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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: CRU CD5-23: 30-day gas injection monitor AOGCC Notification
Date:Wednesday, September 17, 2025 11:22:05 AM
Attachments:image001.png
AnnComm Surveillance TIO for CD5-23.pdf
From: Shulman, Mark <Mark.Shulman@conocophillips.com>
Sent: Wednesday, September 17, 2025 10:58 AM
To: Automation, AK Wells <akwellsautomation@conocophillips.com>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>
Cc: Conklin, Amy A <Amy.A.Conklin@conocophillips.com>; Livingston, Erica J
<Erica.J.Livingston@conocophillips.com>; Taylor, Jenna <Jenna.L.Taylor@conocophillips.com>
Subject: CRU CD5-23: 30-day gas injection monitor AOGCC Notification
Well Name: CD5-23
Facility: WNS
PTD: 217-155
Well Type: Injector
AA Number (if applicable): AIO 18E.004
Internal Waiver (Yes/No if applicable):Yes
Type of Issue: Plan forward
Maximum Pressure (if applicable):
Date of Occurrence (if applicable): 9/17/25
Chris,
CRU CD5-23 is a waivered gas injector (AIO 18E.004) and has completed it’s 30-day gas
injection monitor on 9/17/25. The well is stable and shows no AnnComm issues. Also, CD5-
23 passed a waiver compliance state witness MIT-IA 4,200 psi on 8/31/25 (by Bob Noble).
Attached is a 90-day TIO plat and wellbore schematic. CPAI will continue waiver compliance
gas and water injection operations on this well.
Please let me know if you have any questions or disagree with this plan.
Thanks,
Mark
Mark Shulman
WNS Sr. Well Integrity Engineer
ConocoPhillips Alaska
Mark.Shulman@conocophillips.com
Office (907) 263-3782 Mobile (602) 513-0775
CD5-23 90-Day Bleed History
WELL DATE STR-PRES END-PRES DIF-PRES CASING
CD5-23 2025-06-29 1320 980 -340 IA
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: SET A-1 INJ VALVE ON A 4.5" P2P W/ MID ELEMENT @ 2050' RKB CD5-23 7/9/2025 raineg
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: COIL MILLED OUT X -LOCK. NIPPLE AT 2070' IS LIKELY DAMAGED. SEE ATTACHMENTS.3/22/2024 rmoore22
NOTE: RUNNING NECK AND FISHING SWIVELED OFF DV IN STA #2. WOBBLE RING & SPRING
RECOVERED.
2/9/2018 claytg
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR2019.12 33.3 115.0 115.094.00 H-40 Welded
SURFACE 10 3/4 9.95 37.0 2,219.6 2,179.0 45.50 L-80 Hyd 563
INTERMEDIATE 7 5/8 6.88 34.0 8,620.8 7,444.3 29.70 L80 Hyd563
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
31.0
Set Depth…
8,946.5
Set Depth…
7,485.1
String Max No…
4 1/2
Tubing Description
Tubing – Production
Wt (lb/ft)
12.60
Grade
L-80
Top Connection
H563
ID (in)
3.96
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
31.0 31.0 0.00 HANGER 11.000 FMC 4-1/2" Tubing Hanger H563 FMC TC-EMS
11"x5"
3.958
2,070.9 2,039.2 20.13 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813",
HYD563 (likely damaged. see note
above)
HES X 3.813
3,583.3 3,453.8 21.12 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X
1",H563
SLB
Camco
KBMG3.860
5,882.0 5,595.5 21.05 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X
1",H563
SLB
Camco
KBMG3.860
6,398.3 6,077.2 21.08 GAS LIFT 6.473 GLM KBMG,Camco,4 1/2" X
1",H563
SLB
Camco
KBMG3.860
8,129.3 7,337.8 70.77 PACKER 6.620 Baker permanent production packer
4.5" TC-II x 7 5/8" 29#
BakerPremier 3.870
8,183.1 7,354.7 72.57 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",X,3.813",
HYD563 ***POLISH BORE
DAMAGED***
HES X 3.813
8,227.7 7,367.5 74.04 NIPPLE 5.030 NIPPLE,LANDING,4 1/2",3.813" XN,
3.725" No-go HYD563 ***NIPPLE
MILLED OUT TO 3.80" PRE-CTD
1/12/20***
HES XN 3.800
8,231.0 7,368.4 74.13 LINER 4.500 CROSSOVER,4 1/2"HYD563 X
TXP,BP,24"
3.958
8,232.9 7,368.9 74.18 LINER 4.500 Tubing,4 1/2",12.6#,L80, TXP 3.958
8,941.3 7,484.6 84.20 SHOE 4.500 Orange Peel Shoe (MILLED OUT
FROM 1.00" TO 3.70" ON
3/23/2018)
3.700
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
2,047.02,016.7 20.03 INJ VALVE 4.5" A-1 INJECTION VALVE
ON P2P (MID-ELEMENT @
2050' RKB (SN# HWS-210,
1.25" BEAN, OAL = 84"
7/9/2025 1.250
8,750.0 7,461.3 82.46 4-1/2" BOT
Mono-bore XL
tray
Whipstock
4-1/2" BOT Mono-bore XL tray
Whipstock
2/23/2020
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi)Run Date Com Make Model
Port
Size (in)
3,583.3 3,453.8 21.12 1 GAS LIFT DMY BK 1 0.0 1/13/20190.000
5,882.0 5,595.5 21.05 2 GAS LIFT DMY No
Latch
1 0.0 2/8/2018 No
Latch
0.000
6,398.3 6,077.2 21.08 3 GAS LIFT DMY BK 1 0.06/11/20250.000
HORIZONTAL, CD5-23, 7/10/2025 6:19:24 AM
Vertical schematic (actual)
X O
SHOE; 8,941.3
PERF PUP; 8,930.6
4-1/2" BOT Mono-bore XL tray
Whipstock ; 8,750.0
OPEN HOLE; 8,621.0-27,430.0
INTERMEDIATE; 34.0-8,620.8
NIPPLE; 8,227.7
NIPPLE; 8,183.1
XO THREADS; 8,133.5
PACKER; 8,129.3
XO THREADS; 8,121.5
GAS LIFT; 6,398.3
GAS LIFT; 5,882.0
GAS LIFT; 3,583.3
SURFACE; 37.0-2,219.6
NIPPLE; 2,070.9
INJ VALVE; 2,047.0
CONDUCTOR; 33.3-115.0
HANGER; 31.0
WNS INJ
KB-Grd (ft)
36.55
RR Date
1/24/2018
Other Elev…
CD5-23
...
TD
Act Btm (ftKB)
27,430.0
Well Attributes
Field Name
ALPINE
Wellbore API/UWI
501032076100
Wellbore Status
INJ
Max Angle & MD
Incl (°)
94.15
MD (ftKB)
19,914.56
WELLNAME WELLBORE
Annotation
LAST WO:
End DateH2S (ppm)DateComment
SSSV: NIPPLE
DATA SUBMITTAL COMPLIANCE REPORT
1110/2018
Permitto Drill
2171150 Well Name/No. KUPARUK RIV UNIT 2A -22A Operator
CONOCOPHILLIPS ALASKA, INC. API No. 50-103.20221-01-00
MD
17092
TVD 5943 Completion Date
10/7/2017 Completion Status 1-0I1-
Current Status 1-0I1- UIC No
REQUIRED INFORMATION
/
Mud Log No ✓
Samples No ✓
Directional Survey Yes VX
DATA
INFORMATION
List of Logs Obtained: GR/Res
(from Master Well Data/Logs)
Well Log information:
Log/
Electr
Data
Digital
Dataset
Log Log Run Interval
OHI
Type
Med/Frmt Number Name
Scale Media No Start Stop
CH Received
Comments
ED
C
28686 Digital Data
10/16/2017
Electronic File: 2A -22A EOW - NAD27.pdf
ED
C
28686 Digital Data
10/16/2017
Electronic File: 2A -22A EOW - NAD27.txt
Log
C
28686 Log Header Scans
0 0
-
2171150 KUPARUK RIV UNIT 2A -22A LOG
HEADERS
ED
C
28769 Digital Data
14109 17092
11/2/2017
Electronic Data Set, Filename: 2A -22A GAMMA
RES.las
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A 21VID Final.cgm .
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A 5MD Final.cgm
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A 5TVDSS Final.cgm,
ED
C
28769 Digital Data
P 11/2/2017
Electronic File: 2A -22A 21VID Final.pdf.
ED
C
28769 Digital Data
P 11/2/2017
Electronic File: 2A -22A 5MD Final.pdf
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A 5TVDSS Final.pdf .
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A EOW - NAD27.pdf
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A EOW - NAD27.txt
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A Survey Listing.txt
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A -22A Surveys.txt
ED
C -
28769 Digital Data
11/2/2017
Electronic File: 2A-22A—Final Surveys TO
17092.csv
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A-22A—Final Surveys TO
17092.xlsx
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A-
22A_25_tapescan_BH I_CTK.tM
ED
C
28769 Digital Data
11/2/2017
Electronic File: 2A-22A_5_tapescan_BHI_CTK.txt
AOGC'C'
Page 1 oft
Wednesday, January 10, 2018
DATA SUBMITTAL COMPLIANCE REPORT
1/10/2018
Permit to Drill 2171150 Well Name/No. KUPARUK RIV UNIT 2A -22A
MD
17092
TVD 5943 Completion Date 10/7/2017
ED
C
28769 Digital Data
ED
C
28769 Digital Data
ED
C
28769 Digital Data
ED
C
28769 Digital Data
Log
C
28769 Log Header Scans
Well Cores/Samples Information:
Name
INFORMATION RECEIVED
Completion Report L:/
Production Test Information �Y / NA
Geologic Markers/Tops 10
COMPLIANCE HISTORY
Completion Date: 10/7/2017
Release Date: 9/6/2017
Description
Comments:
Interval
Start Stop
Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-103-20221-01-00
Completion Status 1-0I1 Current Status 1-0I1- UIC No
11/2/2017 Electronic File: 2A-22A_output.tap -
11/2/2017 Electronic File: 2A -22A 2MD Final.tif
11/2/2017 Electronic File: 2A -22A 5MD Final.tif
11/2/2017 Electronic File: 2A -22A 5TVDSS Final.tif -
0 0 2171150 KUPARUK RIV UNIT 2A -22A LOG
HEADERS
Sample
Set
Sent Received Number Comments
Directional / Inclination Data (rr ' Mud Logs, Image Files, Digital Data Y /6) Core Chips Y /A)
Mechanical Integrity Test Informationl�Y/I lA Composite Logs, Image, Data FilesY) Core Photographs Y / A
Daily Operations Summary Cuttings Samples Y / NA Laboratory Analyses Y / NA
Compliance Review
Date Comments
Date:
AOGCC Page 2 of 2 Wednesday, January 10, 2018
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
RECEIVED
NOV 0 8 2017
1. Operations Abandon Ll Plug Perforations
LJ
Fracture Stimulate Ll Pull Tubing Li AutdownLl
Performed: Suspend ElPerforate
ElOther
WfftjpO
Stimulate ❑ Alter Casing El11QM�// YY"�rogram ❑
Plug for Reddll ❑ Perforate New Pool
❑
Repair Well ❑✓ Re-enter Susp Well ❑ Other: 3 tbg patches ❑✓
2. Operator ConocoPhillips Alaska, Inc
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development Ex ry❑
❑ p lorato
Stratigraphic ❑ Service ❑
217-115-0
3. Address: P.O.Box 100360, Anchorage
6. API Number:
Alaska 99510
50-103-20221-01
7. Property Designation (Lease Number):
8. Well Name and Number:
ADL 25571, 25570
KRU 2A -22A
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
N/A
Ku aruk River Field / Ku aruk River Oil Pool
11. Present Well Condition Summary:
Total Depth measured 17092'
feet
Plugs measured none feet
true vertical 5943'
feet
Junk measured none feet
Effective Depth measured 17092'
feet
Packer measured 14227 feet
true vertical 5943'
feet
true vertical 5789' feet
Casing Length Size
MD TVD Burst Collapse
Structural
Conductor 80' 16"
121' 121'
Surface 4887' 9.625"
4928' 2937'
Intermediate
Production 14749' 7"
14787' 6138'
Liner 2044' 2 3/8"
17092' 5943'
Perforation depth Measured depth 14302'-17092'
feet
True Vertical depth 5835'-5943'
feet
Tubing (size, grade, measured and true vertical depth)
3.5" L-80 14213' MD 5780' TVD
Packers and SSSV (type, measured and true vertical depth)
PACKER -BAKER SAB -3 PERMANENT 14227' MD 5789' TVD
SSSV- NONE DS NIPPLE 533' MD 533' TVD
12. Stimulation or cement squeeze summary:
Intervals treated (measured): N/A
Treatment descriptions including volumes used and final pressure:
13.
Representative Daily Average Production or Injection Data
Oil -Bbl
Gas-Mcf I Water -Bbl Casing Pressure Tubing Pressure
Prior to well operation: N/A
N/A N/A N/A N/A
Subsequent to operation: I N/A
N/A N/A INIA N/A
14. Attachments (required Per 20 AAc 25.070, 25.071, s 25.283)
15. Well Class after work:
Daily Report of Well Operations ❑✓
Exploratory ❑ Development E] Service ❑ Stratigraphic ❑
Copies of Logs and Surveys Run ❑
16. Well Status after work: Oil Gas ❑ WDSPL ❑
Printed and Electronic Fracture Stimulation Data ❑
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑
17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Authorized Name: Kelly Lyons
Contact Name: Kelly Lyons / Jan Byrne
Authorized Title: Well Integrity S* ervisor
Contact Email: n1617@cop corn
Authorized Signature:
Date: 11/4/17 Contact Phone: 907-659-7224
VT/_ ,z/7 //'Z 2017
Form 10-404 Revised 4/2017 � 7 ., /71� L Submit Orig incl Only
Date Event Summary
07/03/17
07/22/1
07/25/1
08/03/1
08/04/1
1011211
(PRE -CTD) TIFL- FAILED DUE
DURING MONITOR PERIOD.
Initial T/I/0= 200/975/360. OA FL @ 324' (ruler)
IA FL @ 9548' below OV (7553' OV)
Shut in WH/AL line and stacked out T with lift gas T/I/0= 900/860/360. IA FL @
7421'(inflowed 2127') T FL @ 5681'
Bled AL line 250 psi.
Bled IA 45 min. T/I/0= 810/610/340. IA FL @ 5745' (inflowed 1679') T FL @ 5917'(
outflowed 236')
15 min. reading T/I/0= 850/650/340 (+40) IA FL @ 5066' (inflowed 679') T FL @ 5830'
(inflowed 87')
30 min. reading T/1/0= 890/690/340 (+40)
(inflowed 235')
Final T/I/0= 890/690/340
IA FL @ 4723' (inflowed 343')T FL @ 5595'
SET CATCHER @ 7872' RKB; PULLED GLV & SET DMY @ 3341' RKB; PULLED OV @
7553' RKB & LRS LOAD BACKSIDE WITH 88 BBLS OF DIESEL; PULLED CATCHER @
7872' RKB; SET HOLEFINDER @ 9683' RKB & W/ LRS OBTAIN CMIT TO 2000 PSI
**PASS**; SET DMY VLV @ 7553' RKB & LRS ESTABLISH LLR OF .36 BPM @ 1500 PSI.
READY FOR LEAK DETECT.
BEGIN CMIT TO 2000, INITIAL T/IA/OA = 1275/1425/280, STARTING T/IA/OA =
2050/2200/300 15 MIN = 2025/2175/300 30 MIN = 2025/2175/300 **PASS*
LEAK DETECT LOG, RIH TO POINT OF REFUSAL @ 9030' RKB, BRING LRS ONLINE @
2BPM TO TUBING TAKING RETURNS TO FORMATION, RIH WITH PUMP ASSIST TO
9850' RKB, LRS PUMP DOWN IA @ 0.5BPM TAKING RETURNS TO FORMATION, LOG
UP PASS @ 80 FPM OVER INTERVAL 9850'-9300' RKB, LRS ONLINE @ 1.0 BPM DOWN
IA, LOG UP PASS @ 40FPM OVER INTERVAL 9500'-9300' RKB, LRS ONLINE @ 0.5 BPM
DOWN IA, PERFORM STATION SURVEYS @ 9430', 9426', 9425' RKB, POOH LEAK
FOUND IN TUBING @ 9426' RKB
MIRU. RIH W/ BAKER MICRO VERT TOOL TO TO 10100'. LOG UP @ 120 FPM OVER
INTERVAL 8200'- 10100'. RIH TO 14100'. LOG TO SURFACE @ 120 MIN. RDMO
7 PERFORM 24 ARM CALIPER LOG FROM 14342' RKB, UP TO 12800' CTMD *JOB N
PROGRESS*
SET 2.72" LOWER PIIP MID ELEMENT @ 9650' RKB. SET TEST TOOL &CMIT 2500 PSI
PASS) SET UPPER 2.72" PIIP, SPACER PIPE @ LATCH ASSY MID ELEMENT @ 9620'
RKB. CMIT TO 2500 PSI ( PASS) IN PROGRESS.
BEGIN CMIT. INITIAL T/I/O/FL = 950/950/280/200 LRS PUMP 2.95 BBLS TO PT. START =
2610/2610/280/200 15 MINS= 2605/2605/280/200 30 MINS = 2605/2605/280/200 PASS ON
SECOND TEST
BEGIN CMIT. INITIAL T/I/O/FL = 950/960/280/210 LRS PUMP 3 BBLS STAR =
2600/2600/280/210 15 MINS = 2575/2580/280/210 30 MINS = 2565/2575/280/210
10/13/17
10/14/1
10/15/17
Executive
Summary
SET LOWER 2.72" PIIP MID ELEMENT @ 9447' RKB. CMIT AGAINST TEST TOOL TO
2500 PSI ( PASS) STING MIDDLE PATCH ASSY IN LOWER PIIP @ 9447' RKB. CMIT
AGAINST TEST TOOL TO 2500 PSI ( PASS) IN PROGRESS.
BEGIN CMIT. INITIAL T/I/O/FL = 960/960/280/210 PUMP 2.8 BBLS START =
2590/2595/280/210 15 MINS = 2560/2560/280/210 30 MINS = 2555/2555/280/210 PASS.
BEGIN CMIT. INITIAL T/I/O =1000/960/280 LRS PUMP 3 BBLS. START = 2590/2560/280 15
MINS = 2575/2550/280 30 MINS = 2560/2550/280 45 MINS = 2560/2550/280 PASS
SET UPPER 2.72" PIIP PATCH ASSY MID ELEMENT @ 9399' RKB. MITT TBG TO 2500
PASS) CMIT 2500 ( PASS) SET LOWER 2.72" PIIP PACKER MID ELEMENT @ 8615'
RKB. MITT TBG TO 2500 (PASS) IN PROGRESS
BEGIN MITT. INITIAL T/I/O = 1000/960/280 LRS PUMP .5 BBLS TO PT TBG TO 2500 PSI.
START = 2610/1000/280 15 MINS = 2560/1000/280 30 MINS = 2555/1000/280 ( PASS)
HOOK JUMPER TO PT IA FOR CMIT. START = 2560/2540/280 15 MINS = 2550/2530/280
MINS = 2550/2530/280 PASS.
SET UPPER 2.72" PIIP PACKER, SPACER PIPE & LATCH SEAL MID ELEMENT @ 8585'
RKB. MITT 2500 PSI ( PASS) CMIT 2500 PSI ( PASS) IN PROGRESS.
BEGIN MITT. INITIAL T/I/O = 1360/950/280 LRS PT TBG W/.5 BBLS START =
2625/975/280 15 MINS = 2560/975/280 30 MINS = 2550/975/280
CMIT TxIA. START = 2775/2625/280 15 MINS = 2750/2600/280 30 MINS = 2750/2590/280.
Three TTS retrievable tubing patches were set to repair the tubing. A 48' patch from 9399'-
9447' was used to cover an identified leak at 9426'. Two 30' patches from 8585'-8615' and
9620'-9650' were used to cover areas of high metal loss of the tubing (>80%), as was
identified with Baker's MicroVertilog (a corrosion logging tool). Integrity of the patches was
confirmed with passing MITT/CMIT's.
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
November 4, 2017
Commissioner Hollis French
Alaska Oil & Gas Commission
333 West 7' Avenue, Suite 100
Anchorage, AK 99501
Dear Commissioner French,
RECEIVED
NOV 0 8 2011
AOGCC
Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. Development KRU well 2A -22A (PTD 2171150). The report is for 3
retrievable tubing patches that were set to repair a leak above the packer.
Please call Jan Byrne or myself at 659-7224 if you have any questions.
Sincerely,
Kelly Lyons
Well Integrity Supervisor
Attachments
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RECEIVED
NOV 0 6 2017
WELL COMPLETION OR RECOMPLETION REPORT
1a. Well Status: Oil 21 r Gas[] SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑
20AAC 25.105 20AAC 25.110
GINJ ❑ WINJ ❑ WAC WDSPL ❑ No. of Completions:
1b. Well la
Development E] ' Exploratory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 10f7/2017
14. Permit to Drill Number / Sundry:
217-115 /
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded: uc
-9(27+2837
15. API Number:
50-103-20221-01-00'•
4a. Location of Well (Governmental Section):
Surface: 4523' FNL, 5052' FEL, Sect 3, T11 N, R8E, UM
Top of Productive Interval:
1745' FNL, 992' FEL,Sec 16, T11 N, R8E, UM
Total Depth:
111 V FNL, 3615' FEL, Sec 16, T1 IN, RBE, UM
8. Date TD Reached:
10/1/2017
16. Well Name and Number:
KRU 2A -22A
9. Ref Elevations: KB:135
GL: 94 BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk Oil Pool
10. Plug Back Depth MD/ VD:
N/A
18. Property Designation:
ADL 25570, ADL 25571
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 498620 y- 5960177 Zone- 4
TPI: x- 486842 y- 5962967 Zone- 4
Total Depth: x- 484218 y- 5963606 Zone- 4
11. Total Depth MD/TVD:
17092/5943.
19. DNR Approval Number:
9318991000,931892000
12. SSSV Depth MD1 VD:
N/A
20. Thickness of Permafrost MDf VD:
1543/1497
5. Directional or Inclination Survey: Yes ❑ (attached) No ❑
Submit electronic and printed information per 20 AAC 25.050
13. Water Depth, if Offshore:
N/A (ft MSL)
21. Re-drill/Lateral Top Window MD/TVD:
14307/5838
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
16 62.6 H-40 41 121 41 121 24 250 sx AS 1
95/8 40 L-80 41 4928 41 2937 12.25 820 sx AS III Lead 890 sx Class G
7 26 L-80 38 14787 38 6137 8.5 260 sx Class G
23/8 4.7 L-80 15048 17092 5886 5943 3 Slotted Liner
24. Open to production or injection? Yes ❑� No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
Slotted Liner @ 15048-17092 MD and 5886-5943 TVD
rT
r nT,"
I? I (1_-
Lk -
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MDRVD)
31/2 14265 14103/5716
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes E] No R]�p
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) 1AMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
10/22/2017
Method of Operation (Flowing, gas lift, etc.):
GAS LIFT
Date of Test:
1 0/2 412 01 7
Hours Tested: �,
1\yam
Production for
Test Period
Calculated
24 -Hour Rate
Oil -Bbl:
357
Oil -Bbl:
571
Gas -MCF:
226
Gas -MCF:
362
Water -Bbl:
2708
Water -Bbl:
1 4
Choke Size: Gas -Oil Ratio:
1 176 1 634 MMCF/bbl
Oil Gravity - API (corr):
1 26
Flow Tubing
Press. 226
I Casinq Press:
1330
Form 10-407 Revised 5/2017 V tL /f 1 /5-16 �- CONTINUED % O PAGE 2 ��iC'L?.moi LL' i �U v - 7 Ll) ITubmit ORIGINIAL only/'
,oe '/moi // 7 Y1K?l ll�lSI L7
28. CORE DATA Conventional Core(s): Yes ❑ No ❑D Sidewall Cores: Yes ❑ No ❑+
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this farm,
if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071.
29. GEOLOGIC MARKERS (List all formations and markers encountered):
30. FORMATION TESTS
NAME
MD
TVD
Well tested? Yes ❑ No Q
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1543
1497
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
14308
5839
information, including reports, per 20 AAC 25.071.
Formation @ TPI -Kuparuk C
TO
17092
5943
Formation at total depth:
Kuper k C r
31. List of Attachments: Daily Operations Summary, Definitive Survey, Schematics
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontolonicalr r well
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: Kai Starck Contact Name: Mike Callahan
Authorized Title: CTD Team Lead Contact Email: Mike.Callahan0co .com
Authorized Contact Phone: 907-263-0180
Signature: Date: ` a0l
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a wait must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each
segregated pool is a completion.
Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in hem 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Form 10-407 Revised 5/2017 Submit ORIGINAL Only
2A -22A and 2A-22AL1 Completed Wellbore Schematic
16" 62# H40 shoe
@ 121' MD
95/8" 40# L-80
shoe @ 4928' MD
ILiner Top @ 14,181' MD
vdth Northern Solutions UP
D -Nip milled to 280" ID
@ 14,247 MD
KOP @ 14,308' MD
3-12" XL Monobore WS
set in cement pilot hole
C/A -sand per's
14,302' -14,317' MD
14,330' -14,346' MD
14,352' -14,378' MD
Modified by TH 12 -Oct -2017
3.1/2" DS Nipple (min ID 2.812") @ 532.6' MD
3-1/Z'9.3# L-80 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrel @ 33421, 7554',
10,757',12,955', and 14,018'
Baker 3.1/2" PBR @ 14,080' MD (2.98" ID)
Baker FHL packer @ 14,103' MD (2.93" ID)
3-1/2" Camco DS landing nipple @ 14,153' MD (2.812"
min ID, No -Go)
Poor Boy Overshot @ 14,205'
Baker KBH-22 Anchor SA @ 14,226' MD
Baker SAB -3 Packer @ 14,227
3-1/2" Camco D landing nipple @ 14,242' MO (milled out
to 2.80" min ID, No -Go)
3-1/2" WLEG @ 14,263' MD
ubing tail Perfs
14,237' - 14,239' MD
for cement squeze
12318" Sold Liner frau
ILT-14,434' MD
2A-22AL1 TD @ 17,619 MD
-318' Slotted Liner
@ 14, L-80 shce��l� -
@ 14,787' MD KOP for AL1 off LT Billet Ported Bull Nose
@ 15,04T MD /Deployment Sleeve 2A -22A 1D @ 17,0!
@16,015' MD 23/8' Slotted Liner
MD
y
,l'
ConocoPhillips wen KUP PROD arum
maa(a.nC. W.IIWmAPWWI 7FI¢14
UNIT
2A-22
Iaw3x. n4Vdln 19s260� 1 1201 IDS12016 LLaMWO: I 9292014 1 45.901 (111/1995 I
Annodlbn Oepm mHad EM DeIe
Annoption
WtMM By
EM
-----------—"'--
XAuoER: 34.4
---Last
Tag: RIC 14,399.0 BIfl20D
Rev Reason: TAG, LINER TOP PACKER, GLV
C10, SET 3 PATCHES(1-Leak,2-Proactive)
pproven
101312017
u ng rings
Tubing Debefisn n senna Ma... m gn1 TOP mHB) sal oepin m. Set oePm (rvU1 L.. WI pGn) GraBe TOP Canns,
TUBING Original 3112 2.992 142010 1Q2fi4.fi 5,811.9 9.30 L-80 ABM-EUE
Completion Details
rvamin, l0
rop(rtKa) TOPIrvDHgKa1 TOPlnalr) Henn Dub coin 6N
CONDUCTOR; 41.0210
14,225.8 5)88.0 5260 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSY 3000
14,2261 5,)88.6 52.58 PACKER BAKER SAB -3 PERMANENT PACKER 3.250
uIPPLE; s2.6
14,2420 5,7979 52.22 NIPPLE CFlMCO D LANDING NIPPLE NO GO 2750
14,2627 5,810.6 51.13 WLEG WIRELINE ENTRY GU IDE ELMO V 14258'ON SWS 2992
PERF 811712001
Mmes': B2, s
Perforations & Slots
shin
Oen
TaP)rvD)
BOnmG)
(sb-bu
I
roe (ince)
—I.-,mKBI
mKat
zone
Dm
ro
Tree
coin
14,302.0
14,31 ZO
5835.1
5844.4
Ci, 2A22
6282000
40 APERF
2112" -SU DP, 1804eg
I
M
SVflFACE:4096,98.0—
Sgmulations &Treatments
P,aPpzm DeaL— gsW(Ho) ,,PPenl m Falmmlon(m) Dzh
Mu4rtl:7.5SA9
1Z9/2002
Stimulations & Treatments
val clean Pump
PATCX: a565U
sqp raPlnKa)
atm mne) Oma
srmrtreal Fundmbl)
vin Ed,(eal)
1 14,302 0
14,378.0 12/9/2002
PATCR: e.e1a0
Notes: General & Safety
End De@ Annol —
PATCX:a,3an.0
611/2008 NOTE TUBING PUNCH BETWEEN$AB-3 PACKER& CA -2 PLUG IN TUBING STUB, 9 SHOTS
wrENTRANCE HOLE OF 0.19
PATCX', 9,4160
11h2008 NOTE Vue Schematic wl Alaska ScLemagc9.0
PATCN, 9,46)0
11/5!2014 NOTE 2.81 -DS N.P. @14152RKP MAY BE DAMAGED FROM PULLING PLUG ON 11 514
PATCN: 98300
PATO X: 98500
M.new+a.m6
MmbN; 1$�0
MCMM, 14,0178
LOCATOR; I6,OY13
6EPL A66Y; 16,Q13]
PBR. 160]85
PACKER;14.IMG
NIPPLE:1d,IRa
PACKER;161BJ,0
CYERSNOT,14,318.4
SEALA65Y; 16,313.8
PACKER.
NIPPLE; 14,23.0
W...14,82,]
APERF: 163V3.614,3170
Wtpsbck, Id,3JT0
PROOUCTK AV: %.316]9) 0
FRAC;163'J10
pL 1YwM; t4,faTa1],8180
I
�`�`�y, KUP PROD
c ocwk iiwp$1 I Well Altril
NaBka, ICG ) welhrp' APulwl Hem
2A -22A
uat iLSECS 03aaAM ISS$V. NIPPLE 1 1201 12/512016 IASTWO: I 9292014 I 4.5961 6111/1e9F
AnneMnn peptll Bll(BI End pah AnnotaWn taslMal By nd pate
HANGER, 36<
Last Tag: RKB 14,399.0 8/8201] Rev Reaare Side Track Mnnalt 1112201]
asmg Cgs
caamp Decenpmn 010;1 ) oy (nxa) del Depth sM Depth lrvDl_. PALen(I... Grade Top Th,ead
CONDUCTOR 16["75 .M21;. 41.0 121.0 1210 62.58 H40 WELDED
Casln00e-"thn 010;) N(Ini op MKS) Set Depth HIMS Set eager (TYp1... ML -ll... Grade TopTherd
SURFACE 9518 6835 40.9 4,9280 2,9; 4000 L-80 BTO
.i..� CONDUCTOR: n GIN 0
WsinO leurlpxen Op n) IO6n1 Top(xltBI Set Depth PKB1 SM depth RPdM_. nn.. Grade Top"hed
PRODUCTION ] 6.216 38.3 14]8].0 5,886.6 26.00 L -BO BTC -MOD
Cori.. Gere",nion ODO., IDOn) Topp"" SN DepIn IIIKBI Sal GreenjND)... WIILen(I.., Great, Top Thread
MPPLR:Eaaa
ALateral 23/8 1.992 15,048.0 17,091.5 5,9434 4.60 L-80 STT
Tubing Strings
Tubine Description sp.n. Ma...mgni Tap MIKE'aN Gap" 11 sat Gepth jN.1(...vn HIM,) Top Connwtian
Lot."
TUBING WO -2014 312 2.992 364 14,212.5 5.]800 9.W L-80 PURSES
Mwr3aa+s
Completion Details
xomlmUp
Top M✓•3 rop RV1)36.4 TephOSO Nem Ges 80th lin)
364 36.4 000 HANGER FMC TUBING HANGER 2.992
532.6 532.6 1.64 NIPPLE DS NIPPLE 2.012
SURME:as4.90.0_
140722 5,6987 5628 LOCATOR LOCATOR SUB 2.970
hander: )w3.a
14,0732 5,6992 56M SEALASSY SEAL ASSY ..STICK-UP =7-B. SWALLOW 14.6 -ft 3000
14,0795 5,)027 56.10 PBR BAKER POLISH BORE RECEPTACLE 2.980
14,102.6 5.]15] 5554 PACKER BAKER FHL RETRIEVABLE PACKER 2.930
PATCH: SW 0-
14,152.9 5.744.6 54.31 NIPPLE CAMCO OR NIPPLE 2,812
vnax:eela0
14.2054 57757 53.08 OVERSHOT POOR BOY OVERSHOT...SWALLOW =55 -ft. 3620
..:e..a
Other In Hole (Wireline retrlevable plugs, valves, pumps, fish, etc.)
Tnp ITVDI
ropmd
PATCK S414p
PATCH: e.ax°
Top IRK1e
I..,I°I
Dei
Co._
Run Data
IS Jet
8,5850
3,983.4
73.60
PATCH
UPPER PIIP PATCH ASSY=2.72'PIIP(SN:
CPP35119) 25.25'.21116' SPACER PIPE 8
1011512017
1600
LATCH SEAL( SN: CPAL35068) OAL =30.8T/
PATCH: Stye 0
MID ID =160"
PATCH: 961
8,6150
3,991.9
)3.53
PATCH
LOWER 2.T'PIIP PACKER (SN CPF3132)OAL
10114Q01
1.620
=4.011 MIN ID=1.625
9,399.0
4,220.0
]2]8
PATCH
UPPER 272' POP (SN: CPP3512)) 11.60' OF 2
10_4201)
1.620
Ma'rN, [005].4
1118" SPACER PIPE 6 DYTCH SEAL ASSEMBLY
(SN: CPA1350059 )1).0]' CAL / MIN ID =
1.62" ((1SMID ELEMENT TO BTM))
9,414.0
4,224.5
]276
PATCH
3.5"PBR(SN;CPBR35004)Wx21/16"SPACER
1&132017
1.620
manar.lasss.o
PIPE 8 LATCH SEAL ASSY (SN: CPAL35D50 )
OAL = V35-11 62' ID
9,447,0
4,2342
R.72
PATCH
2J2'PIIPPAOKER(SN:CPP3511)/4.01'OALI
10._32017
1.620
1.62 ID)
Mmr'al:laon.9
9,1120.0
4,285.9
)262
PATCH
2.72' PIIP(SN. CPP35108) 25.5'$ ACE PPIPEB
1&122017
1625
LATCH SEAL ASSEMBLY (SN: CPA05066 I OAL
= 30.86' )
LOCATOR: 14DRz
9,650.0
4,294.8
T1.8]
PATCH
2]2- PUP PACKER I SN:CPP35131 1162FIDl
10112201)
1.625
SEAusaY. ITCI
OAL4.1V)
-R
PBS. 140.5
14,1800
5760.6
5368
PACKER
CATCHERON LINER TOP PACKER W11.781
10_0201)
PACKER: lel..
NIPPLE(OAL=5.3)2')
14.307.0 j
5,0382
.62 51
Whipstock
92&2017
1000
NIPPLE; 1a lsza
Perforations & Slots
snot
cena
(RKa
Topp)
BM Me)
_KSI
zone
pre
.hoW1MKB)
M
Tyra
comPACKER,
1,11800
q3114
6348.0
5.8516
5,860.5
Cd, 2A-22
&1)2001
4.0
APERF
25' HSD Ahernaing
BHPJ, 180 deg phase,3]6-0
5,862.2
5,889.8 Ay2A-22
&1211995
4.0
IPERF
SWS ClTType BHUP;
1
1 W deg ph, oriented 90
CCW I/highside
OARSHOT;14, Se
Stimulations 8 Treahnents
EEALASsv', u.Z35e
PmpwmGe:ianN Ob PmpwmmFormallon fib) Date
PACKER: I4,IlS7
12/92002
Mandrel Inserts
St
xlPrte u.zlzo
au
per
S T.PHIKI
TaplNd)Viva
(XKB)
Make
ModelOD
9n)
8ery
latah Pod6®
Typ Typ B.)
lfteen
(are
Run Dah
Com
1 3,341.5
2,503.2
CAMCO
KBMG
1
GASLIFT
GLV BK 0.188
1,313.0
1&16201)
WIEG114,S11
2 ),553.9
37075
CAMCO
KBMG
1
GAS LIFT
OV BK 0.188
O.o
1&19201)
3 1017574
4,606.1
CAMCO
KBMG
1
GAS LIFT
DMY BK 0000
0.0
10282014
EXTE
MERE14=@14,3G
NDE
Wlyatck,14.2he G
D
FRAC, 4.Kdre
I
4 12,955.0
52518
CAMCO
76MG
1
GAS LIFT
OMY BK -5 0.000
00
91302014
Fee
ALlalemq tltat6t 761904
5 1401 9
66990
CAMCO
K8MG
1
GAS LIFT
pMY BK 0.000
00
10/162017
_ERF: t a, a a 1.D14,340-
Notes: General & Safety
IPERF. 146R0,14per 0
End DeepAnnotation
NOTE WO 9/292014
PHopocrrox:3e.alpez0
A
fVVl
A.,15,018,117.09157
111�
1 KUP PROD
COncic4 il�ips Well Attrib.
Neska Inn. we l.re APVOWI Fkx
2A-22AL1
2hZNll, llreaa+r+oaa'.5I- 1201 1ZW016 I 6/11,1995 �
—. lasiMM By ne 0
Mnohtion OepM iI1NB) Entl Oab An.easo
--
------
Rev Rn: Site Troch jennaX i 11 1IZ201J
aslnp Strings
Came Oescnglan 00(n1 m(q rop inxe) sq OegnlRKal set OePr01TV0i_. wuLen p... 4ratla Top rxroee
AL Lateral 2318 1992 14,181.8 1],619.0 4.60 L-80 STL
Stimulations & Treatments
ft
Pr000eq oee.anetl nnl PIOPPeq In Formation X01 oere
12/912002
CONDUCTOR: 410-131.0
NIPPLE. v`$.9
M.MW; asaysi E
SVRFACE', M.Bi.BID.O-�
1
l
ag.:I...a
PATCR 8.8M.0
PPTCn: EW.O
PATCH', 8..0
PATCH,9A140
PATCH:6ueo
PATCn; 9,..0
PPTCn'.9.SO.0
Masi 1OR74—
Ma dni izrb3.0
Memlex 14.017P
LOCATOR: 18,0732
SE4N88Y;140712
PER', 14.0795
M ER: 14,10.8
xIPPM H,1R9
PACnER: 141 41.0
WEREHOT: 14, MA
HEAL P88Y:
i:..
PACKER: I4.7
NIPPLE; 18,0730
WLEG: 1.28[.]
APERF: 14, 861431]0
WHissai 14.307.0
P(tOG1CT1ox: M 3-14,78] 0
FRAC: 14]9.4
I
ii
ii
AL mu.l:la mlarslRo� 1
uperations Summary (with Timelog uepths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Time
End Time
Our (hr)
Phase
Op Coca
Activity Code
Time P -T-%
Opemtlon
Stan Depth
(flK8)
End Depth (fIKB)
9/23/2017
9/24/2017
8.00
MIRU
MOVE
MOB
P
Trucks to move rig on location -PJSM
0.0
0.0
16:00
00:00
with Peak. Broke drive shaft yoke
pulling sub off well @ 18:30.
Replacement on location @ 20:30. Off
3M with both modules @ 21:30
enroute to 2A
9/24/2017
9/24/2017
3.50
MIRU
MOVE
MOB
P
Continue travels to 2A
0.0
0.0
00:00
03:30
9/24/2017
9/24/2017
1.70
MIRU
MOVE
MOB
P
Arrive on 2A pad, de -jeep modules.
0.0
0.0
03:30
05:12
Prep cellar with herculite and plywood
9/24/2017
9/24/2017
1.00
MIRU
MOVE
MOB
P
Go to spot sub. Pad soft where gravel
0.0
0.0
05:12
06:12
added to level up. Became stuck. Sow
breaks radiator hose. 1 cup spill to
pad. Call for Mats - plywood to spot.
Wait on Peak mechanic
9/24/2017
9/24/2017
3.30
MIRU
MOVE
MOB
P
Leave 2A with one Sow to get shop
0.0
0.0
06:12
09:30
and halfway house. Sow on 3M drive
line repaired. Setting mats for spotting
rig. Leave 3M with shop and halfway
house. At CPF 3 trailer hauling shop
looses wheel bearing. Peak mechanic
to CPF3 to repair trailer. More mats on
2A. Lay out
9/24/2017
9/24/2017
1.50
MIRU
MOVE
MOB
P
Leave CPF 3 with halfway house to
0.0
0.0
09:30
11:00
2A. Arrive on 2A @10:30. Swap out
sow on sub
9/24/2017
9/24/2017
2.00
MIRU
MOVE
MOB
P
Mats all positioned. Spot sub on well
0.0
0.0
11:00
13:00
22
9/24/2017
9/24/2017
2.00
MIRU
MOVE
MOB
P
Back up pits and spot more mats.
0.0
0.0
13:00
15:00
Spot in Pits
9/24/2017
9/24/2017
2.50
MIRU
MOVE
RURD
P
Start working rig up checklist, RIU
0.0
0.0
15:00
17:30
PUTZ, lower stairs
9/24/2017
9/24/2017
4.50
MIRU
WH- DB -OP
NUND
P
Change out stack, grease tree, NU
0.0
0.0
17:30
22:00
BOPE
Rig accept: 22:00 hrs
9/24/2017
9/25/2017
2.00
MIRU
WHDBOP
ROPE
P
Fluid pack, begin BOPE test at 22:15
0.0
0.0
22:00
00:00 1
hrs
9/25/2017
9/25/2017
5.00
MIRU
WHDBOP
BOPE
P
Continue BOPE test. ROPE test
0.0
0.0
00:00
05:00
completed at 5:00 hrs
9/25/2017
9/25/2017
2.10
MIRU
WHDBOP
PRTS
P
PT PDL's & TT line - test gas alarms
0.0
0.0
05:00
07:06
9/25/2017
9/2512017
1.40
PROD1
RPEQPT
PULD
P
PJSM, M/U BHA #1 to mill cement
0.0
68.5
07:06
08:30
pilot hole, Check pack offs, Install
checks in UQC, Make up to coil and
surface test
9/25/2017
9/25/2017
2.80
PROD1
RPEQPT
TRIP
P7-
RIH, Surface test agitator @ 700' -
68.5
14,130.0
08:30
11:18
good
9/25/2017
9/25/2017
0.30
PROD1
RPEQPT
DLOG
P
Log KI for +7 foot correction,
14,130.0
14,155.0
11:18
11:36
PUW=39K
9/25/2017
9/25/2017
0.30
PROD1
RPEQPT
TRIP
P
Continue in well, Encountered cement
14,155.0
14,217.0
11:36
11:54
stringer @ 14205. Set down, PUH
kicked on pump didn't see anything.
Continue in to dry tag TOC @ 14217
Page 1121 Report Printed: 10H712017
. Uperations Summary (with Timelog wepths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
SI81l Tif110
EMTime
Dur (hr)
Phase
Op Code
Activity Code
Time P4T X
Operabon
Start Depth
(ftKB)
End Depth (RKB)
9/25/2017
9/25/2017
4.30
PROD1
RPEQPT
MILL
P
14217 Tag cement, PUH Pumps on @
14,217.0
14,340.0
11:54
16:12
1.79 BPM @ 3515 PSI FS,
BHP=3335, RI W=8.6K @ 1.1 K
DHWOB. Cement ROP down to 25-30
ROP @ 14225 and down to TD
9/25/2017
9/25/2017
0.70
PROD1
RPEQPT
WPRT
P
Wiper up hole, PUW=40K, Back ream
14,340.0
14,260.0
16:12
16:54
14285 to 14260
9/25/2017
9/25/2017
2.00
PRODt
RPEQPT
REAM
P
Make reaming passes per procedure
14,260.0
14,290.0
16:54
18:54
160L, LS, 20R, LS. Dry drift transition
area good
9/25/2017
9/25/2017
0.20
PROW
RPEQPT
OWFF
P
Shut down and monitor well for
14,229.0
14,229.0
18:54
19:06
pressure build up - No flow
9/25/2017
9/25/2017
2.30
PROD1
RPEQPT
TRIP
P
Trip out, EDC open
14,229.0
80.0
19:06
21:24
9/25/2017
9/25/2017
0.60
PROD1
RPEQPT
PULD
P
At surface, Flow check well, PJSM,
80.0
0.0
21:24
22:00
Lay down BHA #1 on dead well, Mill
out @ 2.80 NoGo
9/25/2017
9/25/2017
0.70
PROD1
RPEQPT
CTOP
P
Stab on well with nozzle. Jet stack to
0.0
0.0
22:00
22:42
remove cement debrie. Unstab inject
and rack back
9/25/2017
9/25/2017
0.60
PROD1
RPEQPT
PULD
P
PJSM, WU BHA #2 HES caliper,
0.0
23.1
22:42
23:18
Surface test, cycle fingers. Tag up and
set counters
9/25/2017
9/26/2017
0.70
PROD1
RPEQPT
TRIP
P
Trip in with caliper
23.1
3,000.0
23:18
00:00
9/26/2017
9/26/2017
1.80
PROD1
RPEQPT
TRIP
P
Continue RIW with BHA#2 (caliper),
3,000.0
14,050.0
00:00
01:48
9/26/2017
9/26/2017
0.20
PROD1
RPEQPT
DLOG
P
tie in for+4.1' correction
14,050.0
14,231.8
01:48
02:00
9/26/2017
9/26/2017
0.10
PROD1
RPEQPT
TRIP
P
Continue RIH
14,231.8
14,330.0
02:00
02:06
9/26/2017
9/26/2017
0.20
PROD1
RPEQPT
DLOG
P
Caliper log run #1, PUW = 42K, 50
14,330.0
14,000.0
02:06
02:18
fpm
9/26/2017
9126/2017
0.20
PROD1
RPEQPT
TRIP
P
Close caliper arms, RBIH
14,000.0
14,330.0
02:18
02:30
9/26/2017
9/26/2017
0.20
PROD1
RPEQPT -
DLOG
P
Open caliper arms, caliper log run #2,
14,330.0
14,000.0
02:30
D2:42
50 fpm
9/26/2017
9/26/2017
2.20
PRODt
RPEQPT
TRIP
P
POOH, tag up, flow check well
14,000.0
20.0
02:42
04:54
9/26/2017
9126/2017
0.50
PROD1
RPEQPT
PULD
P
PJSM, LD BHA#2
20.0
0.0
04:54
05:24
9/26/2017
9/26/2017
0.70
PROD1
RPEQPT
PULD
P
PJSM, PU BHA #3 WS Selling
0.0
73.0
05:24
06:06
Assembly, tag up, open EDC
9/26/2017
9/26/2017
2.80
PROD1
RPEQPT
TRIP
P
RIH with BHA#3
73.0
14,136.0
06:06
08:54
9/26/2017
9126/2017
0.20
PROD1
RPEQPT
DLOG
P
Log K1 for+3' correction
14,136.0
14,162.0
08:54
09:06
9/26/2017
9/26/2017
0.20
PROD1
RPEQPT
TRIP
P
Continue RIH, weight check =43K,
14,162.0
14,317.8
09:06
09:18
arrive at setting depth, close EDC,
bring up pumps, release off WS, set
down 4.3K WOB, leaving TOWS =
14,307', oriented 10° ROHS
9/26/2017
9/26/2017
2.50
PROD?
RPEQPT
TRIP --15-
POOH, PUW = 44K, check well for
14,317.8
73.0
09:18
11:48
flow, PJSM for LD & PU, tag up
9/26/2017
9/26/2017
0.50
PRODt
RPEQPT
PULD
P
LD BHA #3 over a dead well
73.0
0.0
11:48
12:18
Page 2121 ReportPrinted: 10/17/2017
Uperations Summary (with Timeiog uepths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Time
End Time
Our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
Stan Oepm
(fIKB)
End Oep(h(flKB)
9/26/2017
9/26/2017
0.60
PROD1
WHPST
PULD
P
Reconfigure & PU BHA #4, Window
O.0
74.0
12:18
12:54
Milling Assembly (10' pup, 0.6° AKO
motor, string reamer, window mill),
slide in cart, MU to coil
9/26/2017
9/26/2017
2.50
PROD1
WHPST
TRIP
P
RIH with BHA #4, begin swapping to
74.0
14,135.0
12:54
15:24
used Power Pro
9/26/2017
9/262017
0.20
PROD1
WHPST
DLOG
P
Tie into Kl for a+4' correction
14,135.0
14,170.0
15:24
15:36
9/262017
926/2017
0.40
PROD1
WHPST
TRIP
P
Continue RIH, weight check =44K,
14,170.0
14,307.0
15:36
16:00
dry tag TOWS right on depth at
14,307', PUW = 44K, bring up pump,
RBIH
9/26/2017
9/26/2017
2.00
PRODt
WHPST
WPST
P
Begin milling wiindow in 7" casing as
14,307.0
14,308.8 .
16:00
18:00
per procedure (tagged TOWS at
14,306.08' pumping 1.8 bpm), FS =
431 psi, CWT =6.6K,
9/26/2017
9/26/2017
4.00
PROD1
WHPST
WPST
P
1.77 bpm, CT 4196 psi, CT Wt 3.66 k
14,308.8
14,327.0
18:00
22:00
lbs, WOB 1.33 k lbs. Saw mill off @
14,311.6' - BOW. Bottoms up sample
from 14,325' formation sand +
glauconite per Geo. CT 3.9 k lbs,
WOB 2.7 k lbs, ROP 10 ft/hr
9/26/2017
9/262017
1.00
PROD1
WHPST
REAM
P
Perform back reamin/dressing passes,
14,308.8
14,327.0
22:00
23:00
14300 -14,315', as drilled, 10 *ROHS,
40 ` ROHS, & 340 *ROHS. Little
motor work -15-20 psi over free spin.
Send 5x5 sweeps. Dry drift clean, PU
30k lbs
9/26/2017
9/262017
0.50
PROD1
WHPST
OWFF
P
SBHP / flow check, park @ 14191' -
14,327.0
14,191.0
23:00
23:30
5741' TVD. IA pressured up from
tubing hole at 9426'. Bleed IA to 143
psi observe it slowly build to 173 psi
while monitoring. Baker Coil track
BHP stabilized at 2506 psi for 8.39
ppg EMW. Flow check at stack -
Good. Mud weight in and out tested w
pressurized mud balance 8.8 heavy
PPg-
9/26/2017
9/26/2017
0.30
PROD1
WHPST
CIRC
P
Establish circulation rate of 1.80 bpm
14,191.0
14,175.0
23:30
23:48
while slowly PUH. CT 4192 psi,
Annular 3778 psi, Bore 4198 psi,
Expro WH 140, (upstream of micro
motion), CTES transducer #6, 17 psi,
(downstream of the micro motion).
Note, micro motion making more noise
than usual and we suspect has
impeded flow from some sort of
blockage.
9/26/2017
9/27/2017
0.20
PROD1
WHPST
TRIP
P
Park, Open EDC, rate to 2.0 bpm,
14,175.0
13,260.0
23:48
00:00
POOH chasing sweep to surface.
9/27/2017
9272017
2.10
PROD1
WHPST
TRIP
P
Continue to POOH, @ -700' out MM
13,260.0
100.0
00:00
02:06
rate and density reading became
erattic. Monitored returns, rale and
density at the shaker, 8.8 ppg heavy,
all looks goad. Contiune out of hole.
9/27/2017
9/27/2017
1.00
PRODi
WHPST
PULD
P
PJSM, Bleed IA from 589 psi to 209
100.0
0.0
02:06
03:06
psi in 3 min, built back to 390 once S/I.
Flow Check - Good, LO BHA #4, Bit
2.79 no go, Mill 2.78 no go, decent
whorl pattern in center of window mill.
Page 3121 - Report Printed: 10/17/2017
(
. operations Summary (with Timelog Uepths)
2A-22
•
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stmt Time
End Tim
Our(hr)
Phase
Op Code
AciNiry Cotle
Time P -T-%
Operation
shad Mph
RKB)
End Depth (RKS)
9/27/2017
9/27/2017
1.20
PROD1
DRILL
CIRC
P
Jet Stack, snake and flush out MM,
0.0
0.0
03:06
04:18
retrieved 3 quarter sized pieces of
flattened aluminum (billet) from the
MM. Blew down choke. Changed out
upper Quick connect
9/27/2017
9/27/2017
0.90
PROD1
DRILL
PULD
P
PU BHA#5 (agitator, 2.3°+AKO
0.0
78.0
04:18
05:12
motor, & RR Hughes bit)
9/27/2017
9/27/2017
2.80
PROD1
DRILL
TRIP
P
RIH, surface test agitator, good
78.0
14,135.0
05:12
08:90
9/27/2017
9/27/2017
0.20
PROD1
DRILL
OLOG
P
Tie into K1 for+3' correction, close
14,135.0
14,163.0
08:00
08:12
EDC, weight check = 38K
9/27/2017
9/27/2017
0.30
PROD1
DRILL
TRIP
P
Continue RIH, pumps off- clean
14,163.0
14,327.0
08:12
08:30
through window, RIW = 9.2K off
bottom, PUH to adjust TF per DD,
RBIH
9/27/2017
9/27/2017
0.30
PROD1
DRILL
DRLG
P
OBD, pumping 1.8 bpm, FS = 850 psi,
14,327.0
14,351.0
08:30
08:48
CWT = 7K, WOB = 1.6K, circ pressure
= 4753 psi, annular = 3754 psi, WHP
= 0 psi, dp = 1151 psi.
WOB up to -4.5 K, PU at 14,345',
PUW = 38K, RBIH & continue drilling,
again at 14,352, rete out dropped to 1
bpm
9/27/2017
9/27/2017
0.50
PROD1
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, rate out
14,351.0
14,367.0
08:48
09:18
1.09 bpm, FS = 762 psi, PU at
14,355', PUW = 40K, pulling negative
WOB up to -4K (possibly hanging up
in window), PU at 14,362', PUW = 38
K,
9/27/2017
9/27/2017
0.70
PROM
DRILL
DRLG
P
Go to near total losses at 14,357' (.25
14,367.0
14,390.0
09:18
10:00
bpm returns), returns begin to heal
with drilling, improving to .98 bpm
returns by 14,387', pump 5 %5 sweeps
at 14,387', continue to pull heavy on
.
PU's (negative WOB up to -6K), call
EOB at 14,390', returns at -59%
9/27/2017
9/27/2017
0.20
PROM
DRILL
TRIP
P
Begin POOH, PUW = 42K
14,390.0
14,135.0
10:00
10:12
9/27/2017
9/2712017
0.50
PROM
DRILL
DLOG
P
RIH to tie into K1 for +0.5' correction,
14,135.0
14,135.0
10:12
10:42
log RA at 14,315', (putting TOW at
14,308'& BOW at 14,314), continue
POOH, close EDC above TOC.
9/27/2017
9/2712017
2.40
PROD1
DRILL
TRIP
P
Continue POOH, holding 11.4 ppg
14,135.0
78.0
10:42
13:06
schedule, tagged up, space out, WHP
at 790 psi
9/27/2017
9/27/2017
1.40
PROD1
DRILL
PULD
P
PJSM for PD & PUD, PUD BHA #5, bit
78.0
0.0
13:06
14:30
came out a 1-1, pumping manage
pressure losing -12 bph, observe
marks on motor, possibly from window
9/2712017
9/27/2017
1.10
PROD1
DRILL
PULD
P
Reconfigure & PD BHA #6 Lateral
0.0
78.0
14:30
15:36
Drilling Assembly (agitator, 0.5° AKO
motor, RR 0-0 HYC B8 Edge), slide in
coil, MU to coil
9/27/2017
9/27/2017
2.50
PROD1
DRILL
TRIP
P
RIH with BHA #6, close EDC, surface
78.0
14,T4-1.0-
15:36
18:06 1
1
1
1
test agitator, good
9/27/2017
9/2712017
0.20
PROD1
DRILL
DLOG
P
Tie into the Kl marker for a+2.5'
14,141.0
14,169.0
18:06
18:18
correction
Page 4121 Report Printed: 10/17/2017
operations Summary (with Timeiog uepths)
2A-22
•
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur(hr)
Phase
Op Code
ActiM Code
tr
Time P -T-%
0 mtbn
pa
Stan Dep1h
(Po(B)
End Dept (fiKB)
9/27/2017
9/27/2017
0.30
PRODt
DRILL
TRIP
P
Wt check, 33k lbs, continue to RIH
14,169.0
14,390.0
18:18
18:36
9/27/2017
9/27/2017
1.10
PROD1
DRILL
DRLG
P
Rate 1.80 in, 1.10 out, CT 4600 psi,
14,390.0
14,534.0
18:36
19:42
free spin diff 1040 psi, Annular 3622
psi w choke wide open. CT RIH Wt
8.7 k lbs.
OBD, CT wt, 6 k lbs, WOB 2.5 k lbs,
ROP 160 fl/hr- 0.63 bpm losses - 38
bbl/hr
Losses quickly healed in 15 min of
drilling from 40% stabilizing @ 27% -
30 bbl/hr
Average ROP over interval drilled -
131 fl/hr average
9/27/2017
9/27/2017
1.80
PROD1
DRILL
DRLG
P
PU @ 14,534' for missed survey, 33k
14,534.0
14,777.0
19:42
21:30
lbs, zero WOB, RBIH, BOBO
stall @ 14553, PU Wt 37k, returns fell
from 1.3 to .7 bpm,
second stall 14,556, PU 38 k lbs
1.77 in 1.12 out, CT Wt 3.66 k lbs,
WOB 2.7 k Ibs, ROP 160 fUhr
IA 1016, OA 280 psi.
Mud weight out started falling off@ —
14,613'- 20:27 - not cleaning the
hole...
14,731', stacked weigh, ROP dropped,
losses increased to - 1 bpm,
Average ROP over interval drilled -
135 ft/hr average
9/27/2017
9/27/2017
0.90
PROD1
DRILL
DRLG
P
PU to rotate HOT, BHA wiper 100', PU
14,777.0
14,855.0
21:30
22:24
Wt 38 k. RBIH
1.80 bpm in, 0.78 k bpm out, CT 4600
psi, RIH Wt 6 k lbs, free spin 1140 psi
OBD, CT Wt 4 it. WOB 2.5 k lbs, ROP
60-160 ft/hr
14,811', 1.80 bpmin , 0.48 bpm out
Average ROP over interval drilled - 87
Nhr average
9/27/2017
9/27/2017
0.20
PROD1
DRILL
WPRT
P
Wiper to window - 500', PU 40 k lbs
14,855.0
14,365.0
22:24
22:36
send 25 bbl ultra hi vis pill— 150k
LSRV
Losses healed slightly, then dropped
again as we drug past 14,457'
9/27/2017
9/27/2017
0.20
PROD1
DRILL
WPRT
P
RBIH RIH Wt 7 k lbs
14,365.0
14,855.0
22:36
22:48
1
I
Page 5121 ReportPrinted: 10/17/2017
' operations Summary (with Timelog Depths)
2A-22
•
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Scarf Time
End Time
Our (hr)
Phase
Op Code
Activity Code
Time P -T-%
Opennion
start DePfh
(xKB)
EM Depih(fiKa)
9/27/2017
9/27/2017
1.00
PROD1
DRILL
DRLG
P
1.78 bpm in, 0.66 bpm out, CT 4967
14,855.0
15,014.0
22:48
23:48
psi, free spin 1033 psi, 6 k lbs RIH Wt
OBD, CT wt 4k lbs, WOB 2 k lbs, ROP
150 f thr
Stall @ 14,890 +1- 6 bbis high vis out
the bit, PU Wt 40 k
Rate out dropped from 0.7 bpm to
0.40 bpm as Hi vis was on the back
side.
Drilling break, up to 380 tt/hr, PU to
roll hot, PU W141 k, RBIH
RIHWt 5 k lbs, 1.8 in 0.40 out, diff
1164 psi
OBD, — 380 ft/hr, friction pressure
from high vis pill on back side
exacerbating losses.
Pill moving @ 60 ft/min with current
returns
Average ROP over interval drilled -
160 tt/hr average
9/27/2017
9/28/2017
0.20
PROD1
DRILL
WPRT
P
PU Wt 38 k lbs
15,014.0
14,462.0
23:48
00:00
CT weight slowly increased from —36 k
to 39 k near the bottom of the window
RBIH to jog solids
9/28/2017
9/28/2017
1.20
PROM
DRILL
WPRT
P
Continue to PUH, order power pro
14,462.0
9,979.0
00:00
01:12
light system(s) in preparation for
closed choke drilling.
9/28/2017
9/28/2017
1.10
PROD1
DRILL
DISP
P
Park, down on the pumps, finish
9,979.0
8,179.0
01:12
02:18
preying high vis pill, line up down the
back side with power pro, establishing
injection, 1 bpm @ 1400 psi WH.
Pump 10 x 10 low/hi vis pill down the
back side.
9/28/2017
9/28/2017
1.00
PROM
DRILL
TRIP
P
RBIH, 100 it/min, lined up down the
8,179.0
14,140.0
02:18
03:18
coil @ 0.6 bpm, pushing sweeps in
front, pipe displacement .5 bpm.
CT 2198 psi, WH 221 psi
9/28/2017
9/28/2017
0.20
PROW
DRILL
TRIP
P
Tie into Kl for + 6' correction
14,140.0
14,156.0
03:18
03:30
9/28/2017
9/2812017
0.30
PROD1
DRILL
TRIP
P
Continue to RIH, window clean, WOB
14,156.0
15,014.0
03:30
03:48
spike as well as Ct weigh stack out in
the build @ 14,386'.
9/28/2017
9/28/2017
1.10
PROD1
DRILL
DRLG
P
1.65 bpm, CT 4347 psi, WH 473 psi,
15,014.0
15,185.0
03:48
04:54
annular 3714 psi. off bottom diff 1124
psi
CT Wt 4.2 k lbs, WOB 2.1 k lbs, ROP
200 ft/hr
PU, 35 k lbs, increase rate to 1.80
bpm, Ct 4800 psi, diff 1150 psi,
annular 3799 psi.
BOBD CT Wt 5 k lbs, WOB 1.08 k lbs,
ROP 160 R/hr
Stall 15,093', PU 39 k lbs, spuded and
restarted, new diff 1,337 psi, plugged
nozzle?
Average ROP over interval drilled -
137 fithraverage
9/28/2017
9/28/2017
0.10
PROD1
DRILL
WPRT
P
PU 38klbs-DD wiper -30'
15,165.0
15,165.0
04:54
05:00
Page 6121 ReportPrinted: 10117/2017
Uperations Summary (with Timelog Uepths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our h
( r)
Phase
Op Code
Activity Code
Time P -T -X
Operation
Start DepN
(n De
End nepih (flKB)
9/28/2017
9/28/2017
1.80
PROD1
DRILL
DRLG
P
1.83 bpm, CT 5007 psi, 1,380 psi diff
15,165.0
15,310.0
05:00
06:48
RIH Wt 61k lbs, WH 836 psi, annular
3775 psi
OBD, CT Wt Ok lbs, WOB 2.5 k lbs,
ROP 180 ft/hr
stall @ 15,195', annular fell off from
3,850 to 3,350 psi at -15,185'
9/28/2017
9/28/2017
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW = 40K
15,310.0
14,333.0
06:48
07:12
9/28/2017
9128/2017
1.30
PROD1
DRILL
WPRT
P
Wiper in-hole, tied in for a+3'
14,333.0
15,310.0
07:12
08:30
correction, difficulty RIH past 14,375' -
14,380' in the build, PU & attempt
various TF's, get by stacking —8K
WOB, back ream up through trouble
area up to 14,350', RBIH and slide
right by 14,375'
Stack weight at 14,409', PUW = 38K,
attempt multiple TF's, no success,
attempt with pumps off, no success,
creep in with pumps at 1.4 bpm and
get by (likely fill)
Stack weight at 15,125', PUW = 42K,
vary TF, no success, creep in at 10
fpm & get by, back -ream up to 15,116'
through trouble spot
9/28/2017
9/28/2017
3.60
PROD1
DRILL
DRLG
P
BOBD, FS = 1230 psi at 1.8 bpm,
15,310.0
15,610.0
08:30
12:06
CWT = 8K, WOB = 1.7K, annular=
3440 psi, WHIP = 346 psi, circ
pressure = 4793 psi, began pumping
PowerPro lite at 15,385', ROP over
interval = —83 fph
9/28/2017
9/28/2017
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW =41K
15,610.0
14,609.0
12:06
12:30
9/28/2017
9/28/2017
0.40
PROD1
DRILL
WPRT
P
Wiper in-hole, RIW=6.5K
14,609.0
15,610.0
12:30
12:54
9/28/2017
9/28/2017
3.20
PROD1
DRILL
DRLG
P
BOBD, FS = 1250 psi pumping 1.8
15,610.0
15,910.0
12:54
16:06
On CWT = 5K, WOB = 2K, annular
= 3692 psi, circ pressure = 5245 psi,
average ROP over interval = 94 fph
Note: CWT, among other values, was
not receiving data in WellLiink from
13:00 hrs - 13:53 hrs ( MWD resolved
issue)
9/28/2017
9/28/2017
0.40
PROD1
DRILL
WPRT
P
Wiper up -hole, PUW =41K
15,910.0
14,895.0
16:06
16:30
9/28/2017
9128/2017
0.50
PROD1
DRILL
WPRT
wiper in-hole, send 5x5, stack weight
14,895.0
15,910.0
16:30
17:00
IP
at 15,816', bring up rate, RBIH &
creep through, RIW = 5.2K
Page 7121 ReportPrinted: 10/17/2017
Uperations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our (hQ
Phase
Op Code
Acumty Code
Time P4 -A
OpemUon
Stan Depm
(fU(a)
End Depth (MB)
9128/2017
9/28/2017
4.80
PROD1
DRILL
DRLG
P
BOBD, FS = 1194 psi pumping 1.77
15,910.0
16,087.0
17:00
21:48
bpm, CWT =2K, WOB =2.2 klbs
Pumped 10x10 sweep, exited @
16,038 bit depth, snub limit set to -3 k
CT wt, WOB in creased from 1 k to
2.8k plus, lubes /solids movement is
helping weight transfer.
Top off pill 1 with new mud 1 % lubes
to be used for sweeps.
PU Wt 41 k lbs BHA wiper
struggle to get restarted 4 times.
Average ROP over interval drilled - 37
ft/hr average
9/28/2017
9/28/2017
0.60
PROD1
DRILL
WPRT
P
PU W141 k lbs, pull 3rd long wiper to
16,087.0
14,145.0
21:48
22:24
window for tie in. -1,757' drug low
side on the way out.
9/28/2017
9/28/2017
0.20
PROD1
DRILL
DLOG
P
Tie into K1 tag for+ 9' correction,
14,145.0
14,206.0
22:24
22:36
bypass high pressure screens
9128/2017
9/28/2017
0.80
PRODt
DRILL
DISP
P
Line up down the back side, bullhead
14,206.0
14,198.0
22:36
23:24
45 bbis new mud W 2 ppb Alpine drill
beads down the backside @ 1.6 bpm
bpm, WH 758 psi initial, WH 1940 psi
final
Pre IA 1333 psi, OA 305 psi, Post la
1706 psi, OA 305 psi
PU Wt 39 k lbs
9128/2017
9/29/2017
0.60
PRODt
DRILL
TRIP
P
RIH, Window clean, small WOB spike
14,198.0
15,625.0
23:24
00:00
at 14,386' near the end of the build, no
CT Wt change. small WOB spike
14,915
9129/2017
9/29/2017
0.20
PROD1
DRILL
TRIP
P
Continue to RIH
15,625.0
16,087.0
00:00
00:12
9/29/2017
9/29/2017
3.70
PROD1
DRILL
DRLG
P
RIHWt 6.8 k lbs, 1.80 bpm, CT 5171
16,087.0
16,332.0
00:12
03:54
psi, Wh 464 psi, annular 3732 psi, diff
1143 psi
OBD, WOB 2.5 k lbs, CT Wt - 3 k lbs,
ROP 54 f 1hr
16,178' PU Wt 38 k lbs, Pumping 10
bbls sweeps of new mud.
Struggling to get restarted
Average ROP over interval drilled -66
ff/hr average
9/29/2017
9/29/2017
0.60
PROD?
DRILL
WPRT
P
Wiper trip #1 - PU Wt 38 k lbs - 1812'
16,332.0
14,520.0
03:54
04:30
9/29/2017
9/29/2017
1.40
PROM
DRILL
WPRT
P
RBIH, spudded in @ 15,144', TF
14,520.0
16,332.0
04:30
05:54
orientation issue, continue in hole.
Started stacking out CWT at
16,088' (though not showing in WOB).
difficulty working to bottom attempting
various pump rates, tagged bottom —9'
higher than expected, plan to inspect
injector counter
Page 8121 ReportPrinted: 10/17/2017
1 Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
SWtl Time
EM Time
Dw(m)Phase
Op Code
Activity Code
Time P -T -X
Opemlbn
Start Depth
(fes)
End Depth(ftKB)
9129/2017
9129/2017
3.20
PROD1
DRILL
DRLG
P
BOBD, FS = 1,250 psi pumping 1.7
16,332.0
16,419.0
05:54
09:06
bpm, CWT= -6K, WOB =1.8K,
annular= 3834 psi, circ pressure
5,065 psi, WHP = 778 psi
PU from 16,360', difficulty RBIH past
16,344', stacking CWT to -8K on
multiple attempts, no WOB indication,
PUH slow waiting for beaded pill to
exit bit, slide right by with beads
Stall at 16,419, stack 8K WOB,PUW =
46K
9129/2017
9/29/2017
3.90
PROD1
DRILL
DRLG
P
Stall a second time attempting to get
16,419.0
16,580.0
09:06
13:00
started 16,419', PUW = 42K, annular
dropped by -500 psi & CWT
increased from -5K to +10K after
stalls at 16,419'
Drilling ahead pumping 1.8 bpm, CWT
= 8K, WOB = 2K, annular= 3,432 psi,
circ pressure = 4,796psi
9/29/2017
9129/2017
1.40
PROD1
DRILL
DRLG
P
Continue drilling ahead at 16,580',
16,580.0
16,631.0
13:00
14:24
CWT = 4K, WOB = 2.6K, annular =
3511 psi, circ pressure = 4966 psi,
WHP = 539 psi
9/2912017
9/29/2017
1.00
PROM
DRILL
WPRT
P
Wiper up -hole, PUW = 38K
16,631.0
14,314.0
14:24
15:24
1
9/29/2017
9/29/2017
1.10
PROD1
DRILL
WPRT
P
Wiper in-hole, clean off injector
14,314.0
16,646.0
15:24
16:30
counter, tie into RA tag for+15.5'
correction, RIW diminished beginning
at 16,545'
9/29/2017
9/29/2017
2.00
PROM
DRILL
DRLG
P
BOBD, FS = 1284 psi pumping 1.8
16,646.0
16,722.0
16:30
18:30
bpm, CWT = -5K, WOB = 2.5K,
annular = 3543 psi, circ pressure =
5118 psi, WHP = 361 psi, lost -10
CWT from immediately before WT.
Immediately send 5x5 sweeps (5bbl
DuoVis w/ 1% 776, 5 bbl Duo Vis
w/beads)
Drilled w neutral to slightly neg surface
weight w/ -2.4 k lbs WOB. CT wt
slowly climbed to -5-7k lbs as the
effects of the pill wore off. Proactively
pumped another 5x5 with @ 200 bbls
out the bit from the first pill
Average ROP over interval drilled -38
ft/hr average
Page 9/21 ReportPrinted: 1011712017
Uperations Summary (with Timelog bepths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stolt Time
End Time
Dur (hr)
Phase
Op Cotle
Activity Code
Time P -T -X
Operation
Stat Dap(h
(ftKB)
End Depth (10(B)
9/2912017
9/29/2017
3.70
PROD1
DRILL
DRLG
P
CT Wt -4.5 k lbs, WOB 2.0 k lbs,
16,722.0
16,806.0
18:30
22:12
Annular 3571 psi, WH 477 psi, IA
1128, OA 306 psi
PU as sweeps exit the bit, PU Wt 41 k
lbs, steady 37 to 39 k Wt while
moving. WH climbed to 1020 psi,
RBIH 1.80 bpm, RH Wt 5 k lbs, CT
4966 psi, FS 1352 psi,
OBD, CT Wt 2 k Ibs, WOB 2.2 k lbs,
ROP 38 ft/hr
CT Wt fell to -8 k Ibs, WOB falling off
to 1.6 k lbs, little motor work
Send 10x10 sweeps to time our for
wiper
Average ROP over interval drilled -
22.7 IUhr average
929/2017
9/2912017
0.30
PROD1
DRILL
DRLG
P
PU W142 k Ibs, 1000' wiper
16,806.0
15,809.0
22:12
22:30
Motor work at 16,447', 16,234',
16,124', and 16,044'
9/292017
9/29/2017
0.40
PROW
DRILL
DRLG
P
RBIH as sweeps exit the bit
15,809.0
16,806.0
22:30
22:54
9/29/2017
9/3012017
1.10
PROD1
DRILL
DRLG
P
RIH Wt 5.8 k lbs, Annular 3600 psi,
16,806.0
16,834.0
22:54
00:00
WH 400 psi, IA 1066, OA 306 psi
1.5 bpm, CT 4105 psi, FS 912 psi
OBD, CT Wt 2 k Ibs, WOB 2.4 k Ibs,
ROP 35 fUhr
Cl Wt diminished to -4.9 k lbs ,
pumped 5x5 WH to 505 psi
Average ROP over interval drilled -25
fUhr average
9/30/2017
9/30/2017
1.40
PROD1
DRILL
DRLG
P
OBD, CT Wt -4 k Ibs, WOB 2 k lbs,
16,834.0
16,865.0
00:00
01:24
ROP 24 fUhr
Average ROP over interval drilled -22
ft/hr average
9/30/2017
9/30/2017
1.20
PROD1
DRILL
DRLG
P
PU 48 k lbs, started out as a BHA
16,865.0
14,320.0
01:24
02:36
wiper, attempt to tum around 16,669'
failed. Snubbing, PUH at 16,840', PU
46 k Ibs. while 2 ppb bead//%
lube/2%LVT pill is completed. Pull
heavy Ct Wt from 36 k to 46 k lbs
starting at 15,811' POOH for tie in
wiper. lots of motor work started at
15,243' fell off at 14,961'.
9/30/2017
9/30/2017
0.20
PRODt
DRILL
DLOG
P
Tie into RA tag for+11' correction
14,320.0
14,349.0
02:36
02:48
9/30/2017
9/30/2017
1.80
PROD1
DRILL
WPRT
P
RBIH, Stack out coil weight briefly at
14,349.0
16,865.0
02:48
04:36
15,903', more significantly @ 16,460'
atemept to work coil to bottom,
snubbing. Send 5x5 pills, chase to bit
while we slowly PUH, PU Wt 36 k lbs.
9/30/2017
9/30/2017
0.60
PRODI
DRILL
DRLG
P
Three false starts, SID WOB to 2.5 k,
16,865.0
16,865.0
04:36
05:12
@ 16,852, PU 43 k Ibs, again at
16,844', PU 38 k lbs, and again at
16,833 PU 45 k lbs. RIH at min rate
and dial up the pump as we saw
WOB. BOBD, 1.78 bpm, WH 714 psi,
CT Wt -2 k k lbs, WOB 2 k Ibs, ROP
24 fl/hr
Page 10121 Report Printed: 10/1712017
e . operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stars Time
End Tim
our (hr)Phase
Op Code
Activity Code
Tme P-T-X
Operation
Start Depth
(axe)
End Depth(M)
9130/2017
9/30/2017
1.20
PROD1
DRILL
WPRT
P
PU 44k lbs, PUH, annular pressuring
16,865.0
14,175.0
05:12
06:24
up, 13.8 ppg ECD at the window.
Confer with town. Plan forward is to
pull above TOC, open choke & try to
establish returns.
9/30/2017
9/30/2017
1.30
PROD1
DRILL
CIRC
P
PUH slowly from 14,175', open choke,
14,175.0
14,120.0
06:24
07:42
pumping 1.8 bpm, rate out stablized at
1.08 bpm, -60% returns, circulate
bottoms up, annular at 3459 psi, begin
pumping 5x5 sweeps
9130/2017
9/30/2017
0.10
PROD1
DRILL
DLOG
P
Begin RBIH, tie-in for +4'correction
14,120.0
14,163.0
07:42
07:48
9/30/2017
9/30/2017
1.60
PROD1
DRILL
WPRT
P
Continue RIH, attempting to hold
14,163.0
16,885.0
07:48
09:24
between 11.4 ppg - 12.2 ppg, unable
to maintain returns and pressure
schedule, close choke & continue to
RIH
Work to pass 16,792', slack 3.5K
WOB at 16,854', PUW of 59K from
16,823' with -61K WOB
9/30/2017
9/30/2017
1.50
PROD1
DRILL
DRLG
P
OBD, CWT=-7.7K, WOB = 1.9K,
16,885.0
16,919.0
09:24
10:54
annular = 3740 psi, WHP = 717 psi,
circ pressure = 5039 psi
Began sending 5x5 sweep at 16,907',
annular to 3800 psi, ROP avg = 23 fph
9/30/2017
9/30/2017
2.10
PROD1
DRILL
DRLG
P
PU from 16,919', PUW =47K, OBD,
16,919.0
16,980.0
10:54
13:00
FS = 1400 psi pumping 1.8 bpm, CWT
= -61K, WOB = 1.7K, annular = 3790
psi, WHP = 832 psi, ROP avg = 29 fph
9/30/2017
9/30/2017
3.60
PROD1
DRILL
DRLG
P
PU from 16,980', PUW = 48K, FS =
16,980.0
17,053.0
13:00
16:36
900 psi pumping 1.5 bpm, OBD, CWT
= -7.7K, WOB = 1.2K, annular = 3786
psi, WHP = 844 psi, pumping sweeps
as required, bring rate back up to 1.8
bpm
PUW = 46K from 17,022', 10 bbl
beaded pill coming around, drilling at
17,025 with -9.4K CWT, WOB = 1.4K,
PUW= 47K from 17,053', RO avg =
20.3 fph
9/30/2017
9/30/2017
2.80
PROD1
DRILL
DRLG
P
OBD, CWT=-1 OK, WOB =1K,
17,053.0
17,086.0
16:36
19:24
annular= 3861 psi, WHP 899 psi,
pumping pillls as required, gained -5K
CWT with beads coming around.
9/30/2017
9/30/2017
0.30
PROD?
DRILL
WPRT
P
PU Wt 44k Ibs, planned 500' wiper.
17,086.0
16,380.0
1924
19:42
Faiedy dean, one spike to 55k.
Pumped pill timed out for turnaround.
9/30/2017
9/30/2017
3.10
PROD1
DRILL
WPRT
P
RBIH, RIH Wt- 3k lbs, WH 62 psi,
17,086.0
17,090.0
19:42
22:48
Annular 3804 psi
RIH wt fell of to as low as -10 k lbs, as
we ran out of seeep, pump more.
WOB spikes 16,778 and 16,788,
cleaned up around 16,828 and deeper
9/30/2017
10/1/2017
1.20
PROM
DRILL
WPRT
P
OBD, CT Wt -10 to 0, WOB 2 - 3.5 k
17,086.0
17,090.0
22:48
00:00
lbs,
low differential pressure. ROP -5
Page 11121 Report Printed: 10/17/2017
Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Time
End Time
Dur(m)
Phase
Op Code
Activity Code
TMP -T -X
Operation
Start Depth
(WS)
End Depth (MB)
10/1/2017
10/1/2017
0.60
PROM
DRILL
DRLG
P
OBD, CT Wt -10 to 0, WOB 2 - 3.5 k
17,090.0
17,090.0
00:00
00:36
lbs, low differential pressure. ROP -5
Start pumping 90 bbl beaded sweep to
bit.
Paint white TO flag at horses head
10/112017
10/1/2017
1.10
PROM
DRILL
WPRT
P
PU Wt 48 k lbs, Pulled 60 k ( 20 overO
17,090.0
14,140.0
00:36
01:42
@ 16,910 and 16,292' up to -1 k
WOB.
10/1/2017
10/1/2017
0.20
PROD1
DRILL
DLOG
P
Tie into the Kt for+9' correction
14,140.0
14,168.0
01:42
01:54
10/1/2017
10/1/2017
0.90
PRODI
DRILL
CTOP
P
Bleed IA from 1466 psi, to 950 psi,
14,168.0
14,168.0
01:54
02:48
SID pumps, observe pressure while
parked w sensor at 5725' TVD. Coil
track pressure fell from 3496 to 3446
psi in 36 min 11.57 ppg EMW
10/1/2017
10/1/2017
1.50
PROD1
DRILL
CTOP
P
Online w pumps, creep up hole while
14,168.0
13,957.0
02:48
04:18
slowly working choke open. Establish
returns, 1.2 bpm in 0.86 bpm out.
Build weighted liner running pill and
KW while circulating bottoms up in
the cased hole. Load coil with 47 bbl
beaded pill to aid RIH, TO
conformation
10/1/2017
10/1/2017
1.40
PROD1
DRILL
TRIP
P
RIH to confirm TD, enter open hole as
13,957.0
17,092.0
04:18
05:42
pill started exiting the bit, confirm TO
at 17,092'
10/1/2017
10/1/2017
4.20
PROD1
DRILL
DISP
P
POOH laying 11.9 ppg liner running
17,902.0
78.0
05:42
09:54
pill at KWF to surface, painted EDP
flags at 16,038'& 13,178', not getting
KWF out on surface, at 175' form
surface, rate out began to drop at
-4500', well is taking -1.25 bpm in
and 0 bpm out, unable to fill hole
10/1/2017
10/1/2017
2.10
PROD1
DRILL
WAIT
T
Confer with town, well is taking 1.25
78.0
78.0
09:54
12:00
bpm with no 11.9 ppg fluid back to
surface, decision made to bull -head
8.5 ppg DuoVis to window, if well is
dead, carry on, if there is flow at
surface, RBIH and obtain SBHP.
Shut pumps down with 15 bbl bull-
headed (1725' MD, 1679' TVD), choke
closed, hole stablized, confer with
town, decison made to RIH to 2000'
and circulate 11.2 ppg KWF,
displacing 15 bbl of 8.5 ppg DuoVis to
surface.
BHP = 23 psi WHP +.052(8.5 ppg)
(1679') +.052(11.9 ppg)(5838' - 1679)
= 3339 psi, or 11.0 ppg EMW
10/1/2017
10/1/2017
1.70
PROD1
DRILL
DISP
P
RIH, water down KWF, & circulate in
78.0
2,500.0
12:00
13:42
11.2+ KWF from 2500', includes
rolling coil to 11.2 ppg at 1.25 bpm,
MW out climbs
10/112017
10/1/2017
0.80
PROD1
DRILL
DISP
P
Begin POOH pumping 11.2 ppg KWF
2,500.0
78.0
13:42
14:30
to surface, MW out climbs to 11.9 ppg
with bit at 2100', all 8.5 ppg out of the
hole and begining to get some original
KWF out of the hole, IA = 959 psi
Page 12121 ReportPrinted: 10/17/2017
Operations Summary (with Timelog Depths)
(M
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Staff Time
End Time
Dix (hr)
Phase
Op Code
Activity Code
Time PJA
Operation
Start Depth
(fIKB)
End Depth(flKa)
10/1/2017
10/1/2017
1.70
PROM
DRILL
PULD
P
Check well for flow, good (on a vac),
78.0
0.0
14:30
1612
get loss rate, PJSM, LD BHA #6, loss
rate at-14bbi/hr, loss rate dropped to
7.5 bbl/hr, bit came out a 4-2
10/112017
10/1/2017
2.00
COMPZ1
CASING
PUTB
P
PJSM, PU liner (ported bull -nose, 27
0.0
1,125.0
16:12
18:12
jnts slottted, liner top billet), loss rate
at 7.5 bbllhr
10/1/2017
10/1/2017
0.80
COMPZ1
CASING
PULD
P
Pick up BHA, checked pack offs -
0.0
1,075.0
18:12
19:00
good, tagged up set counters,
10/1/2017
10/1/2017
3.20
COMM
CASING
RUNL
P
RIH, Returns fell off. Confirmed coil
11,215.0
14,231.0
19:00
22:12
marks (3 minor indentions, not from
slipped blocks) at 1347' from EOP.
Continue to RIH, 80 f tmin, pumping
0.34 bpm in 0.24 bpm out, loosing --
0.33-0.4 bpm. Lost all returns
8031', partial retuns as coil speed
slowed for GLM @ 10,723', fell off.
10/1/2017
10/1/2017
1.30
COMPZ1
CASING
RUNL
P
stop, PU Wt 33 k lbs, Tie into White
14,213.0
17,062.0
22:12
23:30
window flag in tension for -10.5'
correction.
" Coil track pressure parked, pumps
down, 3136 psi, bit depth 14221' TVD
sensor 5306' Calculated BHP 11.37
ppb EMW
Contiue to RIH
Start picking up WOB @ 14,700'
SID 17,086' drive by on flag was -+ 2'
correction
PU, W140 k lbs, RBIH SID 17,0885,
squat neutral coil, 4 K WOB,
Pumps online 1.5 bpm, CT 3900 psi,
PU, 35 k Itis, - 0.95 WOB.
Lost - 50 bbls while RIH
1011/2017
16/212017
0.50
COMPZ1
CASING
TRIP
P
Stop to reset depth, line up pump
17,062.0
15,044.0
23:30
00:00
accros the top,
POOH, paint yellow flag @ 15044.19'
10/2/2017
10/2/2017
0.30
COMM
CASING
TRIP
P
Continue to POOH
15,044.0
14,100.0
00:00
00:18
10/2/2017
10/2/2017
0.20
COMPZI
CASING
DLOG
P
Tie into the K1 for a +14.5' correction
14,100.0
14,137.0
00:18
00:30
Lost 12 bbis while POOH.
10/2/2017
10/2/2017
0.50
COMPZ1
CASING
DLOG
P
Park @ 14,137 bit depth, 5727.6 TVD
14,137.0
14,137.0
00:30
01:00
monitor bottom hole pressure.
InnHial 3365 psi - 11.29 ppg
Open up bleed on the floor, fill hole till
fluid at the stack, SID well on a vac
5 min coil track 3362 psi - 11.28 ppg
Verify MW at inlet 11.23 ppg with
scale.
10 min coil track 3362 psi - 11.28 ppg
- took 1.6 bbis to refill hole.
30 min coil track 3358 psi - 11.27 ppg
Readding BHP of killweight fluid less
the slow leak off.
1012/2017
10/2/2017
2.70
COMPZI
CASING
TRIP
P
Continue to POOH purring across the
14,137.0
110.0
01:00
03:42
top - Lost 89 bbis of KW
Page 13121 Report Printed: 10/17/2017
Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
a
Sten Depth
Siad Tme
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(flK
End Depth (MB)
10/22017
10/2/2017
0.80
COMPZ1
CASING
TRIP
P
At surface, WH 0 psi, open at stack,
110.0
0.0
03:42
04:30
well on a vac, flood up to the half
drum, S/D. Well on a vac. Fill well
after ten min 1.9 bbl fill up. PJSM. LD
BHA #7 over a dead well. hole fill 2
MIS in 30 min. Flat spot on pipe - 8'
back from CC. Plan to UT prior to RIH
w BHA #9.
10/22017
10/2/2017
0.60
COMPZI
CASING
BORE
P
PJSM, PU safety joint, perform weekly
0.0
0.0
04:30
05:06
BOP function test
Hole fill 1 bbl
10/2/2017
10/2/2017
2.00
COMPZI
CASING
PUTB
P
Clear clean floor,prep to run liner.
0.0
966.0
05:06
07:06
PJSM, PU upper liner run #2 (ported
bull -nose, 24 jnts slotted liner, & liner
top billet), keeping the hole full
10/2/2017
10/2/2017
0.60
COMPZI
CASING
PULD
P
PU BHA #8 liner running tools, slide in
966.0
1,011.0
07:06
07:42
cart, MU coil, tag up, EDC closed
10/2/2017
102/2017
4.00
COMPZI
CASING
RUNL
P
RIH with Upper Liner Assemlby, no
1,011.0
16,014.0
07:42
11:42
returns to surface pumping .37 bpm,
begin to see small returns at -2100',
stop at 2177'to establish returns to
surface & ensure the hole is full
(pumping across the top), continue
RIH with no returns to surface
Tied into window flag for a +0.31'
correction, weight check at window =
35K, clean through window, began
taking weight at -14,800' (WOB
spikes to 5K), cleaned up by -15,600,
arrive at set depth, PUW = 40K, RBIH,
release off liner on depth, PUW = 36K,
TOB -15,050'
10/2/2017
10/2/2017
2.80
COMPZI
CASING
TRIP
P
POOH, flow check well, PJSM, losses
16,014.0
74-0-
11:42
14:30
at -9 bbVhr
10/2/2017
10/212017
1.00
COMPZI
CASING
PULD
P
LD BHA #8, UT flat spot on coil (-8'
44.0
0.0
14:30
15:30
up from EOP), minimum value at .150"
wall thickness, within spec to not cut
coil, checked pack -offs
10/22017
102/2017
2.00
PROM
STK
PULD
P
PJSM, PU BHA #9 AL1 KO/Drilling
0.0
78.0
15:30
17:30
Assembly (agitator, 0.5°- AKO motor,
RB Hughes bit), tag up, set counters,
EDC closed
10/22017
10/22017
2.00
PROD2
STK
TRIP
P
RIH with BHA #9, surface test agitator,
78.0
14,140.0
17:30
19:30
good
10/22017
10/2/2017
0.20
PROM
STK
CLOG
P
Log K1 for +31' correction, inspect
14,140.0
14,140.0
19:30
19:42
and clean BHI counter, dirty,
10/2/2017
10/2/2017
1.20
PROM
STK
DISP
P
Line up to pump across the top. bull-
14,140.0
14,T4-0.0-
19:42
20:54
head 68 bbl DuoVis down the
backside, pumping to 11.5 ppg at the
window, annular = 3427 psi, WHP
1270 psi, pumped away 68 bbl, lined
up on coil.
Change out injector counter, retie in
for a O' correction
10/2/2017
1012/2017
0.80
PROD2
STK
TRIP
P
Continue RIH, dry tagged TOB at
14,140.0
15,048.0
20:54
21:42
I
15,048', PUW = 32K, RBIH
Page 14121 ReportPrinted: 10/17/2017
Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan nos"
EM Tune
Dur(hr)
Phase
Op Cod.
Activity Code
Tme P -T -X
Operation
Stan Depth
(ftKB)
End Depth (110)
10/2/2017
10/3/2017
2.30
PROD2
STK
KOST
P
Begin milling off billet (15,046'
15,047.0
15,058.0
21:42
00:00
pumping), pumping 1.43 bpm, rate out
=.63 bpm, annular = 3503 psi, CWT =
12K, WOB =3K, circ pressure = 3892
psi, milling on an open choke with
-49% returns, climbs to -58% returns,
off billet at 15,052'
10/3/2017
10/3/2017
0.40
PROM
DRILL
DRLG
P
Drilling ahead on AL1 lateral
15,058.0
15,095.0
00:00
00:24
10/3/2017
10/3/2017
0.40
PROD2
DRILL
WPRT
P
PU Wt 35 k lbs, min rate see -1k lbs
15,095.0
15,095.0
00:24
00:48
WOB whilepulling up past the billet.
Returns check with open choke
Rate in Rate out % retuns
1.3 0.9 70
1.5 0.79 53
1.6 0.79 50
RBIH, down on the pumps, 4001b
WOB spike as we passed the billet
10/3/2017
10/3/2017
1.30
PROD2
DRILL
DRLG
P
1.42 bpm in, 0.76 bpm out, Ct 3842,
15,095.0
15,230.0
00:48
02:06
diff 760 psi
OBD, CT Wt 8.7 k lbs, WOB 1.6 k lbs,
ROP 100 ft/hr- returns less than 60%
After 20 min drilling returns healed to
0.80 bpm -57 %
Stall 15163, PU 41 k lbs
Pump 5x5 sweep, returns increased
from 0.8 to 0.87 bpm as the low vis
exited the bit
Average ROP over interval drilled -
104 ff/hr
10/3/2017
10/3/2017
2.10
PROD2
DRILL
DRLG
P
Returns fell to 0.70, suspect we
15,230.0
15,383.0
02:06
04:12
crossed fault B,
PU @ 15,241'36 k lbs
OBD, 1.42 bpm in, 0.70 bpm out, Ct
4131,
CT Wt 5.0 k lbs, WOB 1.0 k lbs, ROP
90 ft/hr
Returns slowly healed to 0.75 bpm /
53%
Pull 100' BHA wiper @ 15,364' PU Wt
36k lbs,
Returns 0.78 bpm W PUH, 0.66 W
RIH
BOBD 1.42 bpm in, 0.73 bpm out, CT
3877 psi, FS 770 psi
CT Wt 0, WOB 1.02, ROP 35 ft/hr
Average ROP over interval drilled - 73
ft/hr
10/3/2017
10/3/2017
0.50
PROD2
DRILL
WPRT
P
Pu Wt 36 k lbs, Wiper trip - 1058',
15,383.0
14,325.0
04:12
04:42
slight neg WOB at the billet.
10/3/2017
10/32017
0.20
PROD2
DRILL
DLOG
P
RBIH, Tie into the RA tag for+5'
15,383.0
14,354.0
04:42
04:54
correction.
10/3/2017
10/3/2017
1.70
PROD2
DRILL
CIRC
P
PUH above cement pilot hole, open
14,354.0
14,204.0
04:54
06:36
EDC, pump 5x5 sweep all the way
around. S/D Gose EDC, close choke.
10/3/2017
10/3/2017
0.60
PROM
DRILL
TRIP
P
RIH
14,204.0
15,383.0
06:36
07:12
Page 15121 ReportPrinted: 10/17/2017
Operations Summary (with Timelog Depths)
k 2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
statl Time
End Time
our (hn
Phase
Op Code
Activity Code
ry
Tune P -T-%
0 eralion
p
St (ftKBft )
End Depth (f l(B)
10/3/2017
10/3/2017
3.70
PROD2
DRILL
TRIP
P
1.77 bpm, CT 5411 psi, FS 1075 psi
15,383.0
15,800.0
07:12
10:54
OBD, CT Wt 5.4 k lbs, WOB 1.9 k lbs,
ROP 128
15,390, PU 38 k lbs
CT Wt 0.6 k lbs, WOB 2.4 k lbs, ROP
170 It/hr
15,525'. PU 39k lbs
15,654', PU 391k lbs
15,758', PU 39k lbs
CT Wt -5 k, WOB 1.4 k lbs, ROP fell
off to less than 100
Average ROP over interval drilled -
113 ft/hr
10/3/2017
10/3/2017
0.30
PROM
DRILL
WPRT
P
Pu Wt 39 k lbs - wiper to above the
15,800.0
14,947.0
10:54
11:12
billet - 853'
10/3/2017
10/3/2017
0.30
PROD2
DRILL
WPRT
P
RBIH, RIH Wt 2.6 k lbs
14,947.0
15,800.0
11:12
11:30
10/3/2017
10/3/2017
3.90
PROD2
DRILL
TRIP
P
1.76 bpm, FS 1042 psi
15,800.0
16,202.0
11:30
15:24
OBD. CT Wt 3 k lbs, WOB 1.4 k lbs,
ROP 153
15,933' PU 43 k
CT Wt -5 k, WOB 0.9 k lbs, ROP
dropping off to 50 ft/hr
Pump 5x5 sweep 1% Low torque and
776
Pre CT Wt -3k, WOB 0.9 K ROP 55
fUhr
Post CT Wt -1 k lbs, WOB 1.8 k lbs,
ROP 126 fUhr
Average ROP over interval drilled -
103 ft/hr
10/3/2017
10/3/2017
0.40
PROD2
DRILL
TRIP
P
Pu Wt 39 k, wiper 250'
16,202.0
16,202.0
15:24
15:48
turn around @ 15,950
RBIH
10/3/2017
10/3/2017
2.00
PROD2
DRILL
DRLG
P
1.78 bpm, CT 5058 FS 1012 psi WH
16,201.0
16,385.0
15:48
17:48
911 psi, IA 1450 psi, OA 300 psi
OBD, CT Wt 2 k lbs, WOB 1.0 k lbs,
ROP 100
Average ROP over interval drilled -
tt/hr
10/3/2017
10/3/2017
0.45
PROD2
DRILL
WPRT
P
Wiper up hole, PUW 40 k
16,385.0
15,767.0
17:48
18:15
10/3/2017
10/3/2017
0.35
PROD2
DRILL
WPRT
P
RBIH, pumping 5x5 sweep
15,767.0
16,363.0
18:15
18:36
10/32017
10/3/2017
0.25
PROD2
DRILL
WPRT
P
Wiper up hole, PUW 46 k
16,363.0
16,216.0
18:36
18:51
10/3/2017
10/3/2017
0.25
PROD2
DRILL
WPRT
P
RBIH, pumping 5x5 sweep
16,216.0
16,380.0
18:51
19:06
10/3/2017
10/3/2017
0.75
PROD2
DRILL
WPRT
P
Wiper to the window, PUW 46 k
16,380.0
14,110.0
19:06
19:51
10/32017
10/3/2017
0.25
PROD2
DRILL
DLOG
P
Log the K1 marker correction of plus
14,110.0
14,168.0
19:51
20:06
18.5'
10/3/2017
10/3/2017
1.50
PROM
DRILL
CIRC
P
PUH, bullheading 50 bbl bead/lube pill
14,168.0
13,900.0
20:06
21:36
down the back side, 0.5 bpm at 1,736
psi
10/3/2017
10/3/2017
1.00
PROD2
DRILL
WPRT
P
Wiper back in hole„ cloised choke,
13,900.0
16,380.0
21:36
22:36
pumping 0.28 bpm at 2,125 psi,
Page 16/21 Report Printed: 10/17/2017
9" Operations Summary (with Timelog Depths)
Ali:
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Shan Tlme
EW Time
Dur (hr)
Phase
Op Ootle
Activity Code
Time P -T-%
Operation
shin Depth
(MB)
End Depth(ftKB)
1013/2017
1014/2017
1.40
PROD2
DRILL
DRLG
P
BOBO, 1.76 bpm at 4,600 psi FS,
16,380.0
16,498.0
22:36
00:00
BHP 4000 psi, closed choke, IA 1,426,
OA 307, CTWS= 2 k, DHWOB= 1.8 k,
ROP=83 fph
"" Pump 2 - 5%5 sweeps
10/4/2017
10/4/2017
0.70
PROD2
DRILL
DRLG
P
OBD, 1.76 bpm at 5,100 psi, BHP
16,498.0
16,547.0
00:00
00:42
4,002, Closed choke, IA 1,375, OA
308, CTSW= 4 k, DHWOB= 1 k
10/4/2017
10/4/2017
3.75
PROD2
DRILL
DRLG
P
OBD, 1.76 bpm at 4,743 psi, Closed
16,547.0
16,790.0
00:42
04:27
choke, BHP dropped 400 psi, to
3,684, IA 1,374 psi, OA 308, CTSW=
8.0 k, DHWOB=2.8 k, ROP 166 fph
10/4/2017
10/4/2017
0.50
PROD2
DRILL
WPRT
P
Wiper up hole, PUW 41 k
16,790.0
15,090.0
04:27
04:57
10/4/2017
10/4/2017
0.70
PROD2
DRILL
WPRT
P
Wiper back in hole, RIW
15,090.0
16,790.0
04:57
05:39
10/412017
10/412017
5.60
PROD2
DRILL
DRLG
P
RIH Wt 4.4 k lbs, 1.79 bpm, CT 4860
16,790.0
16,957.0
05:39
11:15
psi, FS 1096 psi,
WH 500 psi, IA 1198 psi, OA 312 psi
OBD, Ct Wt 2-0 k Ibs. WOB 2-3 k lbs,
ROP 80-10 ft/hr
@ 16,955', differential pressure
dropped to - 1000 psi while OBD and
-2k WOB
PU, 48 k lbs, free spin diff returned to
1090 psi RBIH diff increased to 1200
psi then fell off rapidly to less than
1000 psi while OBD w WOB. Motor
still appears to be working, WOB
drilling off. ROP 30 ft/hr average over
interval drilled
10/4/2017
10/4/2017
1.30
PROD2
DRILL
WPRT
T
PU wt 40 k lbs, Wiper up hole,
16,957.0
14,189.0
11:15
12:33
Diferential pressure varying from as
high as 1500 psi to as low as 1000 psi
while POOH at 1.8 bpm. Once above
the cement pilot hole, parked, Open
EDC,
10/4/2017
10/4/2017
2.30
PROD2
DRILL
WPRT
T
Continue to POOH replacing pipe
14,189.0
75.0
12:33
14:51
voidage.
10/4/2017
10/4/2017
0.90
PROD2
DRILL
PULD
T
Bump up, space out, PUD BHA #9
75.0
0.0
14:51
15:45
10/4/2017
10/4/2017
1.10
PROD2
DRILL
PULD
T
Break off bit, motor and agitator. Bit
0.0
75.0
15:45
16:51
rated 2-1. Air blow freely through
agitator, motor appears to work with
air. Bit of black rubber found in bit.
check 1 replace pack offs.
10/4/2017
10/4/2017
1.50
PROD2
DRILL
CTOP
T
check / replace pack offs.
75.0
75.0
16:51
18:21
1
10/4/2017
10/4/2017
0.25
PROD2
DRILL
PULD
T
Stab on, complete PD BHA #10
0.0
75.0
18:21
18:36
10/4/2017
10/4/2017
0.25
PROD2
DRILL
TRIP
T
RIH, close EDC, testes agitator
75.0
600.0
18:36
18:51
10/4/2017
10/4/2017
2.35
PROD2
DRILL
TRIP
T
Continue RIH pumping 0.30 bpm @
600.0
14,100.0
18:51
21:12
2,062 psi
10/4/2017
10/4/2017
0.25
PROD2
DRILL
DLOG
T
Log K1 marker correction of plus 19.0'
14,100.0
14,130.0
21:12
21:27
1014/2017
10/4/2017
1.00
PROD2
DRILL
TRIP
T
Continue RIH to bottom
14,130.0
16,958.0
21:27
22:27
10/4/2017
10/5/2017
1.55
PROD2
DRILL
DRLG
P
OBD, 1.80 bpm at 4918 psi, BHP
16,958.0
22:27
00:00
3,785, WHIP 505, IA 1,159, OA 298,
Page 17121 ReportPrinted: 10/1712017
. Uperations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
Operation
Stan Depth
(MKS)
End Depth(MKB)
10/5/2017
10/5/2017
1.30
PROD2
DRILL
DRLG
P
OBD, 1.78 bpm at 5,106 psi, BHP
17,029.0
17,122.0
00:00
01:18
3,906, WHP 788 (closed choke), IA
1,307, OA 302
10/5/2017
10/5/2017
0.30
PROD2
DRILL
WPRT
T
PUH, notice counter not working, PUH
17,122.0
16,818.0
01:18
01:36
to log formation marker @ 16,818'
10/5/2017
10/5/2017
0.25
PROD2
DRILL
DLOG
T
Log formation correction of plus 30.0'
16,818.0
16,911.0
01:36
01:51
10/5/2017
10/5/2017
0.25
PROD2
DRILL
WPRT
T
RBIH to bottom, RIW 5 k
16,911.0
17,122.0
01:51
02:06
10/5/2017
10/5/2017
2.00
PROM
DRILL
DRLG
P
BOBD, 1.77 bpm at 4,700 psi FS,
17,122.0
17,190.0
02:06
04:06
BHP 3,913, WHP 813, IA 1,319, OA
302, CTSW=minus 1.3 k,
DHWOB=1.3 k, ROP 44 fph
10/5/2017
10/5/2017
1.90
PROD2
DRILL
DRLG
P
OBD, 1.78 bpm at 5,186 psi, BHP
17,190.0
17,251.0
04:06
06:00
3,956, WHP 876, IA 1,389, OA 303,
CTSW=minus 4.7 k, DHWOB=1.3 k,
ROP 40-60 fph
Average ROP over interval drilled 32
ft/sec
10/5/2017
10/5/2017
4.90
PROD2
DRILL
DRLG
P
OBD, 1.78 bpm BHP 3,996, WHP
17,251.0
17,501.0
06:00
10:54
957, IA 1,1546, OA 304,
Cl Wt -5 k lbs, WOB 1.6 k lbs, ROP 40
Struggled to build angle, getting
thrown down, dove and inverted
Average ROP over interval drilled 51
ft/sec
10/5/2017
10/5/2017
0.30
PROD2
DRILL
WPRT
P
Pu Wt 44 k lbs, BHA wiper,struggled
17,501.0
17,096.0
10:54
11:12
to tum around, turned into 405' wiper
10/5/2017
10/5/2017
0.60
PROD2
DRILL
WPRT
P
RBIH, struggle to get below 17,339',
17,096.0
17,501.0
11:12
11:48
sweeps on the back side. Once
sweeps 5 bbls out continue to RIH.
10/5/2017
10/5/2017
2.00
PROD2
DRILL
DRLG
P
OBD, 1.78 bpm BHP 3,996, WHP
17,501.0
17,569.0
11:48
13:48
957, IA 1, 1546, OA 304,
Ct Wt -5 k lbs, WOB 1.6 k lbs, ROP
120-10
Average ROP over interval drilled 34
ft/sec
10/5/2017
10/5/2017
0.80
PROD2
DRILL
WPRT
P
Pu Wt 42 k lbs, wiper, WH increased
17,569.0
15,200.0
13:48
14:36
from 980psi to 1585 psi - 2369' wiper
16,711' pulled heavy, 55 k lbs, -0.6 k
WOB
CT weight and WOB cleaned up after
16,500-
10/5/2017
10/5/2017
0.80
PROD2
DRILL
WPRT
P
RBIH, struggle to get below 17,339',
15,200.0
17,569.0
14:36
16:24
sweeps on the back side. Once
sweeps 5 bbis out continue to RIH.
10/5/2017
10/5/2017
1.50
PROM
DRILL
DRLG
P
OBD, 1.81 bpm BHP 4078 psi, WHP
17,569.0
17,591.0
15:24
16:54
980, CT 5060 psi, FS 1020 psi
Ct Wt 3 k lbs, WOB 3 k lbs, ROP 20
Average ROP over interval drilled 15
ft/sec
10/512017
10/5/2017
0.40
PROW
DRILL
WPRT
P
Pu Wt 40 k lbs, Geo wiper
17,591.0
17,015.0
16:54
17:18
10/5/2017
10/5/2017
0.40
PROD2
DRILL
WPRT
P
RBIH, RIW 6 k
17,015.0
17,569.0
17:18
17:42
Page 18/21 ReportPrinted: 10117/2017
Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Time
EM Time
Cur (IV)
Phase
Op Code
AcWity Code
Time P -T -X
0 ratlon
pe
Start Depth
(ftKe)
EM Depth IWO)
10/5/2017
10/5/2017
0.75
PROD2
DRILL
DRLG
P
BOBD, 1.79 bpm at 5,074 psi FS,
17,569.0
17,601.0
17:42
18:27
BHP 4,110, WHIP 920, IA 1,497, OA
303
10/5/2017
10/5/2017
1.25
PROD2
DRILL
WPRT
P
TD called, wiper up hole, PUW 40 k
17,601.0
14,100.0
18:27
19:42
10/5/2017
10/5/2017
0.25
PROD2
DRILL
DLOG
P
Log the K1 marker correction of Plus
14,100.0
14,163.0
19:42
19:57
28.0'
10/5/2017
10/5/2017
0.25
PROD2
DRILL
TRIP
P
RIH to window
14,163.0
14,290.0
19:57
20:12
10/5/2017
10/5/2017
3.50
PROD2
DRILL
CTOP
P
Static Pressure Survey: Final ECD
14,290.0
14,290.0
20:12
23:42
11.6 ppg
TIME: 20:00 -23:30
WHP: 930 - 761
AP: 3710- 3480
IA: 1497 -1182
10/5/2017
10/6/2017
0.30
PROD2
DRILL
TRIP
P
RIH to confirm TD
14,290.0
15,281.0
23:42
00:00
10/612017
017
1.15
PROD2
DRILL
TRIP
P
Continue RIH to confirm TD 17,619'
15,281.0
17,619.0
00:00
01:09
01:09
10/6/2017
10/6/2017
1.30
PROD2
DRILL
TRIP
P
PUH slowly while mixing liner running
17,619.0
17,210.0
01:09
02:27
pill
10/6/2017
10/6/2017
0.20
PROD2
DRILL
TRIP
P
RBIH while mixing liner running pill
17,210.0
17,549.0
02:27
02:39
10/6/2017
10/6/2017
0.50
PROD2
DRILL
TRIP
P
PUH while mixing liner running pill
17,549.0
17,386.0
02:39
03:09
10/6/2017
10/6/2017
0.40
PROD2
DRILL
TRIP
P
Line up to coil and start pumping liner
17,386.0
17,246.0
03:09
03:33
running pill, continue to creep uphole
10/6/2017
10/6/2017
0.20
PROD2
DRILL
TRIP
P
RBIH to time out Liner running pill
17,246.0
17,619.0
03:33
03:45
10/6/2017
10/6/2017
1.40
PROD2
DRILL
DISP
P
PUH laying in 50 bbl 11.5 ppg liner
17,246.0
14,238.0
03:45
05:09
running pill
Paint Yellow EDP flag @ 14160'
10/6/2017
10/6/2017
1.10
PROD2
DRILL
DISP
P
PUH slowly while bullheading 11.5
14,238.0
14,127.0
05:09
06:15
ppg KW fluid down the CT by tubing
annulus.
Stage pums up to 1.5 bopm, WH 850
psi,
10/6/2017
10/612017
2.30
PROD2
DRILL
DISP
P
SID, Observe well head pressure.
14,127.0
14,127.0
06:15
08:33
Initial 156 psi,
after 10 min WH 96 psi, open choke to
shaker, bleed 0.5 bbls Sit
WH stabilizes @ 87 psi
Bleed another 0.4 bbls to shaker WH
stabilized at 80 psi.
off load 12.0 ppg NaBr from truck
Start building 11.8 ppg KW fluid
Monitor pressure WH fell slowly to 18
psi while building KW fluid
10/6/2017
10/6/2017
0.60
PROD2
DRILL
TRIP
P
Start displacing the coil with 11.8 ppg
14,127.0
10,878.0
08:33
09:09
KW fluid while PUH
Paint white window, flag at 10878.34'
KW fluid at the bit
10/6/2017
10/6/2017
2.00
PROD2
DRILL
TRIP
P
At surface, flow check, well on a vac,
10,878.0
102.0
09:09
11:09
lost
138 bis of KW on the trip from the
window to surface.
10/6/2017
10/6/2017
1.00
PROD2
DRILL
PULD
P
LD over a dead well, Inspect pipe flat
102.0
0.0
11:09
12:09
spots, 0.10" 8 R back. Hole fill 8.5
bbls
Page 19121 ReportPrinted: 10/17/2017
Operations Summary (with Timelog Depths)
2A-22
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Time
End Time
our (hr)
Phase
Op Code
AM,ty Code
Time P-T-X
Operation
Slam Depth
(WB)
End Depth (WB)
10/6/2017
10/6/2017
4.00
COMM
CASING
PUTB
P
Bring in 1 additional R2 slotted joint to
0.0
1,589.4
12:09
16:09
ad to tally for seal bore space out,
Prep rig floor for running liner, shelter
adjusting roller on CTS counter to 2"
pipe from 23/8" pipe.
PU, 1st R2 slotted joint, MU 3 blanks
to the bottom and cap w non ported
bull nose.
Run 2nd R2 slotted joint and top w 78
joints of R3, 8 blank joints of R2 and a
seal bore deployment sleeve.
( 3437.29') filling the hole every 5
joints.
Drift lodged in joint # 18, found joint
full of wood shavings. Cleared drift, re
drifted joint, - clean, carded on.
10/6/2017
10/6/2017
2.00
COMPZ2
CASING
PUTB
P
Continue PU/MU of AL1 liner
1,589.4
2,624.6
16:09
18:09
assembly
10/6/2017
10/6/2017
0.50
COMPZ2
CASING
PUTS
P
Crew change, PJSM, inspect liner
2,624.6
2,624.6
18:09
18:39
running equipment and safety joint.
perform valve check list.
10/6/2017
10/6/2017
1.15
COMPZ2
CASING
PUTB
P
Continue PU/MU AL1 liner asembly
2,624.6
3,437.2
18:39
19:48
10/6/2017
10/6/2017
1.20
COMM
CASING
PULD
P
PU1MU, Coiltrak tools, and BOT 3.0
3,437.2
3,481.4
19:48
21:00
GS, stab into PBR, Hanging weight 25
k on blocks, surface test MWD tools
(good test), stab INJH, open rams
10/612017
10/6/2017
2.00
COMPZ2
CASING
RUNL
P
RIH, with ALl liner assembly,
3,481.4
14,284.2
21:00
23:00
pumping beaded pill min rate down
the backside.
10/6/2017
10/6/2017
0.25
COMPZ2
CASING
RUNL
P
Correct to the EDP flag 14281.46',
14,284.2
14,284.2
23:00
23:15
plus 7.44'
10/6/2017
10/7/2017
0.75
COMPZ2
CASING
RUNL
P
Continue IH
14,284.2
16,590.0
23:15
00:00
10/7/2017
10/7/2017
2.35
COMPZ2
CASING
RUNL
P
Continue to work liner to bottom
16,590.0
17,235.0
00:00
02:21
10/7/2017
10/7/2017
1.00
COMM
CASING
RUNL
P
Continue to work liner to bottom, IA
17,235.0
17,619.0
02:21
03:21
1024, OA 286
10/7/2017
10/7/2017
0.25
COMM
CASING
RUNL
P
Liner is on bottom, PUW 59 k, set
17,619.0
17,619.0
03:21
03:36
down minus 8 k CTSW, DHWOB 0 k,
set back down 8 k CTSW, bring pump
online at 1.75 bpm at 4,000 psi, PUW
33 k,
10/7/2017
10/7/2017
0.25
COMPZ2
CASING
TRIP
P
PUH for a tie in
17,619.0
14,F9-0-0-
03:36
03:51
10/7/2017
10/7/2017
0.25
COMPZ2
CASING
DLOG
P
Log the K1 correction of plus 17.5'
14,090.0
14,120.0
03:51
04:06
10/7/2017
10!1/2017
0.25
COMPZ2
CASING
DISP
P
Perform BHSP sensor depth 14,105.6'
14,120.0
14,120.0
04:06
04:21
MD, 5,717' TVD BHSP 11.625 ppg,
3,456 psi AP
10/7/2017
10/7/2017
0.60
COMPZ2
CASING
DISP
P
Line up SW down the coil,displace CT
14,120.0
13,921.0
04:21
04:57
to seawater.
10/7/2017
10/712017
0.60
COMPZ2
CASING
TRIP
P
Attemptto lift KW fluid, stage pumps
14,120.0
13,921.0
04:57
05:33
up slowly, No returns, well on a vac.
10/7/2017
10/7/2017
1.70
COMPZ2
CASING
TRIP
P
Line up with seawater down the back
13,921.0
57.0
05:33
07:15
side, displacing well bore to seawater
taking returns to the formation while
pulling out of hole. 125 bbls pumped.
WH climbed from 0 to 902 psi.
Page 20121 Report Printed: 10/17/2017
Operations Summary (with Timeiog Depths)
2A-22
Rig:
NABORS CDR3-AC
Job: DRILLING SIDETRACK
Time Log
Start Time
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P-T-x
Operation
Sten Depth
(RKB)
End Depth (ft
KB)10/7/2017
10/7/2017
1.50
COMPZ2
CASING
PULL)P
PJSM, bump up, space out, PUD BHA
57.0
0.0.0
07:15
08:45
#11, LD same.
10/7/2017
10/7/2017
0.70
DEMOB
WHDBOP
FRZP
P
PJSM, LRS, PT, 3500 psi, equalize,
0.0
0.0
08:45
09:27
open up and bullhead 30 bbls diesel
down the tubing. Final WH pressure
1200 psi.
10/7/2017
10/7/2017
1.50
DEMOB
WHDBOP
MPSP
P
PJSM, Pull QTS, Instal ASRC BPV
0.0
0.0
09:27
10:57
lubricator, Set BPV, RD lubricator.
Final pressure under the lubricator
1000 psi.
10/7/2017
10/7/2017
1.00
DEMOB
WHDBOP
CIRC
P
Reinstall QTS, stab on w nozzle, jet
0.0
0.0
10:57
11:57
stack while turning coil over to fresh
water for next well BOPE test.
10/7/2017
10/7/2017
3.00
DEMOB
WHDBOP
CTOP
P
Cut flat spot out of pipe, 20' 1",
0.0
0.0
11:57
14:57
rehead, pull test to 38 k - good.
Rehead a-line, PT to 4,000 psi. Pull
QTS, install night cap. Lock out
storage reel
10/7/2017
10/7/2017
1.00
DEMOB
WHDBOP
RURD
P
Blow down. Pull night cap, vac down
0.0
0.0
14:57
15:57
stack. Bore O scope the slack
10/7/2017
10/7/2017
2.05
DEMOB
WHDBOP
RURD
P
ND and RD in prep to move off. Move
0.0
0.0
15:57
18:00
shop and halfway house spot on 2K-
pad.
"` Note: Rig Released 18:00
10/7/2017
10/7/2017
DEMOB
Trucks back on location, PJSM,
0.0
18:00
18:00
Page 21121
Report Printed:
10/17/2017
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A -22A
50-103-20221-01
Baker Hughes INTEQ
Definitive Survey Report
11 October, 2017
BA ER
F�UGHES
e[.,,, ,
Cowl
company: ConocdPhillips Waska) Inc.-Kup2
Pfolech Kupamk River Unit
Sib: Kupemk 2A Pad
Wall: 2A-22
We11dare: ZA-22A
Need: 2A-22A
Project Kupamk River Unit, North Slope All United Grates
Map Sysbm: US Slab Plane 1927 (Exact solumul System Di em
Geo Datum: NAD 1927 (NADCON CONUS)
Map Zone: Naska Zone 04
ConoeoPhillips
Definitive Survey Report
Local Co-ordinate Reference:
Well26
WD Reference:
2AQ2 13500uld
MD Reference.
2Mi2 135.00usR
North Reference:
TUG
Survey Calculation Melhum
Minimum Curvature
Delaware
EDT Alaska Sandhog
Well
2M22
Phase: ACTUAL
To On Depth: 14,280.49
Well Position
r -B
0 0 cut
Northing:
-vm
0.00 usft
Eaafng:
Position Unartaimy
0.00 usft
Wellhead Elevation:
Wellborn
ZA-22A
Weil
Pl
Magnosics
Model Name
Sample Date
0.00
BGGM2017
300.00
11111201]
0esign
2A -22A
Darts 10162017
Audit Nares:
Fra.
Mean Sea Level
Using M11 Reference Point
U., geodetic scale factor
5,960.177.75us8
498,620.78usft
usft
Declinadgn
C)
1].28
Latitude:
Longitude:
Ground Level:
Dip Angle
V)
80 87
s
70° 18' 8.758 N
150° 0 40.217 W
94.30 usft
File SWngth
(1T)
5],475
vers.n:
1.0
Phase: ACTUAL
To On Depth: 14,280.49
Vertaal S.rb.n
Depth From(Ml
rWS
rEAAN
Okaceon
faun)
Iwai
Weil
Pl
4030
0.00
0.00
300.00
Survey Program
Darts 10162017
Fra.
To
Sully
Gavey
(usft)
(deal
Survey(WMII9ors)
Tool Name
Cescnption
Sort Oate
ErWOab
469.83
14,286.49
2A-22 MWD (2A22)
MWD
MWD - Standard
511911995
61911995
14,30800
14,335.23
2A -22A MWQINC (2A -22A)
MWD -INC ONLY
MWD -INC ONLY FILLER
_ _
9/2512017
8/282017
143]2.3]
17,056.28
2M22A MM (2 22A)
MWD
MWD -Standard
9/262017
10112017
10/112017 402'13PM
Paga2
COMPASS 5000.14 Hudd 85
Conocolshillips RA
1� 9
GonoC iffip5 Oefin0tve Survey Report
Company:
ConOwPhllllps(Alaska) Inc.-Kup2
Local Co-ordiate Rehmrce:
IAISH A.n
Project
Kuparuk Rivet Unit
TVD Reference:
7P.-22 Q 135 OOusR
sib:
Kupamk? Ped
MD Reference:
135 must
~I:
U-22
North Reference:
True
WMOob:
273-2273
survey Calculation Method:
Minimum CunMture
Design:
273-2273
Database:
EDTAaska Sandbox
MD
Inc
ASI
TVD
NDS)
+WS
4E1 -W
Map
Map
DLS
Vertical
(-ft)
111
1°1
(UM)
IuaRl
IueRl
(um)Oft)SO
Harting
p:a
section Survey Tool Nana
m)
1°/100.1
(R)
14.2[8.49
51.84
201317
581301
5.67801
2,780.89
-1174750
5562960.52
MAN SS
237
11564.00 MWIINC ONLY (2)
10308. SO
5162
28126
sM 78
5.70378
2]8]28
-11.]]941
MMA'
MAO 05
0,16
11,584.81 VA INC -ONLY (2)
14,335.23
5820
293.51
5.854.43
5.71943
2792.07
11.001.16
5.982.97171
405821.32
2507
11,816,14 MVr41NCONLY (2)
14,37237
7560
28594
5888.114
5,73364
2,8380
-11.8%,10
5,862.9W.M
40578832
4993
11.649.08 MVA (3)
14,40030
07,07
20971
5,89.83
5,73768
2007.20
-11,860.51
5092900.93
48198
39.00
11676.14 MM (3)
14.43017
0810
292.44
587397
5,73897
2,019.98
-11,86827
5.662,888,03
486,734.21
1001
11,705.54 MWD(3)
14MA7
88.47
MAW
5,87497
5.739,97
2,03387
-1191851
5,963.013.52
4.,703.00
13.40
1173867 WI (3)
14.40N
B720
300.26
5,075.98
5,740.
2,848.49
-11,941,70
5,863,026.15
486,680.80
1362
11,76506 VAD (3)
14,521.18
87.14
Mn
5.877.51
5.74251
9,86307
-11.95820
5883.04273
407854.31
1137
11,766,30 MM (3)
14.55135
0742
30485
587894
5,74384
2907.00
-11,0299
5,953,058.06
486,620.51
364
11,8.8634 SAM (3)
14,507.05
07.73
.10
5,880.19
5,745.19
2,.6.27
-12017.
5.963.07394
485004.03
9.91
11,855,76 MVA(3)
14.611.34
0742
298.71
5.8810
5,746.48
2,91185
-1204390
5,M409132
486,570.54
10.60
11886,21 MWO (3)
14,641,14
8.30
2..31
5802.05
5.747.86
2,0617
-1207049
5.953.104.84
4.,552.03
1140
11,81594 MM (3)
14,671.07
a?N
29272
5.8&,10
574910
2.93734
-12,0781
5,963,11701
481
891
11.94548 MAO(3)
14.701.03
080
290.
5,804.81
5,749.91
2,076.28
-12,125.
5.903,127 84
488,496,85
941
11,97528 MVA(3)
14.33115
8810
20714
588570
5,750.70
2957.87
-12154.22
5,583,13755
481
10.14
12,004.80 MWD(3)
1078136
88..
.585
5M sa
5,75158
283844
-121..17
5.983,140.13
456J3937
4.53
12,034,18 MM (3)
14,791.13
9187
284.37
5M46
5,751 46
2974.21
-12,21195
5.863.15381
48341060
12,16
12,86286 MM (3)
14,02140
8997
28071
5..5.
57WO
2,91
-12,24145
5,833,16047
481
13.
12.0170 MWD 13)
14.85124
09.0
27882
5.8..07
5,751,07
2907.32
-12,NO.0
5,.3.18502
486.35162
1307
12.11860 MWD (3)
14,881,45
92.12
23760
5.559
5,75059
290911
-12,30.07
596318882
4.,32188
845
8147.45 MVA (3)
14,91197
0v
274.91
5,8..13
5.749.17
2,89243
-1233120
5.963.1Y2.15
4.391.36
951
12,175.35 MAD (3)
14912.39
91,11
23260
50..0
5.748.0
2.994.42
-12..1.53
5.053.174.14
48.26104
1028
12=61 SIM (3)
14,871.13
8628
28759
SMS7
5740.67
2,894.47
-12,36.24
5.963,174 20
486,232.32
2418
12227.50 MAO(3)
15,0033
0779
20831
5.885.18
676010
2073.43
-12A1939
59.9316
486,20319
5.70
12=V MVA (3)
15,01.31
90.58
231.
5.88562
5.75062
298340
-1240M
59M.173.Y2
4M,9232
1465
12,27906 MAD (3)
15,061,42
07,9
27381
5,0..21
5,751.21
2,04..
-12,48942
5.963,17032
48614216
130
12,305.86 MM (3)
15,09006
86.83
23610
5.883.76
5,75276
2.99755
-125519
5.933.177.29
48601279
813
12,332.53 MA9(3)
15,12151
9181
284.55
5,88812
5,75.12
3,5304
-12,.8.01
5,963,182.70
486,08277
3106
12361.32 MWD (3)
15,15163
9138
_ 288.57
5,88728
_5,35220
3,011.62
-9,568.67
5,.3191,38
48a053.92
1342
1239007 MWD 131
AmotaVon
TIP
KOP
IMe1o1al0d ADMuth
First good survey
1041&017 4:02:12PM Page 3 COMPASS 500014 Budd W
ConocoPhillips di 0
ConocoPh]Mips Definitive Survey Report
Compnly:
ConocoPhillips lauding) Inc-Kup2
Local Co<IdineM RalMaece:
Wall 2a22
project:
Kupaak Rivet Unit
ND Rotational:
2 M 13500udft
3108:
Kupgak M Pad
MO Reference:
2.zt 135.00usft
Vyell:
24-22
NOMh RMatenca:
True
WMOore:
2A-224
Survey Calculation Method:
Minimum Curvature
Net,.:
m-224
Database:
EDTAIaska Sandeoa
MID
Inc
AM
NO
WindseWF
�BLW
Map
Map
Va l
lural
P)
19
(am)
(ueft)
lueftj
(daft)
Northing
Said,D�
on Survey Tool Nemo Apnotildn
(ft)
(ft)
1°1100'1
h4
15180 to
08.59
28918
5,88].]8
5,]52.]0
3,n20.86
12.5.5 117
5,063,20061
086,026.83
18.92
12418.60 Mi (3)
15.211.35
8]]6
293.11
5,669.32
5.704.32
3.03200
-12,624.70
5,083.21185
485,90780
13.11
12,.035 MNT(3)
15,23589
86.49
29591
5,89.54
5.75564
3,04200
-12,646.89
5,083.221.]6
485.9]5.]1
0.
12,47!.53 MAD (3)
15.263.58
8818
M8.12
5491.33
5!5733
3.05444
-126T1.78
5.963,234 21
485.950.82
11.18
1250131 MM (3)
15,295.]]
8576
29824
5.694.59
5,7..50
3,089.81
-12700.00
5003,24938
4.,.M 53
1.36
12,.00 MAD (31
15,32590
8538
29682
5.896 go
5.761.92
3.003,49
-11,728.73
S,mma 27
40589589
4.86
1258341 MAID (3)
15,355.35
.31
29358
5,699.59
5.]84.58
3.09598
-12.753.28
5,9632]5]6
485.66836
11.46
12,59184 MMD(3)
15,3.]0
8545
29280
598.34
5]6]34
3d08.23
-1216199
5.053,28801
485,840.64
4.64
12,02384 MIND (3)
15,41582
84%
289.04
5,9478
5,7.76
3,118.54
-12809.10
393.29.33
485,613.53
4230
12.85228 MM (3)
15,44031
85.82
2. 38
5,97,48
5,]7245
3,129.48
-12,84053
5.063,309.28
485.78210
2,75
12,884.97 MAD (3)
15481.00
8489
28800
5,81002
5,776M
3.139.82
-12,870.58
5.M.31962
485,75206
3.59
12,718.16 MVA(3)
15,51105
85.]8
28743
5,912.
5.777..
3,14805
-12898.08
5.93.328.86
485.]238]
4.24
12.]45.3] MAD (3)
15.541.]9
6665
206.40
5.914.48
5,]]946
3,15796
-12,92833
5,903.33]]8
465.691.33
4.42
12]]525 MM($)
15.565.]9
85.69
20462
5,915.67
5,780.8]
3,1649
-12,85141
5.963 UR
485,87124
741
12788. MAD (3)
15,59.81
Not
283M
5.917.77
5,76277
3,171.58
-12.980.29
5983351.39
46564237
482
12,827.05 MVA(3)
1583061
M70
28151
5,8'10132
5785.32
3,178.13
-13,01457
5.93.358.9
485,60809
529
12,860.52 MM (3)
156805]
67W
27998
5.922.07
5,]8]07
3,18471
-13.013.95
5,93.361.53
465,578]2
8.14
12.000]5 MND(3)
16MI091
8942
279.15
5,@2.85
5.]81.5
3.1.71
-13,073.
5.933..
485,54901
8.64
1291696 MM (3)
157..81
8083
27815
5,922]9
5,]37]0
3]94.21
-13,403.22
5,963,37405
485,51945
578
12,9..3 MAA(3)
15]50]8
9.34
27813
5,022.48
5,78748
3197,93
-13.132.84
5,933]7]]
495,48974
8..
12,97212 MrYD(3)
15)]7.93
90.34
274%
5,922.32
5.]8].32
3.20058
-13.159.98
5.93.39.41
485,462.71
423
12,9716 MM (3)
15,81067
90.71
2]180
em 02
5.78].02
3,.2.53
-13,19265
5,9330238
485430.03
947
13826.. MM (3)
15810.,2
So%
29.59
5,02169
5,786.60
3,202.92
-13.123]0
5,983.302]7
49,39090
].]1
13052.65 MAD (3)
15.8]34]
$951
2879
5.9187
57.11
3 2014
-13255.
5.953,302.W
48538].28
081
13.09.81 MND(3)
15.00209
91.54
28569
5,92141
5.788.41
3.200.79
-13.28,1.02
5.933968
485.33867
762
13,10189 MM (3)
1599.85
9..
263.61
624.8
5]8586
3,19841
-13.31287
5,983.37828
465.31003
119
13.12832 MM (3)
ignSio33
0046
260.04
5,920.01
5)9..
3.19442
-13,.19
6.963,374 30
485.2982
910
13,15161 MM (3)
15.965.84
Saw
258.54
5,S20..
5,]9..
3,1M..
-13,386.9
5,93.369.34
48525501
1861
13.170.9 When (3)
18,01021
0859
254.15
5,92145
5.75648
3, 1M24
-13.39.45
5,963.353.13
4M.23225
973
13199 MM (3)
18,04515
89.23
25342
5,022.13
5.]8].13
3.173.40
-13,423.99
5,93,35 335
485.19071
278
13,21228 MM (3)
16,08125
0107
256.9
5.922.03
5.78703
3,1..00
-13,150.81
5,983.313.88
485,16.87
947
13.23771 VM(3)
IOAIRO17 4:02:129. Pegg 4 COMPASS 500014 Budd 35
v ConocoPhillips ery��s a♦
ConocOPIillip5 Definitive Survey Report gas
C.":
ConncoPtdido(Alaska) Ino.-Kup2
Local Ce-ordinam R&emnce:
Vass a
Projact:
Kupamk Rlver Dnft
WD Reference:
2A -22C 135.00usft
erok:
Kupamk MPad
MD Referent:
2A-22 a 135.Oousft
Welt:
2A-22
NomO Reference:
Tme
milbon:
2A -23A
Sumey Cakulali0n Method:
Minimum Curvature
Design:
2A -22A
Dalalease:
EDT Masks Santo%
Survey
MD
Mc
Aai
TMD
NDSB
4W -S
1179/.50
loop
Map
pj
Me1p41
foMl)
r)
0
(doll)
Welt)
(usll)
(vert)
NonthMg
Eftinip
pOT
"Pose Survey Teel Name Annotation
m)
m)
(y
(0)
18.111 <5
9233
29.90
5,92114
35766.14
3,14.58
-13,40 91
5,86333]49
485,134.39
855
13.260.01 WM)(3)
16,14305
8)]3
0133
5,92112
5,766.12
315218
-13,519.43
5,98333107
485,10338
1846
13,28495 MM(3)
16,1]0.]1
6685
.3511
5,821 W
5.786.
3,14853
-13.54884
353583,32845
485.0]58]
8]0
13.306.17 MWD (3)
16,201.13
8751
Miss
5.923.01
5.780.01
3.14547
-13.5]].09
5.983.32540
485,0063
568
13,33084 MAD (3)
1Q231.05
8826
26782
5823.86
5,766.86
3,143.5]
-13,60.93
5,963,32350
485,01579
1143
13.35513 oAAD(3)
16,260.53
91.
28937
5.92364
57MM
3,14284
-13836.40
5,98.32278
484,988.32
652
13.38009 mm (3)
16190.43
92.M
u3M
SIM 61
5,]8]81
3,14340
-13,0937
6,983,32343
484,959.46
12.85
13,407 00 AM (3)
16,322.10
as.
2)362
5412.51
5.]0].51
3.145.33
-13.07.88
5,903,32538
484,924.85
1381
13.435.37 MYW(3)
18.36030
87.91
2]5.1]
5823.52
5,78052
3,14749
-13,]25.8]
5,883,32745
48489576
5.50
13.480.79 MNO(31
16,380.31
Se So
27886
5.924N
5,789.%
3,150.58
.13.755,79
5,98333051
484,064.94
6.43
13468.15 MND(3)
1641105
86.53
27910
5,92676
5,]91.]6
3.1 14.]9
-13.]0.10
5.983,3.75
484.036.55
714
13,516.0 MM (3)
16.44080
BBt3
280.84
5,920.0
5.26365
3.159.84
-13.015.24
sees ,339.81
414,850.51
5.37
13,5037 IAM (3)
1647035
07.82
28503
5,83022
5785M
3,166.
-13,04419
5,86334642
484,]]855
15n
13.57284 MAD (3)
18,50025
8663
2870
5,93181
5)081
3174]0
-1380.0
5.933.36CH
484,74988
784
13,901.0 mmp)
16.52642
86.53
28809
5.931.38
5."798.35
3.1..95
-13.0152
5,933,36484
04,72123
6.69
13.01.10 MND(3)
18,560.38
85.42
201a
5,93540
SAW 47
31N41
-13,929.55
5,983,37040
4.,693.21
678
13,6055 MM(3)
16590.33
.0
29351
5,938.02
5,803.02
3.205.83
-13,957.12
5,983.38502
4.,05.
7.06
13.890.14 MND(3)
16,620.26
84n
14467
5940.0
5.588
3,21799
-138..32
5,863.350.99
484,83845
4.32
13,710]] MAR)(3)
16.60.30
..18
2074.
5,94302
5.808.92
3,23085
-14,01135
5.983,41085
184,61153
6.0
13.]49.5] MAq(3)
18.680.35
63.97
298.M
S,N7.02
5,81202
3,24480
-1403'0
5933424 WD
1.,585.10
7.12
13,]]844 MM (3)
16,71025
03..
30025
5.950.27
5,815.27
3,259.56
-14,053.53
5,963439.57
484,559 25
470
13,009.16 MM (3)
16.74022
84M
.135
595353
35,6180
3,27482
-14,00.12
S,9M,454.83
464,53367
390
13,836.98 MMA(3)
18"0.21
8573
30145
does 21
5.82121
3.290.38
-14.114.61
5983.4]0.39
1.,5018
5.78
13.M 80 ~(3)
16.800 12
8840
300.35
5,0774
5.822.]4
3,3072
-14,140.24
5,96348574
484,4056
9th
13,8088] MND(3)
16.03023
00
299.39
5.95].93
San 0
3,32071
-14,166.35
35,503500.73
484,456A5
8.07
13,920]8 Aft (3)
18,.0.22
92,M
29862
5,90.85
5.821.95
3.33524
-14,192.67
5,963,515.26
4.430.24
7.
13.95875 WD (3)
16.891..
9330
297.33
5.955 31
5,82031
3.349.35
-14.21913
5,903,52938
4.40369
461
13.900.80 MND(3)
16.920.33
.0
29625
5.0328
5,81826
3,36284
-14,24584
5,9835428]
4..37699
S.
14,01867 Man (3)
16,95019
9398
26448
595108
5,816.0
3,375.59
-14292]5
5.98355562
4.,350.08
6.10
14,OM.W MMDe)
1590.23
8480
29282
6.079
5.813.79
3,97 .0
-14.314.18
5.943.56763
484.32285
8.12
14.07812 MM(3)
1].010]2
93 ]5
291.57
5.948.51
5.011.51 _
3,30.08
-14,328.33
5,843,5]912
484,29460
535
14,10824 MM (3)
10tl12017 4:02:12PM Pegg 5 COMPASS 500014 Bind 65
v
ConocoPhillips
ConocoPhillips
0
Definitive Survey Report
Company: CommoPhillips(AWska) Inc.-KUP2
Local Co-atlmate Relerenc6:
Wall 2A-22
Piopch Kupenik Miner Unit
NO Reference-.
2A -22a 135.O(lusfl
area: KBp01uk2APad
MD Reference:
ZAQ2®135.00uafl
Wall: 2A-22
North Reference:
Tree
Wellbore: 2,4@2,4
Survey Calculation Method:
Minimum Curveture
Design: 1A -22A
Database:
EDTMaska Sandbox
Survey
MD Inc A.
ND
11,1033
4W4
�-w Me,
At
"Mrtical
Welt), 11 N
(ua0)
late)
(us10
(usD) Narlhing
EasdnD
0100'1
Section Taol ft..
ADDOt8110n
1].1029 82.10 20803
5.9M.he
5.800 ad
3.409.4]
-14355.98 5.("3).. 12
M)
.28887 843
(,)Survey
10137M MM(3)
1].0.56.28 91.75 289.11
S,W 43
5,80943
341478
-14,371,05 5.983,591,82
484,251]9 4.08
14.153.08 Mea) (3)
17,01CO 91.25 289.14
5,91334
8808.34
3AX48
-14,404.)8 5.w608.53
484.21801 000
14.180.15 PROIECMD to TU
10/82017 4:02:12PM Pepe 6 COMPASS 5000.14 BUAd35
21 71 15
BA ERGHES PRINT DISTRIBUTION LIST 2116, 8769
F�U
a GE company� � F =; � � Please sign and return one copy of this transmittal form to:
COMPANY ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc.
Tom Osterkamp (WNS Petroleum Technician6ATA LOGGED
WELL NAME 2A -22A NOV U 2 20 700G Street. kl /I_1 20111
Anchorage, Alaska 99510 KK BENDER
FIELD Greater Kuparuk Area
COUNTY North Slope Borough
BHI DISTRICT Alaska
AUTHORIZED BY Patrick Rider
EMAIL Patrick.Rider@bakerhughes.com
STATUS Final Replacement:
COMPANY
ADDRESS (FEOEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
t BP Narth Slope.
EOA, PBOC, PRB-20(0Rce 109)
ID&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
2 ConecoPhillips Alaska Inc.
Atm: Ricky Elgariw
ATO 708
700 G Street
Anchorage, AK 99510
3 Exxon Mobil, Alaska
Attn: Lynda M. Yaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4 State of Alaska - AOGCC
Attn: Makana Bender
333 W. 7th Ave, Suite 100
Anchorage, Alasks 99501
No
LOG TYPE GR - RES
LOG DATE October 6, 2017
TODAYS DATE October 31, 2017
Revision
Details:
Rev. Requested by: ---
FIELDI
FINALCD/DVD
FINAL
PRELIM
LOGS
(las, dlis, PDF, META,
SURVEY
REPORT
I#OFCOPIES
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTSX
Ur PRIN
# OF COPIES
J#OFCOPIES
0 0 0 0 0
0 1 0 1 0 1 0 0
0 1 1 1 1 1 1 1 0
5 DNR - Division ofOil & Gas "' 1 0 0 i '1 Q
Attn: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
"* Stamp "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrolechnical Data Center, 1R2 -I
900 E. Benson Blvd.
Anchorage, Alaska 99508
0 1 1 1 1 1 1 0
TOTALS FOR THIS PAGE: 0 2 3 3 0
ConocoPhillips
NOV 0 2 2017
AOGCC
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A -22A
50-103-20221-01
Baker Hughes INTEQ
Definitive Survey Report
11 October, 2017
BA ER
F�UGHES
a GE cnm,,,y
21 71 15
28 769
9
Project Kuparuk River Unit, North Slope Alaska, United States
Map System:
ConocoPhillips
w
ConocoPhillips
Definitive Survey Report
Company: ConocoPhillips (Alaska) Inc. -Kup2
Local Coordinate Reference:
Project: Kuparuk River Unit
TVD Reference:
Site: Kuparuk 2A Pad
MD Reference:
Well: 2A-22
North Reference:
Wellbore: 2A -22A
Survey Calculation Method:
Desi n• 2A -22A
Database:
9
Project Kuparuk River Unit, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution)
System Datum:
Geo Datum:
NAD 1927 (NADCON CONUS)
(usft)
Map Zone:
Alaska Zone 04
(usft)
well
2A-22
Well Position
+N/ -S 0.00 Usti
Northing:
2A-22 MWD (2A-22)
+E/ -W 0.00 usft
Easting:
Position Uncertainty
0.00 usft
Wellhead Elevation:
Wellbore
2A -22A
End Date
Magnetics
Model Name
Sample Date
Design
Audit Notes:
Version:
Vertical Section:
Survey Program
From
(usft)
469.83
14,308.00
14,372.37
BGGM2017
2A -22A
11/1/2017
1.0
Phase: ACTUAL
Depth From (TVD)
-NIS
(usft)
Direction
40.70
(usft)
Date 10/6/2017
To
(usft)
Survey (Wellbore)
14,266.49
2A-22 MWD (2A-22)
14,335.23
2A -22A MWD -INC (2A -22A)
17,056.28
2A -22A MWD (2A -22A)
Well 2A-22
2A-22 @ 135 00usft
2A-22 @ 135.00usft
True
Minimum Curvature
EDT Alaska Sandbox
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
5,960, 177.75usft Latitude:
498 620.78usft Longitude:
usft Ground Level:
Declination Dip Angle
C) (1
17.28 80.87
BAr HES
70" 18'8.756 N
150" 0'40.217 W
94.30 usft
Field Strength
(nT)
57,475
Tie On Depth: 14,266 49
-NIS
+E/ -W
Direction
(usft)
(usft)
(')
0.00
0.00
300.00
Survey
Survey
Tool Name
Description
Start Date
End Date
MWD
MWD - Standard
5/19/1995
5/19/1995
MWD-INC—ONLY
MWD-INC—ONLY—FILLER
9/26/2017
9/26/2017
MWD
MWD - Standard
9/26/2017
10/1/2017
/0/11/2011 4 02 12PM Page 2 COMPASS 5000.14 Budd 85
W
ConocoPhillips
ConocoPhillips
Definitive Survey Report
9J
Company: ConocoPhillips (Alaska) Inc. -Kup2
Local Co-ordinate Reference:
Well 2A-22
Project: Kuparuk River Unit
TVD Reference:
2A-22 @ 135.00usft
Site: Kupamk 2A Pad
MD Reference:
2A-22 @ 135.00usft
Well: 2A-22
North Reference:
Tme
Wellbore: 2A -22A
Survey Calculation Method:
Minimum Curvature
Design: 2A -22A
Database:
EDT Alaska Sandbox
Survey
10/1112017 4: 02: 12PM Page 3 COMPASS 5000.14 Build 85
Inc
TVD
NDSS
+N/-5
'-W
Fs
Map
MapMD
DLS
Vertical
usft)
(°)
(1 (°)
)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
(°1700')
Section Survey Tool Name
ADDOtatIOD
(ft)
(ft)
(ft)
14,266.49
51.64
281.36
5,813.01
5.678.01
2,780.89
-11,747,50
5,962,960.52
486,874.96
2.37
11,564.08 MM -INC _ONLY (2)
TIP
j 14,308.00
51.62
281.28
5,83878
5,703.78
2,787.28
-11,779.41
5,962.966.91
486,843.06
0.16
11,594.91 MWD -INC ONLY (2)
KOP
14,335.23
58.20
283.51
5,854.43
5,719.43
2.792.07
-11.801.16
5,962.971.71
486,821.32
25.07
11,616.14 MM -INC -ONLY (2)
Interpolated Azimuth
14.372.37
76.60
285,94
5,868.64
5,733.64
2,800.80
-11,834.16
5,962.980.44
486,788.32
49.90
11,649.08 MWD (3)
First good survey
14,400.38
86.87
289.71
5,872.66
5,737.66
2,809.28
-11,860.51
5,962,988.93
486,761.98
39.00
11 6]6.14 MM (3)
14,430.17
88.10
292.44
5,873.97
5,738.97
2,819.98
-11,888.27
5,962,999.63
486,739.21
10.04
11,705.54 MWD (3)
14,463.47
88.47
296.89
5,874.97
5.739.97
2,833.87
-11,918.51
5,963,013.52
486,703.98
13.40
11,738.67 MM (3)
14.489.89
87.20
300.26
5,875.96
5,740.96
2,846.49
-11,941.70
5,963,026.15
486,680.80
13.62
11,765.06 MWD (3)
14,521,19
87.14
303.79
5,877.51
5,742.51
2,863.07
-11,968.20
5,963,042.73
486,654.31
11.27
11,796.30 MWD (3)
14.551.25
87.42
304.85
5,B78.94
5,743.94
2,880.00
-11,992.99
5,963,059.66
486,629.51
3.64
11,826.24 MWD (3)
14,580.85
87.73
301.93
5,880.19
5,745.19
2,896.27
-12,017.68
5,963,075,94
486,604.83
9.91
11,855.76 MWO(3)
14,611.34
87.42
298.71
5,881.48
5,746.48
2,911.65
-12,043.99
5,963,091.32
486,578.54
10.60
11886.21 MWD (3)
` 14,641.14
87.30
295.31
5,882.85
5,74285
2,925.17
-12,07D49
5,963,104.84
486,552.03
11.40
11,915.94 MM (3)
i 14,671.07
87.94
292.72
5,884.10
5,749.10
2,937.34
-12,097.81
5,963,117.01
486,529.72
8.91
11,945.68 MWD (3)
14,701.03
f
88.93
290.08
5,884.91
5,749.91
2,948.26
-12,125.69
5,963,127.94
486,496.85
9.41
11975.28 MM (3)
I 14,731.15
88.10
287.14
5,885.70
5,750.70
2,957.87
-12,154.22
5,963,137.55
486,468,32
10.14
12,004.80 MWD (3)
14,761.36
88.56
285.85
5,886,58
5,751.58
2,966.44
-12,183.17
5,963,146.13
486,439.37
4.53
12,034.16 MWD (3)
14,791.17
91.87
284.37
5,886A6
5,751.46
2,974.21
-12,211.95
5,933,153.91
486,410.60
12.16
12,062.96 MM (3)
14,821.40
89.97
280.71
5,885.98
5,750.98
2,980.77
-12,241.45
5,963,160.47
486,381.10
13.64
12,091.79 MOO (3)
14,851.24
89.69
276.82
5,886.07
5,751.07
2,985.32
-12,270.93
5,963,165.02
486,351.62
13.07
12,119.60 MWD (3)
14,881.45
92.12
277.60
5.885.59
5,750.59
2,989.11
-12,300,90
5,963,168.82
486,321.66
8.45
12,147.45 MWD (3)
.� 14,911.97
93.22
274.91
5,884.17
5,749.17
2,992.43
-12,331.20
5,963,172.15
486,29L36
9.51
12,175.35 MWD (3)
14,942.39
91.11
272.60
5,883.02
5,748.02
2,994.42
-12,361.53
5,963,174.14
486,261.04
10.28
12,202.61 MWO(3)
14,971A3
86.29
267.59
5,883.67
5,748.67
2,994.47
-12,390.24
5,963,174.20
486,232.32
24.18
12,227.50 MWD (3)
15,000.33
87.79
268.31
5,885.18
5,750.18
2,993.43
-12,419.39
5,963,173.16
486,203.19
5.70
12.252.22 MWD (3)
15,031.31
90.58
271.89
5,885.62
5,750,62
2,993.48
-12,450.35
5,963,173.22
486,172.22
14.65
12.279.% MM (3)
15,061.42
87.17
273.81
5.886.21
5,751.21
2,994.98
-12,480.42
5,963,1]4.]2
486,142.16
13.00
12.305.85 MM (3)
15,090.95
86.83
276.19
5,88776
5,752.76
2,997.55
-12.509.79
5,963,177.29
466,112.79
8.13
12,332.57 MWD (3)
15,121.51
91.81
284.55
5,888.12
5,753.12
3,003.04
-12,539.81
5,963,182.79
486,082.77
31.83
12,361.32 MWD (3)
15,151.63
91.38
288.57, -
5887.28
5752.28 -�
3011.62
-12,568.67
5963,191.38
486,053.92
13.42
12,390.60 MM (3)
10/1112017 4: 02: 12PM Page 3 COMPASS 5000.14 Build 85
ConocoPhillips SA{UGHES
ConocoPhillips Definitive Survey Report
Company:
ConocoPhillips (Alaska) Inc.-Kup2
Local Co-ordinate Reference:
Well 2A-22
Project:
Kuparuk River Unit
TVD Reference:
2A-22 @ 135.00usft
Site:
Kuparuk 2A Pad
MD Reference:
2A-22 @ 135.00usft
Well:
2A-22
North Reference:
True
Wellbore:
2A -22A
Survey Calculation Method:
Minimum Curvature
Design:
2A -22A
Database:
EDT Alaska Sandbox
Survey
Annotation
10/112017 4:02r12PM Page 4 COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Atl
TVD
TVDSS
+N/S
+El -W
Northing
Easting
DLS
Section
Survey Tool Name
(usft)
(°l
P)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(-/100')
(ft)
15,180.18
%.59
289.19
5,887.79
5,752.79
3,020.86
-12,595.67
5%3,200.62
486,026.93
16.92
12,418.60
MWD (3)
15,211.35
87.76
293.11
5,889.32
5.754.32
3,032.09
-12,624.70
5,963,211.85
485,997.90
13.11
12,449.35
MWD (3)
15,235.69
86.49
295.01
5,890.54
5,755.54
3,042.00
-12,646.89
5,963.221.76
485,975.71
9.38
12,473.53
MWD(3)
15,263.58
86.18
298.12
5,892.33
5,757.33
3,054.44
-12,671.78
5,963,234.21
485,950.82
11.18
12,501.31
MWD (3)
15,295.77
85.76
298.24
5,894.59
5,759.59
3,069.61
-12,700.09
5,963,249.38
485.922.53
1.36
12,533.40
MWD (3)
15,325.90
85.36
296.82
5,89fi.92
5,761.92
3,083.49
-12,726.73
5,%3,263.27
485,895.89
4.88
12,563.41
MWD (3)
15,355.35
84.37
293.58
5,899.56
5,764.56
3,095.98
-12,753.26
5.%3,275.76
485,869.36
11.46
12,592.64
MWD(3)
1S,386.70
85.45
292.60
5,902.34
5,767.34
3,108.23
-12,781.99
5,963,288.01
485,840.69
4.64
12,623.64
MWD(3)
15,415.82
84.96
289.04
5,904.78
5,769.78
3,118.54
-12,809.10
5,963.298.33
485,813.53
12.30
12,652.28
MWD(3)
15,449.21
85.82
289.36
5,%7.46
5,772.46
3,129.48
-12,840.53
5,963,309.28
485,782.10
2.75
12,684.97
MWD (3)
15,481.09
84.96
288.60
5,910.02
5,775.02
3,139.82
-12,870.58
5,963,319.62
465,752.06
3.59
12,716.16
MWD 13)
15,51105
85.76
287.43
5,912.44
5,777.44
3,149.05
-12,898.98
5,963,328.86
485,723.67
4.72
12,745.37
MAD (3)
15,591.79
86.65
286.40
5.914.48
5,779.48
3,157.98
-12.928.33
5,%3,337.78
485,694.33
4.42
12,775.25
MWD (3)
15,%5.79
86.69
284.62
5,915.87
5,760.87
3,164.38
-12,95141
5,953,344.19
485,671.24
7.41
12,798.M
MWD (3)
15,595.61
06.01
283.35
5,917.77
5,782.77
3,171.58
-12.980.29
5,963.351.39
485,642.37
4.82
12,82705
MWD (3)
15,630.81
85.70
281.51
5,920.32
5,785.32
3,179.13
-13,014.57
5,963,358.95
485,608.09
5.29
12,860.52
MWD(3)
15,%0.77
87.60
279.98
5,922.07
5,787.07
3,189.71
-13,043.95
5,963.364.53
485,578.72
8.14
12,888.75
MWD (3)
15,690.91
89.42
279.15
5,922.85
5,787.85
3,189.71
-13,073.66
5,%3,369.54
485,549.01
6.64
12,916.98
MWD (3)
15,720.81
90.83
278.15
5,922.79
5,787.79
3,194.21
-13,103.22
5,963.374.05
485.519.45
5.78
12,944.83
MWO(3)
15,750.76
90.34
276.13
5,922.48
5,787.48
3,197.93
-13,132.94
5,963,377.77
485,489.74
6.94
12,972.42
MWD (3)
15,777.93
90.39
274.98
5,922.32
5,787.32
3,200.56
-13,159.98
5,963,380.41
485,462.71
4.23
12,997.16
MWD (3)
15810.67
90.71
27190
5,922.02
5,767.02
3,202.53
-13,192.65
5,963.382.38
485,430.03
9.47
13,026.49
MWD(3)
15,840.72
90.55
269.59
5,921.69
5,785.69
3,202.92
-13,222.70
5,%3,382.77
485,399.99
7.71
13,052.65
MWD (3)
15,873.47
89.51
267.69
5,921.67
5,7%.67
3,202.14
-13,255.44
5,963.382.00
485,367.26
6.61
13,080.61
MWD(3)
15,90209
91.54
266.89
5,921.41
5,786.41
3,200.79
-13,284.02
5,%3,380.66
485,338.67
TU
13,104.69
MWD (3)
15,930.85
90.58
263.61
5,920.88
5,785.88
3,198.41
-13,312.67
5,%3,378.28
485,310.03
11.88
13,128.32
MWD (3)
15,960.33
90.46
260.89
5,920.61
5,785.61
3,194.42
-13,341.88
5,963,374.30
485,280.82
9.40
13,151.61
MAD (3)
15,985.64
88.50
256.54
5,920.89
5,785.84
3,189.46
-13,366.69
5,963,369.34
485,256.01
18.67
13,170.62
MWD (3)
16,010.21
88.59
254.15
5,92L46
5,786.46
3,183.24
-13,390.45
5,%3,363.13
485,232.25
9.73
13,188.09
MWD (3)
16,045.15
89.23
253.42
5922.13
5,787.13
3,173.49
-13,423.99
5,%3.353.38
485,198.71
2.78
13.212.26
MWD (3)
16,081.25
91.07
256.30
5,922.03
5,787.03
3,164.%
-13,458.84
5,%3.343.96
485,163.87
947
13.23772
MWD (3)
Annotation
10/112017 4:02r12PM Page 4 COMPASS 5000.14 Build 85
1w-
ConocoPhillips
ConocoPhillips
Definitive Survey Report
6AE`'RHES
9
Company: ConocoPhillips (Alaska) Inc -Kup2
Local Coordinate Reference:
Well 2A-22
Map
Project: Kuparuk River Unit
ND Reference:
2A-22 @ 135.00usft
(usft)
Site: Kuparuk 2A Pad
MD Reference:
2A-22 135.00usft
(usft)
Well: 2A-22
North Reference:
True
Easting
Wellbore: 2A -22A
Survey Calculation Method:
Minimum Curvature
Design: 2A -22A
Database:
EDT Alaska Sandbox
MD
Inc
ND
NDSS
+W-S
+E/ -W
Map
Map
DLS
Vertical
(usft)
(°)
(1 )
(°)
(usft)
(usft)
(usft)
(usft
Northing
Easting
Section) Survey Tool Name Annotation
(ft)
(ft)
(°/100')
IN)
16,111.45
92.33
258.90
5,921.14
5,786.14
3,157.58
-13,48631
5,%3,33]49
485,134.39
9.56
13,260.01 MWO(3)
j 16,143.05
87.73
261.33
5,921.12
5,7136.12
3,152.16
-13,519.43
5,963,332.07
485,103.28
16.45
13,284.25 MWD (3)
° 16,170.71
i
88.65
263.58
5,921.99
5,786.99
3,148.53
-13,546.84
5,963,328.45
485,075.87
8.78
13,306.17 MWD (3)
' 16,201.13
87.51
264.88
5,923.01
5,788.01
3,145,7
-13,577.09
5,963,325.40
485:045.63
5.68
13,330.84 MWD (3)
16,231.05
1
89.26
267.82
5,923,86
5,788.86
3,143.57
-13,606.93
5,%3,323.50
485,015.79
11.43
13,355.73 MWD (3)
16,260.53
91.60
269.37
5,923.64
5,78864
3,142.84
-13,636.40
5,963,322.78
484,986.32
9.52
13,380.69 MM (3)
i 16,290.43
i
92.34
273.08
5,922.61
5,787.61
3,143,48
-13.665.27
5,953,323.43
484,956.46
12.65
13,407.08 MWD (3)
16,322.10
88.00
273.62
5,922.51
5,787.51
3,145.33
-13,697.88
5,963,325.28
484,924.85
13.81
13,435.37 MWD (3) .
16,350.30
87.91
275.17
5,923.52
5,788.52
3,147.49
-13,725.97
5,963,327.45
484,896.76
5.50
13,460.79 MWD (3)
16,380.31
86.68
276.66
5,924.94
5,789.94
3,150.58
-13,755.79
5,963,330.54
484,866.94
6.43
13,488.15 MWD (3)
f 16,411.05
86.53
279.10
5,926.76
5,791.76
3,154.79
-13,786.18
5,963,334.75
484,836.55
7.94
13,516.58 MWD (3)
! 16,40.60
86.13
280.64
5,928.65
5,793.65
3,159.84
-13,815.24
5,963,339.81
484,807.51
5.37
13,544.27 MVVD(3)
1 16,470.35
87.82
285.03
5,930.22
5,795.22
3,166.44
-13,844.19
5,963.346.42
484,778.55
15.79
13,572.64 MM (3)
16,500.25
86.83
287.09
5,931.61
5.796.61
3,174.70
-13,872.89
5,963,354.68
484,749.86
7,64
13.601.63 MWD (3)
16,530.42
86.53
289.09
5,933.36
5,798.36
3,184.05
A3,901.52
5,963,364.04
484,721.23
6.69
13,631.10 MM (3)
16,560.38
85.42
291.48
5,935.46
5,800.47
3,194.41
-13,929.55
5,%3,374.40
484,61K1,21
8.78
13,660.55 MAD (3)
16,590.33
84.80
293.51
5.938.02
5,803.02
3,205.83
-13,957.12
5,963,385.82
484,665.64
7.06
13,690.14 MWD(3) _
j 16,620.26
84.22
29467
5,940.88
5,805.88
3,217.99
-13,984.32
5,%3,397.99
484,638.45
4.32
13,719.77 MWD (3)
16,650.30
84.18
296.74
5,943.92
5,808.92
3,230.95
-14,011.25
5,963,410.95
484,611.53
6.86
13.749.57 MWD (3)
16,680.35
83.97
298.88
5,947.02
5,812.02
3,244.90
-14,037.68
5,963,424.90
484,585.10
7.12
13,779.44 MWD (3)
16,710.25
83.54
300.25
5,950.27
5,815.27
3,259.56
-14,063.53
5,963,439.57
484,559.25
4.78
13,809.16 MWD (3)
16,740.22
84.00
301.35
5,953.53
5,818.53
3,274.82
-14,089.12
5,%3,464.83
484,533.67
3.96
13,838.95 MM (3)
16,770.20
85.73
301.46
5,956.21
5,821.21
3,290.38
-14,114.61
5,963,470.39
484.508.19
5.78
13,868.80 MWD (3)
16,800.12
88.40
300.35
5,957.74
5,822.74
3,305.72
-14,140.24
5,9133,485.74
484,482.56
9.66
13,898.67 MWD (3)
16,830.23
90.89
299.38
5,957.93
5,822.93
3,320.71
-14,166.35
5,963,500.73
484,456.45
8.87
13,928.78 MM (3)
16,860.22
92.86
298.62
5,956.95
5,821.95
3,335.24
-14,192.57
5,963.515.26
484,30.24
7.04
13,958.75 MWD (3)
16,890.34
93.38
297.33
5,955.31
5,820.31
3,349.35
-14,219.13
5,963,529.38
484,403.69
4.61
13,938.80 MWD (3)
16,920.33
94.43
296.25
5,953.26
5,818.26
3,362.84
-14,245.84
5,963,542.87
484,376.99
5.02
14,018.67 MWD (3)
16,950,19
93.96
294.46
5,951.08
5,816.08
3,375.59
-14,272.75
5,963,555.62
484,350.08
6.18
14,048.36 MWD (3)
16,980.23
94.80
292.82
5,948.79
5,813.79
3,387.60
-14,300.18
5,963,557.63
484,322.65
6.12
14,078.12 MWD (3)
17,010.72
93.75
291.57
5.946.51
5,811.51
3,399.08
-14,328.33
5,963,579 12
484,29450
5.35
14,108.24 MM (3)
10,1112017 4012PM
Page 5
COMPASS 5000.14 Build 85
ConocoPhillips
ConocoPhillips
Company:
ConocoPhillips (Alaska)
Inc. -Kup2
Project:
Kupamk River Unit
Site:
Kuparuk 2A Pad
Local Coordinate Reference:
Well 2A-22
Well:
2A-22
Wellbore:
2A -22A
Design:
2A -22A
MD Reference:
2A-22 @ 135.00usft
Survey
MD
Inc Azi
TVD
TVDSS
(usft)
P) (1
(usft)
(usft)
17,040.29
92.18 289.63
5,944.98
5,809.98
17,056.28
91.75 289.14
5944.43
5,809.43
17.092.00
91.75 289.14
5,94334
5,808.34
10/11/2017 4: 02:12PM Page 6 COMPASS 5000.14 Build 85
ConocoPhillips
6A OSHES
Definitive Survey Report
Local Coordinate Reference:
Well 2A-22
TVD Reference:
2A-22 @ 135.O0usft
MD Reference:
2A-22 @ 135.00usft
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDT Alaska Sandbox
Map
Map
Vertical
+N/S
•E/ -W Northing
Easting DLS
Section
Survey Tool Name
Annotation
(usft)
foal (ft)
(ft) (°/100')
(ft)
3,409.47
-14,355,98 5,963,589.52
484,266.87 8,43
14,137.38
MvsD (3)
3,414.78
-14,371.05 5,963,594.82
484.251.79 4.08
14,153.08
MM (3)
3,42648
-14404.78 5.963,606.53
484218.07 000
14,188.15
PROJECTED to TO
10/11/2017 4: 02:12PM Page 6 COMPASS 5000.14 Build 85
To:
RECEIVED '
OCT 16 2017
AOGCC
VWER�
a U compaiyr
217-115 28686
Letter of Transmittal
Date: DATA LOGGED
October 16 2017 `"`9071
i M K BENDER
Makana Bender
AOGCC
333 West 7" Ave, Suite 100
Anchorage, Alaska 99501
From:
Yosha Ragbirsingh / Michael Soper
Baker Hughes, a GE Company
795 East 9411 Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data for the following well(s):
3M -27A
3M-27AL1
3M-27AL2PB1
3M-27AL2
3M-27AL2-01
3M-27AL3
2A -22A
2A-22AL1
(8) Total prints
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Michael Soper, Baker Hughes, Project Engineer
Michael.Soper@BHGE.com
Yosha Ragbirsingh, Baker Hughes, Survey Manager
Yosha.Ragbirsingh@BHGE.com
.�
ConocoPhillips
RECEIVED
OCT 16 2017
AOGCC
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A -22A
50-103-20221-01
Baker Hughes INTEQ
Definitive Survey Report
11 October, 2017
217-115 28686
BA ER
F UGHES
a GE company
ConocoPhillips
Company: ConocoPhillips (Alaska) Inc. -Kup2
Project: Kuparuk River Unit
Site: Kuparuk 2A Pad
Well: 2A-22
Wellbore: 2A -22A
Design: 2A -22A
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: US State Plane 1927 (Exact solution) System Datum
Geo Datum: NAD 1927 (NADCON CONUS)
I Map Zone: Alaska Zone 04
ConocoPhillips
Definitive Survey Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
F Well
2A-22
Phase: ACTUAL
Vertical Section:
z Well Position
+N/ -S
0.00 usft
Northing:
(usft)
+FJ -W
0.00 usft
Easting:
Position Uncertainty
0.00
0.00 usft
Wellhead Elevation:
Wellbore
2A -22A
(usft)
(usft)
Magnetics
Model Name
14,266.49
Sample Date
BGGM2017 11/l/2017
Design 2A -22A
Audit Notes:
Version:
1.0
Phase: ACTUAL
Vertical Section:
+N/ -S
Depth From (TVD)
Direction
(usft)
(usft)
(°)
40.70
Survey Program
0.00
Date 10/6/2017
1
!' From
To
(usft)
(usft)
Survey (Wellbore)
!6
` 469.83
14,266.49
2A-22 MWD (2A-22)
14,308.00
14,335.23
2A -22A MWD -INC (2A -22A)
14,372.37
17,056.28
2A -22A MWD (2A -22A)
Well 2A-22
ZA-22 Q 135.00usft
2A-22 @ 135.00usft
True
Minimum Curvature
EDT Alaska Sandbox
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
5,960,177.75usft
498,620.78usft
ush —
Declination
(1)
17.28
BA, �(ER
WHFS
Latitude: 70° 18'8.756 N
Longitude: 150° 0' 40.217 W
Ground Level: 94.30 usft
Dip Angle Field Strength
(1) (n -r)
80.87 57,475
Tie On Depth: 14,266 49
+N/ -S
+E/ -W
Direction
(usft)
(usft)
(°)
0.00
0.00
300.00
Survey
Survey
Tool Name
Description
Start Date
End Date
MWD
MWD - Standard
5/19/1995
5/19/1995
MWD-INC–ONLY
MWD-INC–ONLY–FILLER
9/26/2017
9/26/2017
MWD
MWD - Standard
9/26/2017
10/1/2017
1071112017 4: 02: 12PM Page 2 COMPASS 5000.14 Build 85
w. ConocoPhillips
ConocoPhillips Definitive Survey Report
Company:
ConowPhillips (Alaska) Inc. -Kup2
Local Co-ordinate Reference:
Well 2A-22
Project:
Kuparuk River Unit
ND Reference:
2A-22 @ 135.00usft
Site:
Kuparuk 2A Pad
MD Reference:
2A-22 @ 135.00usft
Well:
2A-22
North Reference:
True
Wellbore:
2A -22A
Survey Calculation Method:
Minimum Curvature
Design:
2A -22A
Database:
EDT Alaska Sandbox
Survey
HA4(W �M
1011112017 4:02: 12PM Page 3 COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Azi
ND
NDSS
+N/ -S
+EI -W
Northing
Easting
DLS
Section
(usft)
(1)
(1
(usft)
(usft)
(usft)
(usft)
(°/100')
Survey Tool Name
Annotation
(ft)
(ft)
fill
14,266.49
5164
28136
5,613.01
5,678.01
2.78089
-11,747.50
5,962,960.52
486.874.96
2.37
11,564.08
MWD -INC _ONLY (2)
TIP
14,308.00
5162
281.28
5,838.78
5,703.78
2,787.28
-11,779.41
5,962,965.91
486,843.06
0.16
11,594.91
MWD-INC_ONLY (2)
KOP
14,33523
5820
283.51
5,854.43
5,71943
2,792.07
-11,801.16
5,962,971.71
486,821.32
25.07
11,616.14
MWD -INC -ONLY (2)
Interpolated Azimuth
14,372.37
7660
285.94
5,868.64
5,733.64
2,800.80
-11,834.16
5,%2,98044
486,788.32
49.90
11,649.08
MWD (3)
First good survey
14,400.38
86.87
289.71
5,872.66
5,737.66
2,809.28
-11,860.51
5,962,98893
486,761.98
39.00
11,676.14
MWD (3)
14,430.17
88.10
292.44
5,873.97
5,738.97
2,819.98
-11,888.27
5,962,999.63
486,73421
10.04
11,705.54
MWD (3)
14,46347
88.47
296.89
5,874.97
5,739.97
2,833.87
-11,918.51
5,963,01352
486,703.98
13.40
11,738.67
MWD (3)
14,489.89
8720
300.26
5,875.96
5,740.96
2,846.49
-11,941.70
5,963,026.15
486,680.80
13.62
11,765.06
MWD (3)
14,521.19
87.14
303.79
5,877.51
5,742.51
2,863.07
-11,968.20
5,963,04273
486,654.31
11.27
11,796.30
MWD (3)
14,551.25
87.42
304.85
5,878.94
5,743.94
2,880.00
-11,992.99
5,963,05966
486,629.51
3.64
11,826.24
MWD(3)
14,580.85
8773
301.93
5,880.19
5,745.19
2,896.27
-12,017.68
5,963,97594
486,604.83
9.91
11,855.76
MWD (3)
14,611.34
87.42
298.71
5,881.48
5,746.48
2,91165
-12,043.98
5,963,091.32
486,578.54
10.60
11,886.21
MWD (3)
14,641.14
87.30
295.31
5,882.85
5,747.85
2,925.17
-12,070.49
5,963,104.84
486,552.03
11.40
11,915.94
MWD (3)
14,671.07
87.94
292.72
5,884.10
5,749.10
2,937.34
-12,097.81
5,963,117.01
486,52472
8.91
11,945.68
MWD (3)
14,701.03
88.93
290.08
5,884.91
5,749.91
2,94026
-12,125.69
5,963,127.94
486,496.85
9.41
11,975.28
MM (3)
14,731.15
88.10
287.14
5,885.70
5,750.70
2,957.87
-12,154.22
5,963,137.55
486,468.32
10.14
12,004.80
MWD (3)
14,761.36
88.%
285.65
5,886.58
5,751.58
2,966.44
-12,183.17
5,963,146.13
486,439.37
4.53
12,034.16
MWD (3)
14,791.17
91.87
284.37
5,886.46
5,751.46
2,97421
-12,211.95
5,963,153.91
486,410.60
12.16
12,062.96
MWD (3)
14,82140
89.97
280.71
5,885.98
5,750.98
2,98077
-12,241.45
5,963,160.47
486,381.10
13.64
12,091,79
MM (3)
14,851.24
8969
276.82
5,886.07
5,751.07
2,985.32
-12,270.93
5,963,165.02
486,35162
13.07
12,119.60
MWD (3)
14,881.45
92.12
277.60
5,895.59
5,750.59
2,989.11
-12,300.90
5,963,168.82
486,32166
8.45
12,147.45
MWD (3)
14,911.97
9322
274.91
5,884.17
5,749.17
2,99243
-12,331.20
5,963,172.15
486,29136
9.51
12,175.35
MWD (3)
14,942.39
91.11
272.60
5,883.02
5,748.02
2,994.42
-12,361.53
5,963,174.14
486,261.04
10.28
12,202.61
MWD (3)
14,971.13
86.29
267.59
5,883.67
5,748.67
2,994.47
-12,390.24
5,963,17420
486,232.32
24.18
12,227.50
MWD (3)
15,00033
87.79
268.31
5,885.18
5,750.18
2,993.43
-12,419.39
5,963,173.16
486,203.19
5.70
12,252.22
MWD (3)
15,031.31
90.58
271.89
5,88562
5,750.62
2,99348
-12,450.35
5,983,17322
486,172.22
1465
12,279.W
MM (3)
15,06142
87.17
273.81
5,886.21
5,751.21
2,994.98
-12,480.42
5,963,174.72
486,142.16
13.00
12,305.85
MWD(3)
15,090.95
86.83
276.19
5,887.76
5,752.76
2,997.55
-12,509.79
5,963,177.29
486,112.79
8.13
12,332.57
MWD (3)
15,121.51
91.81
284.55
5,888.12
5,753.12
3,003.04
-12,539.81
5,963,182.79
486,082.77
31.83
12,361.32
MWD (3)
15,15163
9138
288.57
5,887.28
5,752.28
3,01162
-12,568.67
5,963,191.38
486,053.92
13.42
12,390.60
MWD (3)
1011112017 4:02: 12PM Page 3 COMPASS 5000.14 Build 85
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Company:
Project:
Site:
Well:
Wellbore:
Design:
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A-22
2A -22A
2A -22A
Local Co-ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 2A-22
2A-22 @ 135.00usft
2A-22 @ 135.00usft
True
Minimum Curvature
EDT Alaska Sandbox
'Survey
Map
Map
Vertical
MD
Inc
Azl
ND
NDSS
+N/-5
+E/ -W
DOo
(usft)
V)
V)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
(-/100-)
Section
Survey Tool Name
(ft)
(ft)
(ft)
15,180.16
86.59
289.19
5,85739
5,]52]9
3,020.86
-1259567
5,963,200.62
486,026.93
16.92
12,418.60
MWD(3)
15,211.35
8716
293.11
5,889.32
5,759.32
3,032.09
-12,624.70
5,963,21165
485,997.90
13.11
12,449.35
MWD (3)
15,235.69
86.49
295.01
5,890.54
5,755.54
3,042.00
-12,646.89
5,963221.76
485,975.71
9.38
12,473.53
MWD (3)
15,263.58
86.18
298.12
5,892.33
5,757.33
3,054.44
-12,67178
5,963,234.21
485,950.82
11.18
12,501.31
MWD(3)
15,295.77
85.76
298.24
5,894.59
5,759.59
3,06961
-12,700.09
5,963,249.38
485,922.53
1.36
12,533.40
MWD(3)
15,325.90
85.36
296.82
5,896.92
5,761.92
3,08349
-12,726.73
5,963,26327
485,895.89
4.88
12,563.41
MWD(3)
15,355.35
84.37
293.58
5,899.56
5,764.56
3,095.98
-12,753.26
5,963,27576
485,869.36
1146
12,592.64
MWD(3)
15,386.70
85.45
292.60
5,902.34
5,767.34
3,108.23
-12,781.99
5,963,28801
465,84064
4.64
12,623.64
MWD (3)
15,415.82
84.96
289.04
5,904.78
5,769.78
3,118.54
-12,809.10
5,963298.33
485,813.53
12.30
12,652.28
MWD (3)
15,449.21
85.82
289.36
5,907.46
5,772.46
3,129.48
-12,890.53
5,963,309.28
41
2.75
12,684.97
MWD(3)
15,48109
84.96
288.60
5,910.02
5,775.02
3,139.82
-12,870.58
5,963,319.62
485,75206
3.59
12,716.16
MWD (3)
15,511.05
85.76
287.43
5,912.4
5,777.44
3149.05
-12,898.98
5,963,328.8E
485,72367
4.72
12,745.37
MWD(3)
15,591]9
8665
286.40
5,914.48
5,779.48
3,157.98
-12,928.33
5,963,337.78
485,694.33
4.42
12,775.25
MWD(3)
15,56579
86.69
284.62
5,915.87
5.780.87
3,169.38
-12,951.41
5,963,344.19
41
7.41
12,798.44
MWD(3)
15,595.61
8601
283.35
5,917.77
5,782.77
3,171.58
-12,980.29
5,963,351.39
485,642.37
4.82
12,827.05
MWD (3)
15,630.81
8570
281.51
5,920.32
5,785.32
3,179.13
-13,014.57
5,963,358.95
485,608.09
5.29
12,860.52
MWD(3)
15,660.77
87.60
279.98
5,922.07
5,787.07
3,18471
-13,043.95
5,963,364.53
485,578.72
8.14
12,888.75
MWD (3)
15,690.91
89.42
279.15
5,922.85
5,787.85
3,189.71
-13,073.66
5,963,369.54
485,549.01
6.64
12,916.98
MWD(3)
15,720.81
90.83
278.15
5,922.79
5,787.79
3,194.21
-13,103.22
5,963,374.05
485,519.45
5.78
12,944.83
MWD (3)
15,750.76
90.34
276.13
5,922.48
5,787.48
3,197.93
-13,132.99
5,963,377.77
485,489.74
6.94
12,972.42
Mi (3)
15,777.93
i)o'm
274.98
5,922.32
5,787.32
3,200.56
-13,159.98
5,963,380.41
485,462.71
4.23
12,997.16
MWD(3)
15,810.67
90.71
271.90
5,922.02
5,787.02
3,202.53
-13,192.65
5,963,382.38
485,430.03
9.47
13,026.44
MWD(3)
15,840.72
90.55
269.59
5,921.69
5,786.69
3,202.92
-13,222.70
5,963,382.77
481
7.71
13,052.65
MWD (3)
15,873.47
89.51
26].69
5,921.67
5,786.67
3,202.14
-13,255.44
5,963,382.00
485,367.26
6.61
13,80.81
MWD(3)
15,502.09
91.54
266.89
5,921.41
5,786.41
3,200.79
-13,284.02
5.963,380.66
485,338.67
7.62
13,104.69
MWD(3)
15,930.85
90.58
263.61
5,920.88
5,785.88
3,198.41
-13,312.67
5,963,378.28
485,31003
11.88
13,128.32
MWD(3)
15,960.33
90.46
26084
5,920.61
5,785.61
3,194.42
-13,341.88
5,963,374.30
485,280.82
9.40
13,151.61
MWD(3)
15,985.69
88.50
256.54
5,920.84
5,785.84
3,189.46
-13,366.69
5,963,369.34
485,256.01
18.67
13,170.62
MM (3)
16,010.21
88.59
254.15
5,92146
5,786.46
3,183.24
-13,39045
5,963,363.13
485,232.25
9.73
13,188.09
MWD (3)
16,045.15
89.23
253.42
5,922.13
5,787.13
3,173.49
-1342399
5,963,353.38
485,198.71
278
13,212.26
MWD(3)
16,081.25
91.07
256.30
5,922.03
5787.03
3,16406
-13,458.84
5963,34396
485,16387
9.47
13237.72
MWD(3)
10/11/2017 4.'02:12PM
Page 4
SA�I§R ES
Annotation
COMPASS 5000.14 Build 85
ConocoPhillips
ER
I IIGNE$
ConocoPhillips
Definitive Survey Report
Company:
ConocoPhillips
(Alaska) Inc. -Kup2
Local Co-ordinate Reference:
Well 2A-22
Project:
Kuparuk River Unit
TVD Reference:
2A-22 (03 135.00usft
Site:
Kuparuk 2A Pad
MD Reference:
2A-22 @ 135.00usft
Well:
2A-22
North Reference:
True
Wellbore:
2A -22A
Survey Calculation Method:
Minimum Curvature
Design:
2A -22A
Database:
EDT Alaska Sandbox
Survey
._
Map
Map
Vertical
MD
Inc
Azl
TVD
TVDSS
+N1 -S
+E/ -W
DLS
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft)
Northing
Easting
()
Section
STool Name
Survey Y
Annotation
(ft)
(ft)
(ft)
! 16,111.45
92.33
258.90
5,921.14
5,786.14
3,157.58
-13,488.31
5,963,33749
485,134.39
9,%
13,260.01
MWD (3)
16,143.05
8773
261.33
5,921.12
5,786.12
3,152.16
-13,519.43
5,963,332.07
485,103.28
16.46
13,284.25
MWD (3)
16,170.71
88.65
263.58
5,921.99
5,786.99
3,148.53
-13,546.84
5,963,328.45
485,075.87
8.78
13,306.17
MWD (3)
16,201.13
87.51
264.88
5,923.01
5,788.01
3,145,47
-13,577.09
5,963,32540
485,045.63
5.68
13,330.84
MWD (3)
16,231.05
89.26
267.82
5,923.86
5,788.86
3,143.57
-13,606.93
5,963,323.50
485,015.79
11.43
13,355.73
MWD (3)
16,260.53
91.60
269.37
5,923.64
5,788.64
3,142.84
-13,636.40
5,963,322.78
484,985,32
9.52
13,380.89
MWD (3)
16,290.43
92.34
27308
5,92261
5,787.61
3,143.48
-13,666.27
5,963,323.43
484,956.46
12.65
13,407.08
MWD (3)
16,322.10
88.00
273.62
5,922.51
5,787.51
3,145.33
-13,697.88
5,963,325.28
484,924.85
13.81
13,435.37
MWD (3)
16,350.30
87.91
275.17
5,923.52
5,788.52
3,147.49
-13,725.97
5,963,327.45
484,896.76
5.50
13,460.79
MWD (3)
16,380.31
86.68
276.66
5,924.94
5,789.94
3,150.58
-13,755.79
5,963,330.54
484,866.94
6.43
13,488.15
MWD (3)
16,411.05
86.53
279.10
5,926.76
5,791.76
3,154.79
-13,786.18
5,963,334.75
484,836.55
7.94
13,516.58
MWD (3)
16,440.60
86.13
280.64
5,928.65
5,793.65
3,159.84
-13,815.24
5,963,339.81
484,807.51
5.37
13,544.27
MWD (3)
16,470.35
87.82
285.03
5,930.22
5,79522
3,166.44
-13,844.19
5,963,346.42
484,778.55
15.79
13,572.64
MWD (3)
16,500.25
86.83
287.09
5,931,61
5,796.61
3,174.70
-13,872.89
5,963,354.68
484,749.86
7.64
13,601.63
MWD(3)
16,530.42
86.53
289.09
5,933.36
5,798.36
3,184.05
A3,901.52
5,963,364.04
484,721.23
6.69
13,631.10
MWD (3)
16,560.38
85.42
291.48
5,93546
5,80047
3,194.41
-13,929.55
5,963,374.40
484,693.21
8.78
13,660.55
MWD (3)
16,590.33
84.80
293.51
5,938.02
5,80302
3,205.83
-13,957.12
5,963,385.82
484,665.64
7.06
13,690.14
MWD (3)
16,620.26
84.22
294.67
5,940.88
5,80508
3,217.99
-13,984.32
5,963,39799
484,638.45
4.32
13,719.77
MWD (3)
16,650.30
84.18
296.74
5,943.92
5,80892
3,230.95
-14,011.25
5,963,410,95
484,611.53
6.86
13,749.57
MWD (3)
16,680.35
8397
298.88
5,94702
5,81202
3,244.90
-14,037.68
5,963,424.90
484,585.10
7.12
13,779.44
MWD (3)
16,710.25
83.54
300.25
5,950.27
5,815.27
3,259.56
-14,063.53
5,963,439.57
484,559.25
4.78
13,809.16
MWD (3)
16,740.22
84.00
301.35
5,953.53
5,818.53
3,274.82
-14,089.12
5,963,454.83
484,533.67
3.96
13,838.95
MM (3)
16,770.20
85.73
301.46
5,956.21
5,821.21
3,290.38
-14,114.61
5,963,470.39
484,508.19
578
13,868.80
MWD (3)
16,800.12
88.40
300.35
5,957.74
5,822.74
3,30.72
-14,140.24
5,963,485]4
484,482.56
9.66
13,898.67
MM (3)
16,830.23
90.89
299.38
5,95].93
5,822.93
3,320.71
-14,166.35
5,963,500.73
484,456.45
8.87
13,928.78
MWD (3)
16,860.22
9286
298.62
5,956.95
5,821.95
3,335.24
-14,192.57
5,963,515.26
484,430.24
7.04
13,958.75
MAD (3)
16,890.34
93.38
297.33
5,955.31
5,820.31
3,349.35
-14,219.13
5,963,529.38
484,403.69
461
13,988.80
MWD (3)
16,920.33
94.43
296.25
5,953.26
5,818.26
3,362.84
-14,24584
5,963,542.87
484,376.99
5.02
14,018.67
MWD (3)
16,950.19
93.96
294.46
5,951.08
5,816.08
3,375.59
-14,27275
5,963,555.62
484,350.08
6.18
14,048.36.
MM (3)
16,980.23
94.80
292.82
5,94879
5,813.79
3,387.60
-14,300.18
5,963,56763
484,32265
6.12
14,078.12
MWD (3)
17,010.72
9375
29157
5,946.51
5,811.51
3,399.08
-14,328.33
5.963,579.12
484,294.50
535
14,106.24
MWD (3)
10/112017 4:02:
12PM
Page 5
COMPASS 5000.14 Build 85
ConocoPhillips
Well 2A-22
TVD Reference:
Company: ConocoPhillips (Alaska) Inc. -Kup2
MO Reference:
Project Kuparak River Unit
North Reference:
True
Site: Kuparuk 2A Pad
Minimum Curvature
Database:
Well: 2A-22
Section
Survey Tool Name Annotation
Wellbore: 2A -22A
(ft)
i Design: 2A -22A
i..
(ft)
3,409.47
-14,355.98
Survey-_-�-®
484,266.87
8.43
MD Inc Azi
TVD
TVDSS
(usft) V) (1)
(usft)
(usft)
17,040.29 92.18 28963
5,944.98
5,809.98
17,056.28 91.75 289.14
5,944.43
5,80943
17,092.00 91.75 289.44
5,943.34
5,808.34
ConocoPhillips
Definitive Survey Report
Local Co-ordinate Reference:
Well 2A-22
TVD Reference:
2A-22 @ 135.00usft
MO Reference:
2A-22 @ 135.00usft
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Database:
EDT Alaska Sandbox
13A,g
10/112017 4: 02: 12PM Page 6 COMPASS 5000.14 Build 85
Map
Map
Vertical
+N/ -S
(usft)
+E/ -W
(usft)
Northing
Easting
DLS
(=110p)
Section
Survey Tool Name Annotation
(ft)
(ft)
(ft)
3,409.47
-14,355.98
5,963,589.52
484,266.87
8.43
14,137.38
MWD(3)
3,414.78
-14,371.05
5,963,594.82
484,251.79
4.08
14,153.08
MWD (3)
3,426.48
-14,404.78
5,963,606.53
484,218.07
0.00
14,188.15
PROJECTED to TD
13A,g
10/112017 4: 02: 12PM Page 6 COMPASS 5000.14 Build 85
THE STATE
GOVERNOR BILL WALKER
Kai Starck
CTD Team Lead
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Cas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www,aogcc.olaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2A -22A
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 217-115
Surface Location: 4523' FNL, 5052' FEL, SEC. 13, TI IN, R8E, UM
Bottomhole Location: 711' FNL, 4468' FEL, SEC. 16, TI IN, R8E, UM
Dear Mr. Starck:
Enclosed is the approved application for permit to re -drill the above referenced development well.
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,
Cathy P. F erster
Commissioner
DATED this eday of September, 2017.
STATE OF ALASKA
AL/, -.,A OIL AND GAS CONSERVATION COMMIL _ON
PERMIT TO DRILL
20 AAC 25.005
EGEWLD
�!1 5 n 7 7017
1 a. Type of Work:
1 b. Proposed Well Class: Exploratory - Gas Ll Service - WAG ❑ Service - Disp ❑
1 c. Specify if well is proposed for:
Drill ❑ Lateral ❑
Stratigraphic Test ❑ Development- Oil Service - Winj ❑ Single Zone ❑�
Coalbed Gas ❑ Gas Hydrates ❑
Reddll ❑✓ ' Reentry ❑
Exploratory - Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond: Blanket ❑✓ . Single Well ❑
11. Well Name and Number
ConocoPhillips Alaska Inc
Bond No. 5952180,
2A -22A 1 %r [ i
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 18000 TVD: 5867
Kuparuk River Field / Kuparuk Oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation: I
Surface: 4523' FNL, 5052' FEL, SEC 13, T 11N, R 8E, UM
ADL025570, ADL025571
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
1745' FNL, 992' FEL, SEC 16, T 11 N, R 8E, UM
9318991000, 931892000
017 871/51/
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property: Vr
711' FNL, 4468' FEL, SEC 16, T 11 N, R 8E, UM
256g- 51aQ
710'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 135 •
15. Distance to Nearest Well Open
Surface: x- 498620 y- 5960177 Zone- 4
GL / BF Elevation above MSL (ft): 94 ,
to Same Pool: 2,048'
16. Deviated wells: Kickoff depth: 14,310 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 89 degrees
Downhole: 3832 • 11 Surface: 3245' ✓
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks
Hole Casing Weight Grade I Coupling Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 2950'
15,050' 5760 18,000' 5,867' Slotted Liner
19. PRESENT WELL CONDITION SUMMARY (To be completed for Reddll and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
14,797' 6,144' NA 14,340' 5,864' NA
Casing Length Size Cement Volume MD TVD
Conductor/Structural 80.00 16 250 sx ASI 121 121
Surface 4,887.00 9.625 820 sx AS III Lead, 890 sx Class G 4928 2937
Intermediate Tail
Production 14,749.00 7 260 sx Class G 14787 6138
Liner
Perforation Depth MD (ft): 14,302'-14,317', 14,330'-14,348', Perforation Depth TVD (ft): 5,836-5,844%5,852'-5,864'.
14,3521-14,378' 5,866'-5,882'
Hydraulic Fracture planned? Yes ❑ No P1
20. Attachments: Property Plat F-1 BOP SketchDrilling
Diverter Sketch
Program
e Seabed Report
e
Time v. Depth Plot
Drilling Fluid Program
e
Shallow Hazard Analysis
20 AAC 25.050 requirementsB
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval. Contact Name: Trevor Hyatt
Authorized Name: Kai Starck O Contact Email: trevor.nvauawntracmcconowoh'llbs corn
Authorized Title: TO Team Lead Contact Phone: 907-223-3087
"ion SE2(t;,,1L
Authorized Signature: ' Date: 41% 8f7/2017
Commission Use Only
Permit to Drill
API Number:
Permit Approval
See cover letter for other
Number: OL - 1 , j
t1
50- O3 - a r� Q _ U O
Date:
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: 3 p� �-� S 7' 7'0 { d 0 O 1 c{ Samples req'd: Yes ❑ No [?I Mud log req'd: Yes Nou
//9
r❑]
h r7 v ! a r i� I q HiS measures: Yes [r� Nor❑.T Directional svy req'd: Yes u No ❑
rCVf n 9 -n -S , / 2560
P pacing exception req'd: Yes ❑ No L+J Inclination -only svy req'd: Yes ❑ No ❑✓r_
4
Post initial injection MIT req'd: Yes ElNo
/ APPROVED BY
Approved b
COMMISSIONER THE COMMISSION Date: ..
Submit Form an
omi 10-401 R i z5/2017 {��i it�lska�id�rr �4 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
August 3, 2017
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
A1! a 7 ?017
A()CjGC
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill a dual -lateral out of the KRU 2A-22
(PTD# 195-068) using the coiled tubing drilling rig, Nabors CDR3-AC.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC
25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being
limited to 500' from the original point.
The CTD objective will be to drill two laterals (2A -22A & 2A-22AL1), targeting the Kuparuk C -sand intervals. The
work is scheduled to begin August 12th, 2017.
Attached to this application are the following documents:
- Permit to Drill Application Forms (10401) for 2A -22A & 2A-22AL1
- Detailed Summary of Operations
- Directional Plans for 2A -22A & 2A-22AL1
- Current wellbore schematic
- Proposed wellbore schematic
If you have any questions or require additional information, please contact me at 907-263-4109 (cell 907-223-3087).
Sincerely,
Trevor Hyatt
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kup/�aruk/� CTD Laterals
2A -22A & 2A-22AL1 NABORrALASKA
Application for Permit to Drill Document
1.
Well Name and Classification.............................................................................................................2
(Requrements of 20 AAC 25.050(b)).......................................................................................................................................................
6
(Requrements of 20 AAC 25.005(0 and 20 AAC 25.095(b)).................................................. ..........................................................
........ 2
2.
Location Summary...............................................................................................................................2
Attachment2: Current Well Schematicfor2A-22........................................................................................................................6
(Requrements of 20 AAC 25.005(c)(2))...................................................................................................................................................
2
3.
Blowout Prevention Equipment Information....................................................................................2
(Requrements of 20 AAC 25.005(c)(3)).......................................................................................... .....................................................
2
4.
Drilling Hazards Information and Reservoir Pressure....................................................................2
(Requrements of 20 AAC 25.005(c)(4))..................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests......................................................................
2
(Requrements of 20 AAC 25.005(c)(5))...................................................................................................................................................
2
6.
Casing and Cementing Program........................................................................................................
3
(Requrements of 20 AAC 25.005(c)(6))...................................................................................................................................................
3
7.
Diverter System Information..............................................................................................................
3
(Requrements of 20 AAC 25.005(c)(7))...................................................................................................................................................
3
8.
Drilling Fluids Program.......................................................................................................................3
(Requrements of 20 AAC 25.005(c)(8))...................................................................................................................................................
3
9.
Abnormally Pressured Formation Information................................................................................4
(Requrements of 20 AAC 25.005(c)(9))...................................................................................................................................................
4
10.
Seismic Analysis..................................................................................................................................4
(Requrements of 20 AAC 25.005(c)(10)).................................................................................................................................................4
11.
Seabed Condition Analysis................................................................................................................4
(Requrements of 20 AAC 25.005(c)(11)).................................................................................................................................................
4
12.
Evidence of Bonding...........................................................................................................................4
(Requrements of 20 AAC 25.005(c)(12)).................................................................................................................................................4
13. Proposed Drilling Program.................................................................................................................4
(Requrements of 20 AAC 25.005(c)(13))................................................................................................................................................. 4
Summaryof Operations.....................................................................................................................................................................4
LinerRunning......................................................................................................................................................................................6
14. Disposal of Drilling Mud and Cuttings..............................................................................................6
(Requrements of 20 AAC 25.005(c)(14))................................................................................................................................................. 6
15. Directional Plans for Intentionally Deviated Wells..........................................................................6
(Requrements of 20 AAC 25.050(b)).......................................................................................................................................................
6
16. Attachments.........................................................................................................................................6
Attachment l: Directional Plans for 2A-22A&2A-22AL1laterals .............................................................................................6
Attachment2: Current Well Schematicfor2A-22........................................................................................................................6
Attachment 3: Proposed Well Schematic for 2A-22A&2A-22AL1laterals .............................................................................6
Page 1 of 6 August 1, 2017
PTD Application: 2A -22A & 2A-22AL1
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 2A -22A & 2A-22AL1. All laterals will be classified as
"Development -Oil" wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the A and C sand packages in the Kuparuk reservoir. See attached 10-401 form for
surface and subsurface coordinates of the 2A -22A & 2A-22AL1.
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 CDR3-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 4,0P psi. Using the
maximum formation pressure in the area of 3,832 psi in 2A-20 (i.e. 12.46 ppg EMW), the maximum
potential surface pressure in 2A -22A, assuming a gas gradient of 0.1 psi/ft, would be 3,245 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details.
— The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 2A-22 was measured to be 2,962 psi (9.76 ppg EMW) on 11/7/2017. The
maximum downhole pressure in the 2A-22 vicinity is tothe east in the 2A-21 injector at 3,636 psi (11.7 ppg
EMW) from 07/07/2007.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
The offset injection wells to 2A-22 have historically injected gas to the west and southwest.There is a small
probability of encountering free gas while drilling the 2A -22A laterals. If significant gas is detected in the returns
the contaminated mud can be diverted to a storage tank away from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 2A -22A laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 2A -22A laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation
integrity test is not required.
Page 2 of 6 August 3, 2017
PTD Application: 2A -22A & 2A-22AL1
6. Casing and Cementing Program
(Requirements of 20 AA 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
LinerBtm
Liner Top
LinerBtm
Liner Details
MD
MD
TVDSS
TVDSS
2A -22A
15,050'
18,000'
5,760'
5,867'
2-3/8", 4.7#, L-80, ST -L slotted liner;
aluminum billet on to
2A-22AL1
14,240'
18,000'
5,660'5,867`
2-3/8", 4.7#, L-80, ST -L slotted liner;
de to ment sleeve
Diverter System Information
(Requirements of 20 AA 25.005(c)(7))
Nabors CDR3-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 AA 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
— Window milling operations: Chloride -based FloVis mud (8.6 ppg)
— Drilling operations: Chloride -based FloVis mud (8.6 ppg). This mud weight wi/I not hydrostatically
overbalance the reservoir pressure, overbalanced conditions will be maintained using MPD practices
described below
— Completion operations: The well will be loaded with 11.8 ppg NaBr completion fluid in order to provide
formation over -balance and well bore stability while running completions.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole 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 5,000 psi rated coiled
tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 2A -22A laterals we will target a constant BHP of 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 6 August 3, 2017
PTD Application: 2A -22A & 2A-22AL1
Pressure atthe 2A -22A Window H4.310 MD and 5.705' TVDI Using MPn
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.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 2A-22 is a Kuparuk A and C sand producer equipped with 3-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize two laterals to target the A and C sands to the west of 2A-22. The
laterals will increase resource recovery and add new resources.
Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 14,227'
MD and the D nipple at 14,242' MD will be milled out to a 2.80" ID. The existing A and C sand
perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a
means to kick out of the 7" casing.
Following the cement squeeze, Nabors CDR3 will drill a cement pilot hole to 14,340' MD and set a
mechanical whipstock in the 2.80" pilot hole at the planned kick off point of 14,310' MD.
The 2A -22A lateral will exit through the 7" at 14,310' MD and TD at 18,000' MD, targeting the A and C
sands to the west. It will be completed with 2-3/8" slotted liner from TD up to 15,050' MD with an
aluminum billet for kicking off the 2A-22AL1 lateral.
The 2A-22AL 1 lateral will drill to a TD of 18,000' MD targeting the A and C sands. It will be completed
with 2-3/8" slotted liner from TD up inside 3-1/2" tubing tail to 14,240' MD with a deployment sleeve.
Page 4 of August 3, 2017
Pumps On 1.5 bpm)
Pumps Off
A/C -sand Formation Pressure 9.76
2895 psi
2895 psi
Mud Hydrostatic 8.6
2551 psi
2551 psi
Annular fiction i.e. ECD, 0.09 si/ft)
1288 psi
0 psi
Mud + ECD Combined
no chokepressure)
3839 psi
overbalanced -944psi)
2551 psi
underbalanced -344psi)
Target BHP at Window 11.8
3500 psi
3500psi
Choke Pressure Required to Maintain
Tar et BHP 1
0 psi
949 psi
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.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 2A-22 is a Kuparuk A and C sand producer equipped with 3-1/2" tubing and 7" production
casing. The CTD sidetrack will utilize two laterals to target the A and C sands to the west of 2A-22. The
laterals will increase resource recovery and add new resources.
Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail below the packer at 14,227'
MD and the D nipple at 14,242' MD will be milled out to a 2.80" ID. The existing A and C sand
perforations will be squeezed with cement and the 3-1/2" tubing tail will be cemented in place to provide a
means to kick out of the 7" casing.
Following the cement squeeze, Nabors CDR3 will drill a cement pilot hole to 14,340' MD and set a
mechanical whipstock in the 2.80" pilot hole at the planned kick off point of 14,310' MD.
The 2A -22A lateral will exit through the 7" at 14,310' MD and TD at 18,000' MD, targeting the A and C
sands to the west. It will be completed with 2-3/8" slotted liner from TD up to 15,050' MD with an
aluminum billet for kicking off the 2A-22AL1 lateral.
The 2A-22AL 1 lateral will drill to a TD of 18,000' MD targeting the A and C sands. It will be completed
with 2-3/8" slotted liner from TD up inside 3-1/2" tubing tail to 14,240' MD with a deployment sleeve.
Page 4 of August 3, 2017
PTD Application: 2A -22A & 2A-22AL1
Pre -CTD Work
1. Slickline (Fullbore assist):
a. Dummy GLVs
b. Injectivity Test
2. Coil:
a. Obtain GR/CCLjewehy log and memory caliper log above tag
b. Perf tubing tail
c. Mill D nipple and tag TD for depth control
d. Lay in Cement Plug (7" casing up to tubing tail)
3. Slickline:
a. Tag TOC
b. Pressure Test Cement Squeeze and Negative Test
Rig Work
2. MIRU Nabors Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
3. 2A -22A Lateral (A and C sand)
a. Drill 2.80" pilot hole through cement to 14,340' MD
b. Caliper pilot hole
c. Set top of whipstock at 14,310' MD and mill 2.80" window
d. Drill 3" bi-center lateral to TD of 18,000' MD.
e. Run 2%" slotted liner with an aluminum billet from TD up to 15,050' MD.
4. 2A-22AL1 Lateral (A and C sand)
a. Kick off the aluminum billet at 15,050' MD.
b. Drill 3" bi-center lateral to TD of 18,000' MD.
c. Run 2%" slotted liner with deployment sleeve from TD up into 3-1/2" production tubing to
14,240' MD.
5. Freeze protect, ND BOPE, and RDMO Nabors CDR3- AC rig.
Post -Rig Work
1. Obtain SBHP.
2. Install gas lift design.
3. Return to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab vanes on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, double deployment rams, double check valves and double ball vanes 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 property, 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
Page 5 of August 3, 2017
PTD Application: 2A -22A & 2A-22AL7
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
- The 2A -22A laterals will be displaced to an overbalancing fluid (11.8 ppg NaBr) prior to running liner. See
"Drilling Fluids" section for more details.
- While running 2-3/8" slotted liner, a joint of 2-3/8" 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 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well. 1
• 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 (1R-18
or 1B 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).
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 Plans
- Magnetic and inclination surveys will be taken every 30 ff. No gyro will be run. I
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary atclosest point)
Name
Distance
liLateral
2A -22A
710'
2A-22AL1
850'
- Distance to Nearest Well within Pool
Lateral Name Distance Well
2A -22A 2048' 2T-36*
2A-22AL1 2059' 2T-36*
*1490' West Sa k 18 is P&A'd
16. Attachments
Attachment 1: Directional Plans for 2A -22A & 2A-22AL1 laterals
Attachment 2: Current Well Schematic for 2A-22
Attachment 3: Proposed Well Schematic for 2A -22A & 2A-22AL1 laterals
Page 6 of 6 August 3, 2017
KUP PROD 2A-22
Lon0C0YI
Well Attributes _
MaxAngleBMD ITD
Alaska l(N:
WellpareAFIIIMII FINtl Nemo Wallpore 51alu5
ncl l'1 MpItIK81 ACI Bfm (NNBI
501032022100 KUPARUK RIVER UNIT PROP
)589 4,189.53 14,]9]0
C.R. N35(ppm) Oah
SSSV: NIPPLE 120 12/52016
Mnolallon Entl Oah
Last WO'. 9292014
KBGN IN) Rig RNeaxpale
4590 6/11/1995
a-a.enrmn 4e4g1 PM
venrcelwMmam actua
Annohllon Schell Enapale
AnneWbn LaAMM Be Ena psfe
.... ._._ _
Last Tag'. RKB 14,340.0 BI6201]
Rev Reason: HTS. TAG pploven 61)201]
NANGER:35.0
as
Casing DR-ption CO(Ini m(n) Top ml(B) eo-o`dd`111 "I lop/ 11,1... 1%, ll.. Gh4e
Top TM1raN
CONDUCTOR 16 15082 41.0 1210 1210 62.58 HIO
WELDED
Caring Deecriplion Wllnl I011nl iop (XXB) "'NiNB) $eLDMM1 ITVOL�� WVLen 11... --
TOP "-d
SURFACE 95/ 8.035 40.9 4,9280 2,936.] 40.00 L80
BTC
Op 9n) IDlin) Top IXXB) SH pepIM1 (flNpl SN Degn lNpl... WVLen I1... GrNe
Top TM1reaa
PRC---
PRODDCTION ) 8.2]6 36.3 14.]8]0 6.13].6 2600 L00
BTC -MOD
Tubing Strings
cOxpuci0R,4tanplq
tubing Minion slnng M,,,,jIDdnl Top ONS' set pepm ln.. sel Depth Tvpl-. wymm) Graae Top eonnMion
TUBINGWO-2014 31/2 2992 364 14,2125 5,]800 9,30 L-60 EUE BRtl
Completion Details
Nominal lD
Top lnl(5) Top(Np) 364 Top ln0,06 ISERes Com I2
NIPPLE,53Rfi
384 36.4 O.Ofi HANGER FMC TUBING HANGER 2992
5326 532.6 1.64 NIPPLE DS NIPPLE 2,812
14,072.2 5,698.7 56.28 LOCATOR LOCATORSUB 2.970
NI2N1S
14,073.2 5,899.2 5626 SEALASSY SEALASSY..STICK-UP=]fi. SWALLOW=146-X 3.006
1,1,079.5 6,7027 56.10 PER BAKER POLISH BORE RECEPTACLE 2OaO
14,1026 5,)15.] 55.54 PACKER BAKER FHL RETRIEVABLE PACKER 2030
14,152.9 5,7446 54.31 NIPPLE CAMCO ON NIPPLE 2.812
14,205.4 5,7157 308 OVERSHOT POOR BOY OVERSHOT ...SWALLOW =85-X. 3.620
SURFACE', 4044.8]9.0-
Tuping Oescrhnon SMn9 N. 1101in1 Top(XKBI SN Depth W. set Depin I TW ...Wt(IWN) Gratle Tap Gonnxllan
TUBING Original 31/2 2.992 1420]0 16,2646 58110 9.30 L-80 ABM EUE
Completion Details -- -
Nominal IC
Top(nHBI Top(rvDl lnKel Topm260 nemoez Com pnl
MI TRIOS
14,225.0 5]690 5260 SEAL ASSY BARER KB -k22 ANCHOR SEAL ASSY 3000
t 4,226] 5,]086 52.58 PACKER BARER SAB -3 PERMANENT PACKER 3260
14,242.0 5,)8].9 52.22 NIPPLE CAMCO D LANDING NIPPLE NO GO 2150
MaMeHO B]4
14,262.] 5,8106 5173 WtE6 WIRELINE ENTRY GUIDE ELMD L�14258'ON SWS 2.992
PERF 6/17/2001
Perforations & Slots
SM1m
NweNt lzg3.0
rp.KBO
BlMKID
Lens
(snC
Tp1, INNER4,302
BIm IXKe)
(x,01
m1.8
m
Rae
0
Type
con
16,]020
14,3110
5,835.1
5,844.4
-n.2
CJ.2A-22
6/28/2000
40 APERF
21I2'NSD CA, 100 Dag
p11
14.3300
14,3480
5.8526
5,863.6
C4,2M22
6/172001
4.0 APERF
2.5-HSDABemaling
Manb.l. 14.017 9
BI 180 deg phae.
14,3520
14,3)0.0
5,8616.1
5.8823
A -3 ,2A-22
611211995
4.0 ]PERF
SWS TCPType SH UP;
180 deg phI oriented 90
CCW)/highside
Stimulations & Treatments
LOCATOR:II,nR]
proppanl U-dI`N(h) Proppe,I In Formation(lb) Dale
SM ASSY: 14.on.2
12ro2002
PM 14o]as
Stimulations & Treatments
1ACKER:14,10 11
$Ige
iop'tl
71Rale
$Iimlirnl Hit.]bbl)
Vol clean Pump
VOI 51ulry(bEll
1
1 302.0
1 d, 3) 8.0 12/9/2002
Mandrel Inserts
SL
.11
NIPPLE: I4.I Si.e
on Tap(ND)
N Top(I (MIN Mall Model
OD1in1 Sery
Valve
Te.
Lath Porl$lie
Type en)
TRO Run
4 Run Date
Com
1 3.361.5 2,5032 GPMCO KBMG
1 GAS LIFT
GLV
BK 0.1%
1.349.0 12/1512014
2 1.553.9 3,]0).5 CAMCO KBMG
1 GAS LIFT
OV
BK 0.188
0.0 12/152014
ONCRSNOT', 143 .4
3 10.]5].4 6,808.1 CAMGO KBMG
1 GAS LIFT
DMY
BK 0000
0.0 101282014
EXTE
NDED
PKG
SEAL ASSV: 14,28 .8
d 12.955.0 5.2518 CAMCO KBMG
1 GAS LIFE
ONY
BK5 0.000
00 9/30/2014
PACKER', 14,Y13.T
5 10,0119 6,6690 CAMCO KBMG
JIGLIFT
DMY
OK5 0000
Oq 9/30/2014
Notes: General & Safe
Erin Dae AnmLYan
6'12008 NOTE', TUG PUNCH BETWEEN SAB -3 PACKER 8 CA -2 PLUG 1N TERING STUB. 9 SHOTS
BINNTRPNCEH0LE0FO.19
xIPPLE: to 2RO
wIE
i 1192008 NOTE:View SchelmOc in, Alaska SCISSIBic9.0
111512014 NOTE: 2.81 -CS N.P. ®14152' RKP MAY BE DAM4GED FROM PULLING PLUG ON 11 514
WLEG: 142fi3]
APERF', 143082,0.14317.0
APERF:14OOD. 143180
FRAC, 14.3020
IPERF', 14,3520.143700
PRODUCTION;NS-14,]6].O
2A-22 Proposed CTD Schematic
16"62# H-40 shoe
@ 1 21'MD
9-5/8" 401t L-80
shoe @ 4928' MD
C/A -sand penis
14,302'- 14,317' MD
14,330' - 14,348' MD
14,352' - 14,378' MD
7" 26# L-80 shoe
@ 14,787' MD
3-1/2" DS Nipple (min ID 2.812") @ 532.6' MD
3-1/2" 9.3# L-80 EUE 8rd Tubing to surface
3-1/2" Camco MMG gas lift mandrel @ 3342', 7554',
10,757',12,955', and 14,018'
Baker 3-1/2" PBR @ 14,080' MD (2.98" ID)
Baker FHL packer @ 14,103' MD (2.93" ID)
3-1/2" Camco DS landing nipple @ 14,153' MD (2.812"
min ID, No -Go)
Poor Boy Overshot @ 14,205'
Baker KBH-22 Anchor SA @ 14,226' MD
Baker SAB -3 Packer @ 14,227
3-1/2" Camco D landing nipple @ 14,242' MD (2.75" min
ID, No -Go) Needs to be milled out to 2.80" ID
3-1/2" WLEG @ 14,263' MD
2A-22AL1 wp02
TD @ 18.000' MD
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A-22
2A -22A i
Plan: 2A-22A_wp03
Standard Planning Report
02 August, 2017
BA ER
BAT
GE comoanv
ConocoPhillips BAILER
ConocoPhillips Planning Report IGHES
BAT
GEmmpa,
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Site:
Kuparuk 2A Pad
Well:
2A-22
Wellbore:
2A -22A
Design:
2A-22A_wP03
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 2A-22
Mean Sea Level
2A-22 @ 135.00usft
True
Minimum Curvature
rroject Kuparuk River Unit, North Slope Alaska, United States
Aap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Aap Zone: Alaska Zone 04 Using geodetic scale tactor
Kuparuk 2A Pad
Site Position: Northing: 5,960,138.24 usft Latitude:
From: Map Easting: 498,621.00 usft Longitude:
Position Uncertainty: 0.00 usft Slot Radius: 0.000in Grid Convergence:
Well
2A-22
Well Position
-NAS
0.00 usft Northing:
+ENW
0.00 usft Easting:
Position Uncertainty
Measured
0.00 usft Wellhead Elevation:
TVD Below
Wellbore
2A -22A
Build
Magnetics
Model Name
Sample Date
Inclination
BGGM2017 11/1/2017
System
Design
2A-22A_wP03
---
Audit Notes:
Rate
TFO
Version:
(°)
Phase: PLAN
Vertical Section:
(usft)
Depth From (TVD)
(°1100ft)
(°1100ft)
(usft)
(°) Target
14,266.49
-94.30
5,960,177.75 usft Latitude:
498,620.78 usft Longitude:
usft Ground Level:
Declination Dip Angle
1728
+N/ -S
(usft)
0.00
Tie On Depth:
+E/ -W
(usft)
0.00
70° 1F8 367 N
150° 0'40.211 W
-0.01 °
70° 18'8.7 56 N
150° 0'40.217 W
94.30 usft
Field Strength
(nT)
80.87 5747524
14 26649
Direction
(°)
30000
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(°1100ft)
(°1100ft)
(°1100ft)
(°) Target
14,266.49
51.64
281.36
5,678.01
2,780.89
-11,747.50
0.00
0.00
0.00
0.00
14,310.03
51.62
281.27
5,705.04
2,787.59
-11,780.98
0.17
-0.05
-021
-105.85
14,331.03
55.82
281.27
5,717.46
2,790.89
-11,797.57
20.00
20.00
0.00
0.00
14,412.36
88.35
281.27
5,742.14
2,805.82
-11,872.45
40.00
40.00
0.00
0.00
14,612.36
88.40
295.28
5,747.85
2,868.34
-12,061.81
7.00
0.02
7.00
90.00
14,900.00
88.50
275.13
5,755.72
2,943.36
-12,337.86
7.00
0.03
-7.00
270.00
15,200.00
88.60
296.14
5,763.41
3,023.75
-12,625.05
7.00
0.03
7.00
90.00
15,600.00
88.76
268.13
5,772.82
3,106.99
-13,012.12
7.00
0.04
-7.00
270.00
15,900.00
88.84
269.14
5,779.17
3,151.77
-13,306.99
7.00
0.03
7.00
90.00
16,200.00
88.92
268.13
5,785.09
3,196.56
-13,601.88
7.00
0.03
-7.00
270.00
16,650.00
87.51
299.62
5,799.46
3,303.02
-14,033.05
7.00
-0.31
7.00
93.00
17,000.00
86.49
275.11
5,818.05
3,406.56
-14,364.07
7.00
-0.29
-7.00
267.00
17,450.00
87.01
306.65
5,844.21
3,564.69
-14,778.52
7.00
0.11
7.01
90.00
17,700.00
87.15
289.13
5,857.05
3,681.03
-14,998.32
7.00
0.06
-7.01
270.00
18,000.00
88.77
310.08
5,867.86
3,828.34
-15,257.51
7.00
0.54
6.98
86.00
822017 12:16:57PM Page 2 COMPASS 5000.14 Build 85
i
ConocoPhillips HATER
vE
ConocoPhillips Planning Report UGHES
a GEmmpar
Database:
EDT Alaska
Sandbox
Local Co-ordinate Reference:
Well 2A-22
Company:
ConocoPhillips (Alaska)
Inc. -Kup2
TVD Reference:
Mean
Sea Level
Project:
Kuparuk River Unit
MD Reference:
2A-22
@ 135.00usft
Site:
Kuparuk 2A Pad
North Reference:
True
Well:
2A-22✓
Survey Calculation Method:
Minimum
Curvature
Wellbore:
2A -22A
Design:
2A-22A_wp03
-
Planned Survey
- --
�-
------
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
i Depth Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(9
V)
(usft)
(usft)
(usft)
(usft)
(-1100ft)
(°)
(usft)
(usft)
14,266.49
51.64
281.36
5,678.01
2,780.89
-11,747.50
11,564.08
0.00
0.00
5,962,960.52
486,874.96
TIP
14,300.00
51.62
281.29
5,698.81
2,786.05
-11,773.26
11,588.97
0.17
-105.85
5,962,965.68
486,849.20
14,310.03
51.62
281.27
5,705.04
2,787.59
-11,780.98
11,596.42
0.17
-105.81
5,962,967.22
486,841.49
KOP
14,331.03
55.82
281.27
5,717.46
2,790.89
-11,797.57
11,612.45
20.00
0.00
5,962,970.53
486,824.90
End 20
dls, Start 40 its
14,400.00
83.41
281.27
5,741.26
2,803.41
-11,860.37
11,673.08
40.00
0.00
5,962,983.05
486,762.11
14,412.36
68.35
281.27
5,742.14
2,805.82
-11,872.45
11,684.75
40.00
0.00
5,962,985.46
486,750.03
End 40
ills, Start 7 dls
14,500.00
88.36
28741
5,744.66
2,827.50
-11,957.29
11,769.07
7.00
90.00
5,963,007.16
486,665.21
14,600.00
88.39
294.41
5,747.50
2,863.15
-12,050.61
11,867.71
7.00
89.82
5,963,042.83
486,571.90
14,612.36
88.40
295.28
5,747.85
2,868.34
-12,061.81
11,880.01
7.00
89.62
5,963,048.02
486,560.70
6
14,700.00
88.41
289.14
5,750.29
2,901.44
-12,142.89
11,966.77
7.00
-90.00
5,963,081.13
486,479.64
14,800.00
88.44
282.14
5,753.04
2,928.37
-12,239.09
12,063.55
7.00
-89.83
5,963,108.07
486,383.45
14,900.00
88.50
275.13
5,755.72
2,943.36
-12,337.86
12,156.58
7.00
-89.64
5,963,123.08
486,284.70
6
15,000.00
88.51
282.14
5,758.34
2,95B.36
-12,436.63
12,249.62
7.00
90.00
5,963,138.10
486,185.94
15,100.00
88.54
289.14
5,760.91
2,985.29
-12,532.84
12,346A0
7.00
89.82
5,963,165.04
486,089.74
15,200.00
88.60
296.14
5,763.41
3,023.75
-12,625.05
12,445.49
7.00
89.64
5,963,203.51
485,997.55
7
15,300.00
88.61
289.14
5,765.86
3,062.21
-12,717.26
12,544.57
7.00
-90.00
5,963,241.99
485,905.36
15,400.00
88.64
282.14
5,768.26
3,089.14
-12,813.47
12,641.36
7.00
-89.83
5,963,268.93
485,809.16
15,500.00
88.69
275.13
5,770.60
3,104.14
-12,912.24
12,734.40
7.00
-89.86
5,963,283.95
485,710.40
15,600.00
88.76
268.13
5,772.82
3,106.99
-13,012.12
12,822.32
7.00
-89.50
5,963,286.82
485,610.53
8
15,700.00
68.77
275.13
5,774.98
3,109.84
-13,111.99
12,910.24
7.00
90.00
5,963,289.68
485,510.67
15,800.00
88.80
282.14
5,777.10
3,124.84
-13,210.77
13,003.29
7.00
89.85
5,963,304.70
485,411.90
15,900.00
88.84
289.14
5,779.17
3,151.77
-13,306.99
13,100.08
7.00
89.70
5,963,331.65
485,315.70
9
16,000.00
88.85
282.14
5,781.16
3,178.70
-13,403.21
13,196.87
7.00
-90.00
5,963,358.60
465,219.49
16,100.00
88.88
275.14
5,783.16
3,193.71
-13,502.00
13,289.93
7.00
-89.86
5,963,373.62
485,120.72
16,200.00
88.92
268.13
5,785.09
3,196.56
-13,601.88
13,377.85
7.00
-89.72
5,963,376.48
485,020.85
10
16,300.00
8B.56
275.13
5,787.29
3,199.40
-13,701.75
13,465.76
7.00
93.00
5,963,379.34
484,920.99
16,400.00
88.23
262.12
5,790.09
3,214.38
-13,800.52
13,558.79
7.00
92.85
5,963,394.34
484,822.23
16,500.00
87.92
289.12
5,793.46
3,241.27
-13,896.71
13,655.54
7.00
92.65
5,963,421.25
484,726.06
16,600.00
87.64
296.12
5,797.34
3,279.68
-13,988.89
13,754.57
7.00
92.41
5,963,459.67
464,633.89
16,650.00
87.51
299.62
5,799.46
3,303.02
-14,033.05
13,804.49
7.00
92.14
5,963,483.02
484,589.74
11
16,700.00
87.33
296.12
5,801.71
3,326.37
-14,077.20
13,854.39
7.00
-93.00
5,963,506.37
484,545.60
16,800.00
87.01
289.12
5,806.65
3,364.76
-14,169.33
13,953.38
7.00
-92.84
5,963,544.77
484,453.48
16,900.00
86.73
282.11
5,812.12
3,391.62
-14,265.44
14,050.04
7.00
-92.50
5,963,571.65
484,357.39
17,000.00
86.49
275.11
5,818.05
3,406.56
-14,364.07
14,142.93
7.00
-92.11
5,963,586.61
484,258.77
12
17,100.00
86+52
282.12
5,824.15
3,421.50
-14,462.70
14,235.82
7.00
90.00
5,963,601.56
484,160.15
17,200.00
86.80
289.13
5,830.16
3,446.37
-14,558.77
14,332.45
7.00
89.57
5,963,628.44
484,064.10
17,300.00
86.73
296.14
5,835.99
3,486.76
-14,650.85
14,431.39
7.00
89.15
5,963,666.85
483,972.03
17,400.00
86.90
303.15
5,841.56
3,536.12
-14,737.57
14,531.17
7.00
88.74
5,963,716.22
483,885.33
17,450.00
87.01
306.65
5,844.21
3,564.69
-14,778.52
14,580.91
7.00
88.35
5,963,744.79
483,844.40
13
822017 12.16.57PM
Page 3
COMPASS 5000.14 Build 85
ConocoPhillips BA_ ICER
ConocoPhillips Planning Report h' IGHES
aGEmmpany
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Site:
Kuparuk 2A Pad
Well:
2A-22
Wellbore:
2A -22A
Design:
2A -22A wp03
Planned Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 2A-22
Mean Sea Level
2A-22 @ 135.00usft
True
Minimum Curvature
Measured
0.00 0.00 0.00
3,873.131,124,941.02
TVD Below
- plan misses target center by 1136703.23usft at 14266.49usft
MD (5678.01
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/ -S
+EI -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(°)
(>)
(usft)
(usft)
(usft)
(usft)
(°1100ft)
(°)
(usft)
(usft)
17,500.00
BZ02
303.15
5,846.82
3,593.25
-14,819.46
14,630.66
7.00
-90.00
5,963773.36
483,803.46
17,600.00
87.06
296.14
5,851.99
3,642.61
-14,906.20
14,730.46
7.00
-89.82
5,963,822.74
483,716.74
17,700.00
87.15
289.13
5,857.05
3,681.03
-14,998.32
14,829.44
7.00
-89.45
5,963,861.16
483,624.63
14
5,962,810.14
Point 12
0.00
-1,135.39
3,078.57
5,962,708.16
Point 13
0.00
-1,218.34
3,352.62
17,800.00
87.66
296.12
5,861.59
3,719.44
-15,090.47
14,928.45
7.00
86.00
5,963,899.58
483,532.50
17,900.00
88.20
303.10
5,865.21
3,768.79
-15,177.30
15,028.32
7.00
85.68
5,963,948.94
483,445.69
18,000.00
88.77
310.08
5,867.86
3,828.34
-15,257.51
15,127.56
7.00
85.43
5,964,008.51
483,365.50
Planned TD at 18000.00
0.00
5,963,844.00
''. Targets
_ --
Target Name
-hit/miss target
Dip
Angle Dip
Dir. TVD
-NI-S
+E/ -W
Northing
Easting
-Shape
(°) C)
(usft)
(usft)
(usft)
(usft)
(usft)
La0tude
Longkutle
2A-22 CTD Polygon
0.00 0.00 0.00
3,873.131,124,941.02
5,963,844.00
- plan misses target center by 1136703.23usft at 14266.49usft
MD (5678.01
TVD, 2780.89 N, -11747.50 E)
- Polygon
Point 1
0.00
0.00
0.00
5,963,844.00
Point
0.00
215.91
462.10
5,964,059.97
Point
0.00
-70.15
-594.04
5,963,773.97
Point
0.00
-174.11
-378.00
5,963,669.98
Points
0.00
-334.04
47.93
5,963,510.00
Point
0.00
-713.94
550.22
5,963,130.03
Point
0.00
-1,040.82
1,204.36
5,962,803.06
Point
0.00
-1,120.68
1,858.45
5,962,723.09
Point
0.00
-1,089.63
2,048.46
5,962,754.10
Point 10
0.00
-1,011.55
2,366.47
5,962,832.12
Point 11
0.00
-1,033.48
2,638.51
5,962,810.14
Point 12
0.00
-1,135.39
3,078.57
5,962,708.16
Point 13
0.00
-1,218.34
3,352.62
5,962,625.17
Point 14
0.00
-1,041.31
3,381.58
5,962,802.17
Point 15
0.00
-895.39
2,974.51
5,962,948.15
Point 16
0.00
-732.51
2,380.41
5,963,111.13
Point 17
0.00
-423.83
891.19
5,963,420.05
Point 18
0.00
-227.92
448.10
5,963,616.02
Point 19
0.00
0.00
1.00
5,963,844.00
Point 20
0.00
0.00
0.00
5,963,844.00
1,623,450.00
1,623,450.00
1,622,987.99
1,622,856.01
1,623,072.01
1,623,402.01
1,624,000.03
1,624,654.05
1,625,308.06
1,625,498.06
1,625,816.05
1,626,088.06
1,626,528.05
1,626,802.06
1,626,831.05
1,626,424.05
1,625,830.04
1,624,341.02
1,623,898.01
1,623,451.00
1,623,450.00
2A-22A_T02 0.00 0.00 5,819.00 3,350.221,125,766.20 5,963,321.00 1,624,275.00
- plan misses target center by 1137513.85usft at 14266.49usft MD (5678.01 TVD, 2780.89 N, -11747.50 E)
- Point
2A-22A_T03 0.00 0.00 5,859.00 3,652.141,125,155.08 5,963,623.00 1,623,664.00
- plan misses target center by 1136902.93usft at 14266.49usft MD (5678.01 TVD, 2780.89 N, -11747.50 E)
- Point
2A -22A T04 0.00 0.00 5,867.00 3,786.111,124,893.03 5,963,757.00 1,623,402.00
- plan misses target center by 1136640.99usft at 14266.49usft MD (5678.01 TVD, 2780.89 N, -11747.50 E)
- Point
2A-22A_T01 0.00 0.00 5,786.00 3,167.351,126,541.31 5,963,138.00 1,625,050.00
- plan misses target center by 1138288.88usft at 14266.49usft MD (5678.01 TVD, 2780.89 N, -11747.50 E)
- Point
70° 5'3.751 N 140° 58' 1.407 W
70" 4'57.472 N 140° 57'40.128 W
70° 5' 1.293 N 140" 57'56.250 W
70° 5'2.975 N 140° 58'3.145 W
70° 4'541.568 N 140° 57'
&22017 12:16:57PM Page 4 COMPASS 5000.14 Build 85
ConocoPhillips BA ER
ConocoPhillips Planning Report IUGHES
a GE cornpany
Database:
EDT Alaska Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Site:
Kuparuk 2A Pad
Well:
2A-22
Wellbore:
2A -22A
Design:
2A -22A wp03
Casing Points
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 2A-22
Mean Sea Level
2A-22,@ 135.00usft
True
Minimum Curvature
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
18,000 00
5,867.86 2 3/8"
2.375
3.000
a22017 12.16:57PM Page 5 COMPASS 5000.14 Build 85
1
Vertical
Local Coordinates
Depth
+N/ -S
+E/ -W
Fi
(usft)
(usft)
(usft)
Comment
9
5,678.01
2,780.89
-11,747.50
TIP
3
5,705.04
2,787.59
-11,780.98
KOP
03
5,717.46
2,790.89
-11,797.57
End 20 dls, Start 40 dIS
36
5,742.14
2,805.82
-11,872.45
End 40 cls, Start 7 dls
14,612.36
5,747.85
2,868.34
-12,061.81
5
14,900.00
5,755.72
2,943.36
-12,337.66
6
15,200.00
5,763.41
3,023.75
-12,625.05
7
15,600.00
5,772.82
3,106.99
-13,012.12
8
15,900.00
5,779.17
3,151.77
-13,306.99
9
16,200.00
5,785.09
3,196.56
-13,601.88
10
16,650.00
5,799.46
3,303.02
-14,033.05
11
17,000.00
5,818.05
3,406.56
-14,364.07
12
17,450.00
5,844.21
3,564.69
-14,778.52
13
17,700.00
5,857.05
3,681.03
-14,998.32
14
18,000.00
5,867.86
3,828.34
-15,257.51
Planned TD at 18000.00
a22017 12.16:57PM Page 5 COMPASS 5000.14 Build 85
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ConocoPhillips
ConocoPhillips (Alaska) Inc.
-Kup2
Kuparuk River Unit
Kuparuk 2A Pad
2A-22
2A -22A
2A-22A_wp03
Travelling Cylinder Report
02 August, 2017
BT�a
GHES
GE company
Baker HugheslNTEQ BA (ER
ConocoPhillips Travelling Cylinder Report i IUGHES
GE conpany
Company:
Conocor hillips (Alaska) Inc. -Kup2
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 2A Pad
Site Error:
0.00 usft
Reference Well:
2A-22
Well Error:
0.00 usfl
Reference Wellbore
2A -22A
Reference Design:
2A-22A_wp03
Local Co-ordinate Reference:
Wel] 2A-22
TVD Reference:
2A-22 @ 135.00usft
MD Reference:
2A-22 @ 135.00usft
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
OAKEDMP2
Offset TVD Reference:
Offset Datum
teference
2A-22A_Wp03
:ilter type:
GLOBAL FILTER APPLIED: All weilpaths within 200'+ 100/1000 of reference
nterpolation Method:
MD Interval 25.00usft Error Model: ISCWSA
3epth Range:
14,266.49 to 18,000+00usft Scan Method: Tray. Cylinder North
tesults Limited by:
Maximum center -center distance of 1,995.93 usft Error Surface: Pedal Curve
Survey Tool Program Date 8/2/2017From To
(usft) (usfl) Survey(Wellbore) Tool Name Description
469.83 14,266A9 2A-22 MWD (2A-22) MWD MWD -Standard
14,26649 18,000.00 2A-22A_wp03(2A-22A) MWD MWD -Standard
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(usft) (usft) Name
4,928.00 2,936.74 9 5/8" 9-5/8 12-1/4
18,000.00 6,002.86 2 3/8" 2-3/8 3
Summary
Kuparuk 2A Pad - 2A-22 - 2A-22 - 2A-22
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usfl)
(usft)
just)
Measured
(usft)
Refarewe
Kupamk 2A Pad
TooRace+
Offset Wellbore Centre
Casing-
centre to
No Go
Allowable warning
2A -22 -2A -22-2A-22
14,568.02
14,625.00
155.27
22.91
148.63
Pass - Major Risk
2A-22-2A-22AL1-2A-22AL1 Wp02
15,374.93
15,375.00
66.34
1.35
66.11
Pass - Minor 1/10
Kuparuk W.Sak
(oats,
(usrt)
(ust)
/vat)
Y)
just)
W SAK 18 - W SAK 18 - W SAK 18
17,300.00
6,150.00
1,498.84
746.36
759.87
Pass - Major Risk
Offset Design
Kuparuk 2A Pad - 2A-22 - 2A-22 - 2A-22
DRi! site error. 0.00 sats
Survey Program: 476MWD
Rule Assigned: Major Risk
Offset well Ertw: am usfl
Refs..
Dean
Semi Major Aais
Measured
variant
Measured
veredal
Refarewe
Offset
TooRace+
Offset Wellbore Centre
Casing-
centre to
No Go
Allowable warning
Depth
Depth
Depth
Depth
A7imeth
+NIS
+8I -W
Hole Sae
Centre
Dieters
Deviation
(amt
lusts)
(oats,
(usrt)
(ust)
/vat)
Y)
just)
post)
('9
(user
(.an)
lush,
14275.00
581829
1427500
5,618.29
008
0,11
50.86
2,782.20
11,75405
6-5116
0.00
305
-099 FAIL - Major Risk
14,300.00
5,833.81
14,300.00
5,833.01
032
0.41
5084
2,786.05
-11)7326
65/16
000
472
-2.34 FAIL - Major Risk
14,32499
5,849.02
14,32500
son,U
0.47
072
10157
2,789.88
-11]92.48
65/16
039
6.16
-1.32 FAIL - Major Risk
14,34953
5,051.84
14.350.00
5.864.58
Lee
1.03
101.62
2,79369
-11.81170
65116
3.39
7.64
1.23 Pass - Major Risk
14,372.45
5.870.49
14,375.00
5,880.39
0.00
1.34
10158
2.797.48
-11,830.92
65116
10.39
9.12
7.84 Pass -Major Rlak
14,39291
5.875.27
14,400.00
5,895.93
0.96
1.65
101.57
2.801.26
-11,850.14
6-,6116
20.94
10.55
tame Pass - Major Risk
14410.59
5,877.08
14,425m0
5,911.47
1.10
196
101.57
2,805,02
-11,859.36
6-916
34.41
11.90
3128 Pan - Major Risk
14.430.17
5,877.66
14,450.00
5,927.01
125
226
103.02
2,808.76
-11.888.58
6,6116
49.38
13.31
45.90 Pass - Major Risk
14.450.15
5,878.23
14,475.00
5,942.56
1.41
2.57
104.94
2,012.48
-11190)60
65116
8499
14.73
60.51 Pass - Major Risk
14,470.09
5,070.01
14,500.00
$,ball
1.57
2.88
107.03
2,016.19
-11.92T02
65116
78.37
16.14
75.13 Pass - Major Risk
14,48993
5,879.30
1452500
5.97367
1,72
3.19
109.17
2,819.80
-11,946.24
6-916
9442
1]53
81 Pass - Major Risk
14509.87
5,079.94
14,55000
5.989.24
188
3.50
111.34
2.82357
-11,96545
6-5118
109.52
18.91
104.40 Pass - Major Risk
14,529.20
5.88050
14.575.00
6,00483
2.07
380
113.51
2.827,27
-11,98484
6916
12469
2026
119.09 Pan - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
BW017 10:46:21AM Page 2 COMPASS 5000.14 Build 85
Baker HugheslNTEQ
ConocclPhillips Travelling Cylinder Report �I UGHES
a GEcompany
Company:
Conoco Phillips(Alaska) Inc.-Kup2
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 2A Pad
Site Error:
0.00 usft
Reference Well:
2A-22
Well Error:
0.00 usft
Reference Wellbore
2A -22A
Reference Design:
2A-22A_wp03
Local Co-ordinate Reference:
Well 2A-22
TVD Reference:
2A-22 @ 135,00usft
MD Reference:
2A-22 @ 135.00usft
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
OAKEDMP2
Offset TVD Reference:
Offset Datum
Reference Depths are relative to 2A-22 @ 135.00usft
Coordinates are relative to 2A-22
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: -0.01 °
CC -Min centre to center distance or covergent point, SF - min separation tactor, ES -min ellipse separation
8/2/2017 10:46:21AM Page 9 COMPASS 5000.14 Budd 85
Ladder Plot
re
nl
d
e)
^rn
G
d
U
0
C
d
U
0 3700 6000 9000 12000 15000 18000
Measured Depth
LEGEND
CC -Min centre to center distance or covergent point, SF - min separation tactor, ES -min ellipse separation
8/2/2017 10:46:21AM Page 9 COMPASS 5000.14 Budd 85
ConocoPhillips
Project: Kuparuk River Unit
ANTI-OOLLISION SETTINGS
WELL DETAILS: 2A-22
COMPANY DETAILS: ConocoPhillips(Alaska) Inc.-Kup2
Site: Kupar2A-22 k 2A Pad
Wap: 2A-22
-W
Interpolation Method: MD. interval: 25.00
Easting Latnl=
Calculation Method Minimum Curvature
2A -22A
Depth Range From: 14266.49 To 18000.00
150° 0 40.217 W
Sy
DesiMllbgn.
Design: 2q-22q_wp03
Azi
Results Limited B Centre Distance: 1995.93
TFace VSect
Scan McNOC:- Trav cylinder North
51.64
281.36
Reference: Plan. 2A.22A w p03 (2A -22/2H -22A)
0.0011564.08
CB8
5162
281.27
5840.04 2787.59-11780.98 0.17
-105.8511596.42
Wamm Method: Ruedel
ee
Depth Range From: 14266.49 To 18000.00
Azimuth from North [0] vs Centre to Centre Separation [20 usft/in]
BA (ER a
I�UGHES
a GEcompany
WELL DETAILS: 2A-22
+N/ -S +E/
-W
Northing
Easting Latnl=
Longitude
0.00 O.OD
59601]]]5 498620]8 'D.18156 N
150° 0 40.217 W
Sec MD
Inc
Azi
TVD «N/ -S +E/ -W Dleg
TFace VSect
114266.49
51.64
281.36
5813.01 2780.89.11747.50 0.00
0.0011564.08
214310.03
5162
281.27
5840.04 2787.59-11780.98 0.17
-105.8511596.42
314331.03
55.82
281.27
5852.46 279089-11797.57 20.00
0.0011612.45
414412.36
88.35
281.27
5877.14 2805 82 .118n.45 40.00
0.0011684.75
514612.36
88.40
295.28
Sell 286834-12061.81 7.00
90.0011880.01
614900.00
88.50
275.13
5890.72 2943.36-12337.86 7.00
270.0012156.58
715200.00
88.60
296.14
5898.41 3023.75-12625.05 7.00
90.0012445.49
615600.00
88.76
268.13
5907.82 3105.99-13012.12 7.00
270.0012822.32
915900.00
88.84
289.14
5914.17 3151.7]-13306.99 7.00
90.0013100.08
1016200.00
88.92
268.13
5920.09 3196.56-13601.88 7.00
270.0013377.85
1116650.00
87.51
299.62
5934.46 3303.02 -14033.05 7.00
93.0013804.49
1217000.00
86.49
275.11
5953.05 3406.56-14364.07 7.00
267 0014142.93
1317450.00
87.01
306.65
5979.21 3564.69-14778.52 7.00
90 0014580.91
1417700.00
87.15
289.13
5992.05 3681.03-14998.32 7.00
2]0.0014829.44._
1518000.00
88.77
310.08
6002.86 382834-15257.51 7.DD
86.0015127.'
SURVEY PROGRAM
Date:
2017-07-25T00:00:00 Validated: Yes Version:
Depth From Depth
To Survey/Plan
Tool
469.83 14266.49
2A-22 MWD (2A-22)
MWD
14266.49 18000.00
2A-22A_wp03 (2A -22A)
MWD
Color
Ranges by Plan MD
2A- g
A_Wp03
From MD Color To MD
14266---18000
TRANSMITTAL LETTER CHECKLIST
WELL NAME: XAU, aA -
/ PTD: a I? - //SS
Development _ Service _ Exploratory _ Stratigraphic Test Non -Conventional
FIELD: Grt 1 POOL: I lrlt l�/�J KWOG/t� ky&r �i 1
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 Pemmit
LATERAL
No. , API No.
(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. (Company -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 cau t and 10' sam le intervals throu h 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 (Cpmpany Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name l 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
(Comnanv 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#: 2171150 Company CONOCOPHILLIPS ALASKA, INC,. _ _. _. _ ._. _ — Initial Class/Type
Well Name: KUPARUK RIV UNIT 2A -22A _ Program _DEV _ Well bore seg ❑
DEV / PE_ND_ GeoArea 890 _. _ _.. Unit 1116Q - On/Off Shore On.. --- Annular Disposal ❑
Administration
17
Nonconven. gas conforms to AS31.05.030G.1.A),G.2.A-D)
NA
1
Permit fee attached. _
NA
2
Lease number appropriate
Yes
ADL0025570, Surf Loc; ADL0025571, Top Prod.lntery & TD.
3
Unique well. name and number
Yes
KRU 2A -22A
4
Well located in a defined pool
Yes
KUPARUK RIVER,. KUPARUK RIV OIL.- 490100, governed by Conservation. Order No, 432D,.
5
Well located proper distance from drilling unit boundary
Yes
CO 432D contains no spacing restrictions with respect to drilling unit boundaries.
6
Well located proper distance from other wells
Yes
CO 432D 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
Appr Date
11
Permit can be issued without conservation order
Yes
12
Permit can be issued without administrative approval
Yes
PKB 8/8/2017
13
Can permit be approved before 15 -day wail _
Yes
_
14
Well located within area and strata authorized by Injection Order # (put IO# 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.
18
Conductor string. provided
NA
Conductor set. in KRU 2A-22
Engineering
19
Surface casing. protects all known USDWs
NA
Surface casing set in KRU 2A-22
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 slatted 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
Yes
PTD 195-068, Sundry 317-345. _
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 pressure is 3832 psig(12.45 ppg EMW); will use 8.6 ppg EMW and maintain overbal w/ MPD
VTL 8/18/2017
29
BOPEs, do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
MPSP is 3245 psig; will test BOPS to 4000 psig
31
Choke manifold complies w/API RP -53 (May 84).
Yes
32
Work will occur without operation shutdown..
Yes
33
Is presence of 112S gas probable
Yes
1-12S 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
Wells. on 2A -Pad are H2S-bearing. H2S measures required.
Geology
36
Data presented on potential overpressure zones
Yes
Maximum potential reservoir pressure. is 12.46 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique.
Appr Date
37
Seismic analysis of shallow gas zones
NA
PKB 8/8/2017
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA
Sidetrack development well to be drilled.
Geologic Engineering Public
Commissioner: Date: Commissioner: Date Commissioner Date
0)"f 7/)117 6
