Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout2020-03-09_320-109STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
RECEIVED
MAR 0 9 1020
A®GCC
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate Q Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrlll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Refrac
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
Oil Search Alaska
Exploratory Q Development ❑
Stratigraphic ❑ Service ❑
219-151
3. Address:
6. API Number:
PO Box 240927 Anchorage, AK 99524-0927
500-103-20808-01-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
Mitquq 1 ST1
Will planned perforations require a spacing exception? Yes ❑ No Q
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL 393876
undefined
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD):
Casing Length Size MD ND Burst Collapse
Structural
Conductor
16" 3,060 psi 1,450 psi
Surface
9-5/8" 5.750 psi 3,090 psi
Intermediate
Production
7' 7,240 psi 5,410 psi
Liner
Perforation Depth MD (H): Pedoration Depth ND (k): Tubing Size:
Tubing Grade: Tubing MD (ft):
3-1/2"
L80
Packers and SSSV Type: Halliburton PHIL Retrievable Packer
Packers and SSSV MD (ft) and ND (fl):
No SSSV
4,488' MD/4,228' ND
12. Attachments: Proposal Summary Wellbore schematic �J
13. Well Class after proposed work:
Detailed Operations Program Q BOP Sketch ❑
Exploratory Q Straligraphic ❑ Development ❑ Service ❑
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 3/10/2020
OIL Q WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission. Representative:
GINJ ❑ OP Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will
not be deviated from without prior written approval.
Authorized Name: Marc Kuck Contact Name: Marc Kuck
Authorized Title: Senior Engineering Manager Contact Email: marcAuck ollsearch.00m
y� for"kK"Y.Uc- /Z17Z0 Contact Phone: 907-37 5-6 6 0 0 0
C1
Authorized Signature: ,(�1 Dale:
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may wineIas Sundry Number:
320 -log
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑
Other:
Post Initial Injection MIT Req'd? Yes ❑ No ❑
Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Submit Form and
Form 10403 Revised 42017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
ORIGINAL
Oil Search
Mitquq 1 ST1 Sundry Application Requirements
1. Affidavit of Notice —Attachment A
2. Plat showing well location, as well as %: mile radius around well with all well
penetrations, fractures, and faults within that radius —Attachments B and F
3. Identification of freshwater aquifers within %, mile radius —There are no known
underground sources of drinking water within a half mile radius of the current proposed
well bore trajectory for Mitquq 1 STI. At the Mitquq 1 ST1 location, the Permafrost
interval extends down to approximately 1500 ft and therefore, no known shallow
aquifers are located at the Mitquq 1 ST1 location.
4. Plan for freshwater sampling — There are no known freshwater wells proximal to the
proposed operations, therefore no water sampling is planned.
5. Detailed casing and cementing information—Attachment C
6. Assessment of casing and cementing operations — Assessment of casing and cementing
operations will be performed after cementing operations are complete.
7. Casing and tubing pressure test information — Pressure testing will be performed upon
completion of the well's lateral section.
8. Pressure ratings for wellbore, wellhead, BOPE and treating head — Attachment D
9. a -d Lithological and geological descriptions of each zone—Attachment E and below
e. Estimated fracture pressure for each zone listed below:
Treatment
Held IA
IA PRV (psi)
GORV (psi)
Pump Trip
Max Rate
Pressure
Max Prop
Pressure
Depth (ft)
(psi)
Length (ft)
(bpm)
(psi)
Job
2,600
2,900
5,400
5,000
Treatment
MD Perf
TVD Perf
Max Frac
frac 34
Max Rate
Max
Max Prop
Depth (ft)
Depth (ft)
Height (h)
Length (ft)
(bpm)
Pressure
Conc.
(psi)
(PPA)
Job Max
10. Mechanical condition of wells transecting the confining zones— No wells within 1/2 -mile
radius of Mitquq 1 STI. Please see attachment B as reference.
11. Location of faults and fractures in wellbore % mile radius — Based on the seismic and
well data covering the Mitquq 1 ST1 location, there is one identified fault interpreted to
be located within a half mile radius of the wellbore traiectorv.
Oil Search does not expect that any hydraulic fractures during the stimulation of Mitquq
1 ST1 will intersect any faults near the wellbore. If there are indications that a fracture
has intersected a fault during fracturing operations, Oil Search will flush and terminate
the stage immediately.
12. Detailed proposed fracturing program — Attachments G & H
13. Flowback procedure — Attachment I
Section (b) Casing Pressure Test— We will not be treating through production or
intermediate casing strings.
Section (c) Fracture String Pressure Test—Attachment J
Section (d) Pressure Relieve Valve — Attachment K
Proposed Wellbore Schematic—Attachment L
Affidavit
State of Alaska, Third Judicial District
Personally appeared before me, Timothy Jones, who, being
duly sworn according to law, deposes and says:
I. 1, Timothy Jones, am the Land Manager for Oil Search (Alaska), LLC and a Registered
Professional Landman 984167.
2. The Owners, Landowners, Surface Owners and Operators, as defined in relevant state
statutes and regulations, identified in the attached Notice of Operations are correct to the
best of my knowledge.
3. The well location in the attached Exhibit A was taken from Oil Search (Alaska), LLC's
Penn it to Drill submitted to AOGCC.
4. The attached Notice of Operations was sent to the identified Owners, Landowners, Surface
Owners and Operators by certified mail.
Further the affia4( sayeth naught.
I tom& -)2J f/l --
Timothy Jons Date
RPL (184167
UNITED STATES OF AMERICA §
STATE OF ALASKA
tS=
Subscribed and sworn to before me on the day of December, 2019.
e
STEPH LIRETTE Notary Public
Notary Public % I
State of Alaska My commission expires:
My Commission Expires Jul 21, 2023
Attachment A
(A
Oil Search
December 4, 2019
Owners, Landowners, Surface Owners and Operators
See Distribution List
Colville River Area
North Slope Basin, Alaska
Re: Notice of Operations under 20 AAC 25.283 of Oil Search (Alaska), LLC's Sundry
Application for a Fracture Stimulation for the Proposed Mitquq 1 ST1 Sidetrack Well
Dear Owner, Landowner, Surface Owner and/or Operator,
Oil Search (Alaska), LLC (OSA) is applying for a Sundry Application under 20 AAC 25.283 to
perform a fracture stimulation of the proposed Mitquq 1 ST1 sidetrack well. This Notice is being
sent by certified mall to meet the notification requirements under 20 AAC 25.283(a)(1)(A) and
20 AAC 25.283(a)(1)(8).
The complete application is available for review upon request. If you wish to review the
application, please contact Tim Jones, Land Manager, at the following:
Tim Jones
Land Manager
Oil Search (Alaska), LLC
PO Box 240927
Anchorage, AK 99524
Direct: 907-375-4624
tim.ionesPoilsearch.com
OSA, through a search of the public record, has identified you as an Owner, Landowner, Surface
Owner or Operator (as defined in AOGCC regulations) within''/: mile of the proposed Mitquq 1
ST1 sidetrack well trajectory and fracture stimulation. Please contact me should you require
additional information.
Sincer y,
' M
Tim Jo
Land M _ ager
Oil Search Alaska, LLC Anchorage office Tel.+19073754600
PO Box 240927 Fax +1 907 375 4630
Anchorage. AK 99524-0927 . olsearch cam
Attachment A
Distribution List: Alaska Division of Oil and Gas
ASRC Exploration, LLC
Oil Search (Alaska), LLC
Repsol E&P USA Inc.
Oil Search
Attachment A
Contact Information:
State of Alaska
Department of Natural Resources
Alaska Division of Oil and Gas
550 W 7th Avenue, Suite 1100
Anchorage, AK 99501-3560
ASRC Exploration, LLC
Attn: Teresa Imm
3900 C Street, Suite 801
Anchorage, AK 99503-5963
Oil Search (Alaska), LLC
510 L Street, Suite 310
Anchorage, AK 99501
Repsol E&P USA Inc.
Attn: Dennis Henderson
2455 Technology Forest Blvd.
The Woodlands, TX 77381
Oil Search Alaska, LLC Anchorage office
PO Box 240927
Anchorage, AK 99524-0927
Oil Search
Tel: +1 907 375 4600
Fax +1 907 375 4630
w .oilsearch.com
CERTIFIED MAIL
CERTIFIED MAIL
CERTIFIED MAIL
CERTIFIED MAIL
Attachment A
PDL 391910
OPerator.ASRC f
Subsurface Dwner: ADIN
SO.. Ownar: State
ASRC: 100%
/
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0011 N007E02
U011 N007EOI
U01 I N007E04
U011 N007E03
ADL 391023 /
\
OpeatOrs,:A 1
\
suma�Ownv:ADNR 1
\
YSYmece Owner: Slate 1 MROVO
1 BHL
\
+�
ASRC: 100%
A
I
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____
MIiQUQ i S L
_________ I
ADL
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Subsumaa 0,
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er. $late -
\ .
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OSA'
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SubsumaceOwner:AONRI
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Sumac. Owner. Scale
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ORA: 51%
REPSOL 49%
UOI IN007EO9 •
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Operant: ASRC
1
Owner: '
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® r • •I O.5-MILE BUFFER
--"-- WELL PATHLINE
OIL SEARCH ALASKA LLC.
SECTION sme-s itquq 1 Well CAMPAIGN
� MUquq 1 Well Area
• BOTTOM HOLE
ICE ROADS/PADS
N 0 CC, m
(o SURFACE HOLE
Oil Search
LEASE BOUNDARY
®Feel
W E
OCS: NAD 1927 StatePWne Alaska 4 RPSSWN
®Meters
Attachment B
ovule lxprzal9. a£e 10.9y:R
6. 0 100 2CO
Txvmenlmme: oP3_ro-MW-PEM1.Y�nv91_hac5untlry
iCem Service
Oil Search Alaska, LLC
For: Garret Staudinger
Mitquq-1
7" Two -Stage Production
Joh Date: Februaq 10, 2020
Sincerely,
Savannah Mon
Attachment C
Notice
Warning Disclaimer
Although the information contained in this report is based on sound engineering practices, the copyright owner(s) does (do) not accept any
responsibility whatsoever, in negligence or otherwise, for any loss or damage arising from the possession or use of the report whether in
terms of correctness or otherwise. The application, therefore, by the user of this report or any part thereof, is solely at the user's own risk.
Limitations of Liability
Except as expressly set forth herein, there are no representations or warranties by Halliburton, express or implied, including implied
warranties of merchantability and/or fitness for a particular purpose. In no event will Halliburton or its suppliers be liable for consequential,
incidental, special, punitive or exemplary damages (including, without limitation, loss of data, profits, use of hardware, or software).
Customer accepts full responsibility for any investment made based on results from the Software. Any interpretations, analyses or modeling
of any data, including, but not limited to Customer data, and any recommendation or decisions based upon such interpretations, analyses or
modeling are opinions based upon inferences from measurements and empirical relationships and assumptions, which inferences and
assumptions are not infallible, and with respect to which professional may differ. Accordingly, Halliburton cannot and does not warrant the
accuracy, correctness or completeness of any such interpretation, recommendation, modeling or other products of the Software Product. As
such, any interpretation, recommendation or modeling resulting from the Software for the purpose of my drilling, well treatment, production
or financial decision will be at the sole risk of Customer. Under no circumstances will Halliburton or its suppliers be liable for any damages.
f 2015 l lalliburron. All Rights Reserved
Attachment C
HALLIBURTON
Table of Content,�
Customer: Oil Search Alaska, LLC
Job: Mitquq-1 T' Two -Stage Production Cement lob
1.0
Executive Summary ...................................................................................................................................
4
2.0
Job Infolmation............................................................................................................................................
5
2.1
First Stage Job Actuals.................................................................................................................................................................................................................5
2.2
Second Stage Job Actuals.. ................................ .......................................................................................................
........................................ ......................... 5
3.0
Real -Time Job Summary.............................................................................................................................
6
4.0
Job Chari......................................................................................................................................................
9
4.1
First Stage Job Chan.....................................................................................................................................................................................................................9
4.2
First Stage Displacement............................................................................................................................................................................................................
10
4.3
Inflate Packer and Open Tool ...... ..................... ............... ...........................................................................................................................
....................... ........ 11
4.4
inflate Packer........................... ____ ....................... .............. ................. ............................................................................................
............ .............. - ........... 12
4.5
Second Stage Job Chart..............................................................................................................................................................................................................
13
4.6
Second Stage Displacement........................................................................................................................................................................................................
14
5.0
Lab Results..........................................................................._....................................................................
1S
5.1
12.0# First Stage Lead Bulk Test Results.........................................................................................._..................................................._...._............................
15
5.2
15.3# First Stage Tail Bulk Test Results.....................................................................................................................................................................................
19
5.3
12.04 Second Stage Lead Bulk Test Results...............................................................................................................................................................................22
5.4
15.34 Second Stage Tail Bulk Test Results...............................................................................-............................................................._.__..____._._....__.
_.7s
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I Attachment C
HALLIBURTON
1 0 GzcCulivc Junun;Jry
Mr. Staudinger,
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
Halliburton appreciates the opportunity to perform the cementing services on Mitquq ST -1. The service supervisor arrived on location
at 11:30 on Febmary 18", 2020 in order to run the shoe track and ESIPC in hole.
Halliburton maintains a continuous quality improvement process and appreciates any comments or suggestions that you may have.
Halliburton Energy Services again thanks you for the opportunity to perform services work on this well. We hope to be your solutions
provider for future projects.
Thank You,
Savannah Alan
Technical Professional — Cement and Casing Equipment
6900 Arctic Blvd.
Anchorage, AK 99518
Email: savannah.afoa@r)halliburton.com
Mobile: +1 907-223-9423
Office: +1 907-273-3568
"Design Pad Deliver Dependable Barriers Tailored to Minimize Risk and Maximize Production"
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Attachment C
HALLIBURTON
2.0 Job Information
2.1 First Stage Job Acluals
Customer Oil Search Alaska, LLC
Job: Mitquq-1 7"Two-Stage Production Cement lob
Fluid
Target
Volume
Actual
Volume
Average
Density
Target
Density
Avera a Rate
bbls
bbls
( )
( )
(bpm)
2.2 Second Stage Job Actuals
Page 5
Fluid
Target
Volume
Actual
Volume
Average
Density
Target
Density
Avera a Rate
bbls)
bls)
( )
( )
(bpm)
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Attachment C
HALLIBURTON
3.0 Real -Time Job Summary
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
Seq. Graph Label Date Time DS Pump Press
DH Density
Comb Pump
Pump Stg Tot Comments
No.
Rate
(psi)
(pop)
(bbl/min)
(bbl)
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Attachment C
HALLIBURTON
Page 7
Customer: Oil Search Alaska, LLC
Job: Mitquq-17- Two -Stage Production Cement Job
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Attachment C
HALLIBURTON
Page 8
Customer: Oil Search Alaska, LLC
Job: Mitquq-1
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Attachment C
HALLIBURTON
41 First Stage Jub Chart
Page 9
Customer: Oil Search Alaska, LLC
Job: Mequq-1 T'
iCenn' Service
(v. 6.2.393)
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Attachment C
HALLIBURTON
4.2 First Staee Disolacement
Page 10
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
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Attachment C
HALLIBURTON
4.3 Inflate Packer and Open Tool
Page 11
Customer: Oil Search Alaska, LLC
Job: Mitquq-1 T' Two -Stage Production Cement Job
iCem° Service
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Attachment C
HALLIBURTON
4.4 Inflate Packer
Page 12
Customer: Oil Search Alaska, LLC
Jab: Mitquq-17" Two -Stage Production Cement Job
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Attachment C
HALLIBURTON
4.5 Second Stage Jab Chart
Page 13
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
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Attachment C
HALLIBURTON
4.6 Second Stage Displacement
Page 14
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
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Attachment C
HALLIBURTON
5.0 Lab Result,
5.1 12.0# First Stage Lead Bulk Test Results
HALLIBURTON
West Coast, Prudhoe Bay
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement lob
Lab Results- Lead
Request/Slurry 2616380/1 Big Name Date 14/FEB/2020
Submitted By Savatmah Aloa Job Type Production Casing Bulk Plant Prudhoe Bay, AK USA
Customer Oil Search Ltd. Location Greater Prudhoe Bay Well Mitquq ST -I
Casing/Liner Size
Mud Supplier Name Baroid
Mud Trade Name
Cone UOM Cement/.Addifive MP Sample "rwe Sammi t No.
Slurry Comments
Bulk Test for OSA Maquq ST -1 First Stage Lead
Mixability (0 - 5) - 0 is not mixable, Request Test ID37260329
Page 15
Density
Cement Properties
17/FEW2020
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Attachment C
HALLIBURTON Customer: oil Search Alaska, LLC
Job: Mitquq-1 7" Two -Stage Production Cement lob
Thickening Time - ON -OFF -ON, Request Test ID:37267969 IMB/2020
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Attachment C
HA L L I B U R TO N Customer: Oil Search Alaska, LLC
Job: Mitquq-1 7"Two-Stage Production Cement lob
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Attachment C
H A LL I B U R TO N Customer: Oil Search Alaska, LLC
Job: Mitquq-1 7" Two -Stage Production Cement Job
iCem' Service
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Attachment C
HALLIBURTON
5.2 15.3tt First Stage Tail Bulk Test Results
HALLIBURTON
West Coast, Prudhoe Bay
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
Lab Results- Tail
Request/Slurry
2616381/1
Rig Name
Date
14/FEB/2020
Submitted By
Savannah Afoa
Job Type
Production Casing
Bulk Plant
Prudhoe Bay, AK USA
Customer
Oil Search Ltd.
Location
Greater Pmdhoe Bay
Well
Mitquq ST -I
Ifilletif
\lud Supplier Name Baruid
Slurry Comments
Bulk testing for OSA Milquq-ST I Production First Stage Tail
Operation Test Results Request ID 261638//1
Page 19
hlud Trade Name
Density
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Attachment C
HA L L I B U R TO N Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
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Attachment C
HALLIBURTON Customer: oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement lob
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Attachment C
HALLIBURTOIV
5.3 12.04 Second Stage Lead Bulk Test Results
HALLIBURTON
West Coast, Prudhoe Bay
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Jab
Lab Results- Lead
Request/Slurry
2616382/1
Rig Name
Dale
14/FEB/2020
Submitted By
Savannah Afoa
Job Type
Production Casing
Bulk Plant
Prudhoe Bay, AK USA
Customer
Oil Search Ltd.
Location
Greater Prudhoe Bay
Well
Mitquq ST -1
t
blud Supplier Name Baroid Mud Trade Name Density
Cement Information -Lead Design
Bulk [eating for OSA Mitquq-ST 1 Production Second Stage Lead
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Attachment C
HALLI B U RTON Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement lob
Thickening Time - ON -OFF -ON, Request Test ID:37267946 I S/FEB/2020
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Attachment C
HALLIBU RTON Customer: oil Search Alaska, LLC
Job: Mitquq-1 7" Two -Stage Production Cement lob
CCA Comp. Strength, Bequest Tcst 1:37260337 20/FEB/2020
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Attachment C
HALLIBURTON
5.4 15.38 Second Stage Tail Bulk Test Results
HALLIBURTON
West Coast, Prudhoe Bay
Request/Slurry 2616383/1 Big Name
Submitted By Savannah Afore Job Type
Customer Oil Search Ltd. Location
Mud Supplier Nam, Baroid Mud Trade Name
Bulk testing for OSA Mitquq-ST I Production Second Stage Tail
Page 25
Customer: Oil Search Alaska, LLC
Job: Mitquq-17" Two -Stage Production Cement Job
Lab Results- Tail
Date 14/FEB/2020
Production Casing Bulk Plant Prudhoe Bay, AK USA
Greater Prudhoe Bay Well Mitquq ST -1
Density
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Attachment C
HALLIBURTON Customer: oil Search Alaska, LLC
lob: Mitquq-17" Two -Stage Production Cement lob
Thickening Time - ON -OFF -ON, Request Test ID:37260341 IS/FEB/2020
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Attachment C
HALLIBURTON
UCA Comp. Strength, Request Test ID:37260340
Page 27
Customer: Oil Search Alaska, LLC
Job: Mitquq-1 7" Two -Stage Production Cement lob
20/FEB/2020
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Attachment C
189.'
43.0"
78.4"
— 43.0' 43.0"
i
4-1116" IOM4'102
1062
FEMALE WECO
9-10(4-ACME)OTIS
4 -1116 -SM
4-1116" 10M
41116" 10M
4-1116' 10M
4-1118" 10M 3' MALE` J ` / 44116' 16M 3' FEMALE
4-11 WEC0 `M•/ ��/ 1502WE60
4-1/16" 10M
Pressure Control _
BA ER ® 16" x 9-5/8" x 7" x 4-1/2 x 3-1/2" 5/1 OM MB -230 MultibovA Assembly,
IUGHES With MB -230 Upper Head and MB -230 Tubing Hanger and K Tubing Bonnet
a GEcompany
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(KAB Attachment D CIL SEARCH ALASKA
LU
Y
C
N
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Schlumberger
FracCADE*
STIMULATION PROPOSAL
Operator Oil Search
Well
Field
Formation
Mark of Schlumberyar
This info mOtion is presented in good mon bmno worranryisgiwn by and eblumberger euumes no Malay for advice or recommendation made concerning results m be rba
from the use of any product or service. fie results given are estimates be d on calculations produced bye computer model lncfutliag various assumptions ratio well, Maervri
treatment The results depend on input dem provitle0 by the Operator en agencies as to unknown data and can be as more accurate man the model, Me assumptions and
input data. The incarnation presented ii Schlumbergersbast estimate of a what maybe Nat may be achieved and should be used for companion purposes rather then obs
values. Tho c a floyafInput data, Bnd M1anCOIeOYI(5, may be impNVad Nr0 gh the use of Caltam tests and procedures which SchNmbelger can emetic In selecting.
The Operator has superior knowledge of the well, Me reservoir the Bold and conditimsagecting them. Ifthe OpemtorisawareofanyeonditionswM1erebyana,liborimgwellor
might be affected by the treatment proposed harem n is the 0,emler'a responsibility to amity Me owner or owners of the well or walls scenically,
Prices eu0ted are estimates Only and Bre good for 30 days from the date of Issue. Actual charges may very depending upon time, eculpment, and maternal altimamly Rgused to
pedor n these seraces.
Attachment G
Schlumberger -Private
County
North Slope
State
Alaska
Country
United States
Prepared for
Scott Leahy
Service Point PRUDHOE BAY
Proposal No.
Business Phone 1907 659 2434
Date Prepared
3/8/2020
FAX No. 1907 659 2538
Prepared by
Mike Hyatt
Phone
907-273-4748
E -Mail Address
MHyatt®slb.com
Mark of Schlumberyar
This info mOtion is presented in good mon bmno worranryisgiwn by and eblumberger euumes no Malay for advice or recommendation made concerning results m be rba
from the use of any product or service. fie results given are estimates be d on calculations produced bye computer model lncfutliag various assumptions ratio well, Maervri
treatment The results depend on input dem provitle0 by the Operator en agencies as to unknown data and can be as more accurate man the model, Me assumptions and
input data. The incarnation presented ii Schlumbergersbast estimate of a what maybe Nat may be achieved and should be used for companion purposes rather then obs
values. Tho c a floyafInput data, Bnd M1anCOIeOYI(5, may be impNVad Nr0 gh the use of Caltam tests and procedures which SchNmbelger can emetic In selecting.
The Operator has superior knowledge of the well, Me reservoir the Bold and conditimsagecting them. Ifthe OpemtorisawareofanyeonditionswM1erebyana,liborimgwellor
might be affected by the treatment proposed harem n is the 0,emler'a responsibility to amity Me owner or owners of the well or walls scenically,
Prices eu0ted are estimates Only and Bre good for 30 days from the date of Issue. Actual charges may very depending upon time, eculpment, and maternal altimamly Rgused to
pedor n these seraces.
Attachment G
Schlumberger -Private
Client Oil Search
Well Mitquq
Formation Nanushuk
District Prudhoe Bay
Country United States
3chlMopger
Section 1: Zone Data
Attachment
Schlumberger -Private
Client
Oil Search
Well
Mitquq
Formation
Nanushuk
District
Prudhoe Bay
Country
United States
Schlumberger
Attachment
Schlumberger -Private
Client
Oil Search
Well
Mitquq
Formation
Nanushuk
District
Prudhoe Bay
Country
United States
Schlumberger
Section 2: Propped Fracture Schedule
Pumping Schedule
The following is the Pumping Schedule to achieve a propped fracture half-length (XI) of 219.01twith an
average conductivity (Kew) of 15451 md.ft.
Please note that this pumping schedule is under -displaced by 5.0 bbl.
Fluid Totals
Proppant Totals
Pad Percentages
Attachment
Sch I um berger-Private
Job Description
Step
Name
Pump
Rate
(bbl/min)
Fluid Name
Step Fluid
Volume
(bbl)
Gel
Conc.
(Ib/m all
Prop.
Type and Mesh
Prop.
Conc.
(PPA)
PAD
30.0
YF125ST
200
20.0
0.00
1.0 PPA
30.0
YF125ST
96
20.0
16/20 C-
1.00
2.0 PPA
30.0
YF125
138
20.0
16/20 C
2.00
4.0 PPA
28.0
YF125ST
191
20.0
16120 C-
4.00
6.0 PPA
27.0
YF125ST
198
20.0
16/20 C-
6.00
8.0 PPA
25.0
YF125ST
185
20.0
16/20 C-
8.00
9.0 PPA
20.0
YF125ST
90
20.0
16/20C
9.00
10.OPPA
20.0
YF125ST
76
20.0
i"BC-
10.00
FLUSH
20.0 1
WF125
1 40
30.0
0.00
Please note that this pumping schedule is under -displaced by 5.0 bbl.
Fluid Totals
Proppant Totals
Pad Percentages
Attachment
Sch I um berger-Private
Client Oil Search
Well Mitquq
Formation Nanushuk
District Prudhoe Bay
Country United States
Name
PPA
Schlumberger
Fluid Volume Slurry Slurrylume Prop Prop. Surface Time Time
Volume (bbl) Volume Vo(lb) (lb) Pressure (min) (min)
(bbl) I (bbl) (bbl) I (osi)
100.0
300.0
3.3
150.0
450.0
_
_ 5.0
225.0
675.0
8.0
250.0
925.0
_
9.3
250.0
1175.0
_
10.0
125.0
1300.0
_
6.3
110.0
1410.0
_
5.5
40.1
1450.1
_
2.0
5 Attachment G
Schlumberger -Private
Client Oil Search
Well Mitquq
Formation Nanushuk
District Prudhoe Bay
Country United States
3chluMopyr,
Section 3: Propped Fracture Simulation
The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D
Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with
positive net heights.
Initial Fracture Top TVD
Initial Fracture Bottom TVD
Propped Fracture Half -Length
EOJ Hyd Height at Well
Average Propped Width
Net Pressure
Max Surface Pressure..
Results by Fracture
From To Prop. Conc. Propped Propped
(ft) Ih) at End of Width Height
Pumping (in) (ft)
moor
Schlumberger -Private
Frac. Frac. Fracture
Prop. Gel Conc. Conductivity
Conc. (lb/mgal) (md.ft)
n.rw11
Attachment
Schlumberger
Client:
Oil Search Alaska
Well:
Mhquq
Basin/Field:
Pikka
State:
Alaska
County/Parish:
North Slope Borough
Case:
1 Gal 1000 Gal
Disclosure Type:
Pre -Job
Well Completed:
2/14/2020
Date Prepared:
11/19/2019 2:17 PM
Report ID:
RPT -64247
Fluid Name & Volume
Additive
Additive Description
CAS Number
Chernical Name
Waterincludin Mix Water Supplied by Client)*
8484
Enzyme Breaker 8484
0.03 Gal 1000 Gal
^29%
F103
Surfactant
1 Gal 1000 Gal
56-81-5
J450 _
Stabilizing Agent
0.5 Gal 1000 Gal
Sodium tetraborate decahydrate
J475
Breaker
3 Lb / 1000 Gal
<0.1 %
_ 1511
Stabilizing Agent
2.7 Lb 1000 Gal
WF120:YF320ST 67,200 Gal
1532
Crosslinker
_ 5.4 Gal / 1000 Gal
Sorbitol
1580
Gelling Agent
20 tb/1000 Gal__
<0.1 %
1065
Scale Inhibitor
2 Gal/1000 Gal
111-76-2
M002
Additive
0.5 Lb 1000 Gal
Ethoxylated CII Alcohol
M2]5
Bactericide
0.4 Lb 1000 Gal
<0.01 %
$522-1218
Propping Agentvarled
_
concentrations
25038-72-6
5522-1620
Propping Agent
_
varied concentrations
me rotor vmmnenmarn tore mores 000wrcwesenrs the summoaon o)vmrermaaaamves. warens suppxeaay nrem.
Attachment H
0 Schlumber9er1019. Osedby Oil Searh Alaska bypermi.miu Page: I / 2
CAS Number
Chernical Name
Waterincludin Mix Water Supplied by Client)*
-71%
66402-68-4
Ceramic materials and wares, chemicals
^29%
9000-30-0
Guargum
< 1 %
56-81-5
1, 2, 3 - Propanetriol
<0.1 %
1303-96-4
Sodium tetraborate decahydrate
<0.1 %
102-71-6
2_,2',2"-nitrilotriethanol
<0.1 %
107-21-1
Ethylene glycol
<0.1 %
129898-01-7
_ _ _ _
2-Propeno_icacid, polymer with sodium phosphinate
< 0.1 %
50-70-4
Sorbitol
<0.1 %
7727-54-0
Diammonium peroxodisulphate
<0.1 %
67-63-0
Propm-2-ol
<0.1 %
111-76-2
2-buto ethanol
<0.1 %
34398.01-1
Ethoxylated CII Alcohol
<0.1 %
68131-39-5
Ethoxylated Alcohol
<0.01 %
7647-14-5
Sodium chloride
<0.01 %
25038-72-6
Vinylidene chloride/methylacrylate copolymer
<0.01 %
1310-73-2
Sodium hydroxide
<0.01 %
10043-52-4
Calcium Chloride
< 0.01 %
91053-39-3
Diatomaceous earth, calcined_ _
<0.01 %
112-42-5
Undecanol
<m %
7631-86-9
Non -crystalline silica (impurity)
<0.001 %
111-46-6
2,2-oxydiethanol (impurity)
<0.001 %
_ 10377-60-3
Magnesium nitrate
<0.001 %
2617_2_-55-4
5-chloro-2-methyl-2h-isothiazolol-3-one
<0.001 %
7786-30-3
Magnesium chloride
<0.001 %
14807-96-6
Magnesium silicate hydrate (talc)
<0.001 %
7447-40-7
Potassium chloride (impurity)
<0.001 %
9002-84-0
oly(tetrafluoroethylene)
<0,0001 %
2682-20-4
2-methyl-2h-isothi zol-3-one
<0.0001 %
_ 127-08-2
Acetic acid, pot as i um salt
<0.0001%.
68-04-2
14808-60-7
Sodium citr to
Quartz, Crystalline silica
<0.0001 %
<0.0001 %
14464-46-1
CGirtobalite
<0.0001 %
901254-8 _ _ _
Hemicellvlase enzyme
<0.0001 %
64-19-7
Acetic acid(impudty
<0.0001%
2634-33.5
1,2-benzisothiazolin-3-one
<0.00001 %
Attachment H
0 Schlumber9er1019. Osedby Oil Searh Alaska bypermi.miu Page: I / 2
Schlumberger
Client:
Oil Search Alaska
Well:
MRquq
Basin/Field:
Pikka
State:
Alaska
County/Parish:
North Slope Borough
Case:
Disclosure Type:
Pre -lob
Well Completed:
2/14/2020
Date Prepared:
11/19/2019 2:17 PM
Report ID:
RPT -64247
-Mix "ter Is tupplhE by the client SfNumberyetFos petfonne0 twanolytls Lrhe wvteronAcannotproviEeaMeatEoww ofawnponen[s that may have been atltledro Ne watetby lhitbpartles.
-the evolwdm ofafth heddocumentapedorme0boseEonrMrompmitlonafMe hiennfreJpsoiacts ro the eventrhatsuh compositlonallnfmmamn watenown to GRC{hemimis as ofthe date ofthetlowment
was proEuce4 Any new u 0h, will win he ftArM 0in this dMament.
0 Schlambes9er1019. UsedbytN'I Scorch Aloskabypelmission. Attachment Page: 2/2
Mitquq 1 ST -1 Clean-up and Test Summary
Per regulation 20AAC25.235 (d) 6, Oil Serch is requesting AOGCC permission to flare the produced gas
for the duration of the exploration well production test.
Attachment I
Well Cleanup - Operational Summary:
• Estimates Time: or as dictated by Oil Search Reservoir Engineer.
• Target Clean-up Flow Rate:
• Target Post Clean-up Flow Rate:
• Choke Setting: Use adjustable choke to achieve a flow rate at approximately 100 psi per
hour drawdown or until well is stable. Watch BS&W and adjust drawdown rate as
needed. The OSA Reservoir Engineer or OSA Well Test Supervisor will advise choke
changes based on well performance and solids production.
• Proppant Production: Proppant production is expected and will managed by bringing on
the well slowly and beaning up choke based on well performance and bottoms up solids
production.
• Annulus Pressure: The annulus pressure is expected to increase due to thermal
expansion. The maximum annular pressure is 2,000 psi, bleed down as necessary.
• N2 Injection Rate: As per contingency N2 well kick-off procedures if required.
• Methanol Injection Rate: McOH will be injected into the well via the inner annulus to
prevent the formation of hydrates. Injection rates will vary based on produced water
volumes.
• Sampling: As per sampling table below.
Attachment I
Main Flow- Operational Summary:
• Estimates Time: as directed by OS Reservoir Engineer.
• Main Flow Period:
• Choke Setting: Bring the well on slowly using the PTS adjustable choke, OSA Engineer
will advise drawdown targets based on observation from initial flow. Step open choke
until desired flow rate is achieved, then switch to a positive choke. The OSA Reservoir
Engineer & OSA Well Test Supervisor will advise target rates and choke changes.
• Proppant Production: Minimal proppant production is expected.
• Annulus Pressure: The annulus pressure is expected to increase due to thermal
expansion. The maximum annular pressure will be 2,000 psi., bleed as required.
• Downhole Shut-in Valve: A programable down -hole shut-in valve has been installed.
• Sampling: Asper sampling table below
Fluid Rates & Volumes - Tank Straps will be used for all reported fluid rates & Volumes, in addition there
will be turbine meters on the oil and water legs of the separator for reference.
Gas Rates & Volumes - A Daniels differential pressure flow meter.
Attachment I
Mitquq STI Fracturing Procedure
Treatment MD Perf TVD Perf
Depth (ft) Depth (ft)
I Job Max I
Max Frac Frac % Max Rate Max Max Prop
Height (ft) Length (ft) (bpm) Pressure Conc.
(psi) (PPA)
MAW P = 5,700 psi, GORV = 5,400 psi, IA Pressure Max psi = 2,600 psi, IA PRV = 2,900 psi
1. MIRU Schlumberger frac equipment and treating line to the frac tree.
2. R/U to the annulus valve and isolate the pressure relief valve.
3. Pressure test IA line to 3,100 psi.
4. Open line to annular PRV and verify relief at 2,900 psi.
S. Open the casing valve and proceed to pressure up the 7" x 3'/: annulus to 2,600 psi.
6. Prime up the frac pumps.
7. Isolate the GORV on the treating line and pressure test the treating line to 6,500 psi.
8. Upon successful pressure test, bleed off pressure and open the GORV on the treating line.
9. Open well head and pump DataFRAC.
10. Shut down and isolate the wellhead pressure gauge from the pumps if necessary.
11. Monitor the bottom hole, wellhead, and annulus pressures until closure is observed.
12. Modify PAD volume and/or schedule if necessary.
13. Pump frac treatment as referenced in attachment G.
14. Upon completion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and
demobilize frac equipment from wellsite.
Attachment J
Held IA
IA PRV (psi)
GORV (psi)
Pump Trip
Pressure
Pressure
(psi)
(psi)
Job
2,600
2,900
5,400
5,000
Treatment MD Perf TVD Perf
Depth (ft) Depth (ft)
I Job Max I
Max Frac Frac % Max Rate Max Max Prop
Height (ft) Length (ft) (bpm) Pressure Conc.
(psi) (PPA)
MAW P = 5,700 psi, GORV = 5,400 psi, IA Pressure Max psi = 2,600 psi, IA PRV = 2,900 psi
1. MIRU Schlumberger frac equipment and treating line to the frac tree.
2. R/U to the annulus valve and isolate the pressure relief valve.
3. Pressure test IA line to 3,100 psi.
4. Open line to annular PRV and verify relief at 2,900 psi.
S. Open the casing valve and proceed to pressure up the 7" x 3'/: annulus to 2,600 psi.
6. Prime up the frac pumps.
7. Isolate the GORV on the treating line and pressure test the treating line to 6,500 psi.
8. Upon successful pressure test, bleed off pressure and open the GORV on the treating line.
9. Open well head and pump DataFRAC.
10. Shut down and isolate the wellhead pressure gauge from the pumps if necessary.
11. Monitor the bottom hole, wellhead, and annulus pressures until closure is observed.
12. Modify PAD volume and/or schedule if necessary.
13. Pump frac treatment as referenced in attachment G.
14. Upon completion of frac, isolate well head, bleed off line pressure, rig down frac equipment, and
demobilize frac equipment from wellsite.
Attachment J
Mitquq: HP Line PRV Rigup
200— 500 bbl Tank
(with baffles)
1502 Weco Connection
Attachment K
Mitquq 1 ST1
Well Schematic
Surface Casing 9-5/8" 40# L80 BTC
Tubing P/T Gauges
3-%", 'XN' Landing Nipple
3-%" X 7" Packer
Oil Search
Updated Feb 26h, 2020
3-%'. 2.813" Polish Bore 'X'Landing Nipple
3-1/2" 9.2# L80 Vam Top Tubing
ESIPC Stage Cement Too
GLM, 3'/:'
STI Kick Off @
End of Tubing
Planned Perforations
7" casing cut @
3-'/z' BHKA @
Production Casing7" 26# L80 Vam To HC
p 7" 26# L80 Vam Top HC
3-1/2" 9.2# L-80 IBT
Sacrificial Tubing
6-1/8" OH
200 inclination
Attachment L
