Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout215-126Guhl, Meredith D (DOA)
From: Guhl, Meredith D (DOA)
Sent: Monday, September 11, 2017 12:07 PM
To: 'Starck, Kai'
Cc: Bettis, Patricia K (DOA); Loepp, Victoria T (DOA)
Subject: Expired Permit to Drill: KRU 1G-11AL1 (PTD 215-126)
Hello Kai,
The following Permit to Drill, issued to ConocoPhillips Alaska, has expired under Regulation 20 AAC 25.005 (g). The PTD
will be marked expired in the AOGCC database.
• KRU 1G-11AL1, PTD 215-126, Issued 6 August 2015
If you have any questions, please contact me.
Thank you,
Meredith
Meredith Guhl
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl alaska.gov
Direct: (907) 793-1235
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.
The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail,
please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at
907-793-1235 or meredith.guhl(a)alaska.gov.
P 1_" 2/5 -/Z,�_
Loepp, Victoria T (DOA)
From: Eller, J Gary <J.Gary.Eller@conocophillips.com>
Sent: Monday, August 17, 2015 9:52 AM
To: Bettis, Patricia K (DOA)
Cc: Loepp, Victoria T (DOA); Venhaus, Dan E; Phillips, Ron L; Burke, Jason
Subject: RE: KRU 2E-151_1 & 1G-121-1
Follow Up Flag: Follow up
Flag Status: Flagged
Good morning, Patricia!
The exclusion of information on emergency KWF in the KRU 2E-15 (184-189) and 1G-12 (183-132) CTD applications was
intentional. ConocoPhillips' sent an e-mail to Victoria Loepp on July 21, 2015 stating our intention to no longer include
information on the emergency KWF in Kuparuk CTD drilling applications. At Victoria's request, Dan Venhaus
(ConocoPhillips CTD Supervisor), Kai Starck, and myself met with Jim Regg, Guy Schwartz, and Victoria on August 4,
2015 to discuss this. The discussion concluded in less than an hour to the satisfaction of the AOGCC representatives
present. Subsequently, the CTD applications for KRU 1G-11A and AL1 (215-125 & 215-126) were approved by the
Commission without reference to emergency KWF.
I hope that gives you sufficient information to proceed, and I would be glad to discuss this some more with you if that
would be beneficial.
-Gary Eller
From: Bettis, Patricia K (DOA)[ma iIto: patricia.bettis@alaska.gov]
Sent: Friday, August 14, 2015 2:35 PM
To: Eller, ] Gary
Subject: [EXTERNAL]KRU 2E-151-1
Good afternoon Gary,
What weight of KWF and volume of KWF will be available for emergency purposes while drilling this lateral?
Thank you,
Patricia
Patricia Bettis
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, AK 99501
Tel: (907) 793-1238
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential
and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If
you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware
of the mistake in sending it to you, contact Patricia Bettis at (907) 793-1238 or patricia.bettis@alaska.gov.
Loepp, Victoria T (DOA)
From: Venhaus, Dan E<Dan.Venhaus@conocophillips.com>
Sent: Tuesday, July 21, 2015 10:21 AM
To: Loepp, Victoria T (DOA)
Cc: Schwartz, Guy L (DOA); Eller, J Gary; Starck, Kai; Winfree, Mike A
Subject: 1G-11 permit changes
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria —
You should be receiving the PTD application for 1G-11 CTD sidetrack soon. We are making some verbiage changes to the
drilling fluids section and providing more explanation of the MPD equipment/process used in Coiled Tubing Drilling. We
hope to clarify items that you and I discussed on the recent 30-08 permit.
Some highlights:
Removed emergency kill weight fluid from fluids section in the PTD application since this fluid is not required either by
ConocoPhillips drilling policy or Alaska regulation. When MPD drilling was initiated in Kuparuk in 1998 the emergency
kill weight fluid was added as a contingency due to the newness of MPD technology. In 17 years of CTD operations we
have never used the emergency kill weight fluid for well control purposes. We have always maintained primary well
control with CT stripper and the MPD choke, both of which are 5K rated. Secondary well control is provided by the BOPE
while drilling. We feel this third level of well control (emergency kill weight fluid) is no longer needed.
Two wellbore volumes of overbalance completion fluid are readily available on the rig to kill the well for liner installation
(i.e. becomes primary well control). Completion fluid weight is designed for expected reservoir pressure along well
path. PTD applications will continue to include an explanation of how we determined this expected reservoir pressure
along the planned well path.
Maximum potential reservoir pressure in the area will continue to be used for calculating BOPE test pressure.
Please contact me should have any questions. We are more than happy to meet and show schematics of the rig layout
and pressure control systems, if needed.
Thanks!
Dan Venhaus
CTD Engineering Supervisor - Alaska
Cell 907-230-0188
Office 907-263-4372
THE STATE
01
LASKA
GOVERNOR BILL WALKER
D. Venhaus
CTD Engineering Supervisor
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.alaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 G-11 AL l
ConocoPhillips Alaska, Inc.
Permit No: 215-126
Surface Location: 327' FSL, 806' FWL, SEC. 29, T12N, R10E, UM
Bottomhole Location: 737' FSL, 1397' FEL, SEC. 29, T12N, R10E, UM
Dear Mr. Venhaus:
Enclosed is the approved application for permit to re -drill the above referenced development
well.
The permit is for a new wellbore segment of existing well Permit No. 215-125, API No. 50-50-
029-21008-01-00. Production should continue to be reported as a function of the original API
number stated above.
This permit to drill does not exempt you from obtaining additional permits or an approval
required by law from other governmental agencies and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
AOGCC reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to
comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit.
Sincerely,
�J� /!:�� q'—
Cathy P. oerster
Chair
DATED this 4tday of August, 2015.
RECEIVED
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION JUL 2 1 2015
PERMIT TO DRILL (�'y���
20 AAC 25.005 AOGC(-
C
1 a. Type of Work:
Drill ❑ Lateral
Redrill ❑ Reentry E
1 b. Proposed Well Class: Development - Oil ❑✓ Service - Winj ❑ Single Zone ❑
Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Exploratory ❑ Service - WAG ❑ Service - Disp ❑
1 c. Specify if well is proposed for:
Coalbed Gas ❑ Gas Hydrates ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
ConocoPhillips Alaska, Inca
5. Bond: Blanket Single Well
Bond No. 59-52-180
11. Well Name and Number:
KRU 1G-11AL1
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
6. Proposed Depth:
MD: 10303' • TVD: 6290'
12. Field/Pool(s):
Kuparuk River Field
Kuparuk River Oil Pool '
4a. Location of Well (Governmental Section):
Surface: 327' FSL, 806' FWL, Sec. 29, T12N, R10E, UM
Top of Productive Horizon:
1557' FNL, 1259' FEL, Sec. 32, T12N, T10E, UM
Total Depth:
737' FSL, 1397' FEL, Sec. 29, T12N, R10E, UM
7. Property Designation (Lease Number):
ADL 25640 -
8. Land Use Permit:
2571
13. Approximate Spud Date:
8/20/2015
9. Acres in Property:
2459 i
14. Distance to
Nearest Property: 19950
4b. Location of Well (State Base Plane Coordinates - NAD 27):
Surface: x- 540586 y- 5980976 Zone- 4
10. KB Elevation above MSL: , 99 feet
GL Elevation above MSL: 63 feet
15. Distance to Nearest Well Open
to Same Pool: 1G-10BL2 , 990
16. Deviated wells: Kickoff depth: 7614 ft.
Maximum Hole Angle: , 102° deg
17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole: 2898 psig , Surface: 2270 psig .
18. Casing Program:
Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
(including stage data)
Hole
Casing
Weight
Grade
Coupling
Length
MD
TVD
MD
TVD
3"
2.375"
4.7#
L-80
ST-L
2694'
7609'
6412'
10303'
6389'
slotted liner
19
1PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
8208'
Total Depth TVD (ft):
6918'
Plugs (measured)
7831'
Effective Depth MD (ft):
1 7359'
Effective Depth TVD (ft):
6200'
Junk (measured)
none
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
68'
16"
212 sx CS II
106'
106'
Surface
2314'
10.75"
930 sx AS III, 250 sx AS 1
2351'
2206'
Production
8151'
7"
610 sx Class G, 250 sx AS 1
8188'
6901'
Scab Liner
Perforation Depth MD (ft):
7540-7590, 7676-7722, 7945-7950, 7960-7982
Perforation Depth TVD (ft):
6355-6397, 6469-6507, 6694-6698, 6706-6725
20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Prograrr ❑ Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements ❑
21. Verbal Approval: Commission Representative: Date:
22. 1 hereby certify that the foregoing is true and correct. Contact Mike Winfree @ 263-4404
Email Michael.A.Winfreena.cop.com
Printed Name Venh s Title CTD Engineering Supervisor ,C
Signature l �G/'�� 'iiL� Phone:2634372 Date 7— Z,49��
Commission Use Only
Permit to Drill
Number: ( j'� — j
API Number:
50- C�, — : � U(J —�yQ "LV
Permit Approval
Date:
See cover letter
for other requirements
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales:
Other: BSamples req'd: Yes El No M Mud log req'd: Yes❑ No D,o f't5i`fo �oo1f��s i d
,�}hy�UJ pr�Jr�i�t� fry fry f faZjZe� ?easures: Yes [✓� No Directional svy req'd: Yes No
Spacing exception req'd: Yes ❑ No Inclination -only svy req'd: Yes ❑ No
G APPROVED BY THE
Approved by:aZ2,:::�"MMISSIONER COMMISSION Date:
Form 10-401(Rev i 0/201� /� is
tUal1drfjmAth
from the date of approval (20 AAA 25.0705��)j�� I
RECEIVED
ConocoPhillips
philli
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
July 16, 2015
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
..JUL 21 2015
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the Kuparuk Well
1 G-11 using the coiled tubing drilling rig, Nabors CDR2-AC.
CTD operations are scheduled to begin at the end of August, 2015. The objective will be to drill laterals KRU
1G-11A, and 1G-11AL1 targeting the Kuparuk C1 and C3/4 sands respectively.
Attached to this application are the following documents:
— 10-401 Applications for 1G-11A and 1G-11AL1
— Detailed Summary of Operations
— Directional Details for 1G-11A and 1G-1 1AL1 including anti -collision
— Proposed CTD Schematic
If you have any questions or require additional information please contact me at 907-263-4404.
Sincere
.�1 f
Mike A. Winfre
ConocoPhillips Alaska
Coiled Tubing Drilling Engineer
Kuparuk CTD Laterals NABOAR SxA
1 G-11 A& 1 G-11 AL1 Cis,,
Application for Permit to Drill Document 2RC
1.
Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))...................................................................................................................
2
2.
Location Summary..........................................................................................................................
2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................
2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................
2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................
2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................
2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................
3
7.
Diverter System Information..........................................................................................................
3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................
3
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(8))..................................................................................................................................................
3
9.
Abnormally Pressured Formation Information.............................................................................
4
(Requirements of 20 AAC 25.005 c 9...................................................................
4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................
4
11.
Seabed Condition Analysis............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................
4
12.
Evidence of Bonding......................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................
4
13. Proposed Drilling Program............................................................................................................. 5
(Requirements of 20 AAC 25. 005 c 13 ...................... 5
Summaryof Operations...................................................................................................................................................5
PressureDeployment of BHA..........................................................................................................................................6
LinerRunning...................................................................................................................................................................6
14. Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................ 6
15. Directional Plans for Intentionally Deviated Wells....................................................................... 7
(Requirements of 20 AAC 25.050(b))...................................................................................................................................................... 7
16. Quarter Mile Injection Review (for injection wells only)............................................................... 7
(Requirements of 20 AAC 25.402).......................................................................................................................................................... 7
17. Attachments.................................................................................................................................... 7
Attachment 1: Directional Plans for 1G-11A & AL1.........................................................................................................7
Attachment 2: Current Well Schematic for 1 G-11...........................................................................................................7
Attachment 3: Proposed Well Schematic for 1 G-11A & AL1...........................................................................................7
Page 1 of 7 7/20/2015
PTD Application: 1 G-11A & AL1
1. Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1G-11A & AL1. Laterals will be classified as
"Development— OX well.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the C1 & C3/4 sand packages in the Kuparuk reservoir. See the attached 10-401 form
for surface and subsurface coordinates of the 1G-11A & AL1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR2-AC.
BOP equipment is as required per 20 AAC 25.036, for thru-tubing drilling operations.
— Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,000 psi. Using the
maximum formation pressure in the area of 2898 psi in the 1 H-08, the maximum potential
surface pressure, assuming a gas gradient of 0.1 psilft, would be 2270 psi. See the "Drilling
Hazards Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Expected Downhole Pressure
(Requirements of 20 AAC 25.005 (c)(4)(a))
A static bottom hole pressure of 1 G-11 C sand in January 2015 indicated a reservoir pressure of 2794 psi or 8.4
ppg equivalent mud weight. The maximum down hole pressure in the 1G-11 pattern is at 11-1-08 with 2,898 psi.
It is not expected that the 1 G-11 reservoir pressure will be as high as 1 H-08. The 1 G11A & AL1 well bores are
planned over 4,000ft from the 1 H-08 well.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
No specific gas zones will be drilled. Gas injection has been performed on 1 G pad, so cuttings will be
monitored for entrained gas.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
Exposed shale while drilling the 1G-11 laterals, especially at fault crossings, has the potential to cause hole
problems. Managed pressure drilling equipment will be used to keep pressure on the well bore to minimum of
11.8ppge, which has historically kept shale sections stabilized at Kuparuk.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
N/A for this thru-tubing drilling operation.
According to 20 AAC 25.030(f), thru-tubing drilling operations need not perform additional formation integrity
tests.
Page 2 of 7 7/20/2015
PTD Application: 1G-11A & AL.1
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Name
MD
MD
TVDSS
TVDSS
1G-11A
7,655'
10,976'
6,451'
6,436'
2%", 4.7#, L-80, ST-L slotted liner;
with a shorty deployment sleeve..
1G-11AL1
7,609'
10,303'
6,412'
6,389'
2%", 4.7#, L-80, ST-L slotted liner;with
a shorty deployment sleeve.
Existing Casing/Liner Information
Category
OD
Weight
(ppf)
Grade
Conn.
Top
MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
16"
65
H-40
Welded
38'
106'
0'
106'
1640
630
Surface
10-3/4"
45.5
J-55
BTC
37'
2,351'
0'
2,206'
3580
2090
Casing
7"
26
J-55
BTC
37'
8,188'
0'
6,901,
7240
5410
Tubing
3'/2"
9.3
L-80
EUE8Rd mod
31'
7,366'
0'
1 6,212' 1
6990
7400
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
N/A for this thru-tubing drilling operation.
Nabors CDR2-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
Diagram of Nabors CDR2-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride weighted FloVis water based mud (9.1 ppg)
— Drilling operations: Chloride weighted FloVis water based mud (9.1 ppg).' This mud weight will
hydrostatically overbalance the reservoir pressure.
— Completion operations: Liner running operations will be done with 11.8ppg Bromide weighted
completion fluid to maintain well bore stability during completion operations.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the openhole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud
weight is not, in many cases, the primary well control barrier. This is satisfied with the coiled tubing stripper and
MPD choke which are not part of the BOP equipment but are tested to the same pressure and frequency as the
BOPE as detailed in section 3 "Blowout Prevention Equipment Information".
The targeted MPD BHP will be 11.8 ppg EMW at the window. The constant BHP target will be adjusted through
choke pressure and/or mud weight increases to maintain overbalanced conditions if increased reservoir
pressure is encountered. Additional choke pressure or increased mud weight may also be employed for
improved borehole stability. Any change of circulating friction pressure due to change in pump rates or change
in depth of circulation will be offset with back pressure adjustments.
Page 3 of 7 7/20/2015
PTD Application: 1G-11A & AL1
Pressure at the 1G-11A Window (7660' MD, 6455' TVD) Usinq MPD
Pumps On
(1.5 bpm)
Pumps Off
C-sand Formation Pressure (8.4 ppg)
2794 psi
2794 psi
Mud Hydrostatic (9.1 ppg)
3055 psi
3055 psi
Annular friction (i.e. ECD, 0.090 psi/ft)
690 psi
0 psi
Mud + ECD Combined
3745 psi
3055 psi
(no choke pressure)
(over balanced
(over balanced
—950 psi)
—261 psi)
Target BHP at Window (11.8 ppg)
3960 psi
3960 psi
Choke Pressure Required to Maintain
215 psi
905 psi
Target BHP
Pressure at the 1G-11AL1 Window (7614' MD, 6416' TVD) Using MPD
Pumps On
(1.5 bpm)
Pumps Off
C-sand Formation Pressure (8.4 ppg)
2794 psi
2794 psi
Mud Hydrostatic (9.1 ppg)
3035 psi
3035 psi
Annular friction (i.e. ECD, 0.090 psi/ft)
685 psi
0 psi
Mud + ECD Combined
3720 psi
3035 psi
(no choke pressure)
(over balanced
(over balanced
—926 psi)
—241 psi)
Target BHP at Window (11.8 p)
3937 psi
3937 psi
Choke Pressure Required to Maintain
217 psi
902 psi
Target BHP
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A — Application is for a land -based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Page 4 of 7 7/20/2015
PTD Application: 1G-11A & AL1
13. Proposed Drilling Program
(Requirements of 20 AA 25.005(c)(13))
Summary of Operations
Background
KRU 1G-11 will be a dual lateral producer. A recent RWO was performed to replace the tubing to allow
for CTD operations. The objective of this well is to drill 2 laterals on either side of a E-W fault to develop
the C sand regions in the area.
1G-11A will kick off in the C2 sand at 7,660' MD via a 2 string cemented window exit, then land in the B
shale. An evaluation of the C1 resistivity log will be made after landing and the well. The well will
continue to be drilled in the B shale for an additional 800 feet to bypass the fully swept C1 near the parent
well. Length of B shale footage drilled before turning up to reacquire the C1 sand will be determined once
the Cl log near the window has been analyzed. The 1G-11A lateral has two potential faults mapped with
variable throw predicted in the 10-25' range. TD is planned at 10,976' MD. The lateral will be completed
with 2-3/8" slotted liner with the liner top placed inside the window at 7,655' MD.
1G-11AL1 will kick off the billet at 7,614' MD in the C2 sand via a 2 string cemented window exit. The
well bore will drop into the C1 before turning up to acquire the C3/4 interval. The well will be geosteerd in
pay until TD at 10,303' MD. The lateral will be completed with 2-3/8" slotted liner with the liner top set
inside the window at 7,609' MD.
Pre-CTD Work
■ Coil: Cement 3'/2" x 7" annulus around planned window area to support CTD casing exit
■ E-line: Set a 3'/2" thru-tubing whip -stock at 7,660' MD and 0° HS
Rig Work
1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
2. 1G-11A Lateral (Cl sand - South)
i. Mill 2.80" window at 7,660' MD
ii. Drill 2.70" x 3.00" bi-center lateral to TD of 10,976' MD
iii. Run 2%" slotted liner with deployment sleeve from TD up to 7,655' MD
3. 1G-11AL1 Lateral (C3/4 sand - North)
i. Mill 2.80" window at 7,614' MD
ii. Drill 2.70" x 3.00" bi-center lateral to TD of 10303' MD
iii. Run 2%" slotted liner with deployment sleeve from TD up to 7,609' MD
4. Freeze protect the well. Set BPV, ND BOPE. RDMO Nabors CRD2-AC.
Post -Rig Work
1. Pull BPV
2. Obtain static BHP.
3. Put back on production
Page 5 of 7 7/20/2015
PTD Application: 1G-11A & AL1
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves
on the Christmas tree. MPD operations require the BHA to be lubricated under pressure, so installed in this
well is a down hole deployment valve. This valve, when closed using hydraulic control lines from surface,
isolates the well pressure and allows long BHA's to be deployed/un-deployed without killing the well.
If the deployment valve fails, operations will continue using the standard pressure deployment process. A
system of double swab valves on the Christmas tree, double deployment rams, double check valves and double
ball valves in the BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures
there are always two barriers to reservoir pressure, both internal and external to the BHA, during the
deployment process.
During BHA deployment, the following steps are observed.
— Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is
installed on the BOP riser with the BHA inside the lubricator.
— Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened
and the BHA is lowered in place via slickline.
— When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off
above the deployment rams.
— The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is
equalized, and the deployment rams are opened. The BHA and coiled tubing are now ready to run in
the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Liner Running
— While running 23/" slotted liner, a joint of 2%" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 23/" rams will provide
secondary well control while running 2%" liner.
— The 1G-11 CTD laterals will be displaced to an overbalance completion fluid (as detailed in Section 8
"Drilling Fluids Program") prior to running liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well. ,
• All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18
or 1 B disposal facilities) or Prudhoe DS-4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
Page 6 of 7 7/20/2015
PTD Application: 1G-11A & AL1
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
— The Applicant is the only affected owner.
— Please see Attachment 1: Directional Plan
— Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
— MWD directional, resistivity, and gamma ray will be run over the entire openhole section. ✓
— Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name Distance
1 G-11 A 20,200'
1 G-11 ALl 19, 950'
— Distance to Nearest Well within Pool (measured to offset well)
Lateral Name
Distance
Well
1 G-11 A
1, 040'
1 G-14
1 G-11 AL1
990'
1 G-10BL2
16. Quarter Mile Injection Review (for injection wells only)
(Requirements of 20 AAC 25.402)
NA- 1G-11 is a production well.
17. Attachments
Attachment 1: Directional Plans for 1G-11A & AL1
Attachment 2: Current Well Schematic for 1G-11
Attachment 3: Proposed Well Schematic for 1G-11A & AL1
Page 7 of 7 7/20/2015
0
� - \
\ \ \
{ Bo0 "
-
S \]
!\ \\g g_
\} § @ ! m `$ \
o a - - k \ { J
& ) \7 {/] ] - [
�\ ) ru§® § - k K#f §c
)/ .§ \ƒ a) !/ƒ / ) 2 \� \[
2' Luj§ \ 0 0 / ~ )g {�
)[ /�
LA A-
.. .
.. . .. .
� Z«w>•
g
c §
§§ \g( §§ \ \g \g
o
{_) ( ID f ® ~
/ }g bo
\d /ƒ \ \
_° � \\\
§\ &
({ j
M TX)a C)
OC) h M -
M O II
Lo KS cu I I M I I M
C_ Q II II O O
CO 01 (U I M
Q I I O t`
N I p p I
O II 1 i a) II N
ffM a) V) N I O Q
gnf,? a) t0 W I O I Q O
U _ N O 1 Q_ I I
"•i ! `C mod' 0 O f� C j O` -0 I a) o
7 cf7 N (U 1 1 Q I N C
h
O r t; I I J O I I Q�
� Q) 1 1 Q N I I p a)
Q) N M M C-)_ I 0-1 C ti r h M OO + 1 1 �- N I p
@ M 4) cu °� V c0 I N I I W
m¢ '0 n � U Q 6 LO a� i (�M
c o a) o_ p rn a+ O I I N
o 'p co 'c Q -O (O 0 Q O) 1 1 I
[�pqq N a (B O CV N I I I
85
E QO co lot
£ W aM cC, CO I\ UNO I
I` C Q r I I
U W to N
pN`oi UN � a) n 6 YO
CD 7N 'OM (.O U pO �
0
o 0 N U O) Co O. C)
mmo U- ° w -
oM 0 o L m=z
co L U O Ulow(m6 1I1 I111 IIII
II i t
cA N N (1) (1) N N N (N 1
U) N vN I I
N c� c'> ram. m m c.) M w ch O co U O M M
II II
II II
11 II
11 ��
II
11
11
z`
U r..
U)
0
I--
U
p O ?>> o
o ❑o of m C
O L? 2i r_ n0
20 0 c9 to CV L�
O N (D Q C C ao a0
k �p In � (o a) a)
r- _�I � f�� I'- QC) N V LO
Mr�/lM
OCl) _ � (
V @J °ZE@ U04
Q (O(0Ma)�` E
�0 N r- N(O UMM r-
�J�
o °� U) UUU N II II
�-2vo a)
d ��m U
OQ(rp�
6 South( -)/North(+) (250 usft/in)
p0+� t�ii O S in N SZ J N N O p
O
O C
G
O
O O O
_
e;
:
s
:n
O
I
I
9
Mi
1- .__
______
p
C-
f
IF
n
�
9aVu�
_
I
,
s
I
I
_
1
i
t' 9'-
__.._..__
I
of
I
9
a
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1G Pad
1 G-11
1G-11AL1
Plan: 1G-11AL1_wp03
Standard Planning Report
06 July, 2015
ConocoPhillips
Database:
EDM Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1G Pad
Well:
1G-11
Wellbore:
1G-1 1AL1
Design:
1 G-11AL1_wp03
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1G-11
Mean Sea Level
1G-11 @ 99.00usft (1 G-1 1)
True
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
welas
BAKER
HUGHES
Site Kuparuk 1G Pad
Site Position:
Northing:
5,981,540.78usft Latitude:
70° 21' 37.826 N
From: Map
Easting:
540,089.12usft Longitude:
149° 40' 27.705 W
Position Uncertainty: 0.00 usft Slot Radius:
0.000 in Grid Convergence:
0.31 °
Well 1 G-11
Well Position +N/-S
0.00 usft Northing:
5,980,976.13 usft Latitude:
700 21' 32.246 N
+E/-W
0.00 usft Easting:
540,585.50 usft Longitude:
149° 40' 13.280 W
Position Uncertainty
0.00 usft Wellhead Elevation:
usft Ground Level:
0.00 usft
Wellbore 1G-11AL1
Magnetics Model Name
Sample Date
Declination Dip Angle
Field Strength
(') V)
(nT)
BG G M 2015
10/1 /2015
18.85 81.00
57,501
Design 1G-11AL1_wp03
Audit Notes:
Version:
Phase: PLAN
Tie On Depth:
7,600.00
Vertical Section:
Depth From (TVD)
+N/-S +E/-W
Direction
(usft)
(usft) (usft)
(1)
0.00
0.00 0.00
350.00
71612015 4:03:29PM Page 2 COMPASS 5000.1 Build 61
ConocoPhillips
Database:
EDM Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk I Pad
Well:
1G-11
Wellbore:
1 G-11 AL1
Design:
1 G-11AL1_wp03
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Plan Sections
Measured
TVD Below
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
(usft)
(1)
V)
(usft)
(usft)
(usft)
7,600.00
33.47
128.40
6,306.23
-1,880.13
3,219.15
7,614.00
33.54
128.33
6,317.90
-1,884.93
3,225.21
7,639.00
43.54
128.33
6,337.43
-1,894.57
3,237.42
7,669.00
56.87
125.56
6,356.59
-1,908.35
3,255.83
7,699.00
68.21
117.26
6,370.42
-1,922.10
3,278.53
7,729.00
75.37
105.20
6,379.82
-1,932.33
3,305.04
7,799.00
84.66
74.59
6,392.24
-1,931.95
3,373.04
7,869.00
102.21
48.29
6,387.98
-1,899.09
3,433.71
7,939.00
101.43
16.09
6,373.27
-1,841.92
3,469.66
8,249.00
101.72
353.94
6,310.31
-1,541.43
3,496.07
8,529.00
101.70
333.92
6,252.92
-1,279.42
3,420.59
8,629.00
100.17
340.88
6,233.94
-1,188.84
3,382.90
8,783.32
90.00
344.55
6,220.28
-1,042.27
3,337.32
8,933.32
84.77
353.67
6,227.13
-895.34
3,309.03
9,233.32
87.97
14.47
6,246.32
-598.39
3,330.25
9,433.32
88.27
0.46
6,252.91
-400.69
3,356.16
9,933.32
88.59
325.45
6,267.05
69.76
3,211.94
10,303.32
84.37
351.06
6,290.15
409.78
3,076.14
Well 1 G-11
Mean Sea Level
1G-11 @99.00usft(1G-11)
True
Minimum Curvature
Dogleg
Build
Turn
Rate
Rate
Rate
TFO
(°/100ft)
(°/100ft)
(°/100ft)
(�)
0.00
0.00
0.00
0.00
0.57
0.50
-0.50
-28.93
40.00
40.00
0.00
0.00
45.00
44.44
-9.25
350.00
45.00
37.78
-27.64
325.00
45.00
23.87
-40.20
300.00
45.00
13.27
-43.73
284.00
45.00
25.08
-37.58
304.00
45.00
-1.12
-45.99
272.00
7.00
0.09
-7.15
273.00
7.00
-0.01
-7.15
272.00
7.00
-1.54
6.96
102.00
7.00
-6.59
2.38
160.00
7.00
-3.49
6.08
120.00
7.00
1.07
6.93
82.00
7.00
0.15
-7.00
271.00
7.00
0.06
-7.00
270.00
7.00
-1.14
6.92
100.00
OCRs
BAKER
HUGHES
Target
71612015 4:03:29PM Page 3 COMPASS 5000.1 Build 61
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1G-11
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1G-11 @ 99.00usft (1G-11)
Site:
Kuparuk 1G Pad
North Reference:
True
Well:
1 G-11
Survey Calculation Method:
Minimum Curvature
Wellbore:
1G-11AL1
Design:
1 G-11AL1_wp03
Planned Survey
Measured
ND Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(1)
(o)
(usft)
(usft)
(usft)
(usft)
(°/100ft)
(°)
(usft)
(usft)
7,600.00
33.47
128.40
6,306.23
-1,880.13
3,219.15
-2,410.57
0.00
0.00
5,979,113.66
543,814.48
TIP
7,614.00
33.54
128.33
6,317.90
-1,884.93
3,225.21
-2,416.34
0.57
-28.93
5,979,108.89
543,820.56
KOP
7,639.00
43.54
128.33
6,337.43
-1,894.57
3,237.42
-2,427.96
40.00
0.00
5,979,099.31
543,832.82
End 40 dls, Start 45 dls
7,669.00
56.87
125.56
6,356.59
-1,908.35
3,255.83
-2,444.73
45.00
-10.00
5,979,085.64
543,851.30
4
7,699.00
68.21
117.26
6,370.42
-1,922.10
3,278.53
-2,462.21
45.00
-35.00
5,979,072.01
543,874.08
5
7,700.00
68.43
116.85
6,370.79
-1,922.52
3,279.36
-2,462.77
45.00
-60.00
5,979,071.59
543,874.91
7,729.00
75.37
105.20
6,379.82
-1,932.33
3,305.04
-2,476.89
45.00
-59.85
5,979,061.92
543,900.64
6
7,799.00
84.66
74.59
6,392.24
-1,931.95
3,373.04
-2,488.32
45.00
-76.00
5,979,062.68
543,968.63
7
7,800.00
84.91
74.22
6,392.33
-1,931.68
3,374.00
-2,488.22
45.00
-56.00
5,979,062.95
543,969.58
7,869.00
102.21
48.29
6,387.98
-1,899.09
3,433.71
-2,466.50
45.00
-55.97
5,979,095.85
544,029.11
8
7,900,00
102.33
34.01
6,381.36
-1,876.35
3,453.58
-2,447.55
45.00
-88.00
5,979,118.71
544,048.86
7,939.00
101.43
16.09
6,373.27
-1,841.92
3,469.66
-2,416.44
45.00
-91.05
5,979,153.21
544,064.75
End 45
dls, Start 7 dis
8,000.00
101.62
11.74
6,361.08
-1,783.92
3,484.03
-2,361.82
7.00
-87.00
5,979,211.29
544,078.81
8,100.00
101.79
4.59
6,340.76
-1,687.07
3,497.94
-2,268.85
7.00
-87.87
5,979,308.21
544,092.18
8,200.00
101.79
357.44
6,320.30
-1,589.26
3,499.68
-2,172.83
7.00
-89.32
5,979,406.01
544,093.39
8,249.00
101.72
353.94
6,310.31
-1,541.43
3,496.07
-2,125.10
7.00
-90.79
5,979,453.82
544,089.53
10
8,300.00
101.82
350.29
6,299.91
-1,491.98
3,489.23
-2,075.22
7.00
-88.00
5,979,503.22
544,082.42
8,400.00
101.88
343.14
6,279.34
-1,396.80
3,466.76
-1,977.58
7.00
-88.74
5,979,598.27
544,059.44
8,500.00
101.77
335.99
6,258.82
-1,305.15
3,432.61
-1,881.39
7.00
-90.21
5,979,689.73
544,024.80
8,529.00
101.70
333.92
6,252.92
-1,279.42
3,420.59
-1,853.97
7.00
-91.68
5,979,715.38
544,012.64
11
8,600.00
100.63
338.87
6,239.17
-1,215.62
3,392.71
-1,786.29
7.00
102.00
5.979,779.03
543,984.42
8,629.00
100.17
340.88
6,233.94
-1,188.84
3,382.90
-1,758.21
7.00
102.96
5,979,805.76
543,974.46
12
8,700.00
95.49
342.58
6,224.27
-1,122.06
3,360.86
-1,688.62
7.00
160.00
5,979,872.40
543,952.06
8,783.32
90.00
344.55
6,220.28
-1,042.27
3,337.32
-1,605.96
7.00
160.23
5,979,952.06
543,928.09
13
8,800.00
89.42
345.56
6,220.36
-1,026.16
3,333.02
-1,589.34
7.00
120.00
5,979,968.15
543,923.71
8,900.00
85.93
351.64
6,224.43
-928.27
3,313.28
-1,489.52
7.00
119.99
5,980,065.91
543,903.43
8,933.32
84.77
353.67
6,227.13
-895.34
3,309.03
-1,456.34
7.00
119.75
5,980,098.82
543,899.01
14
9,000.00
85.44
358.31
6,232.82
-829.08
3,304.38
-1,390.29
7.00
82.00
5,980,165.04
543,894.00
9,100.00
86.49
5.24
6,239.87
-729.44
3,307.47
-1,292.70
7.00
81.60
5,980,264.69
543,896.55
9,200.00
87.59
12.17
6,245.03
-630.79
3,322.58
-1,198.17
7.00
81.12
5,980,363.41
543,911.12
9,233.32
87.97
14.47
6,246.32
-598.39
3,330.25
-1,167.59
7.00
80.76
5,980,395.85
543,918.62
15
9,300.00
88.06
9.80
6,248.63
-533.26
3,344.25
-1,105.88
7.00
-89.00
5,980,461.05
543,932.27
9,400.00
88.22
2.80
6,251.89
-433.98
3,355.21
-1,010.01
7.00
-88.84
5,980,560.38
543,942.69
9,433.32
88.27
0.46
6,252.91
-400.69
3,356.16
-977.39
7.00
-88.61
5,980,593.67
543,943.45
16
9,500.00
88.28
355.80
6,254.92
-334.09
3,353.99
-911.43
7.00
-90.00
5,980,660.25
543,940.92
9,600.00
88.31
348.79
6,257.90
-235.10
3,340.59
-811.62
7.00
-89.86
5,980,759.16
543,926.99
7/6/2015 4:03:29PM Page 4 COMPASS 5000.1 Build 61
rer®
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1G Pad
Well:
1G-11
Wellbore:
1 G-11 AL1
Design:
1 G-11 AL1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 G-11
Mean Sea Level
1G-11 @ 99.00usft (1G-11)
True
Minimum Curvature
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth
Inclination
Azimuth
System
+N/-S
+E/-W
Section
Rate
Azimuth
Northing
Easting
(usft)
(I
(I
(usft)
(usft)
(usft)
(usft)
(°/1ooft)
(°)
(usft)
(usft)
9,700.00
88.36
341.79
6,260.80
-138.48
3,315.23
-712.06
7.00
-89.65
5,980,855.63
543,901.10
9,800.00
88.44
334.79
6,263.59
-45.67
3,278.27
-614.24
7.00
-89.45
5,980,948.23
543,863.65
9,900.00
88.55
327.79
6,266.22
41.95
3,230.27
-519.62
7.00
-89.25
5,981,035.58
543,815.18
9,933.32
88.59
325.45
6,267.05
69.76
3,211.94
-489.04
7.00
-89.07
5,981,063.29
543,796.70
17
10,000.00
87.78
330.05
6,269.17
126.11
3,176.39
-427.38
7.00
100.00
5,981,119.44
543,760.85
10,100.00
86.60
336.96
6,274.07
215.45
3,131.86
-331.67
7.00
99.85
5,981,208.52
543,715.84
10,200.00
85.47
343.89
6,280.99
309.38
3,098.45
-233.36
7.00
99.52
5,981,302.26
543,681.93
10,300.00
84.41
350.83
6,289.82
406.51
3,076.66
-133.92
7.00
99.04
5,981,399.27
543,659.61
10,303.32
84.37
351.06
6,290.15
409.78
3,076.14
-130.61
7.00
98.42
5,981,402.53
543,659.08
Planned TD at 10303.32
71612015 4:03:29PM Page 5 COMPASS 5000.1 Build 61
ConocoPhillips
Database:
EDM Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1G Pad
Well:
1G-11
Wel I bore:
1 G-11 AL1
Design:
1 G-11AL1_wp03
Targets
Planning Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 G-11
Mean Sea Level
1G-11 @99.00usft(1G-11)
True
Minimum Curvature
BAKER
HUGHES
Target Name
hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting
Shape V) V) (usft) (usft) (usft) (usft) (usft) Latitude Longitude
1G-11AL1_T01 0.00 0.00 6,394.00-8,352.851,143,516.24 5,978,820.00 1,684,018.00 70° 5' S8.782 N 140° 28' 10.525 W
plan misses target center by 1140036.63usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
1G-11 CTD Polygon Nor
0.00 0.00 0.00
-8,462.31 1,143,229.62
5,978,709.00
plan misses target center by 1139768.19usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Polygon
Point 1
0.00
0.00
0.00
5,978,709.00
Point 2
0.00
152.40
114.83
5,978,862.00
Point 3
0.00
299.01
190.63
5,979,009.01
Point 4
0.00
491.09
180.66
5,979,201.01
Point 5
0.00
646.33
137.48
5,979,356.00
Point 6
0.00
810.71
71.36
5,979,520.01
Point
0.00
1,047.03
16.62
5,979,756.00
Point
0.00
1,306.12
5.01
5,980,015.00
Point 9
0.00
1,591.94
44.55
5,980,301.00
Point 10
0.00
1,806.04
29.70
5,980,515.00
Point 11
0.00
2,089.89
-121.80
5,980,797.99
Point 12
0.00
2,271.27
-189.83
5,980,978.99
Point 13
0.00
2,409.48
-226.09
5,981,116.98
Point 14
0.00
2,480.37
169.33
5,981,190.01
Point 15
0.00
2,346.20
198.61
5,981,056.01
Point 16
0.00
2,240.89
254.06
5,980,951.01
Point 17
0.00
1,875.93
424.12
5,980,587.02
Point 18
0.00
1,542.79
444.33
5,980,254.02
Point 19
0.00
1,289.00
398.96
5,980,000.02
Point20
0.00
1,058.87
419.73
5,979,770.02
Point 21
0.00
875.52
479.75
5,979,587.02
Point 22
0.00
650.03
567.55
5,979,362.03
Point23
0.00
435.86
594.41
5,979,148.03
Point 24
0.00
83.13
536.51
5,978,795.03
Point 25
0.00
-84.77
327.58
5,978,626.01
Point 26
0.00
-83.67
122.56
5,978,626.00
Point 27
0.00
0.00
0.00
5,978,709.00
1,683,732.00 70° 5' 58.143 N 140- 28' 19.168 W
1,683,732.00
1,683,845.99
1,683, 920.99
1,683, 909.98
1,683,865.96
1,683,798.96
1,683,742.95
1,683,729.93
1,683,767.92
1,683,751.91
1,683,598.89
1,683,529.89
1,683,492.88
1, 683, 887.87
1, 683, 917.88
1, 683, 973.89
1,684,145.91
1,684,167.92
1,684,123.93
1,684,145.95
1,684,206.95
1,684,295.96
1,684,323.98
1,684, 268.00
1, 684, 060.00
1, 683, 855.00
1,683,732.00
1G-11AL1_Fault2 0.00 0.00 0.00-7,227.251,143,429.33 5,979,945.00 1,683,925.00
plan misses target center by 1139961.12usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Rectangle (sides W395.00 1-11.00 D0.00)
1G-11AL1_T05 0.00 0.00 6,237.00-7,188.531,143,482.55 5,979,984.00 1,683,978.00
plan misses target center by 1139996.62usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
1G-11AL1_T06 0.00 0.00 6,261.00-6,543.691,143,341.02 5,980,628.00 1,683,833.00
plan misses target center by 1139852.12usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
1G-11AL1_T04 0.00 0.00 6,220.00-7,483.831,143,531.95 5,979,689.00 1,684,029.00
plan misses target center by 1140047.52usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
1G-11AL1_T02 0.00 0.00 6,315.00-7,936.181,143,586.51 5,979,237.00 1,684.086.00
plan misses target center by 1140104.50usft at 8200.00usft MD (6320.30 TVD,-1589.26 N. 3499.68 E)
Point
1G-11AL1_T07 0.00 0.00 6,297.00-6,006.031,143,228.92 5,981,165.00 1,683,718.00
plan misses target center by 1139737.81 usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
1G-11AL1_T03 0.00 0.00 6,253.00-7,676.001,143,557.91 5,979,497.00 1,684,056.00
plan misses target center by 1140074.49usft at 8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Point
70'6'9.838N 140'28'8.115WI
70' 6' 10.135 N 140' 28' 6.431 W I
70' 6' 16.604 N 140' 28' 7.665 W i
70' 6' 7.195 N 140' 28' 6.305 W
70° 6' 2.723 N 1400 28' 6.714 W
70° 6' 21.989 N 140' 28' 8.525 W I
70' 6' 5.291 N 140' 28' 6.399 W
7/6/2015 4:03:29PM Page 6 COMPASS 5000.1 Build 61
a- r&A.I
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1G-11
Company:
ConocoPhillips (Alaska) Inc. -Kup1
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1G-11 @ 99.00usft (1G-11)
Site:
Kuparuk 1G Pad
North Reference:
True
Well:
1G-11
Survey Calculation Method:
Minimum Curvature
Wellbore:
1G-11AL1
Design:
1 G-11 AL1 _wp03
1G-11 CTD Polygon Soi 0.00 0.00
0.00
-8,468.51 1,143,266.59
5,978,703.00
1,683,769.00 70' 5' 58.029 N 140' 28' 18.141 W
plan misses target center by 1139805.19usft at
8200.00usft MD (6320.30 TVD,-1589.26 N, 3499.68 E)
Polygon
Point 1
0.00
0.00
0.00
5,978,703.00
1,683,769.00
Point
0.00
286.79
230.57
5,978,991.01
1,683,997.99
Point
0.00
175.08
361.98
5,978,880.02
1,684,129.99
Point
0.00
0.73
423.05
5,978,706.02
1,684,192.00
Points
0.00
-242.03
373.74
5,978,463.02
1,684,144.01
Point
0.00
-467.28
229.52
5,978,237.02
1,684,001.03
Point
0.00
-653.15
13.50
5,978,050.00
1,683,786.04
Point
0.00
-797.46
-303.31
5,977,903.99
1,683,470.04
Point
0.00
-826.66
-640.51
5,977,872.96
1,683,133.04
Point 10
0.00
-867.00
-949.76
5,977,830.95
1,682,824.04
Point 11
0.00
-1,035.86
-1,165.69
5,977,660.94
1,682,609.05
Point 12
0.00
-1,226.13
-1,305.73
5,977,469.93
1,682,470.06
Point 13
0.00
-1,378.75
-1,379.55
5,977,316.93
1,682,397.08
Point 14
0.00
-1,701.12
-1,503.30
5,976,993.93
1,682,275.09
Point 15
0.00
-1,898.75
-1,576.37
5,976,795.92
1,682,203.10
Point 16
0.00
-2,044.58
-1,612.15
5,976,649.92
1,682,168.11
Point 17
0.00
-1,972.43
-2,010.81
5,976,719.90
1,681,769.10
Point 18
0.00
-1,764.69
-1,957.69
5,976,927.90
1,681,821.09
Point 19
0.00
-1,574.21
-1,856.66
5,977,118.91
1,681,921.08
Point20
0.00
-1,383.83
-1,737.62
5,977,309.91
1,682,039.07
Point21
0.00
-1,012.86
-1,537.61
5,977,681.92
1,682,237.05
Point22
0.00
-847.67
-1,383.71
5,977,847.93
1,682,390.04
Point23
0.00
-723.52
-1,223.02
5,977,972.94
1,682,550.04
Point24
0.00
-592.96
-951.29
5,978,104.95
1,682,821.03
Point25
0.00
-401.15
-353.19
5,978,299.98
1,683,418.02
Point26
0.00
-302.13
-168.64
5,978,399.99
1,683,602.02
Point27
0.00
-173.75
-49.94
5,978,529.00
1,683,720.01
Point28
0.00
-84.04
5.55
5,978,619.00
1,683,775.00
Point29
0.00
0.00
0.00
5,978,703.00
1,683,769.00
1G-11AL1_Faultl 0.00 0.00
0.00
-7,947.361,143,619.45
5,979,226.00
1,684,119.00 70' 6' 2.566 N 140' 28' 5.823 W
plan misses target center by 1140155.02usft at
8200.00usft MD (6320.30 TVD,-1589.26
N, 3499.68 E)
Rectangle (sides W400.00 H1.00 D0.00)
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name (in) (in)
10,303.32 6,290.15 2 3/8" 2.375 3.000
7/6/2015 4:03:29PM Page 7 COMPASS 5000.1 Build 61
- ENV
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska Sandbox
Local Co-ordinate Reference:
Well 1 G-11
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1G-11 @ 99.00usft (1G-11)
Site:
Kuparuk 1 G Pad
North Reference:
True
Well:
1G-11
Survey Calculation Method:
Minimum Curvature
Wellbore:
1G-11AL1
Design:
1 G-11 AL 1 _wp03
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/-S
+E/-W
(usft)
(usft)
(usft)
(usft)
Comment
7,600.00
6,306.23
-1,880.13
3,219.15
TIP
7,614.00
6,317.90
-1,884.93
3,225.21
KOP
7,639.00
6,337.43
-1,894.57
3,237.42
End 40 dls, Start 45 dls
7,669.00
6,356.59
-1,908.35
3,255.83
4
7,699.00
6,370.42
-1,922.10
3,278.53
5
7,729.00
6,379.82
-1,932.33
3,305.04
6
7,799.00
6,392.24
-1,931.95
3,373.04
7
7,869.00
6,387.98
-1,899.09
3,433.71
8
7,939.00
6,373.27
-1,841.92
3,469.66
End 45 dls, Start 7 dls
8,249.00
6,310.31
-1,541.43
3,496.07
10
8,529.00
6,252.92
-1,279.42
3,420.59
11
8,629.00
6,233.94
-1,188.84
3,382.90
12
8,783.32
6,220.28
-1,042.27
3,337.32
13
8,933.32
6,227.13
-895.34
3,309.03
14
9,233.32
6,246.32
-598.39
3,330.25
15
9,433.32
6,252.91
-400.69
3,356.16
16
9,933.32
6,267.05
69.76
3,211.94
17
10,303.32
6,290.15
409.78
3,076.14
Planned TD at 10303.32
71612015 4:03:29PM Page 8 COMPASS 5000.1 Build 61
ConocoPhillips
ConocoPhillips (Alaska) Inc.
-Kup1
Kuparuk River Unit
Kuparuk 1G Pad
1 G-11
1G-11AL1
1G-11AL1_wp03
Travelling Cylinder Report
22 June, 2015
�. Baker Hughes INTEQ RAC■
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1G Pad
Site Error:
0.00usft
Reference Well:
1G-11
Well Error:
0.00usft
Reference Wellbore
1G-11AL1
Reference Design:
1 G-11 AL1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 G-11
1G-11 @ 99.00usft (1G-11)
1G-11 @99.00usft(1G-11)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Reference 1G-11AL1_wp03
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA
Depth Range: 7,600.00 to 10,303.32usft Scan Method: Tray. Cylinder North
Results Limited by: Maximum center -center distance of 1,220.43usft Error Surface: Elliptical Conic
Survey Tool Program Date 6/22/2015
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
100.00 7,600.00 1G-11 (1G-11) BOSS -GYRO Sperry -Sun BOSS gyro multishot
7,600.00 10,303.32 1G-11AL1_wp03 (1G-11AL1) MWD MWD - Standard
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name
10,303.32 6,389.15 2 3/8" 2-3/8 3
Summary
Site Name
Offset Well - Wellbore - Design
Kuparuk 1 G Pad
1 G-05 - 1 G-05 - 1 G-05
1 G-09 - 1 G-09 - 1 G-09
1 G-10 - 1 G-10 - 1 G-10
1G-10- 1G-10A- 1G-10A
1 G-10 - 1 G-10B - 1 G-10B
1G-10- 1G-10BL1 - 1G-10BL1
1 G-10 - 1 G-10BL2 - 1 G-10BL2
1G-10- 1G-10BPB1 - 1G-10BPB1
1 G-11 - 1 G-11 - 1 G-11
1G-11 - 1G-11A- 1G-11A_wp02
1 G-12 - 1 G-12 - 1 G-12
Reference Offset Centre to No -Go Allowable
Measured Measured Centre Distance Deviation Warning
Depth Depth Distance (usft) from Plan
(usft) (usft) (usft) (usft)
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
10,303.32 8,950.00 990.95 211.91 779.71 Pass - Major Risk
Out of range
7,624.98 7,625.00 0.42 1.35 -0.88 FAIL- Major Risk
7,624.98 7,625.00 0.42 0.73 -0.31 FAIL- Minor 1/10
Out of range
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
6/22/2015 3:37:19PM Page 2 of 7 COMPASS 5000.1 Build 65
Baker Hughes INTEQ .el..
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1 G Pad
Site Error:
0.00usft
Reference Well:
1G-11
Well Error:
0.00usft
Reference Wellbore
1G-11AL1
Reference Design:
1G-11AL1_wp03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1 G-11
1G-11 @ 99.00usft (1G-11)
1G-11 @99.00usft(1G-11)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Offset Design
Kuparuk 1GPad - 1G-10-1G-10131-2-1G-1OBL2
offset Site Error. 0.00usft
Survey Program: 95-13OSS-GYRO, 6390-MWD, 7481-MWD, 7897-MWD
Rule Assigned: Major Risk
Offset Well Error. 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toolface +
Offset Wettbom Centre
Casing -
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+N/S
+E1-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
M
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
10,126.16
6,374.69
9,400.00
6,615.67
49.13
38.24
-123.02
-202.39
2,028.06
2-11/16
1,205.22
216.78
988.73 Pass - Major Risk
10,133.54
6,375.17
9,375.00
6,615.63
49.17
38.17
-122.67
-179.67
2,038.50
2-11116
1,187.48
216.50
971.29 Pass - Major Risk
10,150.00
6,376.29
9,300.00
6,616.25
49.27
37.99
-121.96
-109.69
2,065.36
2-11116
1,138.91
215.68
923.60 Pass - Major Risk
10,150.00
6,376.29
9,325.00
6,616.05
49.27
38.04
-121.85
-133.36
2,057.31
2-11/16
1,154.17
215.93
938.60 Pass - Major Risk
10,150.00
6,376.29
9,350.00
6,615.87
49.27
38.10
-121.73
-156.69
2,048.33
2-11/16
1,170.50
216.18
954.66 Pass - Major Risk
10,166.82
6,377.48
9,275.00
6,616.41
49.37
37.94
-120.97
-85.73
2,072.49
2-11/16
1,124.46
215.36
909.50 Pass - Major Risk
10,176.09
6,378.16
9,250.00
6,616.70
49.42
37.90
-120.46
-61.53
2,078.75
2-11116
1,111.05
215.08
896.39 Pass - Major Risk
10,185.76
6,378.89
9,225.00
6,616.95
49.48
37.86
-119.91
-37.06
2,083.83
2-11116
1,098.86
214.81
884.49 Pass - Major Risk
10,200.00
6,379.99
9,175.00
6,616.84
49.56
37.79
-119.06
12.42
2,090.93
2-11116
1,077.82
214.29
863.98 Pass - Major Risk
10,200.00
6,379.99
9,200.00
6,616.91
49.56
37.82
-119.04
-12.38
2,087.81
2-11116
1,087.83
214.55
873.73 Pass - Major Risk
10,216.60
6,381.33
9,150.00
6,617.28
49.65
37.76
-118.03
37.31
2,093.21
2-11/16
1,068.90
214.00
855.37 Pass - Major Risk
10,227.35
6,382.22
9,125.00
6,618.32
49.72
37.72
-117.39
62.24
2,094.82
2-11/16
1,061.05
213.69
847.85 Pass - Major Risk
10,250.00
6,384.18
9,050.00
6,620.79
49.84
37.58
-116.09
136.57
2,104.12
2-11116
1,035.09
212.74
822.86 Pass - Major Risk
10,250.00
6,384.18
9,075.00
6,620.18
49.84
37.63
-116.04
111.92
2,099.98
2-11116
1,044.40
213.07
831.84 Pass - Major Risk
10,250.00
6,384.18
9,100.00
6,619.35
49.84
37.68
-116.00
87.13
2,096.91
2-11116
1,053.20
213.42
840.30 Pass - Major Risk
10,270.06
6,385.99
9,025.00
6,621.50
49.96
37.52
-114.87
161.03
2,109.23
2-11116
1,025.01
212.54
813.03 Pass - Major Risk
10,280.56
6,386.96
9,000.00
6,622.53
50.01
37.46
-114.29
185.24
2,115.38
2-11116
1,014.45
212.30
802.73 Pass - Major Risk
10,303.32
6,389.15
8,950.00
6,624.68
50.14
37.33
-113.07
232.58
2,131.26
2-11/16
990.95
211.91
779.71 Pass - Major Risk, CC, ES, SF
10,303.32
6,389.15
8,975.00
6,623.70
50.14
37.40
-112.97
209.08
2,122.80
2-11/16
1,003.22
212.20
791.68 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
6/22/2015 3:37:19PM Page 3 of 7 COMPASS 5000.1 Build 65
Baker Hughes INTEQ
Na®
ConocoPhillips
Travelling Cylinder Report
BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Local Co-ordinate Reference:
Well 113-11
Project:
Kuparuk River Unit
TVD Reference:
1 G-11 @ 99.00usft (1 G-11)
Reference Site:
Kuparuk 1G Pad
MD Reference:
1G-11 @ 99.00usft (1G-11)
Site Error:
0.00usft
North Reference:
True
Reference Well:
1G-11
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00usft
Output errors are at
1.00 sigma
Reference Wellbore
1G-11AL1
Database:
OAKEDMP2
Reference Design:
1G-11AL1_wp03
Offset TVD Reference:
Offset Datum
Offset Design
Kuparuk 1GPad - 1G-11-1G-11-1G-11
offset site Error: 0.00usft
Survey Program: 100-BOSS-GYRO
Rule Assigned: Major Risk
Offset Well Error. 0.00 usft
Reference
offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset Toolface +
Offset Wellbore Centre
Casing -
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+N/-S
+E/-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
7,624.98
6,425.81
7,625.00
6,426.07
0.05
0.16
-51.25
-1,888.69
3,229.99
2-11/16
0.42
1.35
-0.88 FAIL- Major Risk, CC, ES, SF
7,649.25
6,443.57
7,650.00
6,446.88
0.05
0.32
-52.54
-1,897.26
3,240.87
2-11116
4.44
2.95
1.55 Pass - Major Risk
7,671.43
6,456.90
7,675.00
6,467.66
0.06
0.48
-56.16
-1,905.84
3,251.81
2-11116
12.72
4.49
8.36 Pass- Major Risk
7,691.10
6,466.30
7,700.00
6,488.41
0.07
0.64
-62.74
-1,914.41
3,262.80
2-11/16
24.39
5.87
18.86 Pass - Major Risk
7,708.57
6,472.80
7,725.00
6,509.17
0.07
0.80
-70.17
-1,922.95
3,273.81
2-11/16
38.67
7.00
32.24 Pass - Major Risk
7,724.10
6,477.54
7,750.00
6,529.96
0.08
0.96
-78.15
-1,931.43
3,284.80
2-11/16
54.73
7.99
47.54 Pass - Major Risk
7,738.44
6,481.12
7,775.00
6,550.79
0.09
1.12
-86.04
-1,939.84
3,295.78
2-11/16
72.20
8.82
64.38 Pass - Major Risk
7,751.45
6,484.00
7,800.00
6,571.65
0.09
1.28
-93.54
-1,948.19
3,306.74
2-11116
90.65
9.51
82.26 Pass - Major Risk
7,762.69
6,486.20
7,825.00
6,592.55
0.10
1.44
-100.15
-1,956.46
3,317.68
2-11/16
109.97
10.09
101.09 Pass - Major Risk
7,772.37
6,48Z86
7,850.00
6,613.49
0.11
1.60
-105.91
-1,964.65
3,328.61
2-11/16
130.08
10.58
120.76 Pass - Major Risk
7,780.00
6,489.01
7,875.00
6,634.47
0.11
1.76
-110.64
-1,972.75
3,339.53
2-11/16
150.87
10.98
141.18 Pass - Major Risk
7,790.00
6,490.29
7,900.00
6,655.50
0.12
1.91
-116.02
-1,980.76
3,350.43
2-11116
172.25
11.34
162.20 Pass - Major Risk
7,794.17
6,490.76
7,925.00
6,676.57
0.12
2.07
-119.01
-1,988.70
3,361.28
2-11/16
194.08
11.59
183.78 Pass - Major Risk
7,799.51
6,491.28
7,950.00
6,697.72
0.13
2.22
-122.24
-1,996.57
3,372.05
2-11/16
216.36
11.81
205.83 Pass - Major Risk
7,803.59
6,491.62
7,975.00
6,718.92
0.13
2.37
-124.66
-2,004.38
3,382.74
2-11/16
239.02
12.01
228.31 Pass - Major Risk
7,810.00
6,492.00
8,000.00
6,740.19
0.14
2.52
-127.75
-2,012.13
3,393.36
2-11116
262.04
12.15
251.20 Pass - Major Risk
7,810.00
6,492.00
8,025.00
6,761.52
0.14
2.67
-128.48
-2,019.79
3,403.90
2-11/16
285.25
12.33
274.25 Pass - Major Risk
7,810.00
6,492.00
8,050.00
6,782.91
0.14
2.82
-129.08
-2,027.37
3,414.40
2-11116
308.75
12.52
297.62 Pass - Major Risk
7,815.60
6,492.18
8,075.00
6,804.33
0.14
2.97
-131.64
-2,034.89
3,424.87
2-11116
332.34
12.63
321.14 Pass - Major Risk
7,820.00
6,492.22
8,100.00
6,825.74
0.15
3.11
-133.72
-2,042.42
3,435.34
2-11/16
356.13
12.73
344.87 Pass - Major Risk
7,820.00
6,492.22
8,125.00
6,847.16
0.15
3.26
-134.15
-2,049.94
3,445.82
2-11/16
380.00
12.92
368.63 Pass - Major Risk
7,820.00
6,492.22
8,150.00
6,868.58
0.15
3.41
-134.53
-2,057.47
3,456.29
2-11/16
404.00
13.10
392.52 Pass - Major Risk
7,820.00
6,492.22
8,175.00
6,890.00
0.15
3.56
-134.87
-2,064.99
3,466.76
2-11/16
428.12
13.28
416.52 Pass - Major Risk
7,824.95
6,492.17
8,200.00
6,911.41
0.15
3.70
-137.05
-2,072.51
3,477.23
2-11/16
452.23
13.31
440.64 Pass - Major Risk
7,825.41
6,492.16
8,208.00
6,918.27
0.15
3.75
-137.32
-2,074.92
3,480.58
2-11/16
459.97
13.35
448.37 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
612212015 3:37.19PM Page 4 of 7 COMPASS 5000.1 Build 65
10.1
Baker Hughes INTEQ
FeAFAI
ConocoPhillips
Travelling Cylinder Report
BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Local Co-ordinate Reference:
Well 1G-11
Project:
Kuparuk River Unit
ND Reference:
1G-11 @ 99.00usft (1G-11)
Reference Site:
Kuparuk 1G Pad
MD Reference:
1G-11 @ 99.00usft (1G-11)
Site Error:
0.00usft
North Reference:
True
Reference Well:
1 G-11
Survey Calculation Method:
Minimum Curvature
Well Error:
0.00usft
Output errors are at
1.00 sigma
Reference Wellbore
1G-11AL1
Database:
OAKEDMP2
Reference Design:
1 G-11AL1_wp03
Offset ND Reference:
Offset Datum
Offset Design
Kuparuk 1 G Pad - 1 G-11 - 1 G-11 A - 1 G-11 A_wp02
Offset she Error: 0.00 usft
Survey Program: 100-BOSS-GYRO, 76DD-MWD
Rule Assigned: Minor 1110
Offset Well. Error. 0.00 usfl
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toolface+
Offset Wellbore Centre
Casing-
Centre to
No Go
Allowable Warning
Depth
Depth
Depth
Depth
Azimuth
+N/S
+E/-W
Hole Size
Centre
Distance
Deviation
(usfl)
(usft)
(usft)
(usft)
(usft)
(usft)
M
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
7,600.00
6,405.23
7,600.00
6,405.23
0.00
0.00
128.40
-1,880.13
3,219.15
2-11/16
0.00
0.22
-0.22 FAIL- Minor 1/10, CC
7,602.30
6,407.15
9,075.00
6,464.16
0.01
3.18
-136.16
-2,675.88
2,480.36
2-11/16
1,087.43
5.35
1,086.17 Pass - Minor 1/10
7,612.67
6,415.80
9,050.00
6,464.99
0.04
3.09
-136.89
-2,674.45
2,505.31
2-11/16
1,069.54
5.29
1,068.29 Pass - Minor 1/10
7,620.00
6,421.83
9,025.00
6,465.94
0.05
3.01
-137.64
-2,673.76
2,530.28
2-11116
1,052.40
5.18
1,051.15 Pass - Minor 1110
7,624.98
6,425.81
7,625.00
6,426.07
0.05
0.08
-51.26
-1,888.69
3,229.99
2-11/16
0.42
0.73
-0.31 FAIL- Minor 1/10, ES, SF
7,630.00
6,429.72
9,000.00
6,467.01
0.05
2.94
-138.40
-2,673.84
2,555.25
2-11116
1,036.05
5.02
1,034.81 Pass - Minor 1110
7,639.34
6,436.68
8,975.00
6,468.20
0.05
2.86
-139.15
-2,674A3
2,580.22
2-11116
1,020.11
4.85
1,018.87 Pass- Minor 1/10
7,644.80
6,440.55
8,950.00
6,469.52
0.05
2.79
-140.00
-2,673.69
2,605.18
2-11/16
1,003.86
4.72
1,002.62 Pass - Minor 1110
7,649.25
6,443.57
7,650.00
6,446.88
0.05
0.16
-52.54
-1,897.26
3,240.87
2-11116
4.44
0.85
3.61 Pass - Minor 1110
7,650.00
6,444.07
8,925.00
6,470.95
0.05
2.72
-140.82
-2,672.49
2,630.11
2-11/16
987.33
4.57
986.09 Pass - Minor 1/10
7,656.94
6,448.54
8,900.00
6,472.54
0.05
2.65
-141.64
-2,670.55
2,654.98
2-11116
970.51
4.38
969.26 Pass - Minor 1/10
7,663.64
6,452.57
8,875.00
6,474.32
0.05
2.58
-142.41
-2,667.87
2,679.78
2-11/16
953.41
4.20
952.15 Pass - Minor 1/10
7,670.00
6,456.14
8,825.00
6,478.44
0.06
2.45
-143.68
-2,660.32
2,729.02
2-11/16
918.41
3.89
917.14 Pass - Minor 1/10
7,670.00
6,456.14
8,850.00
6,476.29
0.06
2.51
-143.23
-2,664.46
2,704.46
2-11/16
936.02
4.02
934.76 Pass - Minor 1/10
7,671.70
6,457.05
7,675.00
6,467.21
0.06
0.19
-56.46
-1,906.23
3,252.30
2-11/16
12.00
0.74
11.37 Pass - Minor 1/10
7,675.91
6,459.24
8,800.00
6,480.77
0.06
2.39
-144.93
-2,655.46
2,753.43
2-11/16
900.53
3.76
899.27 Pass - Minor 1110
7,680.00
6,461.27
8,750.00
6,485.97
0.06
2.26
-146.25
-2,643.56
2,801.71
2-11116
864.20
3.53
862.93 Pass - Minor 1110
7,680.00
6,461.27
8,775.00
6,483.28
0.06
2.32
-145.90
-2,649.87
2,777.67
2-11/16
882.46
3.64
881.20 Pass - Minor 1/10
7,685.78
6,463.98
8,725.00
6,488.84
0.06
2.20
-147.40
-2,636.55
2,825.53
2-11/16
845.69
3.43
844.43 Pass - Minor 1/10
7,690.00
6,465.83
8,675.00
6,494.89
0.07
2.08
-148.55
-2,620.40
2,872.46
2-11/16
808.10
3.25
806.84 Pass - Minor 1110
7,690.00
6,465.83
8,700.00
6,491.87
0.07
2.15
-148.31
-2,628.83
2,849.12
2-11116
827.00
3.33
825.74 Pass - Minor 1/10
7,693.16
6,467A5
7,700.00
6,484.94
0.07
0.20
-66.01
-1,917.18
3,266.05
2-11116
19.55
0.77
18.91 Pass - Minor 1/10
7,699.00
6,469.42
8,650.00
6,497.83
0.07
2.03
-150.15
-2,611.25
2,895.54
2-11/16
788.94
3.13
787.69 Pass - Minor 1/10
7,699.51
6,469.61
8,625.00
6,500.69
0.07
1.96
-150.46
-2,601.40
2,918.33
2-11116
769.53
3.05
768.29 Pass - Minor 1/10
7,700.00
6,469.79
8,600.00
6,503.47
0.07
1.91
-150.75
-2,590.85
2,940.83
2-11/16
749.94
2.97
748.71 Pass - Minor 1/10
7,704.42
6,471.38
8,575.00
6,506.15
0.07
1.84
-152.08
-2,579.62
2,963.00
2-11/16
730.11
2.88
728.90 Pass - Minor 1110
7,710.00
6,473.28
8,500.00
6,513.64
0.07
1.66
-153.94
-2,541.91
3,027.37
2-11116
669.55
2.63
668.38 Pass - Minor 1/10
7,710.00
6,473.28
8,525.00
6,511.24
0.07
1.72
-153.84
-2,555.14
3,006.29
2-11116
689.91
2.70
688.73 Pass - Minor 1/10
7,710.00
6,473.28
8,550.00
6,508.74
0.07
1.78
-153.72
-2,567.71
2,984.83
2-11116
710.15
2.78
708.94 Pass- Minor 1/10
7,713.95
6,474.55
7,725.00
6,499.40
0.08
0.21
-81.57
-1,930.38
3,281.54
2-11/16
26.83
0.79
26.17 Pass - Minor 1/10
7,714.49
6,474.72
8,475.00
6,515.95
0.08
1.59
-155.25
-2,528.05
3,048.04
2-11/16
648.96
2.53
647.82 Pass - Minor 1110
7,720.00
6,476.38
8,400.00
6,522.24
0.08
1.39
-156.93
-2,482.75
3,107.45
2-11116
586.25
2.27
585.20 Pass - Minor 1110
7,720.00
6,476.38
8,425.00
6,520.25
0.08
1.46
-156.90
-2,498.45
3,088.10
2-11/16
607.30
2.34
606.22 Pass - Minor 1/10
7,720.00
6,476.38
8,450.00
6,518.15
0.08
1.53
-156.86
-2,513.56
3,068.29
2-11/16
628.26
2.41
627.14 Pass - Minor 1/10
7,724.94
6,477.76
8,375.00
6,523.97
0.08
1.33
-158.35
-2,466.49
3,126.36
2-11/16
564.98
2.16
563.97 Pass - Minor 1110
7,729.00
6,478.82
8,350.00
6,525.36
0.08
1.26
-159.54
-2,449.70
3,144.83
2-11/16
543.60
2.04
542.62 Pass- Minor 1110
7,730.00
6,479.07
8,300.00
6,527.15
0.08
1.13
-159.95
-2,414.60
3,180.38
2-11116
500.42
1.89
499.53 Pass - Minor 1/10
7,730.00
6,479.07
8,325.00
6,526.42
0.08
1.19
-159.90
-2,432.39
3,162.84
2-11116
622.06
1.96
521.11 Pass - Minor 1/10
7,733.22
6,479.87
7,750.00
6,510.14
0.09
0.22
-101.28
-1,945A8
3,298.28
2-11116
34.33
0.79
33.65 Pass - Minor 1/10
7,735.27
6,480.37
8,275.00
6,527.54
0.09
1.06
-161.79
-2,396.32
3,197.43
2-11116
478.59
1.77
477.73 Pass - Minor 1110
7,740.00
6,481.49
8,200.00
6,527.49
0.09
0.87
-163.60
-2,338.64
3,245.33
2-11116
412.57
1.55
411.80 Pass - Minor 1/10
7,740.00
6,481.49
8,225.00
6,527.56
0.09
0.93
-163.55
-2,358.34
3,229.94
2-11/16
434.65
1.60
433.85 Pass - Minor 1/10
7,740.00
6,481.49
8,250.00
6,527.61
0.09
1.00
-163.48
-2,377.57
3,213.97
2-11/16
456.70
1.65
455.87 Pass - Minor 1/10
7,746.01
6,482.84
8,175.00
6,527.38
0.09
0.81
-165.69
-2.318.47
3,260.10
2-11/16
390.28
1.44
389.52 Pass - Minor 1/10
7,750.00
6,483.70
7,775.00
6,516.84
0.09
0.23
-122.57
-1,962.01
3,315.75
2-11/16
43.13
0.77
42.43 Pass - Minor 1110
7,750.00
6,483.70
8,125.00
6,527.09
0.09
0.70
-167.03
-2,276.84
3,287.77
2-11/16
345.56
1.32
344.83 Pass - Minor 1/10
7,750.00
6,483.70
8,150.00
6,527.25
0.09
0.75
-167.07
-2,297.87
3,274.25
2-11/16
367.96
1.35
367.21 Pass- Minor 1/10
7,754.85
6,484.70
8,100.00
6,526.91
0.10
0.64
-168.65
-2,255.41
3,300.64
2-11116
323.07
1.23
322.34 Pass - Minor 1/10
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
6/22/2015 3:37.19PM Page 5 of 7 COMPASS 5000.1 Build 65
Baker Hughes INTEQ SAM
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Reference Site:
Kuparuk I Pad
Site Error:
0.00usft
Reference Well:
1G-11
Well Error:
0.00usft
Reference Wellbore
1G-11AL1
Reference Design:
1 G-11 AL1_wp03
Local Co-ordinate Reference:
Well 1G-11
ND Reference:
1G-11 @ 99.00usft (113-11)
MD Reference:
1G-11 @ 99.00usft (1G-11)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
OAKEDMP2
Offset ND Reference:
Offset Datum
Offset Design
Kuparuk 1G Pad - 1G-11 - 1G-11A- 1G-11A_wp02
offset Site Error: 0.00usft
Survey Program: 100-BOSS-GYRO,
7600-MWD
Rule Assigned: Minor 1/10
Offset Well Error: 0.00 usft
Reference
Offset
Semi Major Axis
Measured
Vertical
Measured
Vertical
Reference
Offset
Toolface+
Offset Wellbore Centre
Casing -
Centre to
No Go
Allovrable
Warning
Depth
Depth
Depth
Depth
Azimuth
+N/-s
+E/-W
Hole Size
Centre
Distance
Deviation
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
0
(usft)
(usft)
(usft)
(usft)
(usft)
(usft)
7,760.00
6,485.70
8,050.00
6,526A6
0.10
0.54
-170.15
-2,211.41
3,324.38
2-11/16
277.95
1.13
277.24 Pass -
Minor 1/10
7,760.00
6,485.70
8,075.00
6,526.69
0.10
0.59
-170.34
-2,233.59
3,312.85
2-11/16
300.55
1.15
299.82 Pass -
Minor 1110
7,764.19
6,486.47
7,800.00
6,519.46
0.10
0.25
-142.35
-1,979.59
3,333.30
2-11116
54.41
0.76
53.70 Pass -
Minor 1/10
7,764.74
6,486.57
8,025.00
6,526.21
0.10
0.50
-171.57
-2,188.90
3,335.24
2-11116
255.33
1.06
254.62 Pass-
Minor 1/10
7,770.00
6,487.47
7,975.00
6,525.71
0.11
0.43
-172.57
-2,142.92
3,354.86
2-11/16
210.14
0.97
209.44 Pass-
Minor 1/10
7,770.00
6,487.47
8,000.00
6,525.96
0.11
0.46
-173.09
-2,166.06
3,345.40
2-11/16
232.73
0.99
232.01 Pass -
Minor 1/10
7,773.84
6,488.09
7,825.00
6,520.92
0,11
0.27
-156.77
-1,999A4
3,348.37
2-11/16
71.18
0.76
70.47 Pass-
Minor 1/10
7,776.32
6,488.47
7,950.00
6,525.46
0.11
0.40
-174.17
-2,119A7
3,363.52
2-11116
187.52
0.90
186.82 Pass -
Minor 1/10
7,780.00
6,489.01
7,850.00
6,522.23
0.11
0.29
-165.85
-2,021.62
3,359.77
2-11/16
92.31
0.78
91.60 Pass -
Minor Ill
7,780.00
6,489.01
7,875.00
6,523.38
0.11
0.32
-170.06
-2,045.44
3,367.14
2-11/16
115.73
0.81
115.02 Pass -
Minor 1/10
7,780.00
6,489.01
7,900.00
6,524.31
0.11
0.34
-172.71
-2,070.20
3,370.26
2-11/16
139.98
0.84
139.28 Pass -
Minor 1/10
7,780.00
6,489.01
7,925.00
6,525.01
0,11
0.37
-174.43
-2,095.13
3,369.05
2-11116
164.13
0.86
163.42 Pass -
Minor 1/10
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
6/22/2015 3:37:19PM Page 6 of 7 COMPASS 5000.1 Build 65
Baker Hughes INTEQ MAP k'
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1 G Pad
Site Error:
0.00usft
Reference Well:
1 G-11
Well Error:
0.00usft
Reference Wellbore
1G-11AL1
Reference Design:
1G-11AL1_wp03
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset ND Reference:
Well 1G-11
1G-11 @99.00usft(1G-11)
1G-11 @ 99.00usft (1 G-1 1)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Reference Depths are relative to 1G-11 @ 99.00usft (1G-11) Coordinates are relative to: 1G-11
Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927, Alaska Zone 4
Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is: 0.31 °
Ladder
pint
C
O
.5
f6
Q
N
CO
U
N
C
N
0
a�
C
U
0 2000 4000 6000 8000 10000 12000
Measured Depth
LEGEND
-iE 1G10,1G10BL2,1G10BL2V0 $ 1G11,1G-11,1G11 V1 $ 1G11,1G11A,1G11A_wp02V0
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I I
I I
I I
I I
I I
I I
I
I
I
I
I
I
I
I
j I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I
I
I
I
I
i
I
I
I
I
I
I
I
I
I
I
I
I
I
i
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I I
I III
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
J
I
I
I
I
I
I
1
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation
6/22/2015 3:37 19PM Page 7 of 7 COMPASS 5000.1 Build 65
oA6 s
sag
p _ c E
d �
a
o
Lu
C7 c�0
J
0 m O
3m
O `m
00
a
w
3
gG;
E� n
.E a J
a a
ol
C7 t7
J �
2
c4
°'N3ag
O
a` ma
3
A
a
S.L
PCL
p
V
O
c
U
N
�a)
Q
J �
O
N M
V n
If
R .
U) U @
O V N
_ o a
.t6 O � CD
V V C
C
C O i � t2 ( C O 2
QF-Yvan cO n-ooW��-- d
V
Un-�CDM ONO V On• O V O)O V
O O M O f N 0 0 M V O) N O) C J Lq M O C O
OCON't
�0o COOON MMOMC~O� W M
V V V V V'�� V V �--�a�
vn•CDV
N N N N N N N N N N
Z
N O M O O O O O O o O O O O O O O O O
�CO
NLL 0 0! 0 0 0 0 0 0 0 0 0 O O C:! O O C! O
00000 � V V NMCV N C Cll OGj
n-
JN
MMM NMC4NNNa--�-� NN �
<j
M
_
rnon,o00000oOOOc,C> oO
m 0 Lq 0 0 0 o 0 0 0 0 0 0 0 0 0 0 0 0
p o o v v v v v a v t� n- n.
N
O
C V M C) V V C O n• O O N M LOCO V V
N V C0 �00� C0O U�OMON O)
w M n- W N') M M d) C O O N O O to � CO
} N N N N N M M�- V M M M Cl) M N O
M M M M M M M M M M M M M M M M M M
axA
-ui
(n r2 M n-tOOM LOm V n-�c!
NO
C6 LO
W O
! O) LqMCl O)RC) V ;I:oONMMGO n-r
Z O � � CO CV CV � m � Oi aO N � 00 o d7 Cr
a0 a0 D7 O N M M O V V n- 00 O
Q
V
} <f a7 a7 O O
00
CO 00 W OOO)(TOOCf)N2 OLO
t i
Q
(/JM OMONN V W n-� N V OMN� lO
J
J
Nrn V mN O)N M O)O)N IJ
O> D70Cs
O (O n• C O O C V n• M O N M O n- CC O N n• O
W
M M M M M M M M M LA Cl) N N. .
�tDCOfD
C
tDOO CO CO CO CO CO O(D CO (ND CNp C..
O tD
t
o�
'N OMM [O (OOO TO V N t0 Y] n-1�O CO CO
V M M Cn N N Lq N O CT CA CO KJ CO V V V O
ZO
O
Q
.0 .0 .0 1� Y] V .0 0 0 M M Cl R M 0 LO
co
�2 Z2�2 �2 0 c') V V N C O
0)M
Mf
M M M M M M
C V Cn N M O N V n• O n• O) Cl! Lq CJ
O
�
M M C-i CO C6 LA V N O C:; V n- a6 CO V
MM V CO CO r- COp0000Q7 a0 oD W oDO
�O
W O
C) O O o 0 0 0 0 0 0 0 0 0 N N N N N N
+
0 0 0 0 0 0 0 0 0 0 O O M M M M M M
O V Oi OimM mOit mm mmmmmMM
O M to O N m C D M V. N N a O M M C" J M O
O OCO O CO n- n•OO)N
O
0 N M V M O N fC2 V �O O n• O
(ui/R3sn 06) u1daQ jEoiljaA anj,
w
Z
0
M
O
U
C3
U
TRANSMITTAL LETTER CHECKLIST
WELL NAME: M(&
PTD:
/Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: i 1/ POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. API No. 50- oa - 2 1 OO R - O 1 - O V.
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69)
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- from records, data and logs acquired for well
(name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Com any Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100
PTD#:2151260 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type
Well Name: KUPARUK RIV UNIT 1G-11AL1 Program DEV Well bore seg d❑
DEV / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached
NA
2
Lease number appropriate
Yes
ADL0025640, entire wellbore
3
Unique well name and number
Yes
KRU 1G-11AL1
4
Well located in a defined pool
Yes
KUPARUK RIVER, KUPARUK RIV OIL - 490100, governed by Conservation Order No. 432C
5
Well located proper distance from drilling unit boundary
Yes
CO 432C contains no spacing restrictions with respect to drilling unit boundaries.
6
Well located proper distance from other wells
Yes
CO 432C has no interwell spacing restrictions
7
Sufficient acreage available in drilling unit
Yes
8
If deviated, is wellbore plat included
Yes
9
Operator only affected party
Yes
Wellbore will be more than 500' from an external property line where ownership or landownership changes.
10
Operator has appropriate bond in force
Yes
11
Permit can be issued without conservation order
Yes
Appr Date
12
Permit can be issued without administrative approval
Yes
13
Can permit be approved before 15-day wait
Yes
PKB 7/21/2015
14
Well located within area and strata authorized by Injection Order # (put 10# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only)
NA
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
NA
17
Nonconven. gas conforms to AS31.05.0300.1.A),0.2.A-D)
NA
18
Conductor string provided
NA
Conductor set in KRU 1 G-11
Engineering
19
Surface casing protects all known USDWs
NA
Surface casing set in KRU 1G-11
20
CMT vol adequate to circulate on conductor & surf csg
NA
Surface casing set and fully cemented
21
CMT vol adequate to tie-in long string to surf csg
NA
22
CMT will cover all known productive horizons
No
Productive interval will be completed with uncemented slotted liner
23
Casing designs adequate for C, T, B & permafrost
Yes
24
Adequate tankage or reserve pit
Yes
Rig has steel tanks; all waste to approved disposal wells
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed
Yes
Anti -collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pres is 2898 psi(8.7 ppg EMW); will drill w/ 9.1 ppg EMW and maintain overbal w/ MPD
VTL 7/23/2015
29
BOPEs, do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
MPSP is 2270 psi; will test BOPs to 3000 psi
31
Choke manifold complies w/API RP-53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
112S measures required
34
Mechanical condition of wells within AOR verified (For service well only)
NA
35
Permit can be issued w/o hydrogen sulfide measures
No
Well on 1G-Pad are H2S bearing. H2S measures required.
Geology
36
Data presented on potential overpressure zones
Yes
Max. expected reservoir pressure is 8.88 ppg EMW; will be drilled using 9.1 ppg mud and MPD technique.
Appr Date
37
Seismic analysis of shallow gas zones
NA
PKB 7/21/2015
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA
Onshore development to be drilled.
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
