Amend Order Nos. 407-380 and 407-633 to authorize a total of seven horizontal
wells within the approximate 640 -acre drilling and spacing unit established for Section 16,
Township 5 North, Range 61 West, 6th P.M., for the Niobrara, Fort Hays, Codell and Carlile
Formations, and to authorize 330 90 -foot subsurface setbacks on the northern and southern
boundaries of the unit, 90 330 -foot subsurface setbacks on the eastern and western boundaries
of the unit, and provide that all horizontal wells will be no closer than 150 feet from the productive
interval of any other well producing in the same formation or common source, for the Niobrara,
Fort Hays, Codell and Carlile Formations;
E. Provide that the productive interval of each proposed horizontal well will be no
closer than 150 feet from the productive interval of any other wellbore located in the same
formation or common source of supply, unless authorized by Rule 401.c or Rule 408.u.(1) as
applicable, and establish the following subsurface setbacks for each unit:
a. Drilling and Spacing Unit Nos. 1, 2, 3, 5, 6 and 8, Amended Drilling and
Spacing Unit Nos. 7 and 9, and Wellbore Spacing Unit No. 2: 330 -foot productive interval setbacks
from the eastern and western boundaries of the units and 90 -foot productive interval setbacks
from the northern and southern boundaries of the units for the Niobrara, Fort Hays, Codell and
Carlile Formations. All approved Wells in Drilling and Spacing Unit Nos. 1, 2, 3, 5, 6 and 8,
Amended Drilling and Spacing Unit Nos. 7 and 9, and Wellbore Spacing Unit No. 2 will be drilled
from a north -south or south -north lateral orientation;
b. Wellbore Spacing Unit No. 1 and Amended Drilling and Spacing Unit No.
4: 90 -foot productive interval setbacks from the eastern and western boundaries of the units and
330 -foot productive interval setbacks from the northern and southern boundaries of the units for
the Niobrara, Fort Hays, Codell and Carlile Formations. All approved Wells in Wellbore Spacing
Unit No. 1 and Amended Drilling and Spacing Unit No. 4 will be drilled from an east -west or west -
east lateral orientation;
F. Provide that all approved wells shall be located on Pronghorn P-22 Pad (DSU #1,
DSU #2, DSU #3 and WSU #1), Pronghorn T-4 Pad (DSU #4, DSU #5 and DSU #6), Pronghorn
P-10 Pad (DSU #6) and Pronghorn F-16 Pad (DSU #7, DSU #8, DSU #9 and WSU #2), unless
the Director grants an exception, and approve the associated Form 2As for the Pronghorn P-22
Pad, Pronghorn T-4 Pad, Pronghorn P-10 Pad and Pronghorn F-16 Pad;
G. Find that the development of the Niobrara, Fort Hays, Codell and Carlile
Formations as proposed within the Application Lands will prevent waste of oil and gas resources,
avoid the drilling of unnecessary Wells, protect correlative rights, and protect public health, safety,
welfare, the environment and wildlife resources; and
H. For such other findings and orders as the Commission may deem proper or
advisable in this matter.
Page 11 of 24
DATED March 6, 2024.
Bonanza Creek Energy Operating Company,
LLC
Jamie L. Jost
Kelsey H. Wasylenky
Jost Energy Law, P.C.
Attorneys for Applicant
3511 Ringsby Court, Unit 103
Denver, Colorado 80216
(720) 446-5620
J iost(c�iosteneroylaw. com
Kwasvlenkv(ciiostenerovlaw.com
Applicant's Contact Information:
Bonanza Creek Energy Operating Company, LLC
A Wholly Owned Subsidiary of Civitas Resources, Inc.
ATTN: Jeff Annable
Manager, Well & Location Permitting
Direct: 303-312-8529
jannableC0.civiresources.com
555 17th Street, Suite 3500
Denver, CO 80202
Page 12 of 24
AFFIRMATION
Jeff Annable, of lawful age, being first duly sworn upon oath, deposes and says that he is the
Manager, Well & Location Permitting for Civitas Resources, Inc., and that he has read the foregoing
Amended Application and that the matters therein contained are true to the best of his knowledge,
information and belief.
Dated March 6, 2024.
Jeff Annable
Manager, Well & Location Permitting
Civitas Resources, Inc.
Page 13 of 24
Reference Map - DSU #1
Wattenberg Field, Weld County
Pronghorn P-22 Pad: NE'/4NE% of Section 22, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #1 — 2 Wells:
Pronghorn T34-15-1 OXRLN
Pronghorn Y44-15-10XRLN
Township 5 North, Range 61 West, 6th P.M.
Section 10: EA
Section 15: E'/2
Approximately 640 -acres.
Nearby Public Crossroads: CR 58 & CR 89
.........,„_.
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Page 14 of 24
Reference Map — DSU #2
Wattenberg Field, Weld County
Pronghorn P-22 Pad: NE1 NE1A of Section 22, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #2 — 2 Wells:
Pronghorn 31-34-22HN
Pronghorn 41-44-22HN
Township 5 North, Range 61 West, 6th P.M.
Section 22: E1/2
Approximately 320 -acres.
Nearby Public Crossroads: CR 58 & CR 89
ongliorn
-22 Pad
Page 15 of 24
Reference Map — DSU #3
Wattenberg Field, Weld County
Pronghorn P-22 Pad: NE%NE% of Section 22, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #3 — 2 Wells:
State Pronghorn E-15-10XRLN
Pronghorn 14-15-10XRLN
Township 5 North, Range 61 West, 6th P.M
Section 9: E1/ZE'/2E1/2
Section 10: W�/ZW'/2
Section 15: WY2W'/2
Section 16: E�/ZE'/2E'/2
Approximately 480 -acres.
Nearby Public Crossroads: CR 58 & CR 89
onghorn
-22 Pad
Page 16 of 24
Reference Map - WSU #1
Wattenberg Field, Weld County
Pronghorn P-22 Pad: NE%NE% of Section 22, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
WSU #1 - State Pronghorn Y-15-16XRLN Well:
Township 5 North, Range 61 West, 6th P.M.
Section 15: SY2S1/2S1/2
Section 16: S1/2S1/2S1/2
Section 21: N%N1/2N1/2
Section 22: N%N1/%N1/2
Approximately 320 -acres.
Nearby Public Crossroads: CR 58 & CR 89
33 34 35 4)
Page 17 of 24
Reference Map — DSU #4
Wattenberg Field, Weld County
Pronghorn T-4 Pad: SE1ASE% of Section 4, Township 5 North, Range 61 West,
6th P.M., Weld County, Colorado:
Amended DSU #4 — 2 Wells:
Pronghorn V-B-9HN
Pronghorn 42-12-9HN
Township 5 North, Range 61 West, 6th P.M.
Section 9: All
Approximately 640 -acres.
Nearby Public Crossroads: CR 58 & CR 89
Page 18 of 24
Reference Map — DSU #5
Wattenberg Field, Weld County
Pronghorn T-4 Pad: SEASEA of Section 4, Township 5 North, Range 61 West,
6th P.M., Weld County, Colorado:
DSU #5 — 4 Wells:
Pronghorn Y44-4-33XRLN
Pronghorn 034-4-33XRLN
Pronghorn 024-4-33XRLN
Pronghorn J-4-33XRLN
Township 5 North, Range 61 West, 6th P.M.
Section 4: All
Township 6 North, Range 61 West, 6th P.M.
Section 33: All
Approximately 1,280 -acres.
Nearby Public Crossroads: CR 58 & CR 89
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Page 19 of 24
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Reference Map - DSU #6
Wattenberg Field, Weld County
P ronghorn P-10 Pad: NE%NE1A of Section 10, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #6 — 5 Wells:
Pronghorn 44-3-34XRLN
Pronghorn O34-3-34XRLN
Pronghorn O24-3-34XRLN
Pronghorn J-3-34XRLN
Pronghorn 514-3-33XRLN — to produce from the Pronghorn T-4 Pad
Township 5 North, Range 61 West, 6th P.M.
S ection 3: All
Township 6 North, Range 61 West, 6th P.M.
Section 34: All
Approximately 1,280 -acres.
N earby Public Crossroads: CR 58 & CR 89
Page 20 of 24
Reference Map — DSU #7
Wattenberg Field, Weld County
P ronghorn F-16 Pad: NW1/4NW�/4 of Section 16, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
Amended DSU #7 — 2 Wells:
Pronghorn P31- T34-17HN
Pronghorn 41-44-17HN
Township 5 North, Range 61 West, 6th P.M.
S ection 17: All
Approximately 640 -acres.
N earby Public Crossroads: CR 58 & CR 89
Page 21 of 24
Reference Map - DSU #8
Wattenberg Field, Weld County
Pronghorn F-16 Pad: NWIANW1h of Section 16, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
DSU #8 — 2 Wells:
Pronghorn 34-8-5XRLN
Pronghorn 44-8-5XRLN
Township 5 North, Range 61 West, 6th P.M.
Section 5: E1/2
Section 8: E1/2
Approximately 640 -acres.
Nearby Public Crossroads: CR 58 & CR 89
- 0 2500 5000 -
.0a! ••• I
Page 22 of 24
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25
Reference Map — DSU #9
Wattenberg Field, Weld County
Pronghorn F-16 Pad: NW'/4NW1A of Section 16, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
Amended DSU #9 — 3 Wells:
State Pronghorn 21-24-16HN
State Pronghorn K-O-16HN
State Pronghorn P-T-16HN
Township 5 North, Range 61 West, 6th P.M.
Section 16: All
Approximately 640 -acres.
Nearby Public Crossroads: CR 58 & CR 89
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Page 23 of 24
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Reference Map - WSU #2
Wattenberg Field, Weld County
Pronghorn F-16 Pad: NW%NW1A of Section 16, Township 5 North, Range 61
West, 6th P.M., Weld County, Colorado:
WSU #2 — Pronghorn Y-8-5XRLN Well:
Township 5 North, Range 61 West, 6th P.M.
Section 4:
Section 5:
Section 8:
Section 9:
W1/2W%W1/2
EIAEY2E%
EY2EY2EY2
W1Y2W1Ym%
Approximately 320 -acres.
Nearby Public Crossroads: CR 58 & CR 89
Page 24 of 24
Exhibit D
to BCEI Pronghorn OGDP Application
00AfZfl
CREEK
August 26, 2021
Oil and Gas Energy, Weld County
AEn: Jason Maxey
1301 N. 17' Ave.
Greeley, CO 80631
Re: Notice to Relevant Local Government
Pronghorn F-16
NW/414M/4 Section 16, TSN, 1(61 W, 6"e P.M.
Weld County, Colorado
Dear Director Maxey,
41017th Street Suite 1400
Denver, CO 80202
(720) 440-8100 phone
(720) 305.0804 fax
Bownmak min
The purpose of this letter is to formally notify you that in compliance with the Colorado Oil and
Gas Conservation Commission's ("Commission") Rule 302.e., and in accordance with the Weld
County Code, Bonanza Creek Energy, Inc. ("BCEI") plans to submit the Pronghorn F-16 Oil and
Gas Development Plan ("OGDP}') to the Commission on or about September 30th, 2021.
The proposed OGDP encompasses one (1) oil and gas location, described below, drilling eight (8)
wells located in the following lands:
Township 5 North. Range 61 West, 6. P.M.
Section 4: W2W2
Section 5: E2
Section 8: E2
Section 9: W2W2, SESW, S2SE
Section 16: E2, E2W2, NWNW
Section 17: ALL
BCEI anticipates beginning construction ofthe Pronghorn F-16 location in the fourth quarter, 2022.
The location of the proposed Oil and Gas surface is as follows:
NWI4NW/4 Section 16, TSN, R61W, 6° P.M.
Enclosed with this letter are the following documents:
1. BCE! Operational Guide, which outlines the anticipated date that each phase of operations
will commence by month and year, the proposed construction schedule by quarter and year,
and a description of each operational phase of development and what to expect during each
phase;
2. Pronghorn F-16 Traffic Plan, which outlines the proposed haul routes and traffic volume
associated with each phase of operations;
3. The Commission's information sheet about the procedural steps involved with the
Director's and Commission's review of Oil and Gas Development Plans;
4. The Commission's information sheet about the Commission's public comment process and
the relevant deadlines;
5. The Commission's information sheet about Hydraulic Fracturing Treatments; and
6. The Commission's information sheet about how the public may view the status of the
proposed Oil and Gas Development Plan application on the Commission's website.
To receive more information about the proposed OGDP or to ask questions about the OGDP
please contact Scott Park by email at spark@bonanzacrk.com, or by phone at (970) 415-0778,
or by letter at 410 17" Street, Denver, CO 80202, or the COGCC
(https://cogcc.state.co.usitilhome) at 303-894-2100.
Sincerely,
5-:"<teri"‘
Scott Park
Director, EHS & RC, Operations Management
Enclosures:
BCEI Operational Guide
Traffic Plan
Commission's Information Sheets
Page 2
��eonenzp
CREEK
41017th Street, Suite 1400
Denver, CO 80202
(720) 440-6100 phone
(720) 305.0604 fax
Boogintacrkvolu
liCE1 Operational Guide: BCEI is a Delaware company ("Operator"), submitting this Operational Guide
to Weld County, CO outlining the anticipated timeframes that each phase of operations for the Pronghorn
F-16 project will commence following the proposed construction scheduled quarter and year, and a
description of each operational phase of development and what to expect during each phase.
Construction
Once all required permits have been issued by Weld County, CO and the Colorado Oil and Gas
Conservation Commission ("COGCC"), the construction phase for Operator's Oil and Gas Location
("Location") may begin. Operator plans construction of the Pronghorn F-16 Location to be around the
Fourth Quarter of 2022, An average pad construction takes approximately 14 days. The construction.
process is done during daylight hours and during ideal weather conditions such to avoid construction
inefficiencies and sediment migration from the site. This process may include equipment such as
bulldozers, scrapers, loaders, backhoes, water wagons, rollers, graders, and gravel trucks to construct the
pad and haul in the surface gravel to the Location There are between two and ten people on site during
this phase of work. The pad location will be completed prior to the arrival of a drilling rig. Steps for pad
construction are typically as follows:
I) Installation of perimeter stormwater BIvIPs pursuantto the approved SWMP, COGCC, Weld
County and CDPHE stormwater requirements.
2) Existing vegetation is cleared, and the topsoil is stripped. No burning of debris occurs.
3) Topsoil and spoil piles are clearly separated to ensure preservation of the topsoil for final site
reclamation.
4) Once the basic grading is complete to level the well pad, establish drainage ditches, and spoils and
topsoil stockpiles separated, gravel is hauled in to provide a stable surface for oil and gas
operations. Gravel hauling generates heavy traffic, but generally only lasts a few days, and is more
detailed in Operator's Traffic Plan (also attached).
5) A portion of the well site is then constructed with the permanent production facilities in mind. This
area is located away from the planned wellheads to abide by numerous safety standards set by the
Operator, the COGCC and the American Petroleum Institute. This work may occur
simultaneously to drilling and completion operations.
6) All disturbed ground not needed for subsequent operations, including stockpiles and cut and fill
slopes, are seeded and mulched in accordance with Operator's approved permits.
7) If necessary a perimeter fence is constructed to establish the well pad boundary, turn livestock and
deter the public from entering the Location.
8) Cattle guards may be installed at the Location entrance, in addition to a locking gate. This
perimeter fence will generally remain in place until after interim reclamation (as defined by the
COGCC) has been performed, and all disturbed areas have re-established vegetation. Any
additional fencing requirements under the OA will be installed after interim reclamation occurs.
9) The Well Site is left in a stable condition, ready for the rig.
Comer. am.
Stn... Svn.1400
Denver, CO 80202
tSffccP101440#10D
Origin
Following pad construction, a drill rig will be brought to the well pad, and will begin drilling each of the
Pronghorn F-16 wells. Drilling rig operations are 24 hours per day, and Operator's drilling personnel work
in shifts, with some that stay on site during the entire operation for safety purposes. The crew size can
range from approximately 25 to 40 people at any given time. The Operator will conduct drilling operations
in compliance with all County, State, and Federal rules and regulations. Drilling a single well will typically
take between 5-1,0 days. The Pronghorn F-16 proposed plan contains 8 wells, therefore the drilling
timeframe range will be between 40-80 days.
Multi -well Sites take longer to drill than a single well Well Site Ina yield a smaller overall disturbance
than drilling multiple single -well Well Sites. There will be a period of increased traffic prior to the rig
arriving and while the rig moves off to the next Location.
Standard operations equipment on the Location during the drilling phase consists of a drilling rig at the
center of the pad along with water storage to be used in the drilling operations, pipe racks for temporarily
storing drill piping, pumps, power generators, tool storage, fuel storage for said generators and pumps, and
an enclosure to protect workers from inclement weather.
The Operator utilizes a "closed Loop system" during drilling operations. Water used to support drilling
operations may be trucked in or piped in and temporarily stored on -site. The Operator properly handles all
drilling fluid in accordance with federal regulations. No fluid will be discharged on -she. Drilling fluid will
be disposed of offsite, in a manner approved by the COGCC. Steps for the Drilling Process are typically
as follows:
1) The drilling rig will drill vertically down to a specified depth and then horizontally to a specified
distance. This target depth usually ranges from 6,000' 7,000' below the surface; The deepest
freshwater source is approximately 5000' shallower than the target depth of the well. The wellbore
is chilled in successive sections through the rock layers. Once the desired length of each wellbore
section has been drilled, the drilling assembly is removed, and steel casing is inserted into the
wellbore and cemented in place.
2) A typical wellbore contains surface casing and production casing strings designed to provide a
barrier that protects groundwater resources from the contents that will later flow inside the
wellbore. The Operator's standard surface casing design consists of 9 518" 36 lblfir graded steel
casing. The Operator's standard production casing design consists of 5 4" 20 lb/ft graded steel
pipe. The Operator will follow the COGCC regulations regarding wellbore integrity and testing to
ensure water aquifer protection. The Operator will adhere to all COGCC requirements for easing
setting depths necessary to protect ground water sources, and all drilling permits to ensure that
those setting depths are achieved. To ensure the protection of all freshwater resources, 9-!a' steel
surface easing will be set to a depth at least fifty (50) feet below the base of the deepest aquifer in
water wells located within one mile of the surface location as required by the COGCC. The casing
will be cemented from the bottom of the pipe up to surface.
3) for each well drilled from the Location, cement is installed between the wellbore and casing pipe
and will be allowed to set. While the cement is setting, well control equipment is installed and
tested. After the cement is set and installation of well control equipment is complete, a drill bit is
run into the hole to drill the intermediate portion of the well into the potential oil and gas bearing
formations. The well will be drilled horizontally and will be turned or steered such that a curve is
achieved to approximately 90 degrees or parallel to the surface of the ground. The proposed
vertical depth for the each well drilled from the Location is approximately 7,000 feet below
ground level and the length of the horizontal leg being one to two (1 - 2) miles long.
4) Once the horizontal section of the wellbore is drilled, a string of production casing will be run into
the wellbore. This casing will be 5'!z inches in outer diameter and weighs 20 pounds per linear
Page 2
foot. The grade will be P110, which has a collapse rating of 11,080 psi and a burst rating of 12,640
psi. This casing will be cemented into place to isolate the productive zones of the reservoir.
5) Operator performs Bralenhead tests on all New Wells at all Location during the Drilling Phase
and then annually during the Production Phase of the well.
Once drilling operations are complete, the drilling rig is disassembled and moved offsite. At this stage,
activity stops until the "completion" of the well occurs.
Cnraaletion
Prior to and following the Completion Phase of any New Well, Operator will assess the integrity of
surrounding plugged and decommissioned wells, wells removed from use, and dry holes ("Previously
Abandoned Wells") which are located within 1,500 feet of the proposed New Well borehole.
Hydraulic Fracturing is just one portion of the completions process. There are also other minor activities
that take place on the pad before and after fracturing, such as preparing the New Well for fracturing and.
cleaning the sand out afterwards. Hydraulic fracturing is a completion method that has been used since the
late 1940s.
On average, it takes less than 10 days to complete a New Well and approximately 50-60 days to
complete an eight -well Location. Again, the proposed Pronghorn F-16 Location consists of 8 wells and
show take between the above mentioned 50-60 days to complete. Completion operations occur 24 -hours
per day on the Location. The completions crews work in shifts, with some personnel living on -site during
the entire operation. Crew size can vary but is typically made up of about 20 people, although up to 60
people may be on -site at any time.
During hydraulic fracturing, fracturing materials, mainly sand, are brought in by truck and mixed on -site
with water and other fracturing fluids. Pursuant to the terms of the OA, and to the maximum extent
possible, the Operator will transport water onto the Location through temporary, above -ground water
supply line (not trucks) for this work.
Operator has a site -specific Water Delivery Plan, and Method that has been provided to the City with this
application. All flowhack water is routed to temporary frac tanks which are mobile units and trucked off -
site. These frac tanks also have secondary containment (temporary liner constructed 30-40 ml
polyurethanes and the portable containment is installed with interlocking high -density plastic panels).
The actual fracturing process uses rnacltioery capable of driving fracturing fluid down the length of the
entire wellhore (potentially more than 17,000 feet). The fracturing fluid consists of water, proppant
(typically sand), and some chemical additives. This fracturing fluid is pumped into the well at high
pressures to crack the rock in difi rent stages in the targeted geologic horizon.
Fracturing fluid is comprised of up to 99.5% water and sand. Small amounts of chemical additives are
necessary to reduce fluid friction, kill bacteria that are present in the water source and enhance the fluid's
ability to transport the propping agent
To start the fracturing process, the well casing must first be perforated, At predetermined and specific
intervals (stages) in the well, small perforations are made in the wellbore that allow the fracturing fluid to
pass through the steel casing and exert pressure against the rock. The force of the fluid creates tiny cracks,
or fractures, in the underground reservoir. Once fluid injection stops, pressure begins to dissipate, and the
fractures previously held open by the fluid pressure begin to close. The proppant acts as a tiny wedge to
hold these narrow fractures open, creating pathways for oil, natural gas and fracturing fluids to flow more
easily to the welL
After a stage has been hydraulically fractured, a plug is set inside the casing to isolate the stimulated
section of the wellbore. The next stage is then perforated, fractured and isolated by a plug. The entire
Page
perforate -fracture -plug cycle is repeated at regular irtervals along the targeted section of the reservoir. A
10,000 ft. lateral in the Niobrara formation may have 4l} or more discrete stages associated with a frao job.
Once all stages have been fractured, the plugs are drilled out by a coil tubing rig,, or workover rig, allowing
the oil, natural gas, and fluids to flow into the well casing and up to the surface.
Flowhack and Production Stag
The last stage of the completions process is known as "flowback". Flowback describes the first few days of
production from the well, after the plugs have been drilled out by a coil tubing rigor workover rig.
The well produces an emulsion of hydrocarbon, formation water and produced water from the fracturing
fluid. This emulsion flows through various pieces of temporary equipment on the surface to separate it out
into various components. The flowback water is collected in tanks and may be recycled and blended with
other water to be used at another fracturing site, or disposed of in accordance with all applicable rules,
including COGCC's. This typically means the water is transported by thick to a state -approved injection
well located outside of the City.
At the end of this stage of development, all temporary equipment is removed from the Location, leaving
only the wellhead and the permanent production facilities, including, separators, storage tanks and
emissions control equipment. New well equipment and all existing equipment at the Location will be
anchored to the extent necessary to prevent flotation, collapse, lateral movement, or subsidence in
compliance with applicable Federal Emergency Management Agency ("FERIA") (as administered by the
City) and COGCC rules and regulations. Operator's wells do not leave any anchors buried for future use.
All anchoring is done through surface anchors or removable anchoring systems during Drilling and
Completion Phases.
After drilling and completion operations conclude, the well is "put on production" and may produce for
20+ years. Operator's commitment to safe and environmentally responsible operations continues through
the entire life of each well.
Wells produce an emulsion of oil, gas and naturally occurring water. Certain equipment is needed on the
Location to separate the gas from the oil, and the oil from the water. The oil and gas are measured,
metered, and sold as they leave the Location. The separated water, or "produced water", must be disposed
of according to state and federal regulations.
The plan is for oil to be transported from the Location via pipeline in order to minimize the truck traffic
associated with production operations. Numerous engineering controls are in place to prevent or minimize
the impact of unplanned events such as spills or leaks. Until a water gathering system is constructed,
produced water will be piped, or trucked offsite. Produced water will be disposed of offsite to a stater
approved injection well, as approved by the COGCC.
Natural gas is sold through the meter and transported offsite through a gas gathering pipeline system in
accordance with COGCC regulations.
The physical dimensions of the production facilities may vary based on several factors, all of which are
covered by the OA or in OGP Process. Operator will use electricity to power most equipment on -site. A
combustion device must be available at each Location during the entire Production Phase for maintenance
or emergencies only.
• The combustion device must be fired with natural gas and designed to operate with a 98% or
higher hydrocarbon destruction efficiency.
• The combustion device must be designed and operated in a manner that will ensure no visible
emissions during normal operation. Visible emissions mean observations of smoke for any period
or periods of duration greater than or equal to one minute in any 15 -minute period during normal
Pag54
operation, pursuant to EPA Method 22. Visible emissions do not include radiant energy or water
vapor.
The combustion device must always be operated with a flame present when emissions maybe
vented to it, or other mechanism that does not allow uncontrolled emissions.
All combustion devices must be equipped with an auto -igniter unless manned while in use.
No permanent facilities will be placed outside of the designated pad.
Location facilities must meet internal engineering standards, as well as operating and process integrity
requirements. The facility plans go through a PHA -Hazard Operability Study by a certified facilitator. Any
recommendations are incorporated into the design. Alarms and relief systems are regularly tested, and
personnel are trained to operate facilities responsibly. During the production phase, tanks and separation
equipment are secured to the ground using anchors engineered to resist floatation, collapse, lateral
movement, or subsidence.
To the extent flares, thermal oxidizers, or combustion devices are utilized, all such flares shall be designed
and operated in accordance with the state and federal regulations. Operator will provide a safe and secure
work environment to protect workers, our contractors and the community. Critical equipment will be
secured by lock or with a security seal to prevent unauthorized tampering with equipment. Operator will
use hard -rimmed rings at the Well Sites with sufficient capacity to contain l,5 times the maximum volume
of the largest tank on location that such facility will contain at any given time plus sufficient freeboard to
prevent overflow around all permanent tanks. All berms and containment devices will be inspected
quarterly by Operator and maintained in good condition. No potential ignition sources will be installed
inside the secondary containment area unless the containment area encloses a fired vessel or such sources
are rated in accordance with industry codes and standards. Secondary containment such as duck ponds or
lined earthen berms for temporary tanks may also be used. Containment berms will be constructed of hard -
rimmed rings, designed and installed to prevent leakage and resist degradation from erosion or routine
operation. Secondary containment for tanks will be constructed with a synthetic or 14 engineered liner that
contains all primary containment vessels and is mechanically connected to the steel ring to prevent
leakage. Well Sites will comply with the City's stormwater management requirements, including the me of
stormwater best management practices to minimize water runoff from collecting in local waterways.
An automated safety system, governed by safety devices and a programmable logic computer, will be
installed at the Location. The automated safety system will include the installation, monitoring and remote
control of a Surface Safety Valve ("SSV'T) among other engineered measures sad devices that are
implemented to reduce or eliminate the potential fora well event. The SSV monitors flowing pressures and
other operating parameters which have predetermined threshold values programmed and will remotely shut
the well in should certain upset conditions be detected. Additionally, the automated safety system provides
the ability to remotely shut-in wells on demand through operator remote intervention. The SSV will have
documented annual testing to ensure functionality.
During the Production Phase, Operator will maintain the Location. Debris and flammable material will be
removed from the Location and any mud tracked from the Location to public roads will be addressed.
Reclamation (Interim and Final)
Interim reclamation: will occur within three months of the first production on Well Sites situated in crop
lands, and within six months of first production for Well Sites situated in non -crop lands unless a timeline
exception is granted by the surface owner and COOCC. Interim reclamation is performed in accordance
with COGCC Rules. During this phase, portions of the Well Site that are no longer needed for production
operations are reclaimed back to their original contours and reseeded with appropriate vegetative cover.
Operator will monitor the condition of these reclaimed areas until sufficient vegetative cover is
established. The final fencing is typically installed at this time to enclose the pad area and establish the site
perimeter. The fence can serve multiple purposes including: visually screening the site from view, acting
as a security measure to deter unauthorized access by members of the public and preventing livestock from
Page 5
entering the site.
At the end of a well's productive life which can be 20+ years, the Operator submits a Notice of
Abandonment to the COGCC. The "Final Reclamation" of the Location is dictated by multiple documents,
including COGCC Regulations, any conditions of approval associated with the City permits, the Surface
Use Agreement, and/or Oil and Gas Lease or Leases. The reclamation process is typically as follows:
Final reclamation; plans will include the appropriate surface reclamation necessary for approval from
Weld County and the COGCC. All wellbores are plugged and abandoned in accordance with COGCC
regulations and other applicable laws. At the time of final plugging and abandonment, all surface
equipment is removed, and the Location is graded as nearly as practicable to the natural contours.
Backfilling, leveling and recontouring is performed as soon as practicable after plugging or cessation of
production and removal of production equipment rent and facilities. Stockpiled topsoil is redistributed evenly
over the re -contoured surface.
The Location and any associated access roads are treated to alleviate compaction that may have occurred
during the oil and gas operations.
The reclaimed area is reseeded with the approved seed mixture specifically designed to simulate adjacent
undisturbed vegetation while maximizing utilization by both wildlife and domestic stock. The vegetation
growth is monitored at the Location until the vegetation reaches adequate density per COGCC regulations.
Page
Page 1of1
V�
BOflRflZA
CREEK
TRANSPORTATION PLAN
RPG
RE OU1ES
Project
Report
County,
location
Name:
Date:
State:
Townshi
Pronghorn
8/10/2021
Weld
•, Ran:e, Section : T5N,
1.
County,
R61W,
Number
F-16
516
CO
of Roundtrips
Region:
Field
Proposed
/ Day
Name:
Start Date:
DJ
Wattenberg
4th
Basin
Quarter
2022
Activity
Phase
Type/Roudtrips Size Weight
Single
Unit Truck
10,000
- 20,000
lbs
10 Average RT
Construction
multi
Unit Truck
50,000
- 70,000 lbs
15 Average
RT
Passenger/Pickup
4500
- 8500
lbs
5 Average RT
Single
Unit
Truck
10,000
- 20,000
lbs
10
Average
RT
Drilling
Multi
Unit
Truck
50,000 - 70,000
lbs
10 Average
RT
Passenger/Pickup
4500 - 8500
lbs 30 Average
RT
Single
Unit
Truck
10,000
- 20,000
lbs
5 Average
RT
Completions
Multi
Unit
Truck
50,000
- 70,000
lbs
SO Average RT
Passenger/Pickup
4500 - 8500
lbs
40 Average AT
Single
Unit
Truck 10,000
- 20,000
lbs
1
Average FAT
Production
Multi
Unit
Truck
50,000
- 70,000
lbs 3 Average RT
Passenger/Pickup
4500 - 8500
lbs
1 Average
RT
2. Expected Haul
Route
Route ID
Description
Traffic
will
access
the
location from west
along
US
Highway
34, north
on WCR
87, continue
Route 1
north
on WCR 89, east on WCR 58
Route
will
access the
location
north
from
east
on WCR
along
89, east
US Highway
on
WCR
34, north
58
on WCR
87, continue
Traffic
Traffic
will
access the
location
along
CO Highway
392, east on WCR 68, south
on
from north
Route
3
'NCR 89, east on WCR
58
3.
Travel Distribution
Route ID
Construction Drilling
Completions
Route
1
100%
50% 0%
Route 2
0% 50% 100%
Route
3
0%
0% 0%
4. Expected
Daily Peak
Traffic Time
Peak
traffic
vohumes
are expected around
6am and
6pm when
shift
changes
occur.
This
applies
for drilling
and
completions
which
run on
24
hour operations.
During construction activites, specific
traffic
peaks
are not expected at any time throughout
the
day.
Reviewed By: Joe Schultz
Project Manager
Title:
Signature:
Date: 8/10/2021
eonanzi
CREEK
BonRnzA
CREEK
August 26, 2021
Oil and Gas Energy, Weld County
Attn: Jason Maxey
1301 N. 17th Ave.
Greeley, CO 80631
Re: Notice to Relevant Local Government
Pronghorn P-10
NW/4NW/4 Section 10, T5N, R61W, 6th P.M.
Weld County, Colorado
410 17th Street, Suite 1400
Denver, CO 80202
(720) 440-6100 phone
(720) 305-0804 fax
Dear Director Maxey,
The purpose of this letter is to formally notify you that in compliance with the Colorado Oil and
Gas Conservation Commission's ("Commission") Rule 302.e., and in accordance with the Weld
County Code, Bonanza Creek Energy, Inc. ("BCEI") plans to submit the Pronghorn P-10 Oil and
Gas Development Plan ("OGDP") to the Commission on or about September 30th, 2021.
The proposed OGDP encompasses one (1) oil and gas location, described below, drilling four (4)
wells located in the following lands:
Township 5 North, Range 61 West, 6th P.M.
Section 3: ALL
Section 10: N2N2
Township 6 North, Range 61 West, 6th P.M.
Section 27: S2S2
Section 34: ALL
BCEI anticipates beginning construction of the Pronghorn P-10 location in the first quarter, 2023.
The location of the proposed Oil and Gas surface is as follows:
NW/4NW/4 Section 10, T5N, R61W, 6th P.M.
Enclosed with this letter are the following documents:
1. BCEI Operational Guide, which outlines the anticipated date that each phase of operations
will commence by month and year, the proposed construction schedule by quarter and year,
and a description of each operational phase of development and what to expect during each
phase;
2. Pronghorn P-10 Traffic Plan, which outlines the proposed haul routes and traffic volume
associated with each phase of operations;
3. The Commission's information sheet about the procedural steps involved with the
Director's and Commission's review of Oil and Gas Development Plans;
4. The Commission's information sheet about the Commission's public comment process and
the relevant deadlines;
5. The Commission's information sheet about Hydraulic Fracturing Treatments; and
6. The Commission's information sheet about how the public may view the status of the
proposed Oil and Gas Development Plan application on the Commission's website.
To receive more information about the proposed OGDP or to ask questions about the OGDP
please contact Scott Park by email at sparkhbonanzacrk.com, or by phone at (970) 415-0778,
or by letter at 410 17th Street, Denver, CO 80202, or the COGCC
(https://cogcc.state.co.us/#/home) at 303-894-2100.
Sincerely,
Scott Park
Director, EHS & RC, Operations Management
Enclosures:
BCEI Operational Guide
Traffic Plan
Commission's Information Sheets
Page 2
��eonAnzA
CREEK
410 17th Street, Suite 1400
Denver, CO 80202
(720) 440-6100 phone
(720) 305-0804 fax
Honatiracti-corn
BCEI Operational Guide: BCEI is a Delaware company ("Operator"), submitting this Operational Guide
to Weld County, CO outlining the anticipated timeframes that each phase of operations for the Pronghorn
P-10 project will commence following the proposed construction scheduled quarter and year, and a
description of each operational phase of development and what to expect during each phase.
Construction
Once all required permits have been issued by Weld County, CO and the Colorado Oil and Gas
Conservation Commission ("COGCC"), the construction phase for Operator's Oil and Gas Location
("Location") may begin. Operator plans construction of the Pronghorn P-10 Location to be around the
First Quarter of 2023. An average pad construction takes approximately 14 days. The construction
process is done during daylight hours and during ideal weather conditions such to avoid construction
inefficiencies and sediment migration from the site. This process may include equipment such as
bulldozers, scrapers, loaders, backhoes, water wagons, rollers, graders, and gravel trucks to construct the
pad and haul in the surface gravel to the Location. There are between two and ten people on -site during
this phase of work. The pad location will be completed prior to the arrival of a drilling rig. Steps for pad
construction are typically as follows:
I) Installation of perimeter stormwater BMPs pursuant to the approved SWMP, COGCC, Weld
County and CDPI-IE stonnwater requirements.
2) Existing vegetation is cleared, and the topsoil is stripped. No burning of debris occurs.
3) Topsoil and spoil piles are clearly separated to ensure preservation of the topsoil for final site
reclamation.
4) Once the basic grading is complete to level the well pad, establish drainage ditches, and spoils and
topsoil stockpiles separated, gravel is hauled into provide a stable surface for oil and gas
operations. Gravel hauling generates heavy traffic, but generally only lasts a few days, and is more
detailed in Operator's Traffic Plan (also attached).
5) A portion of the well site is then constructed with the permanent production facilities in mind. This
area is located away from the planned wellheads to abide by numerous safety standards set by the
Operator, the COGCC and the American Petroleum Institute. This work may occur
simultaneously to drilling and completion operations.
6) All disturbed ground not needed for subsequent operations, including stockpiles and cut and fill
slopes, are seeded and mulched in accordance with Operator's approved permits.
7) If necessary a perimeter fence is constructed to establish the well pad boundary, turn livestock and
deter the public from entering the Location.
8) Cattle guards may be installed at the Location entrance, in addition to a locking gate. This
perimeter fence will generally remain in place until after interim reclamation (as defined by the
COGCC) has been performed, and all disturbed areas have re-established vegetation. Any
additional fencing requirements under the OA will be installed after interim reclamation occurs.
9) The Well Site is left hi a stable condition, ready for the rig.
Corporate Office
410.17• Street, Suite 1401)
Denver, CD 80202
Office{720)440.6100.
DD !ing
Following pad construction, a drill rig will be brought to the well pad, and will begin drilling each of the
Pronghorn P-10 wells. Drilling rig operations are 24 hours per day, and Operator's drilling personnel work
in shifts, with some that stay on -site during the entire operation for safety purposes. The crew size can
range from approximately 25 to 40 people at any given time. The Operator will conduct drilling operations
in compliance with all County, State, and Federal rules and regulations. Drilling a single well will typically
take between 5-10 days. The Pronghorn P-10 proposed plan contains 4 wells, therefore the drilling
timeframe range will be between 20-40 days.
Multi -well Sites take longer to drill than a single -well Well Site but yield a smaller overall disturbance
than drilling multiple single -well Well Sites. There will be a period of increased traffic prior to the rig
arriving and while the rig moves off to the next Location.
Standard operations equipment on the Location during the drilling phase consists of a drilling rig at the
center of the pad along with water storage to be used in the drilling operations, pipe racks for temporarily
storing drill piping, pumps, power generators, tool storage, fuel storage for said generators and pumps, and
an enclosure to protect workers from inclement weather.
The Operator utilizes a "closed loop system" during drilling operations. Water used to support drilling
operations may be trucked in or piped in and temporarily stored on -site. The Operator properly handles all
drilling fluid in accordance with federal regulations. No fluid will be discharged on -site. Drilling fluid will
be disposed of offsite, in a manner approved by the COGCC. Steps for the Drilling Process are typically
as follows:
1) The drilling rig will drill vertically down to a specified depth and then horizontally to a specified
distance. This target depth usually ranges front 6,000' - 7,000' below the surface. The deepest
freshwater source is approximately 5000' shallower than the target depth of the well. The wellbore
is drilled in successive sections through the rock layers. Once the desired length of each wellborn
section has been drilled, the drilling assembly is removed, and steel casing is inserted into the
wellborn and cemented in place.
2) A typical wellbore contains surface casing and production casing strings designed to provide a
barrier that protects groundwater resources from the contents that will later flow inside the
wellbore. The Operator's standard surface casing design consists of 9 5/8" 361b/ft graded steel
casing. The Operator's standard production casing design consists of 5 'L" 20 lblft graded steel
pipe. The Operator will follow the COGCC regulations regarding wellbore integrity and testing to
ensure water aquifer protection. The Operator will adhere to all COGCC requirements for casing
setting depths necessary to protect ground water sources, and all drilling permits to ensure that
those setting depths are achieved. To ensure the protection of all freshwater resources, 9-%" steel
surface casing will be set to a depth at least fifty (50) feet below the base of the deepest aquifer in
water wells located within one mile of the surface location as required by the COGCC. The casing
will be cemented from the bottom of the pipe up to surface.
3) For each well drilled from the Location, cement is installed between the wellbore and casing pipe
and will be allowed to set. While the cement is setting, well control equipment is installed and
tested. After the cement is set and installation of well control equipment is complete, a drill bit is
run into the hole to drill the intermediate portion of the well into the potential oil and gas bearing
formations. The well will be drilled horizontally and will be turned or steered such that a curve is
achieved to approxnnately 90 degrees or parallel to the surface of the ground. The proposed
vertical depth for the each well drilled from the Location is approximately 7,000 feet below
ground level and the length of the horizontal leg being one to two (1 - 2) miles long.
4) Once the horizontal section of the wellbore is drilled, a string of production casing will be run into
the wellbore. This casing will be 5'/z inches in outer diameter and weighs 20 pounds per linear
Page 2
foot. The grade will be P110, which has a collapse rating of 11,080 psi and a burst rating of 12,640
psi. This casing will be cemented into place to isolate the productive zones of the reservoir.
5) Operator performs Bradenhead tests on all New Wells at all Location during the Drilling Phase
and then annually during the Production Phase of the well.
Once drilling operations are complete, the drilling rig is disassembled and moved offsite. At this stage,
activity stops until the "completion" of the well occurs.
Completion
Prior to and following the Completion Phase of any New Well, Operator will assess the integrity of
surrounding plugged and decommissioned wells, wells removed from use, and dry holes ("Previously
Abandoned Wells") which are located within 1,500 feet of the proposed New Well borehole.
Hydraulic Fracturing is just one portion of the completions process. There are also other minor activities
that take place on the pad before and after fracturing, such as preparing the New Well for fracturing and
cleaning the sand out afterwards. Hydraulic fracturing is a completion method that has been used since the
late 1940s.
On average, it takes less than 10 days to complete a New Well and 50-60 days to complete an eight -
well Location. Again, the proposed Pronghorn P-10 Location consists of 4 wells and should take between
25-30 days to complete. Completion operations occur 24 -hours per day on the Location. The completions
crews work in shifts, with some personnel living on -site during the entire operation. Crew size can vary
but is typically made up of about 20 people, although up to 60 people may be on -site at any time.
During hydraulic fracturing, fracturing materials, mainly sand, are brought in by truck and mixed on -site
with water and other fracturing fluids. Pursuant to the terms of the OA, and to the maximum extent
possible, the Operator will transport water onto the Location through temporary, above -ground water
supply line (not trucks) for this work.
Operator has a site -specific Water Delivery Plan and Method that has been provided to the City with this
application. All flowback water is routed to temporary frac tanks which are mobile units and trucked off -
site. These frac tanks also have secondary containment (temporary liner constructed 30-40 ml
polyurethanes and the portable containment is installed with interlocking high -density plastic panels).
The actual fracturing process uses machinery capable of driving fracturing fluid down the length of the
entire wellbore (potentially more than 17,000 feet). The fracturing fluid consists of water, proppant
(typically sand), and some chemical additives. This fracturing fluid is pumped into the well at high
pressures to crack the rock in different stages in the targeted geologic horizon.
Fracturing fluid is comprised of up to 99.5% water and sand. Small amounts of chemical additives are
necessary to reduce fluid friction, kill bacteria that are present in the water source and enhance the fluid's
ability to transport the propping agent
To start the fracturing process, the well casing must first be perforated. At predetermined and specific
intervals (stages) in the well, small perforations are made in the wellbore that allow the fracturing fluid to
pass through the steel casing and exert pressure against the rock. The force of the fluid creates tiny cracks,
or fractures, in the underground reservoir. Once fluid injection stops, pressure begins to dissipate, and the
fractures previously held open by the fluid pressure begin to close. The proppant acts as a tiny wedge to
hold these narrow fractures open, creating pathways for oil, natural gas and fracturing fluids to flow more
easily to the well.
After a stage has been hydraulically fractured, a plug is set inside the casing to isolate the stimulated
section of the wellbore. The next stage is then perforated, fractured and isolated by a plug. The entire
perforate -fracture -plug cycle is repeated at regular intervals along the targeted section of the reservoir. A
Page 3
10,000 ft. lateral in the Niobrara formation may have 40 or more discrete stages associated with a frac job.
Once all stages have been fractured, the plugs are drilled out by a coil tubing rig, or workover rig, allowing
the oil, natural gas, and fluids to flow into the well casing and up to the surface.
Flowback and Production Stages
The last stage of the completions process is known as "flowback". Flowback describes the first few days of
production from the well, after the plugs have been drilled out by a coil tubing rig or workover rig.
The well produces an emulsion of hydrocarbon, formation water and produced water from the fracturing
fluid. This emulsion flows through various pieces of temporary equipment on the surface to separate it out
into various components. The flowback water is collected in tanks and may be recycled and blended with
other water to be used at another fracturing site, or disposed of in accordance with all applicable rules,
including COGCC's. This typically means the water is transported by truck to a state -approved injection
well located outside of the City.
At the end of this stage of development, all temporary equipment is removed from the Location, leaving
only the wellhead and the permanent production facilities, including, separators, storage tanks and
emissions control equipment. New well equipment and all existing equipment at the Location will be
anchored to the extent necessary to prevent flotation, collapse, lateral movement, or subsidence in
compliance with applicable Federal Emergency Management Agency ("FEMA") (as administered by the
City) and COGCC rules and regulations. Operator's wells do not leave any anchors buried for future use.
All anchoring is done through surface anchors or removable anchoring systems during Drilling and
Completion Phases.
After drilling and completion operations conclude, the well is "put on production" and may produce for
20+ years. Operator's commitment to safe and environmentally responsible operations continues through
the entire life of each well.
Wells produce an emulsion of oil, gas and naturally occurring water. Certain equipment is needed on the
Location to separate the gas from the oil, and the oil from the water. The oil and gas are measured,
metered, and sold as they leave the Location. The separated water, or "produced water", must be disposed
of according to state and federal regulations.
The plan is for oil to be transported from the Location via pipeline in order to minimize the truck traffic
associated with production operations. Numerous engineering controls are in place to prevent or minimize
the impact of unplanned events such as spills or leaks. Until a water gathering system is constructed,
produced water will be piped, or trucked offsite. Produced water will be disposed of offsite to a state -
approved injection well, as approved by the COGCC.
Natural gas is sold through the meter and transported offsite through a gas gathering pipeline system in
accordance with COGCC regulations.
The physical dimensions of the production facilities may vary based on several factors, all of which are
covered by the OA or in OGP Process. Operator will use electricity to power most equipment on -site. A
combustion device must be available at each Location during the entire Production Phase for maintenance
or emergencies only.
The combustion device must be fired with natural gas and designed to operate with a 98% or
higher hydrocarbon destruction efficiency.
The combustion device must be designed and operated in a manner that will ensure no visible
emissions during normal operation. Visible emissions mean observations of smoke for any period
or periods of duration greater than or equal to one minute in any 15 -minute period during normal
operation, pursuant to EPA Method 22. Visible emissions do not include radiant energy or water
Page 4
vapor.
• The combustion device must always be operated with a flame present when emissions may be
vented to it, or other mechanism that does not allow uncontrolled emissions.
• All combustion devices must be equipped with an auto -igniter unless manned while in use.
No permanent facilities will be placed outside of the designated pad.
Location facilities must meet internal engineering standards, as well as operating and process integrity
requirements. The facility plans go through a PHA -Hazard Operability Study by a certified facilitator. Any
recommendations are incorporated into the design. Alarms and relief systems are regularly tested, and
personnel are trained to operate facilities responsibly. During the production phase, tanks and separation
equipment are secured to the ground using anchors engineered to resist floatation, collapse, lateral
movement, or subsidence.
To the extent flares, thermal oxidizers, or combustion devices are utilized, all such flares shall be designed
and operated in accordance with the state and federal regulations. Operator will provide a safe and secure
work environment to protect workers, our contractors and the community. Critical equipment will be
secured by lock or with a security seal to prevent unauthorized tampering with equipment. Operator will
use hard -rimmed rings at the Well Sites with sufficient capacity to contain 1.5 times the maximum volume
of the largest tank on location that such facility will contain at any given time plus sufficient freeboard to
prevent overflow around all permanent tanks. All berms and containment devices will be inspected
quarterly by Operator and maintained in good condition. No potential ignition sources will be installed
inside the secondary containment area unless the containment area encloses a fired vessel or such sources
are rated in accordance with industry codes and standards. Secondary containment such as duck ponds or
lined earthen berms for temporary tanks may also be used. Contaimnent berms will be constructed of hard -
rimmed rings, designed and installed to prevent leakage and resist degradation from erosion or routine
operation. Secondary containment for tanks will be constructed with a synthetic or 14 engineered liner that
contains all primary containment vessels and is mechanically connected to the steel ring to prevent
leakage. Well Sites will comply with the City's stormwater management requirements, including the use of
stonnwater best management practices to minimize water runoff from collecting in local waterways.
An automated safety system, governed by safety devices and a programmable logic computer, will be
installed at the Location. The automated safety system will include the installation, monitoring and remote
control of a Surface Safety Valve ("SSV") among other engineered measures and devices that are
implemented to reduce or eliminate the potential for a well event. The SSV monitors flowing pressures and
other operating parameters which have predetermined threshold values programmed and will remotely shut
the well in should certain upset conditions be detected. Additionally, the automated safety system provides
the ability to remotely shut-in welts on demand through operator remote intervention. The SSV will have
documented annual testing to ensure functionality.
During the Production Phase, Operator will maintain the Location. Debris and flammable material will be
removed from the Location and any mud tracked from the Location to public roads will be addressed.
Reclamation (Interim and Final)
Interim reclamation: will occur within three months of the first production on Well Sites situated in crop
lands, and within six months of first production for Well Sites situated in non -crop lands unless a timeline
exception is granted by the surface owner and COGCC. Interim reclamation is performed in accordance
with COGCC Rules. During this phase, portions of the Well Site that are no longer needed for production
operations are reclaimed back to their original contours and reseeded with appropriate vegetative cover.
Operator will monitor the condition of these reclaimed areas until sufficient vegetative cover is
established. The final fencing is typically installed at this time to enclose the pad area and establish the site
perimeter. The fence can serve multiple purposes including: visually screening the site from view, acting
as a security measure to deter unauthorized access by members of the public and preventing livestock from
entering the site.
Paae 5
At the end of a well's productive life which can be 20+ years, the Operator submits a Notice of
Abandonment to the COGCC. The "Final Reclamation" of the Location is dictated by multiple documents,
including COGCC Regulations, any conditions of approval associated with the City permits, the Surface
Use Agreement, and/or Oil and Gas Lease or Leases. The reclamation process is typically as follows:
Final reclamation: plans will include the appropriate surface reclamation necessary for approval from
Weld County and the COGCC. All wellbores are plugged and abandoned in accordance with COGCC
regulations and other applicable laws. At the time of fmal plugging and abandonment, all surface
equipment is removed, and the Location is graded as nearly as practicable to the natural contours.
Backfilling, leveling and recontouring is performed as soon as practicable after plugging or cessation of
production and removal of production equipment and facilities. Stockpiled topsoil is redistributed evenly
over the re -contoured surface.
The Location and any associated access roads are treated to alleviate compaction that may have occurred
during the oil and gas operations.
The reclaimed area is reseeded with the approved seed mixture specifically designed to simulate adjacent
undisturbed vegetation while maximizing utilization by both wildlife and domestic stock. The vegetation
growth is monitored at the Location until the vegetation reaches adequate density per COGCC regulations.
Page 6
Page lof1
(� eonRnzA
CHEEH
TRANSPORTATION PLAN
RESOURCES
Project
Report
County,
Location
Name:
Date:
•, Ran:e e, Section):
Pronghorn
8/10/2021
Weld
TS
N,
1.
R61W,
County,
Number
P-10
S10
CO
of Roundtrips
Region:
Field
Proposed
/ Day
Name:
Date:
Di
Wattenberg
1st
Basin
Quarter
2023
State:
Townshi
Start
Activity
Phase
Type/Roudtrips
Size Weight
Single
Unit
Truck
10,000 - 20,000 lbs
10 Average RT
Construction
Multi
Unit Truck
50,000 - 70,000 lbs
15
Average
RT
A
Passenger/Pickup
4500 - 8500
lbs 5 Average
RT
Single
Unit Truck
10,000 - 20,000 lbs
10
Average RT
Drilling
Multi
Unit Truck
50,000 - 70,000 lbs
10 Average RT
Passenger/Pickup
4500
- 8500
lbs 30 Average RT
Single
Unit
Truck
10,000 - 20,000 lbs
5 Average RT
Completions
Multi
Unit Truck
50,000 - 70,000 lbs
50 Average RT
Passenger/Pickup
4500
- 8500
lbs 40 Average RT
Single
Unit
Truck
10,000 - 20,000
lbs
1 Average
RT
Production
Multi
Unit Truck
50,000 - 70,000 Ibs
3 Average RT
Passenger/Pickup
4500 - 8500
lbs 1
Average
RT
2. Expected
Haul
Route
Route ID
Description
Traffic
will
access the
location
from west along
US
Highway
34, north
on WCR 87, continue
Route 1
north
on WCR 89, east on WCR 60
Traffic
will
access the
location
from east along
US
Highway
34, north
on WCR 87, continue
Route 2
north
on WCR 89, east on WCR 60
Traffic
will
access the
location
from
north
along
CO
Highway
392, east on WCR 68, south
on
Route 3
WCR 89, east on WCR 60
3. Travel Distribution
Route ID
Construction Drilling
Completions
Route 1
100% 50% 0%
Route 2
0% 50% 100%
Route 3
0% 0% 0%
4.
Expected
Daily Peak
Traffic Time
Peak
traffic
volumes
are expected
around
6am and 6pm when
shift
changes
occur. This
applies
for drilling
and
completions
which
run on
24
hour operations.
During construction activites, specific
traffic
peaks
are not expected at any time throughout
the
day.
Reviewed
By: Joe Schultz
Title: Project Manager
Signature:
Date: 8/10/2021
O"2:211
August 26, 2021
Oil and Gas Energy, Weld County
Attn: Jason Maxey
1301 N. 17th Ave.
Greeley, CO 80631
Re: Notice to Relevant Local Government
Pronghorn P-22
NEMNE/4 Section 22, TSN, R61W, 60' P.M.
Weld County, Colorado
Dear Director Maxey,
41017th Street, Suite 1400
Denver, CO 80202
(720)4404100 phone
(720) 305.0804 fax
The purpose of this letter is to formally notify you that in compliance with the Colorado Oil and.
Gas Conservation Commission's ("Commission") Rule 302.e., and in accordance with the Weld
County Code, Bonanza Creek Energy, Inc. ("BCEI") plans to submit the Pronghorn P-22 Oil and
Gas Development Plan ("OGDP") to the Commission on or about September 30th, 2021.
The proposed OGDP encompasses one (1) oil and gas location, described below, drilling seven (7)
wells located in the following lands:
Township 5 North. Ranee 61 West. 6th P.M.
Section 9: E2E2
Section 10: E2, W2W2
Section 14: SWSW
Section 15: E2, W2W2, S2E2SW
Section 16: E2E2, S2SW, S2W2SE
Section 17: SESE
Section 20: NENE
Section 21: N2N2
Section 22: E2, N2NW
Section 23: NWNW
BCEI anticipates beginning construction of the Pronghorn P-22 location in the fourth quarter, 2022.
The location of the proposed Oil and Gas surface is as follows:
NE14NE/4 Section 22, T5N,11.61 W, 6a' P.M.
Enclosed with this letter are the following documents:
1. BCEI Operational Guide, which outlines the anticipated date that each phase of operations
will commence by month and year, the proposed construction schedule by quarter and year,
and a description of each operational phase of development and what to expect during each
phase;
2. Pronghorn P-22 Traffic Plan, which outlines the proposed haul routes and traffic volume
associated with each phase of operations;
3. The Commission's information sheet about the procedural steps involved with the
Director's and Commission's review of Oil and Gas Development Plans;
4. The Commission's information sheet about the Commission's public comment process and
the relevant deadlines;
5. The Commission's information sheet about Hydraulic Fracturing Treatments; and
6. The Commission's information sheet about how the public may view the status of the
proposed Oil and Gas Development Plan application on the Commission's website.
To receive more information about the proposed OGDP or to ask questions about the OGDP
please contact Scott Park by email at spark r3bonanzacrk.com, or by phone at (970) 415-0778,
or by letter at 410 17'h Street, Denver, CO 80202, or the COGCC
(https://cogcc.state.co.u.s/#/home) at 303-894-2100.
Sincerely,
Scott Park
Director, EHS & RC, Operations Management
Enclosures:
BCEI Operational Guide
Traffic Plan
Commission's Information Sheets
t \eonAnzA
CREEK
41017th Street, Suite 1400
Denver. CO 88202
(720)440-6100 phone
(720) 305-0804 fax
Ocsuonslissas
BCEI Operational Guide: BCEI is a Delaware company ("Operator"), submitting this Operational Guide
to Weld County, CO outlining the anticipated timeframes that each phase of operations for the Pronghorn
P-22 project will commence following the proposed construction scheduled quarter and year, and a
description of each operational phase of development and what to expect during each phase.
Construction
Once all required permits have been issued by Weld County, CO and the Colorado Oil and Gas
Conservation Comrnission C‘COGCC"), the construction phase for Operator's Oil and Gas Location
("Location") may begin. Operator plans construction of the Pronghorn P-22 Location to be around the
Fourth Quarter of 2022. An average pad construction takes approximately 14 days. The construction
process is done during daylight hours and during ideal weather conditions such to avoid construction
inefficiencies and sediment migration from the site. This process may include equipment such as
bulldozers, scrapers, loaders, backhoes, water wagons, rollers, graders, and gravel trucks to construct the
pad and haul in the surface gravel to the Location. There are between two and ten people on -site during
this phase of work. The pad location will be completed prior to the arrival of drilling rig. Steps for pad
construction are typically as follows:
1) Installation of perimeter storntwater BMPs pursuant to the approved SWMP, COGCC, Weld
County and CDPHE stormwatcr requirements.
2) Existing vegetation is cleared, and the topsoil is stripped. No burning of debris occurs.
3) Topsoil and spoil piles are clearly separated to ensure preservation of the topsoil for final site
reclamation.
4) Once the basic grading is complete to level the well pad, establish drainage diiches, and spoils and
topsoil stockpiles separated, gravel is hauled in to provide a stable surface for oil and gas
operations. Gravel hauling generates heavy traffic, but generally only lasts a few days, and is more
detailed in Operator's Traffic Plan (also attached).
5) A portion of the well site is then constructed with the permanent production facilities in mind. This
area is located away from the planned wellheads to abide by numerous safety standards set by the
Operator, the COGCC and the American Petroleum Institute. This work may occur
simultaneously to drilling and completion operations.
6) All disturbed ground not needed for subsequent operations, including stockpiles and cut and fill
slopes, are seeded and mulched in accordance with Operator's approved permits!.
7) If necessary a perimeter fence is constructed to establish the well pal boundary, usia livestock and
deter the public from entering the Location.
8) Cattle guards may be installed at the Location entrance, in addition to a locking gate. This
perimeter fence will generally remain in place until after interim reclamation (as defaced by the
COGCC) has been performed, and all disturbed areas have re-established vegetation. Any
additional fencing requirements under the OA will be installed after interim reclamation occurs.
9) The Well Site is left in a stable condition, ready for the rig.
si
41017y' Stye; Suite 1.
Dn'liime
Following pad construction, a drill rig will be brought to the well pad, and will begin drilling each of the
Pronghorn P-22 wells. Drilling rig operations are 24 hours per day, and Operator's drilling personnel work
in shifts, with some that stay on -site during the entire operation for safety purposes. The crew size can
range from approximately 25 to 40 people at any given time. The Operator will conduct drilling operations
in compliance with all County, State, and Federal rules and regulations. Drilling a single well will typically
take between 5-10 days. The Pronghorn P-22 proposed plan contains 7 wells, therefore the drilling
timeframe range will be between 35-70 days.
Multi -well Sites take longer to drill than a single -well Well Site but yield a smaller overall disturbance
than drilling multiple single -well Well Sites. There will be a period of increased traffic prior to the rig
arriving and while the rig moves off to the next Location.
Standard operations equipment on the Location during the drilling phase consists of a drilling rig at the
center of the pad along with water storage to be used in the drilling operations, pipe racks for temporarily
storing drill piping, pumps, power generators, tool storage, fuel storage for said generators and pumps, and
an enclosure to protect workers from inclement weather.
The Operator utilizes a "closed loop system" during drilling operations. Water used to support drilling
operations may be trucked in or piped in and temporarily stored on -site. The Operator properly handles all
drilling fluid in accordance with federal regulations. No fluid will be discharged on: site; Drilling fluid will
be disposed of offsite, in a manner approved by the COGCC. Steps for the Drilling Process are typically
as follows.
1) The drilling rig will drill vertically down to a specified depth and then horizontally to a specified
distance. This target depth usually ranges front 6,000' - 7,000' below the surface. The deepest
freshwater source is approximately 5000' shallower than the target depth of the well. The wellbore
is drilled in successive sections through the rock layers. Once the desired length of each wellbore
section has been drilled, the drilling assembly is removed, and steel casing is inserted into the
wellbore and cemented in place.
2) A typical wellbore contains surface casing and production casing strings designed to provide a
barrier that protects groundwater resources from the contents that will later flow inside the
wellbore, The Operator's standard surface casing design consists of 9 518" 36 lb/ft graded steel
casing. The Operator's standard production casing design consists of 5'/A" 20 lb/ft graded steel
pipe. The Operator will follow the COGCC regulations regarding wellbore integrity and testing to
ensure water aquifer protection. The Operator will adhere to all COGCC requirements for casing
setting depths necessary to protect ;ground water sources, and all drilling permits to ensure that
those setting depths are achieved. To ensure the protection of all freshwater resources, 9-=%" steel
surface casing will be set to a depth at least fifty (50) feet below the base of the deepest aquifer in
water wells located within one mile of the surface location as required by the COGCC. The casing
will be cemented from the bottom of the pipe up to surface.
3) For each well drilled from the Location, cement is installed between the wellbore and casing pipe
and will be allowed to set. While the cement is setting, well control equipment is installed and
tested. After the cement is set and installation of well control equipment is complete, a drill bit is
run into the hole to drill the intermediate portion of the well into the potential oil and gas bearing
formations. The well will be drilled horizontally and will be turned or steered such that a curve is
achieved to approximately 90 degrees or parallel to the surface of the ground. The proposed
vertical depth far the each well drilled from the Location is approximately 7,000 feet below
ground level and the length of the horizontal leg being one to two (1 - 2) miles long.
4) Once the horizontal section of the wellbore is chilled, a string of production casing will be run into
the wellbore. This casing will be 5i4 inches in outer diameter and weighs 20 pounds per linear
Page 2
foot The grade will be P110, which has a collapse rating of 11,080 psi and a burst rating of 12,640
psi. This casing will be cemented into place to isolate the productive zones of the reservoir,
5) Operator performs flradenhead tests on all New Wells at all Location during the Drilling Phase
and then annually during the Production Phase of the well.
Once drilling operations are complete, the drilling rig is disassembled and moved offsite. At this stage,
activity stops until the "completion" of the well occurs.
Completion
Prior to and following the Completion Phase of any New Well, Operator will assess the integrity of
surrounding plugged and decommissioned wells, wells removed from use, and dry holes ("Previously
Abandoned Wells") which are located within 1,500 feet of the proposed New Well borehole.
Hydraulic Fracturing is just one portion of the completions process. There are also other mince` activities
that take place on the pad before and after fracturing, such as preparing the New Well for fracturing and
cleaning the sand out aftenvards. Hydraulic fracturing is a completion method that has been used since the
late 1940s.
On average, it takes less than 10 days to complete a New Well and approximately 50-60 days to
complete an eight -well Location. Again, the proposed Pronghorn P-22 Location consists of 7 wells and
should take between the above mentioned 44-53 days to complete. Completion operations occur 24 -hours
per day on the Location. The completions crews work in shifts, with some personnel living on -site during
the entire operation. Crew size can vary but is typically made up of about 20 people, although up to 60
people may be on -site at any time.
During hydraulic fracturing, fracturing materials, mainly sand, are brought in by truck and mixed on -site
with water and other fracturing fluids. Pursuant to the terms of the OA, and to the maximum extent
possible, the Operator will transport water onto the Location through temporary, above -ground water
supply line (not trucks) for this work.
Operator has a site -specific Water Delivery Plan and Method that has been provided to the City with this
application* All flowback water is routed to temporary frac tanks which are mobile units and trucked off -
site. These frac tanks also have secondary containment (temporary liner constructed 30-40 ml
polyurethanes and the portable containment is installed with interlocking high -density plastic panels).
The actual fracturing process uses machinery capable of driving fracturing fluid down the length ofthe
entire wellbore (potentially more than 17,000 feet). The fracturing fluid consists of water, proppant
(typically sand), and some chemical additives. This fracturing fluid is pumped into the well at high
pressures to crack the rock in different stages in the targeted geologic horizon.
Fracturing fluid is comprised of up to 99.5% water and sand. Small amounts of chemical additives are
necessary to reduce fluid friction, kill bacteria that are present in the water source and enhance the fluid's
ability to transport the propping agent
To start the fracturing process, the well casing must first be perforated. At predetermined and specific
intervals (stages) in the well, small perforations are made in the wellbore that allow the fracturing fluid to
pass through the steel casing and exert pressure against the rock. The force of the fluid creates tiny cracks,
or fractures, in the underground reservoir. Once fluid injection stops, pressure begins to dissipate, and the
fractures previously held open by the fluid pressure begin to close. The proppant acts as a tiny wedge to
hold these narrow fractures open, creating pathways for oil, natural gas and fracturing fluids to flow more
easily to the well
After a stage has been hydraulically fractured, a plug is set inside the casing to isolate the stimulated
section of the wellbore. The next stage is then perforated, fractured and isolated by a plug. The entire
Page 3
perforate -fracture -plug cycle is repeated at regular intervals along the targeted section of the reservoir. A
10,000 ft. lateral in fire Niobrara formation may have 40 or more discrete stages associated with a frac job,
Once all stages have been fractured, the plugs are drilled ottt by a coil tubing rig, or workover rig, allowing.
the oil, natural gas, and fluids to flow into the well casing and up to the surface.
Flowback and Production Stares
The last stage of the completions process is known as "fowback". Plowbaek describes the rust few days of
production from the well, after the plugs have been drilled out by a coil tubing rigor workover rig.
The well produces an emulsion of hydrocarbon, formation water and produced water from the fracturing
fluid. This emulsion flows through various pieces of temporary equipment on the surface to separate it out
into various components. The flowback water is collected in tanks and may be recycled and blended with
other water to be used at another fracturing site, or disposed of in accordance with all applicable rules,
including COClCC's. This typically means the water is transported by truck to a state -approved injection
well located outside of the City.
At the end of this stage of development, all temporary equipment is removed from the Location, leaving
only the wellhead and the permanent production facilities, including, separators, storage tanks and
emissions control equipment New well equipment and all existing equipment at the location will be
anchored to the extent necessary to prevent flotation, collapse, lateral movement, or subsidence in
compliance with applicable Federal Emergency Management Agency (" MA") (as administered by the
City) and COGCC rules and regulations. Operator's wells do net leave any anchors buried for future use.
All anchoring is done throws surface anchors or removable anchoring systems during Drilling and
Completion Phases.
After drilling and completion operations conclude, the well is "put on production" and may produce for
20+ years. Operator's commitment to safe and environmentally responsible operations continues through
the entire life of each well.
Wells produce an emulsion of oil, gas and naturally occurring water. Certain equipment is needed on the
Location to separate the gas from the oil, and the oil from the water. The oil and gas are measured,
metered, and sold as they leave the Location. The separated water, or "produced water", must be disposed
of according to state and federal regulations.
The plan is for oil to be transported from the Location via pipeline in order to minimize the truck traffic
associated with production operations. Numerous engineering controls are in place to prevent or minimize
the impact of unplanned events such as spills or leaks. Until a water gathering system is constructed,
produced water will be piped, or trucked offsite. Produced water will be disposed of offsite to a state -
approved injection well, as approved by the COGCC.
Natural gas is sold through the meter and transported offsite through a gas gathering pipeline system in
accordance with COGCC regulations.
The physical dimensions of the production facilities may vary based on several factors, all of which are
covered by the OA or in OGP Process. Operator will use electricity to power most equipment on -site. A
combustion device must be available at each Location during the entire Production Phase for maintenance
or emergencies only.
• The combustion device must be fired with natural gas and designed to operate with a 9t% or
higher hydrocarbon destruction efficiency.
• The combustion device must be designed and operated in a manner that will ensure no visible
emissions during normal operation. Visible emissions mean observations of smoke for any period
or periods of duration greater than or equal to one minute in any 15 -minute period during normal
Page 4
operation, pursuant to EPA Method 22. Visible emissions do not include radiant energy or water
vapor,
• The combustion device must always be operated with a flame present when emissions maybe
vented to it, or other mechanism that does not allow uncontrolled emissions.
All combustion devices must be equipped with an auto -igniter unless manned while in use.
No permanent facilities will be placed outside of the designated pad.
Location facilities must meet internal engineering standards, as well as operating and process integrity
requirements. The facility plans go through a PHA -Hazard Operability Study by a certified facilitator. Any
recommendations are incorporated into the design. Alarms and relief systems are regularly tested, and
personnel are trained to operate facilities responsibly. During the production phase, tanks and separation
equipment are secured to the ground using anchors engineered to resist floatation, collapse, lateral
movement, or subsidence,
To the extent flares, thermal oxidizers, or combustion devices are utilized, all such flares shall be designed
and operated in accordance with the state and federal regulations. Operator will provide a safe and secure
work environment to protect workers, our contractors and the community. Critical equipment will be
secured by lock or with a security seal to prevent unauthorized tampering with equipment. Operator will
use hard -rimmed rings at the Well Sites with sufficient capacity to contain 1.5 times the maximum volume
of the largest tank on location that such facility will contain at any given time plus sufficient freeboard to
prevent overflow around all permanent tanks. All berms and containment devices will be inspected
quarterly by Operator and maintained in good condition. No potential ignition sources will be installed
inside the secondary containment area unless the containment area encloses a fired vessel or such sources
are rated in accordance with industry codes and standards. Secondary containment such as duck ponds or
lined earthen berms for temporary tanks may also ho used. Containment berms will be constructed of hard -
rimmed rings, designed and installed to prevent leakage and resist degradation from erosion or routine
operation. Secondary containment for tanks will be constructed with a synthetic or 14 engineered liner that
contains all primary containment vessels and is mechanically connected to the steel ring to prevent
leakage. Well Sites will comply with the City's storrnwater management requirements, including the use of
stormwater best management practices to minimize water runoff from collecting in local waterways.
An automated safety system, governed by safety devices and a programmable logic computer, will be
installed at the Location. The automated safety system will include the installation, monitoring and remote
control of a Surface Safety Valve ("SSV among other engineered measures and devices that are
implemented to reduce or eliminate the potential fora well event. The SSV monitors flowing pressures and
other operating parameters which have predetermined threshold values programmed and will remotely shut
the well in should certain upset conditions be detected. Additionally, the automated safety system provides
the ability to remotely shut-in wells on demand through operator remote intervention. The SSV will have
documented annual testing to ensure functionality.
During the Production Phase, Operator will maintain the Location. Debris and flammable material will be
removed from the Location and any mud tracked from the Location to public roads will be addressed.
Reclamation (Interim and Rinall
Interim reclamation: will occur within three months of the first production on Well Sites situated in crop
lands, and within six months of first production for Well Sites situated in non -crop lands unless a timeline
exception is granted by the surface owner and COGCC. Interim reclamation is performed in accordance
with COGCC Rules. During this phase, portions of the Well Site that are no longer needed for production
operations are reclaimed back to their original contours and reseeded with appropriate vegetative cover.
Operator will monitor the condition of these reclaimed areas until sufficient vegetative cover is
established. The final fencing is typically installed at this time to enclose the pad area and establish the site
perimeter. The fence can serve multiple purposes including: visually screening the site from view, acting
as a security measure to deter unauthorized access by members of the public and preventing livestock from
Pap 5
entering the site.
At the end of a well's productive life which can be 20+ years, the Operator submits a Notice of
Abandonment to the COGCC. The "Final Reclamation" of the Location is dictated by multiple documents,
including COGCC Regulations, any conditions of approval associated with the City permits, the Surface
Use Agreement, and/or Oil and Gas Lease or Leases. The reclamation process is typically as follows:
Final reclamation: plans will include the appropriate surface reclamation necessary for approval from
Weld County and the COGCC. All wellbores are plugged and abandoned in accordance with COGCC
regulations and other applicable laws, At the time of final plugging and abandonment, all surface
equipment is removed, and the Location is graded as nearly as practicable to the natural contours.
Backfilling, leveling and recontauring is performed as soon as practicable after plugging or cessation of
production and removal of production equipment and facilities, Stockpiled topsoil is redistributed evenly
over the re -contoured surface.
The Location and any associated access roads are treated to alleviate compaction that may have occurred
during the oil and gas operations.
The reclaimed area is reseeded with the approved seed mixture specifically designed to simulate adjacent
undisturbed vegetation while maximizing utilization by both wildlife and domestic stock. The vegetation
growth is monitored at the Location until the vegetation reaches adequate density per COGCC regulations.
Page 6
Page 1of1
B0000IN
CREEN
TRANSPORTATION PLAN
oRPG
rt RE URGES
Basin
Project
Report
County,
Name:
Date:
State:
Pronghorn
8/14/2021
Weld
County,
P-22
CO
Region:
Field
Proposed
Name:
Start
Date:
Di
Wattenberg
4th
Quarter
2022
Location
Townshi • Ran: e Section
: TSN,
R61W,
1.
Number
522
of Roundtrips
/
Day
Activity
Phase
Type/Roudtrips
Size
Weight
Construction
Single
Passenger/Pickup
Multi
Unit
Unit
Truck
Truck
10,000
50,000
4500
- 20,000
- 70,000
- 8500
lbs
lbs
lbs
10
15
5
Average
Average
Average
RT
RT
RT
Drilling
Single
Passenger/Pickup
Multi
Unit
Unit
Truck
Truck
10,000
50,000
4500
- 20,000
- 70,000
- 8500
lbs
lbs
Ibs
10
10
30
Average
Average
Average
RT
RT
RT
Completions
Single
Multi
Unit
Unit
Truck
Truck
10,000
50,000
- 20,000
- 70,000
lbs
lbs
S
SO
Average
Average
RT
RT
Passenger/Pickup
4500
- 8500
Ibs
40
Average
RT
Production
Single
Passenger/Pickup
Multi
Unit
Unit
Truck
Truck
10,000
50,000
4500
- 20)000
- 70,000
- 8500
Ibs
lbs
lbs
1
3
1
Average
Average
Average
RT
RT
RT
2.
Expected
Haul
Route
Route
ID
Description
Route
1
Traffic
will
access
the
location
f rom ,=.pest
along
US
Highway
34, north
on WCR
87, continue
north
on, 'MICR
89,
east
on
WCR
56
Route 2
Traffic
will
access
the
location
north
from
east
on'NCR
along
89,
east
U5
Highway
on
MICR
34, north
56
on WCR
87, continue
Route 3
Traffic
will
access
the
location
from north
along
CD
Higinr.►ay
392, east
on i+'CR
68, south
on
WCR
89, east on
WCR
56
3.
Travel
Distribution
Route
ID
Construction
Drilling
Completions
Route 1
Route 2
0%
50
100%
Route 3
4. Expected
Daily
Peak
Traffic
Time
Peak
traffic
volumes
are expected
around
6at
and
6pm
when
shift
changes
occur.
This
applies
for drilling
and
completions
which
run on
24
hour operations.
During construction
actMtes,
.specific
traffic
peaks
are not expected
at
any
time throughout
the
day.
Reviewed
Signature:
fiy:
Joe Schultz
Title:
Date:
Project
8/10/2021
Manager
��eonpnzA
CREEK
August 26, 2021
Oil and Gas Energy, Weld County
Attn: Jason Maxey
1301 N. 17tH Ave.
Greeley, CO 80631
Re: Notice to Relevant Local Government
Pronghorn T-4
SENSE/4 Section 4, TSN, R61W, 6th P.M.
Weld County, Colorado
Dear Director Maxey,
410 17th Street, Suite 1400
Denver. CO 802202
(120) 404100 phone
(720) 305-0804 fax
The purpose of this letter is to formally notify you that in compliance with the Colorado Oil and
Gas Conservation Commission's ("Commission") Rule 302.e., and in accordance with the Weld
County Cade, Bonanza Creek Energy, Inc. ("BCEI") plans to submit the Pronghorn T-4 Oil and
Gas Development Plan ("OODP" ) to the Commission on or about September 30th, 2021.
The proposed OGD? encompasses one (1) oil and gas location, described below, drilling seven (7)
wells located in the following lands:
Township S North. Ranee 61 West. Gtr P.M.
Section 3: W2W2
Section 4: ALL
Section 9: ALL
Section 10: NWNW
Township 6 North, Ranee 61 West. 6h P.M.
Section 27: SWSW
Section 28:12S2
Section 33: ALL
Section 34: W2W2
BCEI anticipates beginning construction of the Pronghorn T-4 location in the first quarter, 2024.
The location of the proposed Oil and Gas surface is as follows:
SE/4SE/4 Section 4, TSN, R61W, Eta P.M.
Enclosed with this letter are the following documents:
1. BCEI Operational Guide, which outlines the anticipated date that each phase of operations
will commence by month and year, the proposed construction schedule by quarter and year,
and a description of each operational phase of development and what to expect during each
phase;
2. Pronghorn T-4 Traffic Plan, which outlines the proposed haul routes and traffic volume
associated with each phase of operations;
3. The Commission's information sheet about the procedural steps involved with the
Director's and Commission's review of Oil and Gas Development Plans;
4. The Commission's information sheet about the Commission's public comment process and
the relevant deadlines;
5. The Commission's information sheet about Hydraulic Fracturing Treatments; and
6. The Commission's information sheet about how the public may view the status of the
proposed Oil and Gas Development Plan application on the Commission's website.
To receive more information about the proposed OGDP or to ask questions about the OGDP
please contact Scott Park by email at spark@bonanzacrk.com, or by phone at (970) 415-0778,
or by letter at 410 17th Street, Denver, CO 80202, or the COGCC
(https://cogcc.state.co.usfitibome) at 303-894-2100.
Sincerely,
Scott Park
Director, EHS & RC, Operations Management
Enclosures:
BCEI Operational Guide
Traffic Plan
Commission's Information Sheets
Page 2
�SeonpnzR
CREEK
410 17th Street, Suite 1400
Denver, CO 80₹02
(720) 440-8100 phone
(720) 3050804 fax
finnan acrk u+tn
BCEI Operational Guide: BCEI is a Delaware company ("Operator"), submitting this Operational Guide
to Weld County, CO outlining the anticipated timeframes that each phase of operations for the Pronghorn
T-4 project will commence following the proposed construction scheduled quarter and year, and a
description of each operational phase of development and what to expect during each phase.
Construction
Once all required permits have been issued by Weld County, CO and the Colorado Oil and Gas
Conservation Commission ("COGCC"), the construction phase for Operator's Oil and Gas Location
("Location") may begin. Operator plans construction of the Pronghorn T-4 Location to be around the First
Quarter of 2024, An average pad construction takes approximately 14 days, The construction process is
done during daylight hours and during ideal weather conditions such to avoid construction inefficiencies
and sediment migration from the site. This process may include equipment such as bulldozers, scrapers,
loaders, backhoes, water wagons, rollers, graders, and gravel trucks to construct the pad and haul in the
surface gravel to the Location. There are between two and ten people on -site during this phase of work.
The pad location will be completed prior to the arrival of a drilling rig. Steps for pad construction are
typically as follows:
1) Installation of perimeter stormwater BMPs pursuant to the approved SWMP, COGCC, Weld
County and CDPFIE stormwater requirements.
2) Existing vegetation is cleared, and the topsoil is stripped. No burning of debris occurs.
3) Topsoil and spoil piles are clearly separated to ensure preservation of the topsoil for fmal site
reclamation.
4) Once the basic grading is complete to lever the well pad, establish drainage ditches, and spoils and
topsoil stockpiles separated, gravel is hauled in to provide a stable surface for oil and gas
operations. Gravel hauling generates heavy traffic, but generally only lasts a few days, and is more
detailed in Operator's Traffic Plan (also attached).
5) A portion of the well site is then constructed with the permanent production facilities in mind. This
area is located away from the planned wellheads to abide by numerous safety standards set by the
Operator, the COGCC and the American Petroleum Institute. This work may occur
simultaneously to drilling and completion operations.
6) All disturbed ground not needed for subsequent operations, including stockpiles and cut and fill
slopes, are seeded and mulched in accordance with Operator's approved permits.
7) If necessary a perimeter fence is constructed to establish the well pad boundary, turn livestock and
deter the public from entering the Location.
8) Cattle guards maybe installed at the Location entrance, in addition to a locking gate. This
perimeter fence will generally remain in place until after interim reclamation (as defined by the
COGCC) has been performed, and all disturbed areas have re-established vegetation. Any
additional fencing requirements under the OA will be installed after interim reclamation occurs.
9) The Well Site is left in a stable condition, ready for the rig.
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In irk, Suf.,.
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Following pad construction, a drill rig will be brought to the well pad, and will begin drilling each of the
Pronghorn T-4 wells. Drilling rig operations are 24 hours per day, and Operator's drilling personnel work
in shifts, with some that stay on -site during the entire operation for safety purposes. The crew size can
range from approximately 25 to 40 people at any given time. The Operator will conduct drilling operations
in compliance with all County, State, and Federal rules and regulations. Drilling a single well will typically
take between 5-i0 days. The Pronghorn T'-4 proposed plan contains 7 wells, therefore the drilling
timeframe range will be between 35-70 days.
Multi -well Sites take longer to drill than a single -well Well Site but yield a smaller overall disturbance
than drilling multiple single -well Well Sites. There will be a period of increased traffic prior to the rig
arriving and while the rig moves off to the next Location..
Standard operations equipment on the Location during the drilling phase consists of a drilling rig at the
center of the pad along with water storage to be used in the drilling operations, pipe racks for temporarily
storing drill piping, pumps, power generators, tool storage, fuel storage for said generators and pumps, and
an enclosure to protect workers from inclement weather.
The Operator utilizes a "closed loop system" during drilling operations. Water used to support drilling
operations may be trucked in or piped in and temporarily stored on -site. The Operator properly handles all
drilling fluid in accordance with federal regulations. No fluid will be discharged on -site. Drilling fluid will
be disposed of offsite, in a manner approved by the COGCC. Steps for the Drilling Process are typically
as follows:
1) The drilling rig will drill vertically down to a specified depth and then horizontally to a specified
distance. This target depth usually ranges from 6,000' - 7,000' below the surface. The deepest
freshwater source is approximately 5000' shallower than the target depth of the well. The wellbore
is drilled in successive sections through the rock layers. Once the desired length of each wellbore
section has been drilled, the drilling assembly is removed, and steel casing is inserted into the
wellbore and cemented in place.
2) A typical wellbore contains surface casing and production casing strings designed to provide a
barrier that protects groundwater resources from the contents that will later flow inside the
wellbore. The Operator's standard surface casing design consists of 9 5/8" 36 lb/ft graded steel
casing. The Operator's standard production casing design consists of 5 '/i" 20 lb/ft graded steel
pipe. The Operator will follow the COGCC regulations regarding wellbore integrity and testing to
ensure water aquifer protection. The Operator will adhere to all COGCC requirements for casing
setting depths necessary to protect wound water sources, and all drilling permits to ensure that
those setting depths are achieved. To ensure the protection of all freshwater resources, 9-%" steel
surface casing will be set to a depth at least fitly (50) feet below the base of the deepest aquifer in
water wells laded within one mile of the surface location as required by the COGCC. The casing
will be cemented from the bottom of the pipe up to surface.
3) For each well drilled from the Location, cement is installed between the wellbore and ding pipe
and will be allowed to set. While the cement is setting, well control equipment is installed and
tested. After the cement is set and installation of well control equipment is complete, a drill bit is
run into the hole to drill the intermediate portion of the well into the potential oil and gas bearing
formations. The well will be drilled horizontally and will be turned or steered such that a curve is
achieved to approximately 90 degrees or parallel to the surface of the ground. The proposed
vertical depth for the each well drilled from the Location is approximately 7,000 feet below
ground level and the length of the horizontal leg being one to two (1 - 2) miles long.
4) Once the horizontal section of the wellbore is drilled, a string of production casing will be run into
the wellbore. This casing will be 514 inches in outer diameter and weighs 20 pounds per linear
Paget
foot. The grade will be P110, which has a collapse rating of 11,080 psi and a burst rating of 12,649
psi. This casing will be cemented into place to isolate the productive zones of the reservoir.
5) Operator performs Bradenhead tests on all New Wells at all Location during the Drilling Phase
and then annually during the Production Phase of the well.
Once drilling operations are complete, the drilling rig is disassembled and moved offsite. At this stage,
activity stops until the "completion" of the well occurs.
Completion
Prior to and following the Completion Phase of any New Well, Operator will assess the integrity of
surrounding plugged and decommissioned wells, wells removed from use, and dry holes ("Previously
Abandoned Wells") which are located within 1,500 feet of the proposed New Well borehole.
Hydraulic Fracturing is just one portion of the completions process. There are also other minor activities
that take place on the pad before and after fracturing, such as preparing the New Well for fracturing and
cleaning the sand out afterwards. Hydraulic fracturing is a completion method that has been used since the
late 1940s.
On average, it takes less than 14 days to complete a New Well and approximately 50-6(1 days to
complete an eight -wen Location. Again, the proposed Pronghorn T-4 Location consists of 7 wells and
should take between the above mentioned 44-53 day=s to complete< Completion operations occur 24 -hours
per day on the Location. The completions crews work in shifts, with some personnel living on -site during
the entire operation. Crew size can vary but is typically made up of about 20 people, although up to 60
people may be on -site at any time.
During hydraulic fracturing, fracturing materials, mainly sand, are brought in by truck and mixed on -site
with water and other fracturing fluids. Pursuant to the terms of the OA, and to the maximum extent
possible, the Operator will transport water onto the Location through temporary, above -ground water
supply line (not trucks) far this work.
Operator has a site -specific Water Delivery Plan and Method that has been provided to the City with this
application. All flowback water is routed to temporary frac tanks which are mobile units and trucked off -
site. These frac tanks also have secondary containment (temporary liner constructed 30-40 ml
polyurethanes and the portable containment is installed with interlocking high -density plastic panels).
The actual fracturing process uses machinery capable of driving fracturing fluid down the length of the
entire wellbore (potentially more than 17,000 feet). The fracturing fluid consists of water, proppant
(typically sand), and some chemical additives. This fracturing fluid is pumped into the well at high
pressures to crack the rock in different stages in the targeted geologic horizon.
Fracturing fluid is comprised of up to 99.5% water and sand. Small amounts of chemical additives are
necessary to reduce fluid friction, kill bacteria that are present in the water source and enhance the fluid's
ability to transport the propping agent
To start the fracturing process, the well casing must fast be perforated. At predetermined and specific
intervals (stages) in the well, small perforations are made in the wellbore that allow the fracturing fluid to
pass through the steel casing and exert pressure against the rock. The force of the fluid creates tiny cracks,
or fractures, in the underground reservoir. Once fluid injection stops, pressure begins to dissipate, and the
fractures previously held open by the fluid pressure begin to close. The proppant acts as a tiny wedge to
hold these narrow fractures open, creating pathways for oil, natural gas and fracturing fluids to flow more
easily to the well.
After a stage has been hydraulically fractured, a plug is set inside the casing to isolate the stimulated
section of the wellbore. The next stage is then perforated, fractured and isolated by a plug. The entire
Pasta
perforate -fracture -plug cycle is repeated at regular intervals along the targeted section of the reservoir. A
10,0011 ft. lateral in the Niobrara formation may have 40 or more discrete stages associated with a frac job.
Once all stages have been fractured, the plugs are drilled out by a coil tubing rig, or workaver rig, allowing
the oil, natural gas, and fluids to flow into the well casing and up to the surface.
Flowback and Production Staves
The last stage of the completions process is known as "flowback". Flowiback descry the first few days of
production from the well, after the plugs have been drilled out by a coil tubing rig or worknver rig.
The well produces an emulsion of hydrocarbon, formation water and produced water from the fracturing
fluid. This emulsion flows through various pieces of temporary equipment on the surface to separate it out
into various components. The flowback water is collected in tanks and maybe recycled and blended with
other water to be used at another fracturing site, or disposed of in accordance with all applicable rules,
including COGCC's. This typically means the water is transported by truck to a state -approved injection
well located outside of the City.
At the end of this stage of development, all temporary equipment is removed from the Location, leaving
only the wellhead and the permanent production facilities, including, separators, storage tanks and
emissions control equipment. New well equipment and all existing equipment at the Location will be
anchored to the extent necessary to prevent flotation, collapse, lateral movement, or subsidence in
compliance with applicable Federal Emergency Management Agency ("FEMA°') (as administered by the
City) and COGCC rules and regulations. Operator's wells do not leave any anchors buried for future use.
All anchoring is done through surface anchors or removable anchoring systems during Drilling and
Completion Phases.
After drilling and completion operations conclude, the well is "put on production" and may produce for
20, years. Operator's commitment to safe and environmentally responsible operations continues through
the entire life of each well.
Wells produce an emulsion of oil, gas and naturally occurring water. Certain equipment is needed on the
Location to separate the gas from the oil, and the oil from the water. The oil and gas are measured,
metered, and sold as they leave the Location. The separated water, or "produced water", must be disposed
of according to state and federal regulations.
The plan is for oil to be transported from the Location via pipeline in order to minimize the truck traffic
associated with production operations. Numerous engineering controls are in place to prevent or minimize
the impact of unplanned events such as spills or leaks. Until a water gathering system is constructed,
produced water will be piped, or trucked offsite. Produced water will be disposed of offsite to a state -
approved injection well, as approved by the COCC.
Natural gas is sold through the teeter and transported offsite through a gas gathering pipeline system in
accordance with COGCC regulations.
The physical dimensions of the production facilities may vary based on several factors, all of which are
covered by the OA or in OGP Process. Operator will use electricity to power most equipment on -site. A
combustion device must be available at each Location during the entire Production Phase for maintenance
or emergencies only.
• The combustion device must be fired with natural gas and designed to operate with a 98% or
higher hydrocarbon destruction efficiency.
• The combustion device must be designed and operated in a manner that will ensure no visible
emissions during normal operation. Visible emissions mean observations of smoke for any period
or periods of duration greater than or equal to one minute in any 15-minrite period during normal
Page 4
operation, pursuant to EPA Method 22. Visible emissions do not include radiant energy or water
vapor;
The combustion device must always be operated with a flame present when emissions may be
vented to it, or other mechanism that does not allow tmcontrolled emissions.
All combustion devices must be equipped with an auto -igniter unless manned while in use.
No permanent facilities will be placed outside of the designate pad.
Location facilities must meet internal engineering standards, as well as operating and process integrity
requirements. The facility plans go through a PHA -Hazard Operability Study by a certified facilitator. Any
recommendations are incorporated into the design. Alarms and relief systems are regularly tested, and
personnel are trained to operate facilities responsibly. During the production phase, tanks and separation
equipment are secured to the ground using anchors engineered to resist floatation, collapse, lateral
movement, or subsidence.
To the extent flares, thermal oxidizers, or combustion devices are utilized, all such flares shall be designed
and operated in accordance with the state and federal regulations. Operator will provide a safe and secure
work environment to protect workers, our contractors and the community. Critical equipment will be
secured by lock or with a security seal to prevent unauthorized tampering with equipment. Operator will
use hard -rimmed rings at the Well Sites with sufficient capacity to contain 1.5 times the maximum volume
of the largest tank on location that such facility will contain at any given time plus sufficient freeboard to
prevent overflow around all permanent tanks. All berms and containment devices will be inspected
quarterly by Operator and maintained in good condition. No potential ignition sources will be installed
inside the secondary containment area unless the containment area encloses a fired vessel or such sources
are rated in accordance w≥tlu industry codes and standards. Secondary containment such as duck ponds or
lined earthen berms for temporary tanks may also be used. Containment berms will be constructed of hard -
rimmed rings, designed and installed to prevent leakage and resist degradation from erosion or routine
operation. Secondary containment for tanks will be constructed with a synthetic or 14 engineered liner that
contains all primary containment vessels and is mechanically connected to the steel ring to prevent
leakage. Well Sites will comply with the City's stonmwater management requirements, including the use of
stormwater best management practices to minimize water runoff from collecting in local waterways.
An automated safety system, governed by safety devices and a programmable logic computer, will be
installed at the Location. The automated safety system will include the installation, monitoring and remote
control of a Surface Safety Valve ("SSV") among other engineered measures and devices that are
implemented to reduce or eliminate the potential for awell event. The SSV monitors flowing pressures and
other operating parameters which have predetermined threshold values programmed and will remotely shut
the well in should certain upset conditions be detected. Additionally, the automated safety system provides
the ability to remotely shut-in wells on demand through operator remote intervention. The SSV will have
documented annual testing to ensure functionality.
During the Production Phase, Operator will maintain the Location. Debris and flammable material will be
removed from the Location and any mud tracked from the Location to public roads will be addressed.
Reclamation (Interim and Final)
Interim reclamation: will occur within three months of the first production on Well Sites situated in crop
lands, and withinsix months of first production for Well Sites situated in non -crop lands unlessa timeline
exception is granted by the surface owner and COGCC. Interim reclamation is performed in accordance
with COOCC Rules. During this phase, portions of the Well Site that are no longer needed for production
operations are reclaimed back to their original contours and reseeded with appropriate vegetative c -over.
Operator will monitor the condition of these reclaimed areas until sufficient vegetative cover is
established. The final fencing is typically installed at this time to enclose the pad area and establish the site
perimeter. The fence can serve multiple purposes including: visually screening the site from view, acting
as a security measure to deter unauthorized access by members of the public and preventing livestock from
Page 5
entering the site.
At the end of a well's productive life which can be 2U+ years, the Operator submits a Notice of
Abandonment to the COGCC. The "Final Reclamation" of the Location is dictated by multiple decwnents,
including COGCC Regulations, any conditions of approval associated with the City permits, the Surface
Use Agreement, and/or Oil and Gas Lease or Leases. The reclamation process is typically as follows:
Final reclamation: plans will include the appropriate surface reclamation necessary for approval frown
Weld County and the COGCC. All wellbores are plugged and abandoned in accordance with COGCC
regulations and other applicable laws. At the time of final plugging and abandonment, all surface
equipment is removed, and the Location is graded as nearly as practicable to the natural contours.
Backfilling, leveling and recontouring is performed as soon as practicable after plugging or cessation of
production and removal of production equipment and facilities. Stockpiled topsoil is redistributed evenly
over the re -contoured surface.
The Location and any associated access roads are treated to alleviate compaction that may have occurred
during the oil and gas operations.
The reclaimed area is reseeded with the approved seed mixture specifically designed to simulate adjacent
undisturbed vegetation while maximizing utilization by both wildlife and domestic stock. The vegetation
growth is monitored at the Location until the vegetation reaches adequate density per COGCC regulations,.
Page 6
Page 1 of 1
NV Bonanza
CREEK
TRANSPORTATION PLAN
Project
Report
County,
Location
Name:
Date:
State:
(Townshi
•,
Range, Section}:
- -- -
Pronghorn
8/10/2021
Weld
T5N,
1.
R61W,
County,
Number
T-4
S4
-
CO
of Roundtrips
/ Day
Region:
Field
Proposed
Name:
Start
Date:
Di
Wattenberg
First
Basin
Quarter
of
2024
Activity Phase
Type/Roudtrips
Size weight
Single
Unit
Truck
10,000
- 20,000
lbs
10 Average RT
Construction
Multi
Unit
Truck
50,000 - 70,000
lbs 15
Average
RT
Passenger/Pickup
4500 - $500 lbs
5 Average
RT
Single
Unit
Truck
10,000
- 20,000
lbs 10 Average
RT
Drilling
Multi
Unit
Truck
50,000
- 7Q000
lbs 10
Average RT
Passenger/Pickup
4500 - 8500
lbs
30 Average
RT
Single
Unit
Truck
10,000 a 20,000 lbs
5 Average
RT
Completions
Multi
Unit
Truck
50,000
- 70,000 lbs
50 Average
RT
Passenger/Pickup
4500
- 8500
lbs
40
Average RT
Single
Unit
Truck
10,000 - 20,000
lbs
1
Average RT
Production
Multi
Unit
Truck
50,000 a 70,000 lbs
3 Average
RT
Passenger/Pickup
4500 - 8500
lbs
1
Average
RT
2. Expected
Haul
Route
Route
ID
Description
Route
1
Traffic
will
access the
location
fromwest along
US Highway
34, north
on WCR 87, continue
north
on WCR 89, east on WCR
60
Route 2
Traffic
will
access the
location
from east along
US
Highway
34, north on WCR 87, continue
d
north
on Vi/CR 89, east on WCR 60
Traffic
will
access
the
location
from north
along
CO
Highway
392, east on WCR 68, south
on
i Route 3
WCR 89, east on WCR 60
3. Travel Distribution
Route ID
Construction
Drilling
Completions
Route 1
100% 50% 0%
Route 2
0% 50% 100%
Route
3
0% 0% 0%
4. Expected Doily
Peak
Traffic Time
Peak
traffic
volumes
are expected
around
6am and
6pm when shift
changes
occur. This
applies
for drilling
and completions
which
run on
a 24
hour
operations.
During construction activites, specific
traffic
peaks
are not expected
at any time throughout
the day.
Reviewed
By: Joe Schultz
Title:
Project Manager
Signature:
Date: 8/10/2021
Exhibit E
Bonanza Creek Pronghorn OGDP
Interested Parties List
303 Property Holdings, LLC
8801 Investment Co., LLC
A & H Wheeler Co.
A. H. and Maude Price
A.H. Price
Acme Oil Corp., LLC
Acoma Energy, LLC
Alvin L. Sall
Anadarko E&P Onshore, LLC
Ann Tobin Hevenor
Ann Tobin Hevenor
Anna Johanson
Anschutz Exploration Corporation
Archer Pearl Energy
Archer Pearl Energy, LLC
Ashley Behring
Aspect Holdings, LLC
Atomic Capital Minerals LLC
B & J Resources, LLC
Bank of the Hills, as Successor Trustee u/w
of Edward F. Comegys dated 7/11/1970,
f/b/o Edward L. White
Bayard Walker Oil Trust
Bernardine Kirchhof
Beverly A. Schell
Beverly McKee Eaton, Trustee
Bison Oil & Gas II, LLC
Blackriver Niobrara Partners II, LLC
Blackriver Niobrara Partners, LLC
Bonanza Creek Energy Operating Company,
LLC
Brett Stephan Colbert
Bright Rock Holdings, LLC
Brockton M. Bunnell
Brockton Morrow Bunnell
C. M. Smith
C. Russell Talbott and Margret Talbott
Carl Arthur Peterson
Carolyn Jo Rogers Trust
Carolyn Joyce Bohm
Carver Minerals, LLC
Celia Grimes Price
Charlene Allmer
Cheryl Ann Richmond
Colorado Land Services, LLC
ConocoPhillips Company
Dana C. Pfrangle, Successor Beneficiary
David Holl
DDFS Partnership LP
Delacosta Energy LP
Diane H. Smith Trust
Donald Edson Furrow
Douglass Chandler Colbert
Eda Marie Stockover Hull
c/o Todd Hull
Edward J. Tergeson
Edward Ohler, II, heir to the Estate of Hazel
Ohler Mertz Rensink
Edward Tergeson
Edwin M. Jones Oil Company
Elaine Knox
Elaine W. Fiske Family Limited Partnership
Elizabeth Blunk
Ernest Behring
Estate of Avis Ora (Gross) Tyree
Estate of Beverly McKee Eaton, dec.
Estate of Carlos E. Morales
Estate of Corwin Gross
Estate of Dorothy Jean Baker
Estate of Edward L. Behring,
c/o Patrice Ewing
Estate of Elaine Johnson
Estate of Flossie Mae (Gross) Tomlinson
Estate of Gentry D. Gross
Estate of Gerald E. Williams
Estate of H.A. Talbott, deceased.
Estate of James Gross
Estate of Luana M. Simmons
c/o Melanie Simmons
Estate of Mary Adeline Gross Blair
Estate of Patrice Ewing, Irene June Kruse
c/o Valerie Hinchee Jack Patterson
Estate of Pauline Mae Gross McCann Jackie Bowland Jackson Halley
Estate of Rex Carr Eaton Jr. James Lawrence Kirchhof
d o Penny Ann Eaton James R. Harrison and Janice A. Harrison,
Estate of Robert Wayne Gross JTS
Estate of Sandra Stickler Jan Carp
Estate of Shirley Hudgens Jeffrey B. Smith
Estate of W. S. Garnsey, Jr. Jennifer E. Hall, f/k/a Jennifer E. Smith
c/o W. Herrick Garnsey Jim Austin
Esther Jean Smith (d) JoAnna M. Kennedy
Excalibur Energy Company Johann Mandelko
Fashion Institute of Technology John A. Thieke, Trustee of the Bayard
Fernando Morales Walker Oil Trust
Florence Beck, fka Florence Whitcomb John Edward McArthur
Florence Whitcomb Beck John Frank Raizen Revocable Trust
Frances Brenner John Kirchhof
Frank C. Spinner John R. Moran, Jr. and Wells Fargo Bank,
Gary L. Williams N.A., as Co -Trustees of the Moran Family
George G. Vaught, Jr. Minerals Trust
George R. Mandelko and Deborah Lynn Jon E. Jones
Mandelko, JT Judith Lynn Smith Mendoza
Gloria Furrow Julia Ann Mannion
Gloria Morales Melo K. L. Beck
Gold Lake Energy, LLC Kaiser -Francis Oil Company
Gregory B. Williams Kathleen J. Furrow 2017 Trust dated
GRP Energy LP October 4, 2017, Kathleen J. Furrow,
H. Lorraine Mandelko Trustee
Harry Clifford Peterson Kathleen L. Allen
Heather Behring Kathleen Tobin Krueger
Heirs of Ina Marie Withycombe, heir to Kathy Jane Emmons as heir of Audrey
Arthur William Anderson Kathryn Buck
Heirs of Jean Ellen Anderson Brizendine, Kerstin Marina Lundgren
heir to Arthur William Anderson Kimberly Eaton a/k/a Kimberly Hoff a/k/a
Henrietta Yerger Jones Kimberly Hoff-Gebhardt
Hery Oil, LLC Kimberly Jane Monkman
HighPoint Operating Corporation L&S Family, LP
Horace Price Laurie Behring
Howard T. Kingry and Vicki N. Kingry, JTS Lawrence Christopher Eaton
Imogene and Harold Herndon Charitable Leigh Gonzalez
Trust u/w/o Harold D. Herndon Lewis Family Resources, Ltd.
Imogene and Harold Herndon Charitable LHB Ventures, LLC
Trust u/w/o Imogene A. Herndon
Inger Marie Grizzell
Linda Jean Sedgeley, individually and as
trustee of the Davis Family Trust dated April
11, 1991
Lisa McLain Sacripanti
Lorna G. Anderson
Lucile W. Hays Family Limited Partnership
Luz Maria Orrego
Margaret (Stoltman) Mitchell
Margaret R. Stockover
Maria Jose Morales Arteaga
Marilyn J. Williams
Mark T. Tobin Trust c/o Ann Tobin Hevenor,
Trustee
Mark T. Tobin Trust c/o Martha Tobin
Bersch, Trustee
Martha Fosmire
Mary Catherine Armatas
Mary Evalyn Davis
Maude Price
McArthur Minerals
McCulliss Oil and Gas, Inc.
McCulliss Resources Co., Inc.
McGhee Investment Company
McMahon Energy Partners, LP
Mekusukey Oil Company, LLC
Melissa Christine Elshoff
Michael Buck as heir of Audrey Kathryn
Buck and David Alan Buck
Michael Campbell
Michael Douglas Kirchhof
Michael Kirchhof Living Trust, Leigh
Gonzalez, Successor Trustee
Michael Scott Colbert
Michelle K. Easley
Mike's Oil Well, LLC
Nancy Lee Jackson Crespin
Nancy Leigh Eaton, a/k/a Nancy Eaton Stuve
New School for Social Research
New York School of Interior Design
O. S. Osborne
Okreek Oil and Gas II, LLC
Palmares Energy LP
Pamela K. Goodrich
Patricia Sue Fickes
Patrick B. Tobin
Paul F. Mandelko
Paula Fisher as heir of Audrey Kathryn Buck
PEC Minerals, L.P.
Peggy Ann DeLidle
Penny Eaton Hancock, f/k/a Penny Ann
Eaton
Penny Lee Reid
Phillip P. Tobin
Phillips Petroleum Company
PNH Resources LLC
Pratt Institute
Raisa Funding I, LLC
Randall Bruce Stewart
Rex C. Eaton, III
Richard Barton Furrow
Richard L. Zisch & Roberta N. Zisch Trust #1
dated October 29, 1984
RJC Energy, Inc.
RJC Ventures, LLC
Robert Lawrence Eaton
Robert Neil Wilkinson
Robert Tracy
Royalty Asset Holdings, LP
Ryan Thomas Elshoff
Santa Fe Minerals
Schneider Energy Services
Sean J. Kennedy, Successor Beneficiary
Shawna Kaye Colbert Wagstaff
Sheila Carter, heir to the Estate of Hazel
Ohler Mertz Rensink
Shirley Chandler, Trustee of the Shirley
Chandler Living Trust uta dated 10/10/2005
Sigrid Becili
Susan R. Swanson
Suzanne Davis, LP
The Estate of Mildred O. Evans
The First National Bank and Trust Company
of Tulsa, Successor Trustee of the Sidney H.
Davis Trust C
The National Non -Profit for Americans with
Disabilities, Inc., Trustee of the Guardian
Pooled Trust dated 6/6/2002 - Shelly
Bunnell Account
The Nordan Trust
The Peter F. and Julie A. Kirchhof Family
Trust dated February 15, 2016
The Petram Group, LLC, f/k/a Wolfhawk
Energy Holdings, LLC
The Walker B. Comegys, Jr. Family LLC, a
Texas limited liability company
The Walker N. Comegys, Jr. Family LLC
c/o Cocke Willford & Eddins PC
Therese Reichardt
Thomas N. Kennedy, Beneficiary
Tofte Energy Partners, Limited Partnership
Top Brass Properties, Inc.
Travis Buck as heir of Audrey Kathryn Buck
and David Alan Buck
Uni Roylaty Group, Ltd.
Univestors, LLC
Valerie Hinchee
Vicky L. Higginbotham
Virginia Ann Smith Foss
Weld County, c/o Boad of County
Commissioners
Weld County, Colorado by and through the
Board of County Commissioners
Western Colorado Energy, LLC
Whitetail Minerals, LLC
William Carl Stockover
William Vilas Hanks, as Trustee for the
Louise H. Davis Irrevocable Trust, created
August 31, 1976
Woody Creek, LLC
Xor Chia Moua and May See Moua
Dennis W. Grotheer Living Trust
John Carlyle Daniel
State of Colorado
Barbara J. Synar, John Synar, Logan Steen
Joseph J. Hawkins
L&S Capital Ltd.
Roy Alexander Jobes
School District No. RE 50
Wiggins Fire Protection District
Weld County Sherriff's Office
Harold Leaman Jr. Irrevocable Trust
Jason Maxey, Weld County LGD
Colorado Parks and Wildlife
Attn: Brandon Marette
CDPHE, Attn: Tessa Sorensen
Colorado State Land Board
BLM Colorado State Office
A. H. and Maude Price
Anna Johanson
C. M. Smith
Estate of Corwin Gross
Estate of Elaine Johnson
Estate of Gentry D. Gross
Estate of James Gross
Estate of Mary Adeline Gross Blair
Estate of Pauline Mae Gross McCann
Estate of Robert Wayne Gross
Estate of Sandra Stickler
Estate of Shirley Hudgens
Heirs of Ina Marie Withycombe, heir to
Arthur William Anderson
Heirs of Jean Ellen Anderson Brizendine,
heir to Arthur William Anderson
Kerstin Marina Lundgren
O. S. Osborne
Sigrid Becili
The Estate of Mildred O. Evans
40
COLORADO
Oil &Gas Conservation
coin
Departmental N'atural Resewe
COGCC INFORMATION SHEET:
PROCEDURAL STEPS FOR THE
COMMISSION'S REVIEW OF OGDPs
(As required by COGCC Rule 303.e.(2).C)
Why am I receiving this information sheet?
Oil and gas operating companies ("Operators") are
required to obtain approval of an Oil and Gas
Development Plan ("OGDP") from the Colorado Oil
and Gas Conservation Commission ("COGCC") prior
to undertaking any new operations such as drilling
oil and gas wells or building oil and gas locations.
When an Operator submits an OGDP application to
the COGCC for consideration, and the application
has been received and is deemed complete,
COGCC staff begins a formal technical review of
the application materials, and a public comment
period starts.
COGCC has prepared this information sheet to
inform the public of the procedural steps involved
with the Director's and Commission's review of an
OGDP, so that the public is informed and may
participate in the review process if they choose.
As part of the process, Operators must provide
this information sheet to certain recipients, like
yourself, that include mineral owners within the
area of proposed development and all landowners,
homeowners, commercial property owners,
tenants, and other entities within 2,000 feet of an
oil and gas location proposed by a pending OGDP
application.
What is an Oil and Gas Development Plan
(OGDP)?
An OGDP is an Operator's plan to develop oil or
gas resources ("minerals") from one or more
surface locations. Operators prepare an OGDP and
associated application materials, consistent with
the requirements of COGCC Rule 303, and submit
the plan for approval through the Commission's
Hearings process. The application materials
include a hearing application; one or more Form
2A, Oil and Gas Location Assessments; a Form 2B,
Cumulative Impacts Data Identification; and a
Form 2C, OGDP Certification. The application
may also include a request for the establishment
of one or more Drilling and Spacing Units
("DSUs"). The OGDP, along with its associated
supporting documents, will be heard at a public
hearing where the Commission will make a final
determination to approve or deny the OGDP
application.
What are the procedural steps involved with
the Director's and Commission's review of
Oil and Gas Development Plans?
1. OGDP application is submitted: Operator/
Applicant submits a complete OGDP
application with all supporting documents. The
written portion of the application is submitted
to the COGCC hearings unit via the eFilings
system, and Forms 2A, 2B, and 2C are
submitted to technical staff via the eForms
system. (See Rules 303 ft 304)
2. OGDP application is received: The COGCC
hearings unit reviews the written hearing
application, assigns a docket number for the
OGDP, and provides public notice for the
hearing. (See Rules 303 Ft 504)
3. Completeness determination: The COGCC
technical staff and Director review the
application materials for completeness. When
deemed complete:
a. the OGDP application materials are posted
on COGCC's website;
b. the Operator provides notice (including this
information sheet) to relevant persons;
c. the public comment period begins;
d. the formal consultation period commences
as applicable (including relevant/
proximate local governments and other
agencies such as Colorado Parks and
Wildlife ("CPW") or Colorado Department
Page 2
of Public Health and Environment
("CDPHE")); and
e. COGCC staff begin their technical review
of the OGDP components. (See Rule 303).
4. Director's review of application (technical
review): COGCC technical staff conducts the
technical review of all application materials to
ensure compliance with COGCC Rules, ensure
the protection of public health, safety,
welfare, the environment, and wildlife
resources, and to evaluate potential
Cumulative Impacts. The technical review
includes analysis and assessment of:
a. DSUs and protection of mineral owner's
correlative rights;
b. proposed surface locations and alternative
locations;
c. downhole and engineering considerations;
d. best management practices;
e. public comments and recommendations
provided by consulting agencies;
financial assurance; and
the need for conditions of approval. (See
Rule 306)
5. Director's recommendation: Once the
Director has reviewed the application
materials, the Director provides a written
recommendation to the Commission in support
of the approval or denial of the OGDP
application. The Director will post the
recommendation on COGCC's website, notify
relevant parties', and submit it to the COGCC
hearings unit in preparation for hearing. (See
Rule 306.c)
6. Commission's consideration and final action
(public hearing): The Commission receives the
f.
g.
' Parties who receive this information sheet will not
necessarily be included in the notice of the Director's
recommendation. Parties who make a public comment
on the Form 2A and include their email address will
receive the notice of the Director's recommendation.
Director's recommendation of the OGDP and
begins review of the OGDP with support from
the COGCC hearings unit. The review includes
all supporting documents, written testimony,
public comments, consulting agency recom-
mendations, and Director's recommendation.
The Commission considers the OGDP at a
public hearing, which may include oral
testimony provided during the hearing. The
Commission makes a final determination and
presents its findings in a written order based
on the evidence in the record; the
Commission's order to approve or deny the
OGDP application is final. (See Rule 307)
Where can I get additional information?
For more information about the COGCC
administrative hearing process and OGDPs, please
refer to the COGCC website at
http://cogcc.state.co.us. You may also contact
the COGCC at dnrogcc®state.co.us or
303-894-2100. Please note, COGCC staff are not
available to provide legal advice. COGCC
recommends that you engage an attorney with
knowledge of oil and gas matters to assist you
with reviewing any offers you receive from an oil
and gas operator or other person.
Version 1.0 March 9, 2021
COLORADO
Oil Er Gas Conservation
Commission
Department of Natural Resources
COGCC INFORMATION SHEET:
PUBLIC COMMENTS
(As required by COGCC Rule 303.e. (2)D)
Purpose
This information sheet provides details on how to make
public comments on an Oil and Gas Development Plan
submitted to the Colorado Oil and Gas Conservation
Commission via the Form 2A, Oil and Gas Location
Assessment permit application.
Why am I receiving this Information Sheet?
You have received this Colorado Oil and Gas
Conservation Commission ("COGCC") information sheet
because an oil and gas operator ("the Operator") has
submitted an application for an Oil and Gas
Development Plan ("OGDP"), and that application is
under review by the COGCC. Per COGCC Rule 303.e. (1),
the Operator is required to provide this information to
you within seven days of the application materials
being posted on the COGCC website.
COGCC Rule 303.d requires the COGCC to open a formal
"public comment period" upon posting the OGDP
application to our website. This public comment period
allows the public to review OGDP applications and their
components (i.e., proposed Oil and Gas Locations), and
provide comments on those pending permit
applications.
How can I provide comments on pending
permits in an OGDP?
Members of the public can access OGDP applications
through the COGCC website to review permit
information and provide comments. Public comments
may be made directly on Form 2A, Oil and Gas Location
Assessment permit applications ("Form 2A") through
the COGCC website.
1. Go to the COGCC website https://cogccestate.co.us
2. On the green menu bar, click on the "Permits"
page. This will take you to the "Drilling and
Location Permits Search" tool for Pending Permits.
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3. Under "Pending Permits", find "Oil and Gas
Location Assessment Permits (Form 2A)". Select the
county of interest from the dropdown menu and
click "Go!"
Pending Permits (Riad ON or AFTER January 15th, 2Q21)
01 & Gas Locadon Assessment Per;nks (Form 2A):
4. This will generate a table of pending applications
and will indicate the status of the public comment
period for each permit within the COGCC review
process.
5. Scroll through the list of pending permits to find
the one you would like to review. You may wish to
use "crtl + f" to search for a specific document
number, operator name, or location name.
6. To view the submitted Form 2A and its associated
attached documents, click the "Location Name"
link for any permit application.
Pending Location Permits - All Counties
Back
Export to Excel
Doc State
(Public
C Link)
Final Gay of Pubic
Comment Ptnad
(Closes at Mengbq
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7. To make a public comment on a specific permit
application, click the "Doc Number" of the permit
on which you wish to comment.
Pending Location Permits - All Counties
»
Export to Frr$
Doc NI:inner
(r :iblic
Comment Link)
Final cay of Public
Comment Parlay
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After
clicking the Doc Number link, you will be taken to
the Public Comment portal.
8. In the Public Comment portal, you may review the
Form 2A application including the PDF and all
attachments.
Selected Vile€i 1 Location:
Document Number Form Type
I4D2165141 02A COL
Attachments I
PDF
Make Comment
9. To make a public comment, click the "Make
Comment" button. A Form will open for you to
provide your name, contact information, and your
comment. Only the text in the Comment box will
be made public; your contact information will be
kept confidential by COGCC.
Please ft gal the fields below WS to si.tbmd your comment
Name: 1 i Eras:
Stale:
Phone Number:
10. Click the "Submit Comment" button when you are
ready to submit your comment.
Page 1 2
11. You may also view other public comments and read
yours after it is posted by scrolling down on this
page (see below about a delay in displaying
comments).
How long do I have to submit a comment on
a permit?
The Public Comment Period begins once the COGCC
Director determines the OGDP application is complete
and has been successfully submitted by the operator.
The Director wilt approve the Form 2C, OGDP
Certification form, and post the OGDP application on
the website for public review.
In order to be considered by the Director and
Commission during the review of the OGDP, public
comments must be received as follows:
1. Within 30 days from the date that the Director
posts thethe OGDP on the website, OR
2. Within 45 days if the OGDP includes any
proposed Oil and Gas Locations within 2,000
feet of a Residential Building Unit, High
Occupancy Building Unit, or School Facility
within a Disproportionately Impacted
Community.
The final day for public comments can be found in the
list of all pending permits:
Pending Location Permits - All Counties
Back
float to Excel
Doc Number
(Ptatlic
Comment L.1ek)
Fir -al day of Pubhe
Comment Pend
(Closes at Mid r4 tt)
Received
t o aUon Name
Status
Status
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When the Public Comment Period closes, the date will
revert to read "Comments Closed". The link to the
public comment portal will remain active, but
comments will no longer be accepted. You will still be
able to view any public comments submitted for
pending permits.
The Direcor may extend or reopen the public comment
period per Rule 303.g, for up to an additional 30 days
for a proposed OGDP if the Director determines an
extension or reopening is reasonable in order to obtain
public inp at.
What happens to my comment?
Your comment will become part of the public record of
the application and will be reviewed by the applicant,
COGCC staff, Director, and the Commission. COGCC
staff may recommend permit conditions in response to
comments. But, Staff does not routinely respond
individually to comments; instead, COGCC staff will
work directly with the applicant to address the
site -specific concerns expressed.
Submitted comments may not be immediately visible;
it may be a few days before you see your comments
posted. This delay allows COGCC supervisory staff to
screen for offensive language prior to publication.
What if I want to make my comment to the
Commission?
COGCC Staff and the Director review every comment
received on a Form 2A permit application. They review
the site specific concerns against the totality of the
application materials, including the alternative location
analysis, cumulative impacts evaluation, and best
management practices proposed by the applicant.
When the Director makes a recommendation to the
Commission to either approve or deny an OGDP, that
recommendation will include the consideration of the
public comments received.
In their review of an OGDP for a final determination at
the administrative hearing, the Commission will have
access to the entire record, including your public
comment.
Can I remain anonymous?
Yes. Only the "Comment" portion of your submitted
comment will be made publicly viewable. Your name
and contact information will be kept confidential, and
will only be used by COGCC staff to contact you if
necessary in the course of permit application review.
If you choose to include your name and contact
information in the body of your comment text, it will
be part of the public record.
Links
The following [inks provide guidance and additional
information on providing Public Comments.
COGCC Permits Page:
ttpacc.state.co.us/permits.html
Numerous helpful guidance documents can be found at
the link on the COGCC Permits Page:
https; / / cogcc. state. co. us/permits2. htm.#/permitshelp
Daily Activity Dashboard (DAD) is another useful tool
and can be used to access the public comment portal
as well: https: / /cogcc. state. co. us/dashboard. html
Version 1.0
March 9, 2021
a
COLORADO
Oil Et Gas Conservation
Commission
Department of Natural Resources
INFORMATION SHEET:
HYDRAULIC FRACTURING
TREATMENT
(As required by COGCC Rule 303.e.(2).E)
Why am I receiving this information sheet?
The Colorado Oil and Gas Conservation
Commission ("COGCC") prepared this information
sheet to provide the public with information
related to hydraulic fracturing. Pursuant to
Commission Rule 303.e.(2).E, Operators' are
required to provide this information sheet to
mineral owners within the area of proposed
development and all landowners, homeowners,
commercial property owners, tenants, and other
entities within 2,000 feet of a proposed oil and
gas location.
What is hydraulic fracturing treatment, and
why is it necessary?
Hydraulic fracturing treatment is the process of
creating small cracks, or "fractures," in the rocks
of deep, underground geological formations that
have oil and natural gas. The fractures enhance
the flow of oil and gas from the formation to the
oil and gas well where it flows or is pumped up
the well to the production equipment located on
the surface of the site.
The process of hydraulic fracturing has been used
for decades in Colorado, dating back to the 1970s.
Operators' continue to improve hydraulic
fracturing, and it is now a standard practice used
in almost all oil and gas wells in the state, and
across much of the country. Hydraulic fracturing
has made it possible to produce oil and gas from
rock formations that did not often produce oil and
gas in the early to middle part of the twentieth
century.
What happens before hydraulic fracturing
treatment?
The operator uses a drilling rig to drill a "surface
hole" and set a steel pipe called "surface casing"
in the hole. The surface casing may extend many
hundreds of feet, sometimes more than 1,000
"Operator" as defined in COGCC Rules
a Hereinafter, and only for the purpose of describing the
hydraulic fracture treatment process, the term "operator"
includes the operator itself and all contractors and
service providers that the operator hires to perform work.
feet, underground. The operator places cement on
the outside of the surface casing to seal and
protect groundwater. The operator tests the
surface casing with pressure, then a smaller
"production hole" is drilled out the bottom of the
surface casing. After completing a formation
integrity test, the operator drills down to the
geological formation containing oil and gas,
usually many thousands of feet underground. The
operator lowers a production casing into the
production hole, and cement is used to make a
seal above the deep oil and gas formation. The
operator "completes" the well by placing holes, or
"perforations" in the casing at the deep oil and
gas formation, to allow oil and gas to flow into the
well. The well is then ready for hydraulic
fracturing treatment.
What happens during and after hydraulic
fracturing treatment?
The operator performs the treatment by using
high pressure water pumps to fracture the deep
oil and gas rock formation. The pumps push
fracturing fluids down the well and out through
the perforations, into the oil and gas rock
formation. The hydraulic fracturing fluids are
mostly water and sand, with a small amount of
chemical additives. The sand, also called
"proppant," remains in the fractures to help keep
the fractures open allowing oil and gas to flow
through the fractures to the perforations.
After hydraulic fracture treatment, the well is
allowed to "flowback," meaning hydraulic
fracture fluids, oil, gas, and produced water from
the formation flow through the perforations and
up the well to the surface where the fluids are
separated. The operator sells the oil and gas.
Waste products, mostly water produced from the
oil and gas formation and hydraulic fracture
fluids, are captured and stored for proper
treatment or disposal.
Page 2
Overhead view of a multiple -well site with hydraulic
fracturing equipment set up inside a sound wall
Common questions and answers about
hydraulic fracturing treatment.
Q: How is an oil and gas well designed to be
protective of public health, the environment,
and wildlife resources?
A: COGCC engineering staff review all well
permits to ensure that wells are lined with
multiple layers of steel and cement sufficient to
isolate groundwater from the deep oil and gas
rock formations. The operator's wellbore design
must meet COGCC wellbore isolation standards
and rules in order to receive a permit to drill.
Surface casing extends from the ground surface to
50 feet or more below groundwater. Production
casing is cemented to seal the oil and gas
formation in the well and prevent flow between
groundwater and the oil and gas formations. The
operator performs a well survey, called a "cement
bond log," to verify the cement placement around
the production casing. Additionally, the operator
pressure tests surface equipment and ensures that
nearby, "offset" wells that are close enough for
pressure communication in the oil and gas
formation have properly -rated surface equipment
or downhole plugs.
Q: Will hydraulic fracturing treatment cause
problems with water wells
A: Water well problems related to hydraulic
fracturing in Colorado are rare, which is largely a
result of COGCC's long-standing mission to protect
Waters of the State of Colorado, including
groundwater. Most recently, the COGCC adopted
new rules for wellbore isolation, effective
November 2, 2020 to further strengthen this
mandate.
Geologic factors in Colorado also serve to help
prevent groundwater impacts. Often, many
thousands of feet of confining rock layers separate
shallow groundwater formations that are used for
drinking water, livestock, and irrigation from deep
oil and gas formations. In cases where an operator
intends to perform a hydraulic fracture treatment
at a depth of less than 2,000 feet underground, a
geological and engineering evaluation is required
prior to approving a drilling permit. In cases where
deep groundwater is present, COGCC rules require
additional cement in oil and gas wells to seal the
deep groundwater formations.
Q: What is hydraulic fracture fluid?
A: The COGCC and regulatory agencies of other oil
and gas producing states partner with FracFocus, a
Chemical Disclosure Registry, that operators use
to report hydraulic fracture fluid chemical data
(https: //www. fracfocus.org/). According to
FracFocus, approximately 98% to 99% of the
fracturing fluid volume in most wells is water and
sand. The remaining portion is made up of
chemical additives used to reduce friction during
pumping and prevent corrosion of the steel casing.
Biocide is used to kill bacteria in the water.
Surfactants promote water flowback from the
formation, up the well and into the oil and gas
production equipment at the well site or a nearby
"tank battery." Fracturing chemicals are similar
to other industrial chemicals which must be
handled properly. COGCC rules require that
operators properly store and handle chemicals in a
manner that protects operator's employees, the
public, the environment, and wildlife.
COGCC rules require operators to publicly disclose
the components and concentrations of fracturing
chemicals for each well within 60 days of the
hydraulic fracture treatment on the FracFocus
website, which is searchable by county, operator,
and well. The website also provides information
on chemicals used and their purpose.
Version 2.1
April 2, 2021
P age3
Q: How are hydraulic fracturing fluids managed
on the well site?
A: Operators manage large volumes of drilling
fluid, hydraulic fracturing fluid, and flowback
during drilling and hydraulic fracturing treatment.
Operators protect the public, environmental
resources, and wildlife by implementing best
management practices specified by permit
conditions and COGCC rules for spill prevention.
After hydraulic fracturing treatment, fluids return
to production equipment at the well site as
flowback. These flowback fluids are considered oil
and gas Exploration and Production Waste ("ESP
Waste") that are recycled for other oil and gas
operations, or are disposed of in accordance with
state regulations. Marketable production fluids,
including oil and gas, are separated and contained
in tanks or vessels, or sent by pipeline to sales.
Q: What can neighbors expect to experience
during hydraulic fracturing treatment?
A: The operator provides the COGCC and the local
government a 48 -hour notice before performing
hydraulic fracturing treatment. As the operator
mobilizes the hydraulic fracturing crews, water
tanks are placed at the site. The operator
transports water to the site for hydraulic
fracturing fluid by pipeline or water trucks. Heavy
equipment, such as sand haulers, pump trucks,
blending units and a control van arrives and the
equipment is connected to the well with high
pressure piping. The operator pressure tests the
equipment, then the hydraulic fracture treatment
begins. The work can take several days to several
weeks, depending on the number of wells on the
well site and the number of treatment stages
needed for each well. The equipment noise from
engines, pumps, and vehicles will be noticeable
during the work. Induced seismicity from hydraulic
fracturing is very low intensity, too small to be
noticed by people at the ground surface, and
therefore man-made earthquakes are not a
common occurrence in Colorado during hydraulic
fracturing treatment operations.
Where can I get additional information?
FracFocus (www.fracfocus.org) contains detailed
information on hydraulic fracturing, chemicals
used, groundwater protection and how to find a
well near you.
COGCC rules related to hydraulic fracturing:
• Rule 308 Form 2, Application to Drill, Deepen,
Re -Enter, or Recomptete, and Operate, Information
Requirements
• Rule 405.k Notice of Intent to Conduct Hydraulic
Fracturing Treatment
• Rule 408 General Drilling Rules
• Rule 411 Public Water System Protection
• Rule 419 Bradenhead Monitoring, Testing, and
Reporting
• Rule 423 and 424 Noise and Lighting
• Rule 437 Hydraulic Fracturing Chemical Additives
• Rule 614 Coalbed Methane Wells
• Rule 615 Groundwater Baseline Sampling and
Monitoring
• Rule 905 Management of E&IP Waste
• Rule 912 Spills and Releases (includes landowner
notification requirements)
COGCC's rules are available as downloadable files at
coecc.state.co.us.
Version 2.1 April 2, 2021
COLORADO
Oil Er Gas Conservation
Commission
Depanytert I''! Ngzurai Resources
s
COGCC INFORMATION SHEET:
OGDP STATUS INFORMATION
(As required by COGCC Rule 303.e.(2).G)
Why am I receiving this information sheet?
The Colorado Oil and Gas Conservation
Commission ("COGCC") prepared this information
sheet to inform the public in the vicinity of a
proposed Oil and Gas Development Plan ("OGDP")
how to access documents and view the status of
proposed OGDPs through the COGCC's website,
eForms, and eFiling system. A review of public
property records indicates that you may have an
interest in lands that an oil and gas operator
wishes to develop as part of an OGDP. Pursuant to
Commission Rule 303.e.(2).G, operators are
required to provide this information sheet to
certain recipients near their development plans.
What is an Oil and Gas Development Plan?
An OGDP is an operator's plan to develop
subsurface oil and gas resources ("minerals") from
one or more surface locations. An OGDP consists
of a hearing application and associated permit
materials that provide technical information. The
Director (i.e. COGCC Staff) reviews the technical
information and makes a recommendation to the
Commission for the hearings application; the
Commission has the ultimate authority on
approval or denial of the OGDP.
How do I view the status of the pending
OGDP hearing application?
Members of the public may view the status of
proposed OGDP applications through the COGCC
eFiling System by creating an account in the
Applications and Docket Portal, available on the
"Hearings Page."
1. From the COGCC homepage, click "Regulation"
in the green menu bar, and then "Hearings" on
the blue bar.
2. On the right-hand side of the Hearings page,
under the Hearings eFiling System header, click
on "Application and Docket Portal".
Hearings eFiling System
(Beginning November 9, 2020)
• Document Search
• Appbcation & Docket Portal •
3. Create a user account by clicking "Request
Access to Account," and completing the
required registration information. There may
be a delay for processing following your
request before you are granted access. Check
your email for access approval.
4. Once registration is complete, access the
Application and Docket Portal by entering your
user name and password.
5. Search for the 9 -digit docket number provided
by the operator in their cover letter using the
"Find Hearing Application by Docket Number"
option at the bottom left of the page.
Find Hearing Application by Docket Number
SC- 1.ES.&T's
Number
210012345
6. The general status of the docket is listed in
the first column on the left, titled "Docket
Status."
7. Double click the docket search result to load
the docket's main page, which will show
additional information, including the
application type, status, assigned Hearing
Officer, and applicant information.
Do I have to create an account to view
documents?
No. You may view documents through the
"Document Search" described below without
creating an eFiling System account, but you will
not be able to view the "status" of the docket
through this method.
1. On the right-hand side of the Hearings page,
under the Hearings eFiling System header, click
on the "Document Search" link.
Hearings eFiling System
(Beginning November 9, 2020)
• Document Search
• Application & Docket Portal
2. From the "Search Type" dropdown menu,
select "DNRCOG Search for Docket Related
Documents."
Sem* Type
CNT C0 3 New Aphf?i;ns
IRCC 3 New Appictcns
DNRCOG Naas 3icc.j rer s
DNRCOG Search for Docket Related Doeumerd5
Page 2
3. Input the docket number provided by the
operator.
DNRCOG Docket Number
21O012345
4. If you don't have a docket number, or to view
any OGDP, scroll down to the "DNRCOG
Application Type" dropdown menu and select
"OIL Et GAS DEVELOPMENT PLAN."
DNRCOG Application Type
ADDMONAL WELLS
COMPREHENSIVE AREA PLAN
EN ORCEAMBIT
EXCEPTION LOCATION
GENES ADMINISTRATIVE
OIL & GAS DEVELOPMENT PLAN
PIT S-11=0
5. After step 3 or 4, scroll down and click the
"Search" button at the bottom of the scroll
bar.
6. A list of all related documents will appear.
Click on any item to view its contents.
How do I view general forms, permits, and
data regarding permits and OGDPs?
You may use the Daily Activity Dashboard to access
frequently requested oil and gas data at the
county and state levels. The Daily Activity
Dashboard is located in the right-hand corner of
the COGCC homepage, and allows you to search
and generate custom-made statistical charts,
graphs, tables, and maps for information including
pending permits, welt status, production, well
inspections, Notices of Alleged Violation, active
notifications, and spills. The COGCC also provides
access to pending and approved permits through
its "Permits Search" and interactive map on the
COGCC website.
To view the status of pending Form 2As (Oil and
Gas Location Assessment Permits) through the
"Permit Search" function, follow the steps
outlined below:
1. Click "Permits" in the green menu bar on the
COGCC homepage. This will take you to the
"Drilling and Location Permits Search" page.
2. Under Pending Permits, find "Oil £t Gas
Location Assessment Permits (Form 2A)".
Select "All Counties" or a specific county
using the drop down menu and click "Go!".
Pending Permits (Filed ON or AFTER January 15th. 2021)
Oil & Gas Location Assessment Permits (Fr 2.41):
All Counties
3. A table will show all pending Form 2As
currently under review by the COGCC.
eirm►ts - All Counties
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a. Clicking a "Doc Number" link will take you
to the Public Comments portal for that
pending permit.
b. Clicking a "Location Name" link will take
you to a list of documents related to that
permit, including the Form 2A (as
submitted by the operator) and supporting
documents that are attached to the
pending permit application.
Can I view pending applications on the
COGCC Map?
Yes. You may access the COGCC GIS Online
Interactive Map by clicking "Maps" in the green
banner on the COGCC homepage, then click "Click
HERE to access interactive map". You may use the
"address search" option to zoom to your address
to see oil and gas activity near you. With the map
zoomed to your area of interest, you may specify
pending permits by checking the appropriate
boxes on the left-hand menu.
0
■
•
Permits
Pending Wel (For . 2) Perc .11
Approved Wel (Para 2) Perritnt
OPending Location (Form 2A) Permit
❑ Approved Location [Form 1k) Perm;
La
To select and view a pending application, use the
arrow tool to double-click on the pending icons to
display the Application.
Links
COGCC Homepage:
https: / /cogcc.state.co.us/#/ home
Hearings Page:
https: / /cogcc. state. co. us/reg.html#/hearings
eFiling system help:
http: / /cogcc/documents/reg/Hearings/External E
filing System Users Guidebook 20201109.pdf
COGCC GIS Online Interactive Map help:
http: / /cogcc/documents/about/Help/Search%20pendin
g%20permits%20on%20the%20COGCC%20map. pdf
Version 1.0
March 9, 2021
Hello