Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout218-067Originated:
Schlumberger
PTS-PRINTCENTER
6411 A Street
Anchorage, AK 99518
(907) 273-1700 main (907)273-4760fax
Delivered to:
'f
1/ AOGCC
ATTN: Natural Resources Technician II
)- AlaskaCil & Gas Conservation Commision
333 W. 7th Ave, Suite 100
+! Anchorage, AK 99501
2180:7
30 01 7
TRANSMITTALDATE
TRANSMITTAL# .�
WELL NAME
2B110
1H-108
1H-105
1J-156
1A -04A
— AN #
50-029.21084-00
50-029-23608-00
50-029-20727.01
50-029-23311-00
50-029-20621-00
ORDERSERVICE
#
EOSH-00034
E540-00064
E540-00065
EAI8-00008
E540-00068
FIELD NAME
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
KUPARUK RIVER
DESCRIPTION DELIVERABLE
WL
WL
WL
Memory
WL
DESCRIPTION
(PROF
IPROF
IPROF
IPROF
Caliper
DATA TYPE
FINAL FIELD
FINAL FIELD
FINAL FIELD
FINAL FIELD
FINAL FIELD
color
DATE LOGGED Prints
26 -Mar -19
27 -Mar -19
28- Mar-19
29 -Mar -19
4 -Apr -19
1
1
1
1
1
31-1-18
50.103.20095-00
EBLV-00002
KUPARUK RIVER
WL
IPROF
FINAL FIELD
6 -Apr -19
1
2K-26
50-103-20126.00
EBLN-00004
KUPARUK RIVER
WL
Caliper
FINAL FIELD
8 -Apr -19
1
1Q-06
50-029.21224-00
EBSI-00001
KUPARUK RIVER
WL
PPROF
FINAL FIELD
—10 -Apr -19
1
n
8
Name
Signature
Please return via courier or sign/scan and email a copy
Date
lumberger and CPAL
Schlumberger -Private
A Transmittal Receipt signature confirms that a package (box,
envelope, etc.) has been received and the contents of the
package have been verified to match the media noted above. '
specific content of the CDs and/or hardcopy prints may or may
not have been verified for correctness or quality level at this
point.
DATA SUBMITTAL COMPLIANCE REPORT
11/26/2018
Permitto Drill 2180670 Well Name/No. KUPARUK RIV U WSAK iH-108 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-00-00
MD
6527
TVD 4042 Completion Date
6/22/2018 Completion Status P&A
Current Status P&A UIC No
REQUIRED INFORMATION
Mud Log No "
Samples NoV
Directional Survey Yes
DATA
INFORMATION
List of Logs Obtained: GR/ RES/ DEN
(from Master Well Data/Logs)
Well Log Information:
Log/
Electr
Data
Digital
Dataset
Log Log Run Interval OH/
Type
Med/Frmt
Number Name
Scale Media No Start Stop P CH
Received
Comments
ED
C
29533 Digital Data
32 1840
7/18/2018
Electronic Data Set, Filename: CPAI_1H-
108_Scope_Gamma_Ray_LW D001_RM_LAS.las
ED
C
29533 Digital Data
1647 6526
7/18/2018
Electronic Data Set, Filename: CPAI_1H-
108_V ISION_Service_LW D002_RM_LAS.las
ED
C
29533 Digital Data
32 6526
7/18/2018
Electronic Data Set, Filename: CPAI_111-1-
H-
108—VISION —Service
108_V ISION_ServiceRM_LAS.Ias
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_Scope_Gamma_Ray_RM_DLIS_L W D001.dli
s
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_Scope_Gamma_Ray_RM_DLIS_LWD001.ht
ml
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_VISION_Service_RM_DLIS_LW D002.d1is
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_VISION—Service _ RM_ DLIS_LWD002.html
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
1108—VISION—Service DLIS.dlis
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_VISION_ Service _DLIS.html
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPA[ -
_1H
108_V I S I O N_Service_2MD_RM.pdf
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_V IS ION_Service_2T V D_RM.pdf
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-
108_V I S I O N_S e ry i c e_5 M D_ R M. p d f
AOGCC
Pagel of 3
Monday, November 26, 2018
DATA SUBMITTAL COMPLIANCE REPORT
11/26/2018
Permitto Drill 2180670 Well Name/No. KUPARUK RIV U WSAK 1H-108 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608-00-00
MD
6527
TVD 4042 Completion Date 6/22/2018
Completion Status P&A Current Status P&A UIC No
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI 1H-
H-
108_VISION_Service_5T V D_RM.pdf
108—VISION — Service — 5T
ED
C
29533 Digital Data
7/18/2018
Electronic File: CPAI_1H-108_PdntSurveyList.csv
ED
C
29533 Digital Data
7/18/2018
Electronic File: Gyrodata Survey - 1H-108 - Post
SLB SAG.pdf
ED
C
29533 Digital Data
7/18/2018
Electronic File: Gyrodata Survey - 11-1-1108 - Post
SLB SAG.xlsx
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD27 EOW Compass
Surveys [Canvas].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD27 EOW Compass
Surveys [Macro].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NA027 EOW Compass
Surveys [Petrel].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD27 EOW Compass
Surveys [Surveys].bd
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD27 EOW Compass
Surveys.pdf
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD83 EOW Compass
Surveys [Canvas].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD83 EOW Compass
Surveys [Macro].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD83 EOW Compass
Surveys [Petrel].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD83 EOW Compass
Surveys [Surveys].txt
ED
C
29533 Digital Data
7/18/2018
Electronic File: 1H-108 NAD83 EOW Compass
Surveys.pdf
Log
C
29533 Log Header Scans
0 0
2180670 KUPARUK RIV U WSAK 1H-108 LOG
HEADERS
Well Cores/Samples
Information:
Sample
Interval
Set
Name
Start Stop
Sent Received Number
Comments
INFORMATION RECEIVED
AUG(C( Page 2 of 3 Monday, November 26, 2018
DATA SUBMITTAL COMPLIANCE REPORT
11/26/2018
Permit to Drill 2180670 Well Name/No. KUPARUK RIV U WSAK 1 H-108 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-23608.00.00
MD 6527 TVD 4042
Completion Report 5
Production Test Information Y
Geologic Markers/Tops UY
COMPLIANCE HISTORY
Completion Date: 6/22/2018
Release Date: 5/24/2018
Description
Comments:
Compliance Reviewed
Completion Date 6/22/2018 Completion Status P&A Current Status P&A
Directional / Inclination Data 6) Mud Logs, Image Files, Digital Data Y / !�
Mechanical Integrity Test Information Y / NA Composite Logs, Image, Data FilesY
Daily Operations Summary Cuttings Samples l
CD Y /9
Date
Comments
UIC No
Core Chips Y /
Core Photographs Y /
Laboratory Analyses Y /
Date:
AOGC(' Page 3 o£3 Monday, November 26, 2018
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT
AND LOG
ta. Well Status: oil ❑ Gas❑ SPLUG ❑ Other ❑ Abandoned ❑� Suspended ❑
20MC 25.105 20AAC 25.110
GINJ❑ WINJ❑ WAG[_WDSPL❑ No. of Completions:
1b. Well Class:
Developme0tlf� Exploratory El
Service JZ i(IV Stratigraphic Test C]
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 6/22/2018
14. Permit to Drill Number / Sundry:
218-067 - 2
3. Address:
P.O. Box 100360 Anchorage, AK 99510.0360
7. Date Spudded:
6/16/2018
15. API Number:
50-029-23608-00-00
4a. Location of Well (Governmental Section):
Surface: 50' FSL, 770' FEL, Sec 28, T12N, R10E, UM
Top of Productive Interval:
1409' FNL, 2728' FEL, Sec 34, T12N, R10E, UM
Total Depth:
1616' FNL, 2031' FEL, Sec 34, T12N, R10E, UM
8. Date TD Reached:
6/21/2018
16. Well Name and Number:
KRU 1H-108
9. Ref Elevations: KB:92.99
GL:54 BF:
17. Field / Pool(s):
Kuparuk River Field/West Bak Oil Pool
10. Plug Back Depth MD1TVD:
3550/2869
18. Property Designation:
ADL 25639
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 549570.98 y- 5980752.52 Zone- 4
TPI: x- 552905 y- 5979316 Zone- 4
Total Depth: x- 553604 y- 5979115 Zone- 4
11. Total Depth MD/TVD:
6527/4042
19. DNR Approval Number:
80-261
12. SSSV Depth MD/TVD:
N/A
20. Thickness of Permafrost MD/TVD:
1685/1634
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:
N/A
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/Den
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH ND AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
20 94 H-40 Surface 119 Surface 119 42 Existing, cement to surface
10.75 45.5 L-80 Surface 1834 Surface 1767 13.5 969 ax 11.0 Class G, 221sx
12.0 Class G
24. Open to production or injection? Yes ❑ No I]
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
aid
�_ L A
V� RR�lEU
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/rVD)
31/2 1834 N/A
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes E] No 0
Per 20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
N/A
Method of Operation (Flowing, gas IF, etc.):
PLUGGED BACK
Date of Test:
Hours Tested:
Production for
Test Period
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size:
Gas -Oil Ratio:
Flow Tubing
Press.
Casino Press:
I
Calculated
24 -Hour Rate
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity - API (corr):
Form 10-407 Revised 5/2017 RBDMSV - SEP 10 2WNTINUED ON PAGE 2 (` (�' Submit ORIGINAL only,
flU -.N- Y I�r- , a,1 1418
28. CORE DATA Conventional Core(s): Yes ❑ No ❑� Sidewall Cores: Yes ❑ No ❑�
If Yes, list formations and intervals cored (MD/ VD, From/ro), and summarize lithology and presence of oil, gas or water (submit separate pages with this form,
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
ND
Well tested? Yes ❑ No ❑�
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1685
1635
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
5735
3730
information, including reports, per 20 AAC 25.071.
Formation @ TPI -West Sak
TO
6527
4042
Formation at total depth:
West Sak
31. List of Attachments: Daily Operations Summary, Definitive Survey, Cement Report, Schematic
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontolooical report. production or well test results. per 20 AAC 25.070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
NL
Authorized Name: G.L. Alvord Contact Name: Nick Lehman
Authorized Title: 42 Alaska Drilling Manager Contact Email: nick.r.lehman co .com
Authorized Q�J it (�� Contact Phone: 263-4951
' t
Signature: a 1(
INSTRU TI S
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 101104 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a well 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 1b: Well Class - Service wells: Gas Injection, Water Injection, Water-Afternating-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 ND 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 item 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 101407 Revised 5/2017 Submit ORIGINAL Only
0
7
0
n
0
:r
Insulated Conductor:
20" Casing
Top of Kickoff Plug @
1784' MD / 1,723' TVD
Btm of Kickoff Plug
2284' MD / 2,121' T'
Wellbead
13-3/8" SM
q q
\ q
r q
q q
a q
Top of Abandonment Plug #3 @
3.,550' MD / 2,870' TVD
Btm of Abandonment Plug #3 @ 4,155'
MD / 3,120' TVD
10-3/4" 45.5#, L-80 HYD563
@ 1,834' MD - Existing
Btm of Abandonment Plug #1 @ 5,735'
MD / 3,729' TVD
1H-108 Injector Well Design
Post -Abandonment Planned
Wellbore Schematic
4-- Top of Ugnu C @ 4,155' MD / 3120' TV D
Top of N -Sand @ 5,208' MD / 3,528' TVD
�q t-- Top of WestSak D -Sand @ 5,735' MD / 3,729' TVD
q
q
q
q
q
q
q
\ y g\ r_� 8-3/4" Open Hole TD @
q 6,527' MD
q
Top of Abandonment Plug #2 @ 4,557'
q
MD/3,277'TVD
10 H
q
q
Btm of Abandonment Plug #2 @ 5,057'
q
q
MD / 3,470' TVD
--�)►\\
Top of Abandonment Plug #1 @ 5,057'
MD / 3,470' TVD
Btm of Abandonment Plug #1 @ 5,735'
MD / 3,729' TVD
1H-108 Injector Well Design
Post -Abandonment Planned
Wellbore Schematic
4-- Top of Ugnu C @ 4,155' MD / 3120' TV D
Top of N -Sand @ 5,208' MD / 3,528' TVD
�q t-- Top of WestSak D -Sand @ 5,735' MD / 3,729' TVD
q
q
q
q
q
q
q
\ y g\ r_� 8-3/4" Open Hole TD @
q 6,527' MD
y, KUP INJ 1H-108
CalocuPhllllp$QWESTSAK
Well Attribu Max Angle ] TD
Fb10 Name Wellbore APVUWI WeIIEore Slalus nclfl MD O.. ACI BIm (XNB)
Naska, 1110 500292360800 INJ 11185 54)923 65270
1w1a6. enrmle eas:aui
Last Tag
VxEcel KAmeOc lerKua
Annotation
IAST TAG
Ell ogle
tNtAh
B) Inst MW ay
jennalt
Last Rev Reason
X os.. 9.0
Anmiailon
Ene oats
Iasi MaE By
REV REASON
jennal(
Casing Strings
.... ...
crime 0escnpbon
oOtm1
TcplXnal
setoeWIMKBl
sal0ep.1 ,o...
WIILena...vrWe
Top TMaaO
CONDUCTOR
20
1920
I 39.0
1190
119.0
78.67
B
liana oescnpilon
oofn)
1W..)
Bn BaN61Xxe1
Stloswln 1
WNlen 11
TOPTmeae
SURFACE
10314
Pon,
9.95
40.5
1,834.3
V674
45.50
1...
L-80 HIdnI 563
KOR�9obe1:76.2
CONDUCTOR', A96 180
INTERMEONTE: 3l0d,BY9
.Lstl CE: M61 BL.3sssssss—
Uperations Summary (with Timelog Depths)
1H-108
•
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stam Depth
Siert Tirre
End Tinre
Dur (hr)
Phase
Op Cade
AdWity Cade
Time P -i -X
Operation
(WB)
End Depth (110)
6/4/2018
6/4/2018
0.75
MIRU
MOVE
MOB
P
Move rock washer & pipe shed.
0.0
0.0
00:00
0045
SIMOPS install Amphion/NOVOS
upgrade in drillers cab.
6/4/2018
6/4/2018
1.00
MIRU
MOVE
MOB.
P
Move power module. Install travel
0.0
0.0
00:45
01:45
tongue on sub. Finish unplugging
interconnects f/ pits to sub. SIMOPS
install Amphion/NOVOS upgrade in
driller cab.
6/4/2018
6/4/2018
1.00
MIRU
MOVE
MOB
P
Skid rig floor & raise stompers.
0.0
0.0
01:45
02:45
6/4/2018
6/4/2018
0.50
MIRU
MOVE
MOB
P
Latch sub to truck & move off 1 H-110.
0.0
0.0
02:45
03:15
6/412018
614/2018
2.25
MIRU
MOVE
MOB
P
Move sub towards 1 H-108. Set rig
0.0
0.0
03:15
05:30
mats for 1H-108. Spot sub over well.
Remove travel tongue & skid rig floor
to drill position.
6/4/2018
6/4/2018
0.50
MIRU
MOVE
MOB
P
Spot pits complex to sub base.
0.0
0.0
05:30
06:00
6/412018
6/4/2018 "
2.00
MIRU
MOVE
MOB
P
Spot pumps, power, pipe shed, & rock
0.0
0.0
06:00
08:00
washer. SIMOPS install
Amphion/NOVOS upgrade in drillers
cab.
6/4/2018
614/2018
3.00
MIRU
MOVE
RURD
P
Spot cuttings tank, hook up all
0.0
0.0
08:00
11:00
interconnects, lower/secure skate rail
& test skate. Complete rig acceptance
checklist@ 11:00 hrs.
6/4/2018
6/4/2018
1.00
MIRU
MOVE
NUND
P
Torque diverter tee & annular flanges.
0.0
0.0
11:00
12:00
Attach diverter line extension. Swap to
shore power at 12:00 hrs.
6/4/2018
6/4/2018
3.00
MIRU
MOVE
NUND
P
Obtain RKB's. Nipple up riser
0.0
0.0
12:00
15:00
extension, riser & mouse hole. Align &
secure annular. Hook up kill, choke, &
cement lines in interconnects. Secure
all tools & housekeeping.
As of 15:00 bra decision was made to
perform maintenance as bridge has
washed out. Release from 1 H-108 and
accept onto summer maintenance.
6/16/2018
6/16/2018
2.75
MIRU
MOVE
BOPE
P
Perform Diverter Test, Test witnessed
0.0
0.0
12:00
14:45
byAOGCC Rep Guy Cook. - Knife
valve open in 7 sec; annular closed in
30 sec; initial system pressure 3050
psi; pressure after closure 1950 psi;
200 psi recharge time 6 sec; full
recharge 45 sec; 6 nitrogen bottles
avg pressure 2033 psi; lest gas, flow,
& pit level alarms.. 1 - FP change out
knife valve hydraulic hoses for fire
rated hydraulic hoses.
6/16/2018
6/16/2018
0.50
MIRU
MOVE
SFTY
P
Pre -spud meeting held with rig crew,
0.0
0.0
14:45
15:15
SLB directional, MI Rep, & CPA] Rep.
6/16/2018
6/16/2018
2.25
MIRU
MOVE
BHAH
P
PJSM, pick up surface BHA 1 as per
0.0
91.0
15:15
17:30
SLB DD to 91' MD.
6/16/2018
6116/2018
0.50
MIRU
MOVE
SEOP
P
Flood high pressure mud lines to top
91.0
91.0
17:30
18:00
drive. Test high pressure mud lines to
3500 psi, good lest.
6/16/2018
6/16/2018
2.00
MIRU
MOVE
DRLG
P
Clean out conductor w/ 13-1/2"
91.0
119.0
18:00
20:00
surface drilling assembly f/91'-119'
MD, 119' TVD, 450 gpm, 450 psi on,
off 425 psi, FO 32%,40 rpm, Tq 2K,
off 1 K, WOB 2K, PU 64K, SO 70K,
ROT 66K, MW 8.8ppg, Max Gas 0.
Page 1135 Report Printed: 8/1012018
Operations Summary (with Timelog Depths)
Awl
�I
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Stan Time
EM Tune
our(hq
Phase
Op Code
Activity Coda
Time PJA
Operation
mi<a)
End Dept (MB)
6/16/2018
6/17/2018
4.00
SURFAC
DRILL
DDRL
P
Directional drill 13-1/2" surface hole f/
119.0
301.0
2000
00:00
119'-301' MD, 301' TVD, 450 gpm,
550 psi on, 475 psi off, FO 38%, 50
rpm, Tq on 2K, off 1 K, WOB 9K, PU
64K, SO 70K, ROT 66K, MW 8.8 ppg,
Max Gas 0, AST 0, ART 2.56, ADT
2.56, BIT 2.56, Jars 2.56. Total
Footage 182'
6/17/2018
6/17/2018
6.00
SURFAC
DRILL
DDRL
P
Directional drill 13-1/2" surface hole f/
301.0
797.0
00:00
06:00
301'-797' MD, 796' TVD, 500 gpm,
1100 psi on, 950 psi off, FO 38%, 60
rpm, Tq on 4K, off 3K, WOB 29K, PU
78K, SO 82K, ROT 79K, MW 9.0 ppg,
AST 1.53, ART 2.43, ADT 3.96, BIT
6.46, Jars 3.94. Total Footage 496'
6/17/2018
6/17/2018
6.00
SURFAC
DRILL
DDRL
P
Directional drill 13-1/2" surface hole f/
797.0
1,367.0
06:00
12:00
797'-1367' MD, 1346' TVD, 550 gpm,
1400 psi on, 1150 psi off, FO 40%, 60
rpm, Tq on 5K, off 1 K, WOB 29K, PU
93K, SO 93K, ROT 92K, MW 9.4+
ppg, AST 2.35, ART 2.03, ADT 4.38,
BIT 10.86, Jars 8.34. Total Footage
570'.
6/17/2018
6/17/2018
5.00
SURFAC
DRILL
DDRL
P
Directional drill 13-1/2" surface hole f/
1,367.0
1,840.0
12:00
17:00
1367'-1840' MD, 1772' TVD, 550 gpm,
1424 psi on, 1360 psi off, FO 37%, 60
rpm, Tq on 5K, off 1 K, WOB 29K, PU
97K, SO 100K, ROT 96K, MW 9.5
ppg, AST 1.58, ART 1.52, ADT 3. 10,
BIT 13.96, Jars 11.44. Total Footage
473'.
6/17/2018
6/17/2018
0.75
SURFAC
CASING
BKRM
P
BROOH f/ 1840'-1703' MD, 552 gpm,
1,840.0
1,703.0
17:00
17:45
1205 psi, FO 36%, 60 rpm, Tq 2K, PU
97, SO 100, ROT 96K. Shoot final
survey on bottom. BROOH w/ 1 BU
during 1 stand on drill pipe.
6/17/2018
6117/2018
0.50
SURFAC
CASING
OWFF
P
Monitor well, static.
1,703.0
1,703.0
17:45
18:15
6/17/2018
6/17/2018
2.75
SURFAC
CASING
BKRM
P
BROOH f/ 1703'-850' MD, 554 gpm,
1,703.0
850.0
18:15
21:00
1090 psi, FO 37%, 60 rpm, Tq 2K.
6/17/2018
6/18/2018
3.00
SURFAC
CASING
BHAH
P
Rack back 2 stands of HWDP, lay
850.0
32.0
21:00
00:00
down remaining HWDP & BHA 1 f/
850'-32' MD, as per SLB DD.
6/18/2018
6/18/2018
0.50
SURFAC
CASING
BHAH
P
Continue laying down BHA 1. Pull mud
32.0
0.0
00:00
00:30
motor, flush & break off bit
(3,2,WT,A,E,1,NO,TD). Clean & clear
rig floor.
6/18/2018
6/18/2018
1.50
SURFAC
CASING
RURD
P
Rig up casing handling equipment for
0.0
0.0
00:30
02:00
10-3/4" surface casing. PJSM for all
personnel involved in running casing.
6/18/2018
6/18/2018
0.75
SURFAC
CASING
PUTB
P
Make up 10-3/4", 45.5#, L-80, Hydril
0.0
125.0
02:00
02:45
563, dopeless shoe track to 125' MD.
First 2 joints centralized with 2
bowspring centralizers at 1 O' from top
& bottom. Centralizer installed on
each collar after. Connections
BakerLok'd & torque to 19,400 ft/Ibs.
Check floats, good.
6/18/2018
6/18/2018
4.25
SURFAC
CASING
PUTS
P
Continue to run 10-3/4", 45.5#, L-80,
125.0
1,790.0
02:45
07:00
Hydril 563, dopeless casing f/ 125'-
1790' MD, PU 117K, SO 102K,
connections torque to 19.4K,
centralized on each collar, total
centralizers ran 44 & 4 stop rings.
Page 2135 Report Printed: 8/1012018
Uperations Summary (with Timelog Depths)
IH -108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
alert Depth
Start Time
End Time
Dur (hr)
Phase
Op Code
Aotieky Cade
Time P -T -X
Operetlon
(MB)
End Depth (SKa)
6/18/2018
6/18/2018
0.50
SURFAC
CASING
PUTB
P
Make up Vetco fluted casing hanger &
1,790.0
1,834.0
07:00
07:30
landing joint. Wash down at 3 bpm,
145 psi, FO 16%, PU 117K, SO 112K,
land hanger w/ shoe depth at 1834'
MD, 1776' TVD.
6/18/2018
6/18/2018
0.75
SURFAC
CEMENT
CIRC
P
Circulate & condition mud for
1,834.0
1,834.0
07:30
08:15
cementing, stage up pump to 8 bmp,
ICP 145 psi, FCP 130 psi, FO 22%,
PU 117K, SO 112K, reciprocate pipe
20'.
6/18/2018
6/18/2018
0.25
SURFAC
CEMENT
RURD
P
Rig up cement manifold & cement line
1,834.0
1,834.0
08:15
08:30
to Volant CRT. Blow down the top
drive.
6/18/2018
6/16/2018
2.75
SURFAC
CEMENT
CIRC
P
Circulate & condition mud for
1,834.0
1,834.0
08:30
11:15
cementing, stage up pump to 8 bmp,
ICP 309 psi, FCP 270 psi, FO 22%,
_
PU 117K, SO 112K, reciprocate pipe
20'.
6/18/2018
6/18/2018
3.25
SURFAC
CEMENT
HOSO
P
PJSM w/ all involved parties for
1,834.0
0.0
11:15
14:30
cementing. Pump 5 bbls of H2O to
flood lines. Test cement lines to 3500
psi, good. Pump 40 bbis of CW -100, 5
bpm, 120 psi, FO 13%. Pump 76 bbls
of 10.5 ppg Mud Push It w/ red dye, 5
bpm, ICP 152 psi, FCP 130 psi, FO
16%. Drop bottom plug. Pump 328
bbls of 11 ppg Lead Cement, 6 bpm,
171 psi, FO 15%. Pump 65 bbls of 12
ppg Tail Cement, 5-6 bpm, ICP 220
psi, FCP 274 psi, FO 15%, PU 117K,
SO 97K. Drop top plug. Kick out plug
w/ 10 bbls of H2O. Swap to rig &
pump treated 9.6 ppg mud, 7 bpm,
ICP 250 psi, FCP 391 psi, FO 17%.
Reciprocate casing w/ 20 strokes
throughout job & land casing on
hanger w/ 1000 strokes pumped by rig
pump. Slow pump rale to 3 bpm at
1300 strokes, 250 psi, FO 11%. Bump
the plug with 1569 strokes, pressuring
up to 750 psi. Hold pressure for 5
minutes, bleed off, & floats holding.
CIP @ 14:13 hrs. Total of 84 bbls of
cement back to surface.
6/18/2018
6/18/2018
0.75
SURFAC
CEMENT
PRTS
P
Pressure test 10-3/4" surface casing
0.0
0.0
14:30
15:15
to 3000 psi for 30 minutes, charted.
Pressure up w/ 9.6 ppg mud at 7 spm
to 3340 psi in 32 strokes. Shut in &
observe pressure for 30 minutes.
ISICP 3280 psi, FSICP 3280 PSI, bled
back 3 bbls.
6/18/2018
6/18/2018
1.25
SURFAC
CEMENT
RURD
P
Rig down / blow down testing &
0.0
0.0
15:15
16:30
cementing equipment. RD cement
lines & manifold. Lay down Volant
CRT. Pull landing joint. Clear rig floor
of casing & cementing equipment.
6/18/2018
6/18/2018
0.50
SURFAC
CEMENT
W W WH
P
Make up stack washing tool & flush
0.0
0.0
16:30
17:00
surface stack w/ black H2O pill at 866
gpm, 115 psi, FO 35%, 30 rpm, Tq 1 K,
Blown down top drive & lay down
stack washing tool.
6/18/2018
6/18/2018
3.00
SURFAC
CEMENT
NUND
P
Drain stack, remove 4" conductor
0.0
0.0
17:00
20:00
valves, riser, annular, diverter tee &
starting head. Rig down diverter line.
Page 3135 Report Printed: 8/10/2018
Operations Summary (with Timelog Depths)
11-1-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Stan Time
End Tore
Dur tat
Phase
Op Code
Activity Cade
Time P-T.X
Operation
Mks)
Ertl Depth (11101)
6/18/2018
6/18/2018
3.75
SURFAC
WHDBOP
NUND
P
Prep casing hanger & install thread
0.0
0.0
20:00
23:45
ring. Set wellhead per GE Rep.
Orientation verified by CPAI Rep &
pad Operator. Install flanges on well
head valves. Install sweeping 90's.
Top of cement measured T below
hanger flutes.
6/18/2018
6/19/2018
0.25
SURFAC
WHOBOP
NUND
P
Test seal between casing hanger &
0.0
0.0
23:45
00:00
wellhead to 2000 psi for 10 minutes,
witnessed by CPAI Rep.
6/19/2018
6/19/2018
3.00
SURFAC
WHDBOP
NUND
P
Set spacer spool and stack / TQ all
0.0
0.0
00:00
03:00
flanges. set riser and install choke /
Kill lines,
6/19/2018
6/19/2018
0.50
SURFAC
WHDBOP
RURD
P
Rlg up to test BOPE
0.0
0.0
03:00
0330
6/19/2018
6/19/2018
4.50
SURFAC
WHDBOP
BOPE
P
Test BOPE equipment . BOPE test
0.0
0.0
03:30
0800
waived witness by AOGCC Matt
Herrera. Test performed at 50 psi
low/ 3,500 PSI high with 3 1/2" & 7"
testjoint. choke valves 1-14, Upper
and lower IBOP valves. Kill valves on
floor, Mez, HCR kill, Man kill, XT 43
TIW and dart. Man /Hyd choke test to
2,500 PSI. w3 1/2" and 4 1/2" test jt
with lower VBR's. HCR, and man
choke. Koomey drawn down test -
ISP = 2,900 PSI, after closure 1,950
PSI. 200 PSI in 12 sec. Full pressure
in 42 Sec. 6 btl average of 1,975 PSI.
Test pit level alarms & FO system.
H2S / combustible gas alarms. H2S
tested audible and light. Passed.
6/19/2018
6/19/2018
1.00
SURFAC
WHDBOP
RURD
P
Pull test plug and install 12 1/4" wear
0.0
0.0
08:00
09:00
bushing. RILDS X2. RD testing equip
an BD same.
6/19/2018
6/19/2018
2.00
SURFAC
CEMENT
SLPC
P
Slip & Cut 73' of 1.375" DL. Calibrate
0.0
0.0
09:00
11:00
Amphion system.
6/19/2018
6/19/2018
2.00
SURFAC
CEMENT
SHAH
P
PU/MU drilling BHA#2 to 99' MD.
0.0
388.0
11:00
13:00
Pre job safety meet. Monitor disp via
pit 1.
6/19/2018
6/19/2018
0.75
SURFAC
CEMENT
TRIP
P
RIH with drilling BHA#2 on 4 1/2" DP
388.0
1,443.0
13:00
13:45
from 388' MD - 1,443' MD. Monitor
disp via Pit 1. Up WT = 84K. DWN
WT = 82K.
6/19/2018
6/19/2018
0.25
SURFAC
CEMENT
DHEQ
P
Shallow hole test MWD, @ 1,443' MD.
1,443.0
1,443.0
13:45
14:00
with 500 GPM @ 855 PSI DPP. 30%
F/O. (PASSED). BD TD.
6/19/2018
6/19/2018
5.50
SURFAC
CEMENT
OTHR
P
Comission New NOVIS system. Work
1,443.0
1,443.0
14:00
19:30
7" casing in pipe shed / house
keeping.
6/19/2018
6/19/2018
0.75
SURFAC
CEMENT
TRIP
P
RIH with Drilling 3HA#2 from 1,443'
1,443.0
1,730.0
19:30
20:15
MD - 1,730' MD monitoring disp via Pit
#1. Up WT=86K DWN WT=83K.
Conduct 5 min test on OA valve to
3,000 PSI. (PASSED)
6/19/2018
6/19/2018
2.25
SURFAC
CEMENT
DDRL
P
Drill out shoe tract system and 20' new
1,730.0
1,860.0
20:15
22:30
hole. 60 RPM 4K To 550 GPM @
1,040 PSI DPP. C/O to 1,8601. UP W
T= 86K, DWN WT = 84K.
6/19/2018
6/19/2018
1.00
SURFAC
CEMENT
CIRC
P
Circulate BU X2 for mud conditioning.
1,860.0
1,860.0
22:30
23:30
580 GPM @ 1,100 PSI DPP. recip
pipe above shoe while rotating 60
RPM. 9.5+ in 9.5+ out.
6/19/2018
6/20/2018
0.50
SURFAC
CEMENT
FIT
P
Perform FIT to 220 PSI - 12 PPG
1,860.0
1,860.0
23:30
00:00
EMW. (PASSED)
Page 4135
Report Printed: 811012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Stan Tlme
End Tone
Dur (ht)
Phase
Op Code
ActlNry Code
Tone P -T -X
Operation
(RKB)
End Depth (11(8)
6/20/2018
6120/2018
6.00
PROD1
DRILL
DDRL
P
DDRL from 1,860'MD - 2,692'MD
1,860.0
2,692.0
00:00
06:00
2,372' TVD. 650 GPM @ 981 PSI
DPP. 29% F/O 140 RPM @ 3K TO. 2
-6K WOB with ECD's 10.24 PPG. Off
bottom - 950 PSI, UP WT = 96K, DW N
WT = 90K. ROT - 92K. 21K TO, Max
gas = 404 units. ADT - 4, Bit His - 4,
Jar his. - 48.52
SPRs @ 2,120' MD 2,004' TVD MW =
9.1 Time 0300 hrs
MP 1) 30 SPM - 90 PSI 40 SPM - 120
PSI
MP 2) 30 SPM - 90 PSI 40 SPM - 120
PSI
6/20/2018
6/20/2018
6.00
PROD1
DRILL
DDRL
P
DDRL from 2,692' MD 2,372' TVD -
2,692.0
3,738.0
06:00
12:00
3,738' MD 2,956' TVD. 650 GPM @
1,257 PSI DPP. 30% F/O 140 RPM @
5K TQ. 14K WOB with ECD's 10.86
PPG. Off bottom - 1,277 PSI, UP WT
=111 K, OWN WT=92K. ROT -99K.
3K TO, Max gas = 51 units. ADT -
4.21, Bit Hrs - 8.21, Jar hrs. - 52.73
SPRs @ 2,782' MD 2,427' TVD MW =
9.0 Time 0630 his
MP 1) 30 SPM - 120 PSI 40 SPM -
160 PSI
MP 2) 30 SPM - 120 PSI 40 SPM -
150 PSI
6/20/2018
6/20/2018
6.00
PROD1
DRILL
DDRL
P
DDRL from 3,738' MD 2,956' TVD -
3,738.0
4,403.0
12:00
18:00
4,403' MD 3,216' TVD. 650 GPM @
1,408 PSI DPP. 30% F/O 140 RPM @
51K TO. 14K WOB with ECD's 10.51
PPG. Off bottom - 1,390 PSI, UP WT
=11 OK, DWN WT=90K. ROT -99K.
3K TO, Max gas = 105 units. ADT -
3.22, Bit Hrs - 11.43, Jar hrs. - 55.95
6/20/2018
6/21/2018
6.00
PROD1
DRILL
DDRL
P
DDRL from 4,403'MD 3,216'TVD-
4,403.0
5,332.0
18:00
00:00
5,332' MD 3,575' TVD. 650 GPM @
1,492 PSI DPP. 30% F/O 140 RPM @
6K TO. 14K WOB with ECD's 10.83
PPG. Off bottom - 1,450 PSI, UP WT
=117K, OWN WT=93K. ROT -
105K. 51K TO, Max gas = 43 units.
ADT - 3.49, Bit Hrs - 14.92, Jar hrs. -
59.44
SPRs @ 4,591' MD 3,291' TVD MW =
9.1 Time 1900 his
MP 1) 30 SPM - 200 PSI 40 SPM -
240 PSI
MP 2) 30 SPM - 200 PSI 40 SPM -
240 PSI
Page 5135 ReportPrinted: 8/10120181
Operations Summary (with Timelog Depths)
IH -108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stmt Depth
start Time
End Time
our (hr)
Phase
Op code
Activity Code
Time P -T -X
Operation
(ftKB)
End Depth(ftKB)
6/21/2018
6/21/2018
6.00
PRODt
DRILL
DDRL
P
DDRL from 5,332'MD 3,575'TVD-
5,332.0
6,208.0
00:00
06:00
6,208' MD 3,916' TVD. 650 GPM @
1,635 PSI DPP. 30% F/O 160 RPM @
81K TQ. 10K WOB with ECD's 10.94
PPG. Off bottom - 1,620 PSI, UP WT
=130K, DWN WT=96K. ROT -
108K. 5K TQ, Max gas = 154 units.
ADT - 3.55, Bit Hrs - 18.47, Jar hrs. -
62.99
6121/2018
6/21/2018
1.50
PROD1
DRILL
DDRL
P
DDRL from 6,208' MD 3,916' TVD -
6,208.0
6,527.0
06:00
07:30
6,527' MD 4,043' ND. 650 GPM @
1,820 PSI DPP. 30% F/O 160 RPM @
81K TQ. 18K WOB with ECD's 11.04
PPG. Off bottom - 1,760 PSI, UP WT
=130K, DWN WT=100K. ROT -
108K. 6K TQ, Max gas = 144 units.
ADT - 1, Bit Hrs - 19.47, Jar hrs. -
63.99
6/21/2018
6/21/2018
0.75
PROD1
CASING
CIRC
P
Final survey and SPR's, BROOH from
6,527.0
6,497.0
07:30
08:15
6,527' MD - 6,497' MO. at 650 GPM
@ 1,760 PSI DPP. 30% F/O, 130
RPM, 6K TQ. UP WT = 130K, OWN
WT = 100K. ROT= 108K. Total
strokes pumped = 3,875
6/21/2018
6/21/2018
0.50
PROD1
CASING
OWFF
P
OWFF (Static)
6,497.0
6,497.0
08:15
08:45
6/21/2018
6/21/2018
3.25
PROD1
CASING
BKRM
P
BKRM OOH from 6,497' MD - 5,245'
6,497.0
5,245.0
08:45
12:00
MD with 650 GPM @ 1,790 PSI DPP.
with FCP 1,638 PSI DPP 30% F/O
11.08 ECD. 120 RPM 5K TQ, UP WT
= 95K.
6/21/2018
6/21/2018
6.00
PRODt
CASING
BKRM
P
BKRM OOH from 5,245' MD - 3,170'
5,245.0
3,170.0
12:00
18:00
MD 650 GPM @ 1,374 PSI DPP, 30 %
F/O, 120 RPM, 10.80 ECD, 4K TQ,
88K UP WT while BKRM.
6/21/2018
6/21/2018
3.00
PROD1
CASING
BKRM
P
BKRM OOH from 3,170' MD - 1,824'
3,170.0
1,824.0
18:00
21:00
MD. 650 GPM @ 1,374 PSI DPP.
30% NO, 120 RPM With ECD 10.80
PPG. 41K TQ UP WT = 88k.
6/21/2018
6/21/2018
1.00
PROD1
CASING
CIRC
P
Circulate while recip in shoe @ 700
1,824.0
1,824.0
21:00
22:00
GPM, 1,200 PSI DPP, 110 RPM with
UP WT=82K. OWN WT=80K.
pump 5,000 STKS. observe well 10
min (Static).
6/21/2018
6/21/2018
1.00
PROD1
CASING
TRIP
P
POOH from 1,824' MD -388' MD
1,824.0
388.0
22:00
23:00
rackin gback 4.5" DP. Monitor well at
HWDP 10 min.
6/21/2018
6/22/2018
1.00
PROD1
CASING
BHAH
P
Begin breaking down 8 3/4" BHA
388.0
226.0
23:00
00:00
6/22/2018
6122/2018
1.50
PROD1
CASING
BHAH
P
Continue to LD 8 3/4" drilling BHA.
226.0
0.0
00:00
01:30
Gear and clean rig floor.
6/22/2018
6/2212018
1.00
PROD1
PLUG
RURD
X
RU 3 1/2" handling equipment for 3
0.0
0.0
01:30
02:30
1/2" EUE cement stinger asym.
6/22/2018
6/22/2018
4.75
PROD1
PLUG
TRIP
X
MU and RIH with 1,193.92' of 3 1/2"
0.0
6,250.0
02:30
07:15
9.3# L-80 cement stinger asym for
P&A program. PUsh in hoe with 4 112"
DPto 6,250' MD in preparation for plug
program.
Page 6/35 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stas Depth
Startliras
End Time
our (hr)
Phase
Op Code
Activity Code
Time P -T -X
operation
(fiKB)
End Depth(ILKS)
6/22/2018
6/22/2018
2.25
PROD1
PLUG
CIRC
X
Recip pipe from 6,250' MD - 6,155'
6,250.0
5,722.0
07:15
09:30
MD Circulating up to 650 GPM ICP -
193 PSI DPP. with FCP - 1,058 PSI
DPP. 32% F/O. Pumped 7800 STKS
for initial. Spot 50 BBL of 12 PPG
high vis pill @ 355 GPM 420 PSI @
24% F/O. chase with 78 BBLs of
-SND @ 355 GPM 542 PSI @ 23%
F/O. PUH to 5,722' MD UP WT =
119K OWN WT = 88K. BD Top drive
and RU cement manifold / hose.
6/22/2018
6/22/2018
1.50
PROD1
PLUG
CIRC
X
Condition mud and circulate while
5,722.0
5,722.0
09:30
11:00
stage pumps up to 7 BPM ICP = 167
. -
FCP = 420 18% F/O. PJSM for
cement program.
6/22/2018
6/22/2018
3.00
PROD1
PLUG
CMNT
X
Begin fat cement plug testing lines to
5,722.0
5,206.6-
11:00
14:00
800 - 3000 PSI, Pump 26 BELS 12.5
PPG mud push @ 3 BPM ICP = 150
PSI DPP, FCP = 50 PSI DPP. rose
bag and batch up cement. Open bag
and pump 50 BBLS of 15.8 Class G
cement @ 3.5 BPM ICP = 50 PSI
DPP, FCP = 102 PSI DPP. Close bag
and drop foam ball. / Open bag to
pump 4 BBLS 12.5 PPG mud push,
Swap to rig pumps and pump 58
BBLS LSND @ 7 BPM, ICP = 60 PSI
DPP, FCP = 300 PSI DPP. catch up
to vement after 400 stks away. reduce
rate to 4 BPM 12% FIC. PUH on
elevators at 1300 hrs from 5,722' MD
to 5,206' MD. UP WT = 111 K. Stage
up pumps to 7 BPM With ICP 196 PSI
DPP, FCP - 420 PSI DPP. 18% F/O.
pump 3400 silks.
6/22/2018
6/22/2018
2.25
PRODi
PLUG
CMNT
X
Begin 2nd cement plug pumping 26
5,206.0
4,610.0
14:00
16:15
BBLs 12.5 PPG mud push It. @ 3
BPM with ICP 222 PSI DPP, FCP - 50
PSI DPP. 10% F/O. Close bag and
batch up cement. Open bag pump 50
BBLS of 15.8 PPG Class G cement.
with ICP 50 PSI DPP. FCP 120 PSI
DPP. 14% F/O. Close bag drop foam
ball, Open bag and pump 4 BBLS 12.5
PPG. Mud push ii Swap to rig pumps.
pump 51 BBLS of LSND @ 7 BPM.
ICP = 153 PSI. catch cement @ 260
silks. Reduce rate to 4 BPM FCP =
374 15% F/O. PUH on elevators from
5206' - 4,610' MD. UP WT=104K.
Circulate staging pumps up to 650
GPM @ ICP 1,230 PSI FCP - 600 PSI
DPP. 31 % F/O, Reduce rate due to
contaminated mud returning to surface
at 350 GPM. 352 PSI DPP. 22% F/0,
3,575 STKS pumped.
6/22/2018
6/22/2018
2.25
PROD1
PLUG
CIRC
X
Spot 45 BBL 12 PPG hi vis pill at 350
4,610.0
4,132.0
16:15
1830
GPM 382 PSI DPP. 22% F/O. Chase
pill with 56.8 LSND mud at 350 GPM
380 PSI DPP 22% F/O. POUH on
elevators from 4,610' MD - 4,132' MD.
UP WT = 99K, OWN WT = 80K.
Condition mud and circulate pumping
441 GPM 565 PSI DPP, 27% F/0,
Reduce rate due to contaminated mud
returns to 350 GPM 350 PSI DPP,
23% F/O. 5,580 STKS pumped.
Page 7135 Report Printed: 811 012 01 8
Operations Summary (with Timelog Depths)
1H-108
11PRig:
DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Stan Tma
PnETme
Wits)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(fiKB)
EM Depth (WG)
6/22/2018
6/22/2018
2.25
PROD?
PLUG
CMNT
X
Begin 3rd cement isolation plug pump
4,132.0
3,400.0
18:30
20:45
25 BBLS 12.5 PPG Mud push ii. 4
BPM @ 220 PSI, 12% F/0, close bag.
Batch up cement. CEMENT WET
1852 HRS. Pump 70.3 BBLS 15.8
PPG class G cement at 4 BPM, 390
PSI DPP. Close bag drop foam ball,
Open bag and pump 5 BBLS of 12.5
PPG Mud push II then swap to rig
pumps pumping 33 BBLS of 9.3 PPG
LSND @ 7 BPM, catch cement at 180
STKS ICP = 300 PSI DPP FCP = 750
PSI. PUH from 4,132'MD-3,400'MD
monitor disp via pit #5, UP WT = 85K.
OWN WT=80K. Break over weight at
119K.
6/22/2018
6/22/2018
1.25
PROD?
PLUG
CIRC
X
Circulate @ 3,400' MD at 450 GPM
3,400.0
3,400.0
20:45
22:00
560 PSI 27% F/O. Total stks 6,600.
UP WT = 84K. OWN WT = 79K.
6/22/2018
6/22/2018
0.25
PROD?
PLUG
OWFF
X
BD lop drive and OWFF.
3,400.0
3,400.0
22:00
22:15
6/22/2018
6/22/2018
1.25
PRODi
PLUG
TRIP
X
POOH from 3,400'to 1,190'MD
1,190.0
1,190.0
22:15
23:30
standing back DP. Monitor disp via pit
5
6/22/2018
6/23/2018
0.50
PROD1
PLUG
TRIP -
X
Stand back 3 1/2" L-80 tubing from
1,190.0
722.0
23:30
00:00
1,190' MD - 722' MD. Monitor disp
viat Pit 5.
6/23/2018
6/2312018
0.75
PRODt
PLUG
TRIP
X
Continue to POOH with 3.5" 9.3# L-80
722.0
0.0
00:00
00:45
cement string standing back in derrick
from 722' MD - surface.
6/23/2018
6/23/2018
0.75
PROD1
PLUG
W W WH
X
MU Jhnny Wacker tool and wash
0.0
275.0
00:45
01:30
BOP'S. 21 BPM then RIH three
stands.
6/23/2018
6/23/2018
17.50
PROD1
PLUG
WOC
X
Wait on cement to cure. SIMOPs
275.0
0.0
01:30
19:00
NOVO's troubleshooting / training.
6/23/2018
6/23/2018
2.50
PROD1
PLUG
TRIP
X
MU 3/5" cement muleshoe and RIH
0.0
3,282.0
19:00
21:30
with 3 1/2" 9.3# L-80 cement string.
Monitor displacement via pit #1.
6/23/2018
6/23/2018
0.50
PRODt
PLUG
CIRC
X
Circulate bottoms up stage pumps to
3,282.0
3,282.0
21:30
22:00
450 GPM @ 480 PSI DPP. 27% F/O,
UP WT = 83K, OWN WT 77K, MW in -
9.1 MW Out =9.3 VERY
CLOBBERISH!
6/23/2018
6/23/2018
0.75
PROD1
PLUG
WASH
X
Wash down from 3,282' MD at 2 BPM
3,282.0
3,402.0
22:00
22:45
110 PSI DPP. 7% F/O, tag TOC at
3,402' MD. rotate string 180 Deg and
confirm tag at 3,402' MD with 7-8K
dwn wL
6/23/2018
6/2312018
0.25
PROD1
PLUG
TRIP
X
POOH from 3,402' MD - 2,806' MD UP
3,402.0
2,806.0
22:45
23:00
WT=75K. OWN WT=73K.
6/23/2018
6/23/2018
0.50
PROD1
PLUG
CIRC
X
Spot 50 BBLS hi vis 13.5 PPG pill and
2,806.0
2,806.0
23:00
2330
chase with 315 stks LSND.
6/23/2018
6/24/2018
0.50
PROD1
PLUG
TRIP
X
POOH from 2,806 MD - 2,334' MD UP
2,806.0
2,334.0
23:30
00:00
WT=68K. OWN WT=67K.
6/24/2018
6/24/2018
0.25
PROD1
PLUG
TRIP
X
Continue to PUH to 2,267' MD.
2,334.0
2,267.0
00:00
00:15
6/24/2018
6/24/2018
1.00
PROD1
PLUG
RURD
X
Blow down lop drive and rig up
2,267.0
2,267.0
00:15
01:15
cement equipment. Blow down
cement line and hold PJSM for
cement program.
Page 8135 Report Printed: 8 /1 012 01 8
AftOperations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Start Time
End Time
our (m)
Phase
Op Code
ACUVity Coda
Taxa P -T-%
Operation
(NKr)
End Depth(ftKB)
6/24/2018
6/24/2018
1.25
PROD1
PLUG
CMNT
X
Pump kick off plug. Pressure lest all
2,267.0
2,267.0
01:15
02:30
lines to 3,500 PSI. Pump 25 BBLs of
12.5# at 3.3 BPM 90 PSI DPP, Gose
bag and batch up cement. pump 50
BBLS of 17# class G cement @ 3.3
BPM 70 PSI, Close bag and drop
foam wiper ball. Open bag and pump
4 BBLS 12.5# Mud push II, chase with
1 BBL afresh water to clear surface
lines. Swap to rig pumps and displace
with 13 BBLs @ 4 BPM 215 PSI.
Catch cement at 8 BBLS into
displacement. Cement wet at 0138
hrs. Cement in plae 0228 hrs.
6124/2018
6/24/2018
0.75
PROD1
PLUG
TRIP
X
POOH from 2,267' MD to 1,661' MD
2,267.0
1,661.0
02:30
03:15
Monitor displacement via Pit 1 UP WT
= 58K, DWN WT = 60K.
6/24/2018
6/24/2018
0.75
PROD1
PLUG
CIRC
X
Circulate three bottoms up while recip
1,661.0
1,661.0
03:15
04:00
from 1,661' MD - 1,600' MD. Monitor
returns via pit #1. UP WT = 58K,
DWN WT = 60K. 450 GPM @ 210
PSI DPP, 26% Flo, total siks pumped
= 3100. MW in = 9.1+ MW out = 9.2
PPG.
6/24/2018
6/24/2018
3.50
PROD1
PLUG
PULD
X
BD top drive monitor well (static) and
1,661-0
0.0
04:00
07:30
POOH from 1,661' MD to surface.
Monitor disp via Pit #1. LD all 3.5" L-
80 tubing down sideways from 1,193'
MD to surface and kick out.
6/24/2018
6/24/2018
1.50
PROD1
PLUG
RURD
X
Rig down GBR and release. clean dg
0.0
0.0
07:30
09:00
floor.
6/24/2018
6/25/2018
15.00
PROD1
PLUG
WOC
X
Wait on cement to cure. Crews
0.0
0.0
09:00
00:00
performing maintenance / cleaning /
paint / training.
6/25/2018
6/25/2018
7.00
PROD1
PLUG
WOC
X
Continue to WOC. Sim ops rig
0.0
0.0
00:00
07:00
maintenance.
6/2512018
6/25/2018
0.25
PROD1
PLUG
SFTY
X
PJSM
0.0
0.0
07:00
07:15
6/25/2018
6/25/2018
1.25
PROOI
PLUG
SHAH
X
MU Drilling BHA#3 as per SLB rep. to
0.0
379.0
07:15
08:30
379' MD. Monitor disp via pit#1.
6/25/2018
6125/2018
1.00
PROD1
PLUG
TRIP
X
Continue to RIH from 379' MD to
379.0
1,625.0
08:30
09:30
1,625' MD running 4 1/2" bP out of
derrick. UP WT=81 K. DWN WT=
84K. Monitor disp via pit #1.
6/25/2018
6/25/2018
0.25
PROD1
PLUG
DHEQ
X
Shallow hole lest @ 525 GPM, 785
1,625.0
1,625.0
09:30
09:45
PSI SPP. 29% F/O test good.
6/25/2018
6/25/2018
1.25
PROD1
PLUG
CIRC
X
Condition mud and circulate @ 650
1,625.0
1,625.0
09:45
11:00
GPM, 1,025 PSI DPP @ 30% F/O,
Total stks 10,075.
6/25/2018
6/25/2018
0.50
PROD1
PLUG
WASH
X
Wash down from 1,625' MD to 1,772'
1,625.0
1,772.0
11:00
11:30
MD TOC. Set 5K DWN. UP WT=
81 K, DWN WT=84K, ROT -81 K.
6/25/2018
6/25/2018
0.50
PROD1
PLUG
DRLG
X
Drill cement from 1,772' MD- 1,817'
1,772.0
1,817.0
11:30
12:00
MD with 520 GPM @ 750 PSI DPP.
31 % F/O, 60 RPM, 2-4K TQ, 4K
WOB. Off BTM Press 743 PSI, ECD
10. 18, UP WT=81 K, DWN WT=
84K, rotation WT = 84K.
6/25/2018
6/25/2018
2.00
PROD1
PLUG
DRLG
X
Drill cement form 1,817 MD - 1,900'
1,817.0
1,900.0
12:00
14:00
MD W 520 GPM @ 750 PSI DPP.
31 % FlO, 60 RPM, 2-41K TQ, 4K
WOB. Off BTM = 743, ECD = 10.18,
UP WT = 81K, DWN WT = 84K, ROT
WT = 84K
Page 9135 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
11-1-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Stan Time
End Time
Mr (m)
Phase
Op Code
Activity Code
Time P -T -X
Opeahcm
(11m)
End Depth(IlKS)
6/25/2018
6/25/2018
4.00
PROD2
DRILL
DDRL
X
DDRLfrom 1,900'MD - 2,181'MD
1,900.0
2,181.0
14:00
18:00
2,060 TVD, 550 GPM @ 38% F/O,
100 RPM 3K To, 4K WOB, ECD =
10.07 Off Btm = 670 PSI, UP WT =
90K, OWN WT = 84K, ROT- 87K,
Max Gas = 5 units, ADT - 1.98, Bit Hrs
- 1.98, Jar hrs - 65.99
SPR's @ 2,000' MD 1,911' TVD MW =
9. PPG Time 1545 hr
MP1) 30 SPM 80 PSI 40 SPM 110 PSI
MP2) 30 SPM 80 PSI 40 SPM 110 PSI
6/25/2018
6/26/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 2,181'MD 2,060 TVD-
2,181.0
3,159.0
18:00
00:00
3,159' MD 2,586' TVD, 650 GPM @
29% F/O, 140 RPM 4K TO, 5K WOB,
ECD = 10.25 Off Btm = 1,020 PSI, UP
WT = 99K, DWN WT= 85K, ROT -
89K, Max Gas = 170 units, ADT - 3.37,
Bit Hrs - 5.35, Jar hrs - 69.36
SPR's @ 2,298' MD 2,148' TVD MW =
9.2 PPG Time 1835 hr
MP1) 30 SPM 80 PSI 40 SPM 120
PSI
MP2) 30 SPM 80 PSI 40 SPM 120
PSI
6/26/2018
6/26/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 3,159'MD 2,586'TVD-
3,159.0
4,153.0
00:00
06:00
4,153' MD 2,821' TVD, 650 GPM @
1,180 PSI DPP 29% NO, 140 RPM
6K To, 13K WOB, ECD = 10.61 Off
Btm = 1,170 PSI, UP WT = 108K,
DWN WT = 78K, ROT- 89K, 4K TO
Max Gas = 20 units, ADT - 3.26, Bit
Hrs - 8.61, Jar hrs - 72.62
6/26/2018
6/26/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 4,153'MD 2,821'TVD-
4,153.0
5,022.0
06:00
12:00
5,022' MD 3,099' TVD, 650 GPM @
1,180 PSI DPP 29% F/0, 140 RPM
6K TO, 8K WOB, ECD = 10.61 Off
Btm = 1,170 PSI, UP WT = 108K,
DWN WT= 78K, ROT -89K, 4K TO
Max Gas = 20 units, ADT - 3.48, Bit
Hrs -12.09, Jar hrs - 76.10
SPR's @ 4,198' MD 2,831' TVD MW =
9.2 PPG Time 0620 hr
MPI) 30 SPM 160 PSI 40 SPM 200
PSI
MP2) 30 SPM 160 PSI 40 SPM 190
PSI
6/26/2018
6/26/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 5,022' MD 3,099' TVD
5,022.0
5,725.0
12:00
18:00
5,725' MD 3,362' TVD, 650 GPM @
1,450 PSI DPP 29% F/O, 140 RPM
7K To, 1 OK WOB, ECD = 10.04 Off
Btm = 1,400 PSI, UP WT = 122K,
DWN WT = 83K, ROT- 99K, 8K TO
Max Gas = 112 units, ADT - 3.89, Bit
Hrs - 15.98, Jar hrs - 79.99
Page 10135 ReportPrinted: 8/10/2018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Smn Time
End rime
Dw(hr)
Phase
Op Code
Activity Code
Time P -T -x
Operation
sten Deplh
(ftKB)
End DWh(OKB)
6/26/2018
6/27/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 5,725' MD 3,362' TVD -
5,725.0
6,550.0
18:00
00:00
6,550' MD, 650 GPM @ 1,565 PSI
DPP 27% F/O, 150 RPM 9K TO, 20K
WOB, ECD = 10.69 Off Btm = 1,560
PSI, UP WT = 136K, DWN WT = 90K,
ROT- 106K, 71K TO Max Gas = 70
units, ADT - 3.45, Bit Hrs - 19.43, Jar
hrs - 83.44
SPR's @ 5,726' MD 3,362" TVD MW
= 9.2 PPG Time 1800 hr
MP1) 30 SPM 160 PSI 40 SPM 210
PSI
MP2) 30 SPM 170 PSI 40 SPM 210
PSI
6/27/2018
6/27/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 6,550' MD 3,701' TVD -
6,550.0
7,439.0
00:00
06:00
7,493 MD 4,033' TVD, 650 GPM @
1,790 PSI DPP 29% F/O, 140 RPM
9.5K TO, 15K WOB, ECD = 10.92 Off
Btm = 1,780 PSI, UP WT = 148K,
DWN WT= 88K, ROT- 111K, 7K TO
Max Gas = 180 units, ADT - 3.69, Bit
Hrs - 23.12, Jar hrs - 87.13 Drilled
350' w/NOVO's
6/27/2018
6/27/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 7,493 MD 4,033'TVD-
7,439.0
8,076.0
06:00
12:00
8,076' MD 4,066' TVD, 650 GPM @
1,678 PSI DPP 30% F/O, 100 - 150
RPM 9.51K TO, 12-15K WOB, ECD =
10.87 Off Blm = 1,649 PSI, UP WT =
143K, DWN WT = 79K, ROT- 105K,
9K TO Max Gas = 317 units, ADT -
4.15, Bit Hrs - 27.27, Jar hrs - 91.28
Drilled 350' w/NOVO's
SPR's @ 7,435' MD 4,0511 " TVD MW
= 9.2+ PPG Time 0600 hr
MP1) 30 SPM 240 PSI 40 SPM 280
PSI
MP2) 30 SPM 240 PSI 40 SPM 280
PSI
6/27/2018
6/27/2018
6.00
PROD2
DRILL
DDRL
X
DDRL from 8,076'MD 4,066'TVD-
8,076.0
8,741.0
12:00
18:00
8,741' MD 3,948' TVD, 650 GPM @
2,000 PSI DPP 29% F/O, 150 RPM
11 K TO, 12K WOB, ECD = 10.81 Off
Bim = 1,995 PSI, UP WT = 138K,
DWN WT = 73K, ROT- 101 K, 8K TO
Max Gas = 236 units, ADT - 3.96, Bit
Hrs - 31.23, Jar hrs - 95.24
6/27/2018
6/27/2018
4.00
PROD2
DRILL
DDRL
X
DDRLfrom 8,741'MD3,948'TVD-
8,741.0
9,245.0
18:00
22:00
9,245' MD 3,787' TVD, 650 GPM @
2,135 PSI DPP 28% F/O, 150 RPM
12K TO, 13K WOB, ECD = 11.12 Off
Btm = 2,130 PSI, UP WT = 132K,
DWN WT= 60K, ROT -95K, 9K TO
,
Max Gas = 220 units, ADT - 2.76, Bit
Hrs - 33.99, Jar hrs - 98
Page 11/35 ReportPrinted: 8/10/2018
Operations Summary (with Timelog Depths)
11-1-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Start Time
End Time
Duf (hr)
Phase
Op Code
Activity code
Time P -T -X
Operation
(110)
EM Depth(ftKB)
6/27/2018
6/27/2018
1.00
PROD2
CASING
CIRC
X
Cycle pipe from 9,146' MD to 9,245'
9,245.0
9,146.0
22:00
23:00
MD while circulating bottoms up @
650 GPM, 28% Flo, 12 RPM, 8K TO,
10.8 ECD. UP WT=127, DNW WT=
65K, ROT 96K.
6/27/2018
6/27/2018
0.50
PROD2
CASING
OWFF
X
OWFF (Static)
9,146.0
9,146.0
23:00
23:30
6/27/2018
6128/2018
0.50
PROD2
CASING
BKRM
X
BKRM OOH from 9,146' MD - 9,016
9,146.0
9,016.0
23:30
00:00
UP WT = 90K, 645 GPM @ 2,053 PSI
DPP, ECD - 10.79 gas 27 units.
6/28/2018
6/28/2018
3.00
PROD2
CASING
BKRM
X
Continue to BKRM OOH from 9,016'
9,016.0
7,822.0
00:00
03:00
MD - 7,822' MD. UP WT = 140K,
OWN WT= 82K. 650 GPM @ 1,875
PSI DPP. 140 RPM with 8K TQ. ECD
= 10.64
6128/2018
6128/2018
1.50
PROD2
CASING
CIRC
X
Circulate bottoms up with a high vis
7,822.0
7,628.0
03:00
04:30
sweep. 7,822'MD-7,628'MD. UP
WT = 143K, OWN WT = 83K. pumped
11,500 STKS, with a MWI 9.2 MWO =
9.3 10.45 ECD, 650 GPM @ 28%
F/O, 150 RPM with 8K TQ.
6/28/2018
6/28/2018
0.50
PROD2
CASING
TRIP
X
POOH on elevators from 7,628' MD -
7,628.0
7,477.0
04:30
05:00
7,477' MD. Swabbing and 25K
overpull. go back to BKRM
6/28/2018
6/28/2018
7.00
PROD2
CASING
BKRM
X
BKRM OOH from 7,477' MD - 4,777'
7,477.0
4,777.0
05:00
12:00
MD. 650 GPM @ 1,526 PSI DPP.
28% F/O, 140 RPM, 5K TO, ECD =
10.62 UP WT = 91 K w/pump, DWN
WT=81K.
6/28/2018
6/28/2018
8.75
PROD2
CASING
BKRM
X
BKRM OOH from 4,777' MD - 1,736'
4,777.0
1,736.0
12:00
20:45
MD. Rate of BKRM = 750 FT/HR -
500 FT/HR. 650 GPM @ 1,525 -
1,030 PSI DPP. F/O 28%. 140-100
RPM. UP WT 83-88K, DWN WT =
84K. Slow down for coal areas 3,541'
- 3,066'/ 3,066 - 2400' . Recip pipe
while pumping high vis sweep at shoe.
6/28/2018
6/28/2018
0.50
PROD2
CASING
OWFF
X
OWFF (dropped 2"). Service TO situ
1,736.0
1,736.0
20:45
21:15
op.
6/28/2018
6/28/2018
0.50
PROD2
CASING
CIRC
X
Pump slug to surface then BD lop
1,736.0
1,736.0
21:15
21:45
Drive.
6/28/2018
6/28/2018
1.00
PROD2
CASING
TRIP
X
POOH from 1,736' MD - 379' MD.
1,736.0
379.0
21:45
22:45
Monitor disp via TT.
6/28/2018
6/28/2018
0.25
PROD2
CASING
OWFF
X
OWFF. Dropped 1".
379.0
379.0
22:45
23:00
6128/2018
6/29/2018
1.00
PROD2
CASING
SHAH
X
LD BHAfrm 379'- 94' MD as per DD.
379.0
94.0
23:00
00:00
Monitor well via TT.
6/29/2018
6/29/2018
1.25
PROD1
CASING
SHAH
X
Continue to lay down BHA from 94' As
94.0
0.0
00:00
01:15
per SLB. Monitor disp via TT. Clear
and clean rig floor.,
6/29/2018
6/29/2018
0.75
PROD1
PLUG
RURD
X
RU to run 3 1/2" cement string. Bring
0.0
0.0
01:15
0200
GBR to rig floor. Spot equip. PJSM
6/29/2018
6/29/2018
2.00
PROD2
PLUG
PULD
X
MU 31/2" Cement string BHA of 3
0.0
1,225.0
02:00
04:00
1/2" 9.3# EUE from surface to 1,225'
MD
6/29/2018
6/29/2018
3.25
PROD2
PLUG
TRIP
X
RIH with 4 1/2" DP from 1,225' MD -
1,225.0
8,000.0
04:00
07:15
8,000' MD. Monitor disp via TT UP
WT = 129K, DWN WT = 83K.
6129/2018
1.50
PROD2
PLUG
CIRC
Cir bottoms up while recip from 7,925'
8,000.0
8,000.0
07:15
08:45
MD - 8,000' MD. 308 GPM @ 430
161211211111
IX
PSI DPP. 20% F/O, Pump 5,427
STKS,
Page 12/35 _ ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
1 H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Staff Depth
start Time
End Time
our (hr)
Phase
op cme
Activity CoEe
Time P -T-%
operation
(1&S)
Entl Depth (ftKrn
6/29/2018
6/29/2018
0.50
PROD2
PLUG
CIRC
X
Spot 48 BBL pill of 12# Hi Ys spacer
8,000.0
8,000.0
08:45
09:15
and chase with 102.5 BBLS
6/29/2018
6/29/2018
0.50
PROD2
PLUG
TRIP
X
PUH from 8,000' MD - 7,497' MD.
8,000.0
7,497.0
09:15
09:45
Monitor disp via pit #1.
6/29/2018
6/29/2018
0.75
PROD2
PLUG
CIRC
X
RU cement manifold and circ 284
7,497.0
7,497.0
09:45
10:30
GPm @ 450 PSI DPP. 18% F10,
PJSM for cement job with
SLB/MI/DDI.
6/29/2018
6/29/2018
1.50
PROD2
PLUG
CMNT
X
Pump 1st stage of cement plug
7,497.0
7,497.0
10:30
12:00
program @ 7,497' MD. Flood all lines
and PT to 3,500 PSI. Close bag and
take all returns thru choke. Pump 27
BBLS 12.5# MP2 @ 4.2 BPM 100
PSI. Batch and pump 48.3 BBLS
15.8# cement at 4.5 BPM, 100 PSI.
drop wiper ball and pump 3 BBLS of
MP2. Swap to rig for displacement
with 82.7 BBLS LSND. Pump 4 BPM
@ 220 PSI, @ 772 stks reduce rate to
2 BPM, 197 PSI. Cement wet at 1112
HRS>
6/29/2018
6/29/2018
0.75
PROD2
PLUG
TRIP
X
PUH from 7,497' MD -7,000' MD.
7,497.0
7,000.0
12:00
12:45
1,500 FPH pulling speed. Monitor
disp via Pit #1. UP WT = 129K, DWN
WT = 79K.
6/29/2018
6/29/2018
1.00
PROD2
PLUG
CIRC
X
Circulate bottoms up while recip from
7,000.0
7,000.0
12:45
13:45
6,930' MD - 7,000' MD. Stage up
pumps to 650 GPM @ 1,380 PSI.
29% F/O.
6/29/2018
6/29/2018
0.50
PROD2
PLUG
CIRC
X
Spot 40 BBL pill of 12# Hi Vis spacer
7,000.0
7,000.0
13:45
14:15
and chase with 89.8 BBLS -SND.
892 STKS @ 239 GPM 300 PSI, 13%
F10.
6/29/2018
6/29/2018
0.75
PROD2
PLUG
TRIP
X
PUH from 7,000' MD to 6,580' MD.
7,000.0
6,580.0
14:15
15:00
MU 10' PUPjt. UP WT= 129K, DWN
W T= 81 K. Monitor disp via Pit #1.
6/29/2018
6/29/2018
0.50
PROD2
PLUG
CIRC
X
From 6,585' circulate bottoms up at
6,580.0
6,580.0
15:00
15:30
630 GPM. 1,290 PSI at 32% F/0.
total stks 4,071.
6/29/2018
6/29/2018
1.25
PROD2
PLUG
CMNT
X
PJSM . RU cement hose and
6,580.0
6,580.0
15:30
16:45
manifold, Close ann, open choke and
pump cement plug #2. 27 BBPS
12.5# MPII @ 4.2 BPM 50-156 PSI
DPP. Close choke and batch up
cement. With super choke 1/2 open
pump 59.5 BBLS of 15.8# class G
cement. 4.7 - 4.2 BPM @ 84-111 PSI
DPP. Close super choke to drop wiper
ball. Pump 3 BBLS MPII spacer and 1
BBL water. swap to rig pumps and
displace at 5 BPM, 220-250 PSI DPP.
4 BPM at 642 stks.340 PSI DPP. 2
BPM from 691 STKS at 232 FCP.
6/29/2018
6/29/2018
0.75
PROD2
PLUG
TRIP
X
PUH to 5,972' MD UP WT= 118K.
6,580.0
5,972.0
16:45
17:30
OWN WT = 83K. Monitor disp via Pit
#1.
6/29/2018
6/29/2018
1.25
PROD2
PLUG
CIRC
X
Circulate bottoms up while recip from
5,972.0
5,972.0
17:30
18:45
5,942' MD - 5,972' MD. at 626 GPM
1,400 PSI DPP. 32%F/0. Reduce
-
rate at 2,700 stks due to interface
overflowing drag chain system.
Increase rate to 633 GPM at 5,400
stks 1,380 PSI. 32% F10. 7,379 total
stks pumped.
Page 13/35 ReportPrinted: 8/10/2018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Shit Depth
Start Tone
End Time
Dur(ho
Phase
Op Cods
Activity Code
Time P -T -X
Operation
tm)
End Depth (1tKB)
6/29/2018
6/2912018
1.50
PROD2
PLUG
CMNT
X
Pump cement plug # 3 at 5,972' MD.
5,972.0
5,972.0
18:45
20:15
MU cement hose assym and close
arm taking returns through super
choke and closing chokes with pumps
off. Pump 27 BBLS 12.5# MPII. at 4
BPM 850 ICP, 340 FCP, Mix and pump
48.3 BBLS of 15.8#. cmt at 4 BPM. 78
-230 PSI. Stop wiper ball at 160 stks.
4 BPM from 420 stks 500 PSI. reduce
to 3 BPM 518 PSI FCP. 617 total stks
pumped.
6/2912018
6/29/2018
0.75
PROD2
PLUG
TRIP
X
PUH from 5,972' MD to 5,470' MD.
5,972.0
5,470.0
20:15
21:00
UP WT= 114K, DWN WT= 78K.
Swabbing occuring so slow down to
115
FPM.
6129/2018
6/29/2018
2.75
PROD2
PLUG
CIRC
X
Circulate while recip from 5,440' MD -
5,470.0
5,470.0
21:00
23:45
5,470' MD. stage pumps to 630 GPM
@ 1,320 PSI DPP. 34% Flo, total
stks pumped 16,690. UP WT = 107.
DWN WT= 76K.
6129/2018
6/30/2018
0.25
PROD2
PLUG
CIRC
X
5,3467' MD spotting 45 BELS spacer
5,470.0
5,470.0
23:45
00:00
pill and chase with 682 STKS at 5
BPM 328 PSI DPP. 15% F/O.
6/30/2018
6/3012018
0.75
PROD1
PLUG
TRIP
X
PUH and space outwith 15' PUP to
5,470.0
5,007.0
00:00
00:45
get on depth at 5,007' MD. UP WT =
107K Monitor disp via pit #1.
6/30/2018
6130/2018
0.50
PROD1
PLUG
RURD
X
Flush choke manifold from previous
5,007.0
5,007.0
00:45
01:15
cement plugs. Rig up cement
manifold to DP.
6/30/2018
6/30/2018
1.00
PROD2
PLUG
CMNT
X
Pump Cement plug #4 of AS1. Pump
5,007.0
5,007.0
01:15
02:15
27 BBLS of 12.7 PPG mud pushll @
3.7 BPM 170 PSI DPP. Close bag,
batch up cement system. Open
-
Annular and pump 67.7 BBLS of 15.7#
ASI cement at 4.3 BPM 90 PSI DPP.
Close bag and drop wiper ball. Pump
3 BBLS Mud pushll and one barrel
fresh water. Displace cement with rig
pumps of LSND at 4 BPM with last 5
BBLS being pumped at 2 BPM. 470
PSI DPP. Was able to catch cement
21 BBLS into displacement. Cement
wet at 0213 hrs.
6/30/2018
6/30/2018
1.00
PROD2
PLUG
TRIP
X
PUH from 5,007' MD - 3,980' MD.
5,007.0
3,980.0
02:15
03:15
starting at 15 FPM then changed to 30
FPM. Monitor disp via Pit #1. UP WT
= 94K, DWN WT = 74K.. 28K OP to
move pipe.
6/30/2018
6/30/2018
5.75
PROD2
PLUG
WOC
X
630 GPM @ ICP of 1,120 PSI DPP
3,980.0
3,980.0
03:15
09:00
FCP 965 PSI DPP. 34% F/0.
6/30/2018
6130/2018
1.00
PROD2
PLUG
WASH
X
Wash down from 3,980' MD - 4,298'
3,980.0
4,280.0
09:00
10:00
MD @ 2 BPM 145 PSI DPP. 7% F/0,
UP WT=94K, DWN WT=78K. Wash
thin set down at 4,272' MD - 4,280'
MD.
6/30/2018
6/30/2018
1.75
PROD2
PLUG
WASH
X
Wash down and circulate with
4,280.0
4,513.0
10:00
11:45
reciprocations from 4,280' MD -4,513'
MD @ 2 BPM with ICP of 145 PSI,
-
FCP of 210 PSI. 9% F/O, UP WT =
96K, DWN WT = 78K.
6/30/2018
6/30/2018
2.00
PROD2
PLUG
CIRC
X
CBU while recip from 4,513'4,456'
4,513.0
4,513.0
11:45
13:45
MD treating Fluids due to clobbering.
Stage up to 660 GPM 1,285 PSI, 33%
F/O, 8,830 STKS @ full rate.
-
Page 14135 ReportPrinted: 811 012 01 8
Uperations Summary (with Timelog Depths)
1 H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
startTime
End Toe
our (hr)
Phase
op Code
A i Code
ty
Time P-T-X
Operation
Start Depth
n De
EM Depth (flKe)
6/30/2018
6/30/2018
0.75
PROD2
PLUG
WASH
X
Continue to wash down to tag depth of
4,513.0
4,714.0
13:45
14:30
4,714' MD. Tagged three times and
witnessed by Jeff Jones with AOGCC.
UP WT = 96K, OWN WT = 78K.
Tagged with 2 BPM and 1 OK DWN
WT.
6/30/2018
6/30/2018
1.25
PROD2
PLUG
CIRC
X
CBU while recip from 4,714' MD -
4,714.0
4,714.0
14:30
15:45
4,641' MD Staging pumps up to 630
GPM @ ICP 1,380 PSI DPP, FCP =
-
1,080 PSI. 5,964STKS.
6/30/2018
6/30/2018
1.50
PROD2
PLUG
TRIP
X
POOH from 4,714' MD - 2,784' MD.
4,714.0
2,784.0
15:45
17:15
Monitor disp via Pit#'. UP WT=
100K, DWNWT=80K.
6/30/2018
6/30/2018
0.25
PROD2
PLUG
CIRC
X
Pump 48.35 BBL spacer pill Hi-Vis
2,784.0
2,784.0
17:15
17:30
monitoring disp via Pit 1. chase with
218 stks.
6/30/2018
6/30/2018
0.50
PROD2
PLUG
TRIP
X
PUH from 2,784' MD - 2,282' MD
2,784.0
2,282.0
17:30
18:00
monitoring disp via Pit 1, UP WT =
72K, DWN WT = 71 K,
6/30/2018
6/30/2018
0.75
PROD2
PLUG
CIRC
X
Circulate while recip from 2,282' MD -
2,282.0
2,282.0
18:00
18:45
2,189' MD, 630 GPM @ 820 PSI DPP.
32% F/O. UP WT = 69K. DWN WT =
171K. Total strokes pump= 3,900.
6/30/2018
6/30/2018
1.25
PROD2
PLUG
CMNT
X
RU cement head and pump KO plug.
2,282.0
2,282.0
18:45
20:00
PUmp 27 BBLS of 12.5# MP @ 4.8
BPM54 PSI DPP> close bag and
batch cement. Open bag and pup 51
BBLS ofAS1 15.7# cement at 4.6
BPM 100-421 PSI DPP. close bag
and drop ball. Pump 3 BBLS Mud
Push II and 1 BBLS fresh water
behind ball then wasp to rig pumps for
displacement of 11.47 BBLS LSND at
4 BPM, 35 PSI with last 5 BBLS at 2
BPM 42 PSI. Cement wet at 1920
hm. CIP @ 1946 hrs.
6/30/2018
6/30/2018
1.00
PROD2
PLUG
TRIP
X
PUH from 2,282' MD - 1,684' MD. 15
2,282.0
1,684.0
20:00
21:00
FPM@ 62K UP WT, 59K DWN WT.
Monitor disp via TT.
6/30/2018
6/30/2018
0.50
PROD2
PLUG
CIRC
X
Circulate while recip form 1,684' MD-
1,684.0
1,684.0
21:00
21:30
1,602'MD. UP WT=62K DNW WT=
59K. 630 GPM @ 760 PSI DPP FCP
= 681 PSI DPP.
6/30/2018
6/30/2018
0.25
PROD2
PLUG
OWFF
X
OWFF BD TD.
1,684.0
1,684.0
21:30
21:45
6/30/2018
6/30/2018
0.75
PROD2
PLUG
PULD
X
POOH laying down 41/2" DP from
1,684.0
1,225.0
21:45
22:30
1,634' MD- 1,225' MD. Monitor disp
via pit #1.
6/30/2018
6/30/2018
0.50
PROD2
PLUG
RURD
X
RU GBR handling equipment for 3
1,225.0
1,225.0
22:30
23:00
1/2" 9.3# tubing.
6/30/2018
7/1/2018
1.00
PROD2
PLUG
TRIP
X
POOH with 3 1/2" L-80 tubing
1,225.0
540.0
23:00
00:00
standing back in derrick. C/O seal
rings on the fly. Monitor disp via Pit
#1.
7/1/2018
7/1/2018
1.50
PROD2
PLUG
TRIP
X
Continue to stand back in derrick 3
540.0
0.0
00:00
01:30
1/2" L-80 - 8 rnd EUE tubing while
replacing seal rings. Monitor disp via
Pit 1. Clear and clean rig floor.
7/1/2018
7/1/2018
0.75
PROD2
WWWH
X
MU Johnny wackerand wash 930
0.0
0.0
01:30
02:15
GPM @ 160 PSI. wellhead/BOP'S
JPLUG
from post cement programs. Pull Wer
busing and service.
Page 15135 ReportPrinted: 8/10/2018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Start Time
End Time
Dur(m)
Phase
Op Code
Activity Code
Time P -T -X
operation
(BKB)
End Depth(ftKB)
7/1/2018
7/1/2018
0.50
PROD2
PLUG
BOPE
X
Install test plug / flood stack with fresh
0.0
0.0
02:15
02:45
water and test blind rams to 250 /
3500 PSI. 5/5 charted (Passed) UII
test plug / install wear bushing.
7/1/2018
7/1/2018
1.25
PROD2
PLUG
BHAH
X
M/U BHA for cleanout using 9 7/8"
0.0
285.0
02:45
04:00
Generic rock bit. Monitor disp via Pit
.1
7/1/2018
7/1/2018
0.75
PROD2
PLUG
TRIP
X
TIH from 285' MD- 1,616' MD.
285.0
1,616.0
04:00
04:45
Monitor disp via Pit 1.
7/1/2018
7/1/2018
0.25
PROD2
PLUG
CIRC
X
Circulate bottoms up at 630 GPM ,
1,616.0
1,661.0
04:45
05:00
650 PSI DPP. 60 RPM with 2K TQ.
Recip pipe.
7/1/2018
7/1/2018
0.75
PROD2
PLUG
WASH
X
Wash down from 1,661' MD to
1,661.0
1,750.9
05:00
05:45
1,750.89' MD at 2 BPM 105 PSI
DPP, 7% F/O, tag cement at 1,750.89'
MD. with 15K OWN WT. UP WT=
77K, OWN = 80K.
7/1/2018
7/112018
0.25
PROD2
PLUG
DRLG
X
Drill cement from 1,750.89' MD-
1,750.9
11765.0
05:45
06:00
1,765' MD. 800 GPM @ 875 PSI
DPP. 34% F/O, 60 RPM with 2K TO.
1KSOB. ,
7/1/2018
7/1/2018
0.75
PROD2
PLUG
CIRC
X
Circulate BU while rotating and recip
1,765.0
1,765.0
06:00
06:45
from 1,765' MD - 1,705' MD. 807
GPM @ 880 PSI DPP. 34% F/O, 60
RPM 1.5K TQ. 6,500 STKS pumped.
UP WT = 80K. OWN WT =- 80K.
7/1/2018
7/1/2018
1.75
PROD2
PLUG
PRTS
X
RU and perform a rasing pressure
1,765.0
1,765.0
06:45
08:30
test against TOC. 1,500 PSI = 300
PSI bleed off over charted 30 min test.
Bleed off and dg dwn test equip.
7/1/2018
7/112018
0.25
PROD2
PLUG
DRLG
XT
Drill cement from 1,765' MD - 1,784'
1,765.0
1,784.0
08:30
08:45
MD at 802 GPM 850 PSI. 34% F/O,
60 RPM, 2K TO, SK WOB.
711/2018
7/1/2018
0.75
PROD2
PLUG
CIRC
XT
Circulate bottoms up while recip from
1,784.0
1,799.0
08:45
09:30
1,784' MD -1,799' MD. @ 802 GPM,
805 PSI DPP. 34% F/O, 60 RPM 1.5K
TQ. 3535 total stks pumped. UP WT
.
= 82K, OWN WT= 80K. Tag cement
with 11 K OWN WT.
7/1/2018
7/1/2018
2.50
PROD2
PLUG
PRTS
XT
MU test equip and test / chart cmt plug
1,799.0
1,799.0
09:30
12:00
to 1,500 PSI. Pressure dropped on
initial test from 1,500 PSI - 570 PSI.
PUmped 1.8 BBLS to obtain 1500
PSI. Check all surface equip and
repeat test X 3 with pressure leveling
off at 850 PSI, then droppping to 500
PSI after isolating rasing. RD test
equip B/D same. test witnessed by
Jeff Jones with AOGCC.
7/112018
7/1/2018
4.25
PROD2
PLUG
PULD
X
UD std @16 from string in hole to
1,799.0
1,708.0
12:00
16:15
1,708' MD. Cont to LD stds from
derrick via mousehole. LD total of 47
stds. Off bottom UP WT = 80K. OWN
WT = 80K.
7/1/2018
7/1/2018
0.75
PROD2
PLUG
TRIP
XT
POOH racking back DP in derrick.
1,708.0
285.0
16:15
17:00
Monitor disp via Pit 1.
7/1/2018
7/1/2018
0.25
PROD2
PLUG
OWFF
X
OWFF/pre job LD BHA
285.0
285.0
17:00
17:15
7/1/2018
7/1/2018
2.25
PROD2
PLUG
BHAH
X
LD BHA monitor disp via Pit 1. Clean
285.0
0.0
17:15
19:30
rig floor /jet flow line and clean floor
pan.
7/112018
7/1/2018
0.50
PROD2
PLUG
SVRG
X
Service top drive /Blocks / crown.
0.0
0.0
19:30
20:00
Page 16135 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
AN
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time log
Start Depth
Start Time
End Time
Dur(m)
Phase
Op Cade
Activity Code
Tare P -T -X
Operation
(ftKB)
End Depth(ftKB)
7/1/2018
7/1/2018
1.25
PROD2
PLUG
TRIP
X
Make up Baker 10 3/4" N-1 cement
0.0
1,726.0
20:00
21:15
retainer and RIH to 1,726' MD.
Monitor disp via Pit 1. UP WT = 73K.
DWN WT = 70K.
7/1/2018
7/1/2018
1.00
PROD2
PLUG
CIRC
X
Fill pipe and RIG to tag TOC. Tag at
1,726.0
1,786.0
21:15
22:15
1,786' MD. Pick up 3' and circ 1.5 SIB
# 6 BPM. 285 PSI 16% F/0, total stks
pumped 2,350. UP WT = 73K. DWN
WT=71K.
7/1/2018
7/1/2018
1.00
PROD2
PLUG
MPSP
X
Set cement retainer as per BOT REP.
1,786.0
1,782.0
22:15
23:15
Top of retainer at 1,782' MD. PU and
RU to test retainer to 1,500 PSI for 30
MIN (PASSED).
7/1/2018
7/2/2018
0.75
PROD2
PLUG
DISP
X
Displace well over to sea water at 10
1,782.0
1,782.0
23:15
00:00
BPM 240 PSI DPP 20% F/O, UP WT =
73K, DWN WT=72K.
7/2/2018
7/2/2018
1.75
PROD2
PLUG
PRTS
X
RU and test cement retainer with sea
1,782.0
1,782.0
00:00
01:45
water to 1,500 PSI charted 30 min.
(PASSED)
7/2/2018
7/212018
0.50
PROD2
PLUG
OWFF
X
OWFF and monitor same. BD top
1,782.0
1,782.0
01:45
02:15
drive / equip
7/2/2018
7/2/2018
1.50
PROD2
PLUG
PULD
X
POOH laying down singles from 1,782'
1,782.0
0.0
02:15
03:45
MD Monitor disp via TT.
7/2/2018
7/2/2018
0.50
PROD2
PLUG
WWWH
X
Make up Johnny Wacker and wash
0.0
0.0
03:45
04:15
WH / pull wear bushing.
7/2/2018
7/2/2018
0.75
PROD2
PLUG
RURD
X
RU to RIH with 3 112" 8md EUE 9.3#.
0.0
0.0
04:15
05:00
for a kill string.
7/2/2018
7/2/2018
5.50
PROD2
PLUG
PUTB
X
RIH with 9.3# L-80 8rnd EUE kill
0.0
1,783.9
05:00
10:30
string. from surface to tag of cement
retainer at 1,783.9' MD. DDWN WT=
58.5K UP WT = 54K. Space out and
pick up hanger. Damaged hanger
when picking up. Replace with new
from warehouse.
7/2/2018
7/2/2018
1.00
PROD2
PLUG
THGR
X
Make up new hanger and landing jt.
1,783.9
1,781.9
10:30
11:30
Orient hanger profile and land. Top of
retainer at 1,783.9' MD. Bottom of kill
string at 1,781.89' with space out.
Verify alignment via tubing port and
RILDS.
7/2/2018
7/2/2018
0.50
PROD2
PLUG
THGR
X
PT hanger seals to 5,000 PSI
1,781.9
1,781.9
11:30
12:00
witnessed,. LD landing joint and pu
dry rod.,
7/2/2018
7/2/2018
1.00
PROD2
WHDBOP
MPSP
X
Install BPV and test from beloow with
1,781.9
0.0
1200
13:00
sea water to 1,500 PSI. charted for 10
min (PASSED). BD /RD.
7/2/2018
7/2/2018
3.00
PROD2
WHDBOP
NUND
X
Pull riser and mousehole. ND BOPE
0.0
0.0
13:00
16:00
Secure same.
7/2/2018
7/2/2018
1.25
PROD2
WHDBOP
NUND
X
Clean well head pick and set tree. NU
0.0
0.0
16:00
17:15
istall test dart.
7/2/2018
7/2/2018
1.25
PROD2
WHDBOP
PRTS
X
TEst Bonnet seals to 5,000 PSI
0.0
0.0
17:15
18:30
witnessed. Fill tree with diesel with 5
gal buckets and test to 250 / 5000 PSI
(Charted). PASSED
7/2/2018
7/2/2018
0.50
PROD2
WHDBOP
MPSP
X
Drain tree and pull test dart 713PV.
0.0
0.0
18:30
19:00
7/2/2018
7/2/2018
2.25
PROD2
WHDBOP
FRZP
X
RU LRS and tiger tank test return line
0.0
0.0
19:00
21:15
then pump lines. Freeze protect IA X
TBG with 180 BBLS deisel at 4 BPM,
ICP 350 PSI, FCP 350 PSI. Diesel
returns to surface @ 165 BBLS away.
BD RD.
Page 17135 ReportPrinted: 811 012 01 8
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
StartTms
Endnme
Our(hr)
Phase
Op Code
Activity Code
Time P -M
Operation
(flKB)
End DWh(ftKB)
7/2/2018
7/2/2018
1.25
PROD2
WHDBOP
MPSP
X
RU lubricator and set BPV I test to
0.0
0.0
21:15
22:30
1,500 PSI, Good. LD lubricator via
Beaver slide.
7/2/2018
7/3/2018
1.50
DEMOB
MOVE
RURD
X
Install flanges and jewlery on tree.
0.0
0.0
22:30
00:00
Clean and secure wellhead. Install
well sign. TBG / IA 010 press. Swap
to generator power, disconnecting
electrical interconnect.
Rig release to move to 1 H-115 @
2359 hrs 7/2/2018.
7/19/2018
7/19/2018
8.00
MIRU
MOVE
MOB
X
Released rig F/1 H-115 at 10:00
1,834.0
1,834.0
10:00
18:00
Moved rig over 1 H-1 08B, Rigged up
and completed rig acceptance check
list. Rig accepted at 18:00 hrs.
7/19/2018
7/19/2018
1.50
MIRU
MOVE
RURD
X
Rig up to circulate out diesel to tiger
0.0
0.0
18:00
19:30
tank
7/19/2018
7/19/2018
3.00
MIRU
WHDBOP
MPSP
X
Monitor well pull BPV. Re -install BPV.
0.0
0.0
19:30
22:30
( Rig waiting on vis. Brine decision
made to reinstall BPV) test BPV 250
low- 2,500 psi high. (Charted) N/D
tree, Install blanking plug, Set install
plate on top of hanger and torque.
7/19/2018
7/20/2018
1.50
MIRU
WHDBOP
NUND
X
Set spacer spools, Set BOP stack,
0.0
0.0
22:30
00:00
Install choke and kill lines. Install flow
riser.
7/20/2018
7/20/2018
1.50
MIRU
WHDBOP
NUND
X
Complete torquing all flanges on
0.0
0.0
00:00
01:30
BOPE. Install mouse hole
7/20/2018
7/20/2018
2.50
MIRU
WHDBOP
CIRC
X
Pull blanking plug & BPV, Install
0.0
0.0
01:30
04:00
landing joint. Rig up to reverse
circulate out diesel freeze protect to
tiger tank. Pump 6 bpm, 600 psi.
1,800 strokes until brine visable at
tiger tank.
7120/2018
7/20/2018
7.00
MIRU
WHDBOP
BOPE
X
Install BPV & blanking plug. Witness
0.0
0.0
04:00
11:00
of test waived by AOGCC Insp Adam
Earl. Test w/ 3.5", 4.5" and 7" test jls.
Test 250 psi low and 3500 psi high, 5
min each.Install BPV & blanking plug.
Test Super & manual choke T/2,500
psi. Test all other 250-3,500 psi. Test
choke valves 1-14. Test mud manifold,
Mezzanine, HCR & manual kill valves.
Manual & HCR choke, Annular W/7"- 3
-1/2'testjts. 41/2" XT43 and 4"XT39
TIW & dart Valves, Test Upper & lower
top drive IBOP's. Lower VBRS. W/3-
1/2" & 4-1/2" test its. Upper rams W/7"
test It. Perform koomey draw down
test- Initial system psi 3,000, After
closure 1,750 psi, 200 psi attained 7
sec. Full psi- 48 sec. 6 nitrogen bottles
average psi 1,975. Test pit levels, flow
out alarm, 112S & Combustable gas
audible & light alrams.
7/20/2018
7/20/2018
1.00
MIRU
WHDBOP
RURD
X
Rig down testing equipment, Blow
0.0
0.0
11:00
12:00
down all lines.
7/20/2018
7/20/2018
1.00
PROD2
PLUG
PULL
X
PJSM/ FI Laying down 3-1/2" EUE 9.3
1,781.0
1,750.0
12:00
13:00
ppf. tubing and hanger. Pick up
landing joint make uplo hanger, Make
up cement hose T/ Circulate, Pull
hanger W/62k up. Pull hanger to floor.
7/20/2018
7/20/2018
0.50
PROD2
PLUG
CIRC
X
Circulate @ 523 gpm, 12 bom, 327
1,750.0
1,750.0
13:00
13:30
psi, 27% flow out. Total strokes
pumped - 3,030. Sim -Ops R/U GBR
Page 18/35 Report Printed: 8/1012018
Operations Summary (with Timelog Depths)
11-1-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depth
Start 7vne
End Time
Dur(hr)
Phase
Op Code
Actively Code
Time P -T -X
Operation
(ftKB)
End Depth(rIKB)
7/20/2018
7/20/2018
3.25
PROD2
PLUG
PULL
X
UD hanger & Landing Joint. Lay down
1,750.0
0.0
13:30
16:45
55 joints & 2, pups of 3-1/2 EUE 9.3
ppf tubing. Up wt. 60k On wt. 591k.
Monitor via trip tank.
7/20/2018
7/20/2018
1.00
PROD2
PLUG
RURD
X
Rig Down GBR. Clear and clean rig
0.0
0.0
16:45
17:45
floor.
7/20/2018
7/20/2018
0.50
PROD2
PLUG
RURD
X
Mobilze saver sub & BHA to rig floor
0.0
0.0
17:45
18:15
712012018
7/2012018
1.25
PROD2
PLUG
SVRG
X
Change out XT -43 saver sub in top
0.0
0.0
18:15
19:30
drive.
7/20/2018
7/20/2018
1.25
PROD2
PLUG
SLPC
X
Slip & Cut 63' of Drill line, Calibrate
0.0
0.0
19:30
20:45
block height
7/20/2018
7/20/2018
0.50
PROD2
PLUG
SVRG
X
Service Top Drive, Blocks & Crown
0.0
0.0
20:45 .
21:15
7/20/2018
7/20/2018
0.50
PROD2
PLUG
RURD
X
set 12-318" ID- Wear ring. Obtain IRKS
0.0
0.0
21:15
21:45
measurements
7/20/2018
7/20/2018
2.00
PROD2
PLUG
BHAH
X
PIU CIBP & Cement drill out BHA-
0.0
482.0
21:45
23:45
T1482' MD.
Monitor displacement via pit # 1
7/20/2018
7/21/2018
0.25
PROD2
PLUG
TRIP
X
Trip in picking up 4-1/2" XT43
482.0
703.0
23:45
00:00
ddllpipe. F/482'MD - T/ 703' MD.
Monitor displacement via pit # 1
7121/2018
7/21/2018
1.25
PROD2
PLUG
TRIP
X
Continue RIH P/U 4-1/2" XT -43
703.0
1,777.0
00:00
01:15
Drillpipe F/703' MD - T/1,777' MD.
Monitor displacement via pit # 1.
Up wt. 92k, on wt, 87k, Rot wt. 90k
7/21/2018
7/21/2018
0.50
PROD2
PLUG
CIRC
X
Fill Pipe, Obtain Slow Pump Rates
1,777.0
1,782.0
01:15
01:45
Wash down and lag at 1,782' MD
7/21/2018
7/21/2018
4.25
PROD2
PLUG
COCF
X
Drill/ CIBP & Cement F/1,782' MD -
1,782.0
1,809.0
01:45
06:00
T/1.809' MD. 800 gpm,415 psi, 29%
flow out, 70 rpm, 1-1 OK torque. 2040k
bit wt. up wt. 98k. Dn wt. 87K. Rot wt.
90K.
7/21/2018
7/21/2018
3.00
PROD2
PLUG
COCF
X
Ddill CIBP & Cement F/1,809' MD -
1,809.0
1,836.0
06:00
09:00
T/1.836' MD. 567 gpm,400 psi, 29%
flow out, 70 rpm, 1-1 OK torque. 2040k
bit wt. up wt. 98k. On wt. 87K. Rot wt.
90K.
7/21/2018
7/21/2018
0.50
PROD2
PLUG
CIRC
X
Wash &Ream F/1,830'MD - T/1,800'
1,836.0
1,830.0
09:00
09:30
MD. -
700 gpm, 423 psi, 34% flow out
70 rpm, 3K. Torque,
Up wt. 98K. on Wt. 87K. Rol. Wt. 90K.
Total strokes pumped - 3,330
7/21/2018
7/21/2018
0.50
PROD2
PLUG
DISP
X
Displace well F/ viscosified brine - T/
1,830.0
1,830.0
09:30
10:00
9.0 ppg. LSND. Pump 30 bbl. spacer
followed by 9.0 ppg LNSD. Rotate &
Reciprocate F/ 1,830' MD - T/1,800'
MD.
700 gpm, 423 psi, 34% flow out, 3K
torque.
Up wt. 98k Dn wt. 87k. Rot wt. 90k.
Total strokes pumped - 5,358
7/21/2018
7/21/2018
0.50
PROD2
PLUG
CIRC
X
Obtain slow pump rates
1,830.0
1,810.0
10:00
10:30
MP#1) 30 spm -60 psi 40 spm - 70 -psi
MP#2) 30 spm -60 psi 40 spm - 70 -psi
Rack back stand # 15, OWFF- static
7/21/2018
7/21/2018
1.50
PROD2
PLUG
TRIP
X
Pump dry job, TOOH - F/1,81 O' MD -
1,810.0
300.0
10:30
12:00
j
j
T/300' MD. Pulling on elevators.
Monitor via trip tank.
7/21/2018
7/21/2018
1.00
PROD2
PLUG
SHAH
X
UD Cleanout BHA F/300' MD
300.0
0.0
12:00
13:00
1
Monitor via trip tank
Page 19135 Report Printed: 8/10120181
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
start Depth
Start Time,
End Time
Da (hr)
Phase
Op Code
AeNY4 Code
Time P -T -x
operation
(110)
End Depth(HKB)
7/21/2018
7/21/2018
0.50
PROD2
PLUG
SHAH
X
Clear and Clean dg floor
0.0
0.0
13:00
13:30
7/2112018
7/21/2018
0.75
PROD2
PLUG
SHAH
X
Pick up Drilling assembly with
0.0
368.0
13:30
14:15
Milltooth bit
T/386' MD. Ran in with BHA F/ Derrick
F/ 86' MD - T/368' MD. Drill collars,
HWDP & Jars
Up wt. 59k. Dn wt. 64k.
Monitor displacement via trip tank.
7/21/2018
7121/2018
1.50
PROD2
PLUG
TRIP
X
TIH, F/368' MD -T/1,794' MO. Picking
368.0
1,794.0
14:15
15:45
up 4-1/2" XT -43 drillpipe F/Pipeshed.
Shallow pulse test downhole tools
W/550 gpm, 776 psi. 37% Flow out at
1,794' MD.
7/21/2018
7/21/2018
0.75
PROD2
PLUG
REAM
X
Wash & Ream down F/1,794' MD -
1,794.0
1,836.0
15:45
16:30
T/1,836' MD. W/587 gpm, 816 psi.
30% flow out. 60 rpm. 3k. torque
Up wt. 85k. Dn wt. 82k. Rot wt. 82k.
7/21/2018
7/21/2018
1.50
INTRM1
DRILL
DDRL
X
Dril 8-3/4" hole F/1,836'MD-T/1,884'
1,836.0
1,884.0
16:30
18:00
MD. 1,813' TVD. 560 gpm,770
psi,28% Flow out,60 rpm,2K torque,
5k. WOB, Up wt. 85k. On wt. 82k. Rot
wt. 82k. 1k. Torque off bottom, Off
bottom psi -764. Max gas units 17
ADT -96 Bit Hm..96, Jar hrs. = 59.4
Sidetrack not confirmed at this depth.
Indications good.
7/21/2018
7/21/2018
4.50
INTRMI
DRILL
DDRL
X
Drill 8-3/4" hole F/1,884'MD - T/2,264'
1,884.0
2,264.0
18:00
22:30
MD, 2,119' ND. 550 gpm,830 psi.
30% flow out, 60 rpm, 3k. torque 20k.
Bit wt. ECD's 9.8. OR bottom psi =
820. Up -89k. Down -86k. Rot -87k.
1.5k. torque off, Max gas 40 units.
ADT- 3.61 Bit hrs. 4.57. Jar hrs. 63.01
7/21/2018
7/21/2018
0.50
INTRMI
DRILL
CIRC
X
Circulate 2 times bottoms up Rot&
2,264.0
2,170.0
22:30
23:00
recip F/2,264' MD - T/2,170' MD. 600
gpm, 930 psi.29% flow out, 60 rpm,
1.5k. torque off. Total strokes 3,300.
MW in 9.0 MW out 9.1. Up 88k. Down
87k. Rot 87k.
7/21/2018
7/21/2018
0.25
INTRMI
DRILL
OWFF
X
Monitor well for 10 minutes fluid level
2,170.0
2,170.0
23:00
23:15
dropped 3"
7/21/2018
7/22/2018
0.75
INTRMI
DRILL
TRIP
X
POOH on elevators, F/2,170' MD -
2,170.0
1,604.0
23:15
00:00
T/1,980' MD. Swabbing- Kelly up &
pump out at 5 bpm, 220 psi. 13% flow
out. F/1,980' MD -T/ 1,790' MD.
Pulling spped 40 fpm.
POOH on elevators F/1,980' MD -
T/1,604' MD. Up - 80k. Down 78k.
SPR's @ 2,264' MD - 2,119' TVD MW
- 9.0 ppg. Time 23:00
Pump #1= 30 spm 90 psi, 40 spm 120
psi.
Pump #2= 30 spm 90 psi, 40 spm 120
psi.
7/22/2018
7/22/2018
0.50
INTRMI
DRILL
TRIP
X
TOOH F/1,604' MD -T/ 367' MD.
1,604.0
367.0
00:00
00:30
Monitor via trip tank, Up 63k. Down
66k.
7/22/2018
7/22/2018
1.00
INTRM1
DRILL
SHAH
X
Rack back HWDDP, Jars, Drill collars,
367.0
0.0
00:30
01:30
Lay down BHA components. Down
621k. Hole fill monitored via trip tank.
7/22/2018
7/22/2018
1.25
INTRMI
DRILL
SHAH
X
Make up BHA# 7. Per directional
0.0
381.0
01:30
02:45
driller T/381' MD. Displacement
monitored via trip tank. Up 87k. Down
83k.
Page 20135 ReportPrinted: 8/1012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
start Depen
star r ne
EM Time
our (hr)
Phase
Op Code
Activity Code
Tmte P -T -x
Operation
tflKB)
EM Depth (kKB)
7/22/2018
7/22/2018
0.75
INTRMI
DRILL
TRIP
X
Run in hole with drillpipe from Derrick
381.0
1,813.0
02:45
03:30
T/1,813' MD.
Displacement monitored via trip.
Up 87k. Dwon 83k.
7/22/2018
7/22/2018
2.50
INTRMI
DRILL
DHEQ
X
Shallow pulse test tools, (Good test)
1,813.0
2,264.0
03:30
06:00
MADD pass F/1,813' MD - 712,264'
MD.
600 gpm, 800 psi, 30% flow out.
MADD pass at 3501ph.
7/22/2018
7/22/2018
6.00
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate section F/
2,264.0
2,820.0
06:00
12:00
2,264' MD - T/2,820' MD, 2,418' TVD.
605 gpm,864 psi,30 % Flow out Off
bottom psi = 560. ECD's - 9.72 ppg.
Max gas 89 units. Up 98k. Down 821k.
Rot 87k. A. Torque.
ADT -3.35, Bit hrs. 3.35, Jar hrs. 66.36
SPR's @ 2,286' MD, 2,131' TVD, MW
9.2 ppg
MP#I) 30 SPM- 90 psi. 40 SPM -120
psi.
MP#2) 30 SPM- 90 psi. 40 SPM- 120
psi.
7/22/2018
7/22/2018
1.50
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate section F/
2,820.0
2,983.0
12:00
13:30
2,820' MD -T/2,983' MD. 605 gpm,
846 psi. 30% flow out.max gas 53
units. off bottom psi = 850. ECD's 9.72
ppg. Rot 120 rpm, 3.5k. Torque, 2k.
bit wt. Up 98k. Dwon 82k. Rot 871k.
Observed 200 psi packoff.
7/22/2018
7/2212018
4.00
INTRMI
DRILL
DDRL
X
Drill coal section F/2,983' MD. -T/
2,983.0
3,030.0
13:30
17:30
3,030' MD. 2,505' TVD. 420-481 gpm,
psi 460- 517. Flow out 29%
80 rpm, 3.5k. Torque 1-3 bit wt.
7/22/2018
7/22/2018
0.50
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate section,
3,030.0
3,050.0
17:30
18:00
F/3,03U MD. - T/3,050' MD. 2,505'
TVD. 605 gpm,870 psi, 30%, Flow out.
ECD's 9.7 ppg. Off bottom psi- 863.
Gas 57 units. 3.5k. torque Bit wt4k.
max gas 57 units. 140 rpm. 3k. torque,
off bottom. Up 98k. Down 82k. Rot
87k.
ADT- 2.46 hrs. Bit hrs. 5.81 Jar hrs -
68.82.
7/22/2018
7/23/2018
6.00
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate section,
3,050.0
4,100.0
18:00
00:00
F/3,050' MD. -T/4,100' MD. 2,875'
TVD. 700 gpm,1320 psi, 33%. Flow
out. ECD's 10.33 ppg. Off bottom psi -
1,315. Gas 95 units. 6k. torque Bit wt
141k. max gas 95 units. 140 rpm. 3.51k.
torque, off bottom. Up 109k. Down
831k. Rol 94k.
ADT- 4.2 hrs. Bit hrs. 10.01 Jar hrs -
73.02.
Pump Hi -Vis weighted sweeps every
500'
MP#1) 30 SPM- 100 psi. 40 SPM- 140
psi.
MP#2) 30 SPM- 10 psi. 40 SPM- 140
psi
Page 21/35 ReportPrinted: 8/10/2018
` Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
elsd Depth
Start'rime
End Time
Dw(hd
Please
Op code
Activity Code
Time P -T -X
Operatlon
(ftKB)
End Depth(ftKB)
7/23/2018
7/23/2018
6.00
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate hole, F/4,100'
4,100.0
5,180.0
00:00
06:00
MD - T/ 5,180' MD, 3,228' TVD. 700
gpm, 1,530 psi, 33% flow out, 140
rpm, 6k torque, bit wl. 7k. ECD's
10.57, Off bottom -1,540 psi,Up 116k,
Down 851k, Rot 99k, 5k torque off, Max
gas 60 units.
ADT - 4. 1, Bit hrs: 14. 11, Jar hrs. -
T7.12
7/23/2018
7/23/2018
6.00
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate hole, F/5,180'
5,180.0
5,845.0
06:00
12:00
MD - T/ 5,845' MD, 3,409' TVD. 748
gpm, 1,406 psi, 32% flow out, 130
rpm, 6.5k torque, bit wt. -2k. ECD's
10.13, Off bottom -1,407 psi,Up 119k,
Down 87k, Rot 100k, 5k torque off,
Max gas 201 units.
ADT - 4.03, Bit hrs.- 18.14, Jar hrs. -
81.15
SPR's- 5,237' MD, TVD - 3,247' MW -
9.0 ppg
MP # 1) 30 SPM - 240 psi. 40 SPM -
280 psi.
MP # 2) 30 SPM - 240 psi. 40 SPM -
290 psi.
No losses
7/23/2018
723/2018
3.50
INTRMI
DRILL
DDRL
X
Drill 8-3/4" Intermediate hole, F/5,845'
5,845.0
6,191.0
12:00
15:30
MD - T/ 6,191' MD, 3,463' TVD. 720
gpm, 1,745 psi, 32% flow out, 140
rpm, 7 k torque, bit wt. -1 2 k. ECD's
10.35, Off bottom -1,740 psi,Up 120 k,
Down 85 k, Rot 100 k, 5k torque off,
Max gas 90 units.
ADT - 2.57, Bit hrs.- 20.71, Jar hrs. -
79.69.
Xceed tool problem, Discontinue
drilling.
7/23/2018
7/23/2018
2.25
INTRMI
DRILL
CIRC
XT
Rot 8 Reciprocate pipe 6,189' MD -
6,191.0
6,191.0
15:30
17:45
6,099' MD. 771 gpm, 1,848 psi, Flow
out 34%, 100 rpm, 6 k torque. Up 120
k. Down 85 k. Rot 100 k. Total strokes
pumped 9,050
SPR's- 6,186' MD, ND - 3,463' MW -
9.1+ ppg
MP # 1) 30 SPM - 160 psi. 40 SPM -
210 psi.
MP # 2) 30 SPM - 170 psi. 40 SPM -
210 psi.
7/232018
7/23/2018
0.50
INTRMI
DRILL
OWFF
XT
Observe well for flow, Fluid level
6,191.0
6,191.0
17:45
18:15
dropped 6"
Sim -Ops- Service wash pipe, Blow
down topddve
7/23/2018
723/2018
0.75
INTRMI
DRILL
TRIP
XT
Pullout of hole F/6,189' MD -T/5,816'
6,191.0
5,816.0
18:15
19:00
MD.
Up 129k. down 77k. 20-30k Overpull,
well swabbing.
7/23/2018
7/24/2018
5.00
INTRMI
DRILL
BKRM
XT
Back Ream Out of Hole, F/5,816' MD-
5,816.0
3,531.0
19:00
00:00
T/3,531' MD. 700 gpm, 1,420 psi, 33%
Flow out, 140 rpm, 5k. Torque, ECD's
10.54 ppg. Up. 103k. Down 83k.
7/24/2018
DRILL
BKRM
XT
Back Ream Out of Hole, F/3,531' MD-
3,531.0
1,809.0
00:00
04:15
Tr
T/1,809' MD. 600 gpm, 925 psi, 32%
17124/2618
Flow out, 140 rpm, 3k. Torque, ECD's
10.03 ppg. Up. 86k. Down 84k.
Page 22135 Report Printed: 8/10/2018
Operations Summary (with Timelog Depths)
1 H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
SW Depth
I
Start Tme
End Time
Dur (hr)
Phase
Op Code
Activity Code
Time P -TA
Operation
M)
End Depth (fiKB)
7/24/2018
7/24/2018
0.25
INTRMI
DRILL
CIRC
XT
Circulate bottoms up Rotating and
1,809.0
1,809.0
04:15
04:30
reciprocating drillstring. F/ 1,809' MD -
T/ 1,728' MD. 700 gpm, 1,100 psi,
33% flow out. 100 rpm, 1.8k Torque.
9.69 ECD's. Total strokes pumped =
1,700
7/24/2018
7/24/2018
0.25
INTRMI
DRILL
OWFF
XT
Monitor well (Static) Pump 15 bbl. dry
1,809.0
1,809.0
04:30
04:45
job 10.3 ppg.
7/24/2018
7/24/2018
0.75
INTRMI
DRILL
TRIP
XT
POOH F/1,809' MD - T/ 381' MD. (At
1,809.0
381.0
04:45
05:30
BHA)
Monitor hole fill via trip tank
7/24/2018
7/24/2018
1.50
INTRMI
DRILL
BHAH
XT
Rack back HWDP, Jars, Stand DC's.
381.0
0.0
05:30
07:00
Lay down Xceed tool and bit. (Per
D.D.)
7/24/2018
7/24/2018
0.50
INTRM1
DRILL
CLEN
XT
Clear and Clean Rig Floor. - Sim Ops,
0.0
0.0
07:00
07:30
PM Service on drawworks.
7/24/2018
7/24/2018
1.00
INTRMI
DRILL
BHAH
XT
Make up BHA# 8, Run NM Drill collar,
0.0
383.0
07:30
08:30
HWDP & Jars F/Derrick. F/ 95'MD. -
T/383' MD. Up 61 k. Down 67k.
Monitor displacement via trip tank.
7/24/2018
7/24/2018
3.25
INTRMI
DRILL
TRIP
XT
Continue to RIH with BHA#8 with 4.5"
383.0
6,102.0
08:30
11:45
DP from derrick. 383' MD - 6,102' MD.
UP WT= 120K. OWN WT=78K.
Monitor disp via TT Shallow hole
pulse test at 1,810' MD (GOOD). 569
GPM @ 888 PSI DPP. 31% F/O.
Taking 15K DWN WT @ 2,374' MD.
and 5,850' DM.
7/24/2018
7/24/2018
0.75
INTRMI
DRILL
WASH
XT
Wash down from 6,102' MD to 6,187'
6,102.0
6,187.0
11:45
12:30
MD while staging up pumps to 550
GPM ICP 160 PSI DPP FCP' 1,225
PSI DPP. 31% F/O. 70 RPM with 6K
TQ. UP WT=120 K. DWN WT=
78K. ROT WT- 97K. take SPR's.
SPR's 6,188' MD 3,463' TVD MW =
9.2 PPG hrs 12:30
SPM 1) 30 SPM - 180 PSI 40 SPM -
220 PSI
SPM 2) 30 SPM - 180 PSI 40 SPM -
220 PSI
7/24/2018
7/24/2018
5.50
INTRMI
DRILL
DDRL
X
DDRL 83/4" hole from 6187'MD to
6,187.0
6,880.0
1230
18:00
6,880' MD 3,510' TVD. a1646 GPM
1,694 PSI DPP. 30% F/0, 140 RPM
8K TQ, with 15K WOB. ECD - 10.38,
Off bottom 1,658 PSI. UP WT = 132K,
DWN WT= 78K. ROT- 102K. Max
gas = 122 units, ADT - 3.57 Bit hrs
3.57, Jar hrs 83.26
7/24/2018
7125/2018
6.00
INTRMI
DRILL
DDRL
X
DDRL 83/4" hole from 6,880' MD
6,880.0
7,620.0
18:00
00:00
3,510' TVD - 7,620' MD 3,697' TVD.
at 646 GPM 1,950 PSI DPP. 32% F/O,
140 RPM 8K TO, with 19K WOB.
ECD -10.72, Off bottom 1,940 PSI.
UP WT = 136K, DWN WT = 78K.
ROT - 102K. 8K TO Max gas = 30
units, ADT - 3.93 Bit hrs 7.5, Jar hrs
87.19
SPR's 7,140' MD 3,612" TVD MW =
9.0+ PPG hrs 1920
SPM 1) 30 SPM - 180 PSI 40 SPM -
240 PSI
SPM 2) 30 SPM - 180 PSI 40 SPM -
230 PSI
Page 23/35 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
1 H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Deptlt
Star)Time
Entl Time
Our(hp
Phase
Op code
ActivityC W
Time P-T-X
Operation
(RKB)
End Depth (fiK6)
7/25/2018
7/25/2018
6.00
INTRMI
DRILL
DDRL
X
DDRL 8 3/4" hole from 7,620' MD
7,620.0
8,296.0
00:00
06:00
3,697' TVD - 8,286' MD 3,791' TVD.
at 646 GPM 1,745 PSI DPP. 31 % F/O,
140 RPM 9K TO, with 4K WOB. ECD
- 10.62, Off bottom 1,735 PSI. UP WT
=136K, OWN WT=77K. ROT-
106K. 9K TQ Max gas = 50 units,
ADT - 4.08 Bit him 11.58, Jar him 91.27
7/25/2018
7/2512018
3.00
INTRMI
DRILL
DDRL
X
DDRL 83/4" hole from 8,286'MD
8,296.0
8,517.0
06:00
09:00
3,791' TVD - 8,517' MD 3,809' TVD.
at 525 GPM 1,333 PSI DPP. 27% FIO,
80 RPM IOK TO, with 5K WOB. ECD
- 10.28, Off bottom 1,909 PSI. UP WT
=142K, DWN WT=77K. ROT-
107K. 9K TO Max gas = 137 units,
ADT - 2.3 Bit hrs 13.88, Jar Ins 93.57
SPR's 8,451' MD 3,804" TVD MW =
9.2+ PPG hrs 1000
SPM 1) 30 SPM - 190 PSI 40 SPM -
240 PSI
SPM 2) 30 SPM - 200 PSI 40 SPM -
250 PSI
7/25/2018
7125/2018
1.00
INTRMI
CASING
CIRC
X
Rotate and recip from 8,517' MD -
8,517.0
8,517.0
09:00
10:00
8,450' MD circulating at 650 GPM,
1,687 PSI DPP. 30% FIO. 140 RPM,
12K TO.
7/25/2018
7/25/2018
0.50
INTRMI
CASING
OWFF
X
OWFF. (static).
8,517.0
8,517.0
10:00
10:30
7/25/2018
7/26/2018
13.50
INTRMI
CASING
BKRM
X
BKRM OOH from 8,517' MD - 3,517'
8,517.0
3,517.0
10:30
00:00
MD. UP WT = 102K W/pump 140K
WO.
7126/2018
7/26/2018
5.00
INTRMI
CASING
BKRM
X
Continue to BKRM OOH from 3,517'
3,517.0
1,811.0
00:00
05:00
MD -1,811' MD at 650 GPM 1,110 PSI
DPP. 32% F/O with 140 RPM @ 3K
TQ. 9.39 ECD. UP WT=87K. DWN
WT = 86K.
7/2612018
7/26/2018
0.75
INTRMI
CASING
CIRC
X
Circulate high vis sweep while recip
1,811.0
1,811.0
05:00
05:45
from 1,811'- 1,716' MD. 750 GPM Q
1,350 PSI. 33% F/O with 100 RPM
2K TQ. 9.42 ECD. MWI 9.0 MWO
9.0... 4,745 STKS pumped. UP WT =
86K DWN WT=85K.
7/26/2018
7/26/2018
0.25
INTRMI
CASING
OWFF
X
OWFF dropped-3". Pump DJ.
1,811.0
1,811.0
05:45
06:00
7126/2018
7/26/2018
1.50
INTRMI
CASING
TRIP
X
Continue to POOH from 1,811' MD -
1,811.0
383.0
06:00
0730
383' MD. UP WT= 85K.. DWN WT =
85K. Monitor disp via TT.
7/26/2018
7/26/2018
2.50
INTRMI
CASING
SHAH
X
LD HWDP jars and BHA#8. Clean rig
383.0
0.0
07:30
10:00
floor while monitor disp via TT.
7/26/2018
7/26/2018
2.00
INTRMI
CASING
RURD
X
MU 4 112" DP cross over and stack
0.0
0.0
10:00
12:00
flushing tool. flush stack at 900 GPM /
simiops bringing GBR tools to rig floor
and setting up. Clean rig floor. Pull
wear bushing and prep to RIH with 7"
casing.
7/26/2018
7/26/2018
0.25
INTRMI
CASING
SFTY
X
PJSM for running casing with GBR
0.0
0.0
12:00
12:15
and rig crew.
7/26/2018
7/26/2018
0.50
INTRMI
X
MU / Baker Lock Shoe track assym.
0.0
120.0
12:15
12:45
TQ TXP connections to 17,700 FT/LB.
JCASING
JPUTS
HYD 563 TQ - 9,400 FT / LB. Monitor
disp via TT.
Page 24135 ReportPrinted: 8/10/2018
Operations Summary (with Timelog Depths)
114-108
Rig:
DOYON 142
Job:
DRILLING
ORIGINAL
Time Log
start Time
End Time
Dur (hr)
Phase
op Code
Acti' Code
My
Time P -T -X
CPeratron
nDe
SWrt Depth
EM Depth (/tl(B)
7/26/2018
7/26/2018
0.25
INTRMI
CASING
CIRC
X
Check floats (Good). staged up
120.0
199.0
12:45
13:00
pumps to 8 BPM @ 350 GPM, 85 PSI
casing pressure, 26% F/O. 330 stks.
7/26/2018
7/26/2018
1.75
INTRMI
CASING
PUTS
X
Continue to RIH with 26# L-80 TXP 7"
199.0
940.0
13:00
14:45
casing from 199' MD TQ TXP to
17,700 FT/LB. Monitor disp via Pit 5.
7/26/2018
7/26/2018
1.50
INTRMI
CASING
EQRP
XT
GBR hose failure. Shut down for hose
940.0
940.0
14:45
16:15
replacement and troubleshoot. clean
up hyd fluid. Spill -1 gal of hed fluid to
pad.
7/26/2018
7/27/2018
7.75
INTRMI
CASING
PUTS
X
Continue to RIH with 7" 26# TXP L-80
940.0
4,245.0
16:15
00:00
casing from 940' MD - 4,245' MD filling
every 10. Losses minimal and
acceptable. Monitor disp via pit#5.
7/27/2018
7/27/2018
6.00
INTRMI
CASING
PUTS
X
Continue to RIH with 7" 26# L-80 TXP
4,245.0
6,672.0
00:00
06:00
casing from 4,245' MD - 6,672' MD.
Fill on the fly and top off every ten
joints. Monitor disp via pit #5. UP WT
= 167K. DWN WT = 86K.
7/27/2018
7/27/2018
0.75
INTRMI
CASING
CIRC
X
Circulate bottoms up while recip from
6,672.0
6,672.0
06:00
06:45
6,672' MD - 6,632' MD. Stage pumps
up to 7 BPM @ 305 PSI. 22% F/O.
2,300 STKS pumped MWI = 9.2#
MWO = 9.2#.
7/27/2018
7/27/2018
4.00
INTRMI
CASING
PUTS
X
Continue to RIH with 7" 26# L-80 TXP
6,672.0
8,466.0
06:45
10:45
casing from 6,672' MD - 8,466' MD.
Fill on the fly and top off every 10 its.
Monitor disp via Pit#5. UP WT=
204K. DWN WT= 94K.
7/27/2018
7/27/2018
0.75
INTRMI
CASING
HOSO
X
Make up HNGR assym and wash
8,466.0
8,508.0
10:45
11:30
down to land on depth at 4 BPM 350
PSI with 14% F/O.
7/27/2018
7/27/2018
4.00
INTRM1
CEMENT
CIRC
X
RU cement hose and circulate while
8,508.0
8,488.0
11:30
15:30
recip from 8,504' MD - 8,488' MD.
Stage up to 7 BPM @ 500 PSI, 23%
F/O with UP WT = 173K (While
pumping), DWN WT= 84K. Raise
rate to 8 BPM and pump a total of
15,120 stks.
7/27/2018
7/27/2018
0.50
INTRMI
CEMENT
PRTS
X
RU Schlumberger pump and pump 5
8,488.0
8,488.0
15:30
1600
BBL of fresh water to PT. Replace
1502 gsket and retest to 4,000 PSI.
Page 25135
Report Printed:
8/10/2018
. Operations Summary (with Timelog Depths)
111-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Depth
Start Time
End Time
Dur(ho
Phase
op code
Activity Code
Time P-T-XStart
Opeatbn
(MB)
End Dept (iKa)
7/27/2018
7/27/2018
2.75
INTRMI
CEMENT
CMNT
X
Drop bottom plug number 1 and pump
8,488.0
8,508.0
16:00
18:45
40.1 BBLS of 12.5# mud push.
pumping at 4.1 BPM with 80-177 PSI
casing pump pressure. 10-14% F/O,
Launch 2nd bottom plug and pump
173.1 BBLS of 15.8PPG class G
cement at 3.7 - 5.2 BPM at 50-140
PSI pump pressure. 11-21%F/O.
UP WT=230K. DWN WT=54K.
Launch Top plug and push with 10
BBLS Fresh water prior to switching to
rig pumps. On dg pump and displace
with 9.2# LSND @ 8 BPM at 2,089
STKS. ICP = 200 PSI, FCP = 737
PSI. 23% F/O, UP WT = 250K, DWN
WT = 52K. Lower rate to 5 BPM
pump 2,730 STKS with ICP 575 PSI
17% F/O, FCP = 863 PSI, UP WT =
250 K DWN WT = 40K. Land on
hanger at 2,230 STKS due to lack of
down wt. Reduce rate to 3 BPM with
a FCP of 900 PSI 8% F/O. Bump plug
at 3,074 STKS. raise pressure to
1,400 PSI and hold for 5 min. Cement
in place at 1830 hrs. Bleed off.
7/27/2018
7/2712018
1.00
INTRMI
WHDBOP
PRTS
X
RU and pressure test casing to 3,600
8,508.0
8,508.0
18:45
19:45
PSI for 30 charted min. (PASSED)
Pumped 6 BBLS and bled back same.
Floats holding (PASSED)
7/27/2018
7127/2018
0.50
INTRMI
CEMENT
RURD
X
BD lines and pull landing joint I lay
8,508.0
0.0
19:45
20:15
down same.
7/27/2018
7/27/2018
0.75
INTRMI
WHDBOP
WWSP
X
Drain stack and set pack off. RILDS
0.0
0.0
20:15
21:00
and test to 5,000 PSI witnessed by
Rock. LDtestjoint.
7/27/2018
7/27/2018
2.00
INTRMI
CEMENT
CIRC
X
C/O saver sub to XT -39 and run
0.0
0.0
21:00
23:00
injection line to OA. Inject 13 BBLS
into 10 3/4" X 7" annulus to ensure
injectivity, at 1 BPM 450 PSI.
7/27/2018
0.50
INTRMI
CEMENT
RURD
X
Test 4" dart valve to 250/3,500 PSI for
0.0
0.0
17/27/2018
23:00
23:30
5 min ea. Tested 4" XT39 FOSV to
250 psi / 3500 psi 5 min ea. All tests
charted. Set 9" wear bushing.
7/27/2018
7/28/2018
0.50
INTRMI
CEMENT
BHAH
X
Bring BHA and handling tools to rig
0.0
22.0
23:30
00:00
floor. Hold PJSM for making up PD to
bit.
7/28/2018
7/28/2018
2.25
INTRMI
CEMENT
SHAH
X
Continue to MU BHA#9 from 22'-
22.0
-§9 5-0
00:00
02:15
395' MD.
7128/2018
7/28/2018
2.00
INTRMI
CEMENT
TRIP
X
RI from 395' MD to 1,900' MD.
395.0
1,900.0
02:15
04:15
Monitor disp via pit #1. UP WT = 80K.
DWN WT= 76K. Fill every ten.
7/28/2018
7/28/2018
0.25
INTRMI
CEMENT
DHEO
X
Shallow hole test MWD at 250 GPM
1,900.0
1,900.0
04:15
04:301
11,330
PSI DPP. 18% F/O.
7/28/2018
7/28/2018
1.50
INTRMI
CEMENT
DEVIL
X
Continue to RIH logging free pipe from
1,900.0
2,862.0
04:30
06:00
1,900' MD to 2,100' MD' MD at 800
FPM. Making up stands in mouse
hole
hole. Monitor disp via pit#1. UP WT =
DWN WT=78K.
Page 26135 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
sred oepm
Sl Tiime
End Tare
our (hr)
Phem
op cove
Activity Code
Time P-T-X
operation
(OKB)
End Dwp rftKa)
7/28/2018
7/28/2018
10.26
INTRMI
CEMENT
QEVL
X
Continue to RIH with BHA#9 from
2,862.0
8,338.0
06:00
16:15
2,862' MD - cement tag at 8,338' MD.
Filling pipe every ten and monitoring
disp via Pit V. Log cement quality
form 6,001' MD - 8,338' MD at 800
FPH. Simops to flush and freeze
protect OA with 89 BBLS of FW and
97 BBLS diesel. SIP after water flush
= 460 PSI. After diesel = 600 PSI.
Max pressure while injecting 635 PSI.
7/28/2018
7/28/2018
1.75
INTRM1
CEMENT
DRLG
X
Drill cement from 8,338' MD - 8,382.8
8,338.0
8,385.0
16:15
18:00
MD. at 240 GPM, 1,810 PSI DPP.
21 % FIO, 50 RPM with 1 OK TQ. Tag
plugs at 8,382' MD. Drill plugs from
8,383' MD - 8,385' MD. @ 150 -200
GPM, 1,100 PSI DPP. 15% F/0 7K
WOB. 10K TQ.
7/28/2018
7/28/2018
2.75
INTRM1
CEMENT
DRLG
X
Continue to drill shoe track from 8,385'
8,385.0
8,517.0
18:00
20:45
MD - 8,517' MD. at 230 GPM 80
RPM, 9.5K TO, 15K WOB, 11.5 ECD,
Tag top of shoe at 8,506' MD. Drill out
with 6-10K WOB.
7128/2018
7/28/2018
0.25
INTRM1
CEMENT
DRLG
X
Drill 61/8" hole form 8,517' MD-
8,517.0
8,537.0
20:45
21:00
8,537' MD 3,812' TVD. at 240 GPM
1,900 PSI 17% F/0, 80 RPM 9.5K TQ.
12K WOB, ECD's = 11.38, ADT .16.
Bit HRS=.16, Jarhm=.16.
7/28/2018
7128/2018
1.00
INTRM1
CEMENT
CIRC
X
Circulate bottoms up while recip and
8,537.0
8,537.0
21:00
22:00
rotating from 8,537' MD-8,503' MD.
240 GPM @ 1,850 PSI. 18% F/O, 80
RPM wiht 9K TO. UP WT = 175K.
OWN WT=56K. ROT =104K. 9.1
PPG MWI/MWO. 2,230 STKS
pumped.
7/28/2018
7/28/2018
0.75
INTRMI
CEMENT
FIT
X
RU and perform an FIT to 13 PPG
8,537.0
8,537.0
22:00
22:45
EMW. 9 stks, to pressure up. .6
BBLS bled back. BD/RD. (PASSED)
7/28/2018
7/29/2018
1.25
PRODS
DRILL
DDRL
X
DDRL 6 1/8" hole form 8,537 MD -
8,537.0
8,597.0
22:45
00:00
8,597' MD 3,815' TVD. 250 GPM
1,815 pSl DPP. 17% F/O, 100 RPM,
9.4K TQ with 4K WOB. ECD'c =
11.06, Off bottom 1,810 PSI, UP WT =
137K, DWN WT=75K. ROT =98K.
9K TQ. ADT .68, Bit hrs .84, Jar
hrs .84
7/29/2018
7/29/2018
6.00
PROD3
DRILL
DDRL
X
DDRL 6 1/8" hole form 8,597' MD
8,597.0
9,323.0
00:00
06:00
3,815' TVD - 9,323' MD 3,830' TVD.
250 GPM 1,950 PSI DPP. 19% FIO,
150 RPM, 6.5K TO with 3K WOB.
ECD'c = 11.5, Off bottom 1,940 PSI,
UP AT = 125K, DWN WT = 76K.
ROT = 94K. 5K TO. ADT .3.86, Bit
hrs 4.7, Jar hrs 4.7 MAX gas = 1,030
units
SPR's @ 8,657' MD 3,818' TVD MW =
9.2 PPG hrs 0100
1) 20 SPM 530 PSI 30 SPM - 730 PSI
2) 20 SPM 520 PSI 39SPM - 720 PSI
Page 27135 Report Printed: 8110/2018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
stall Depth
n De
Stan Time
EM Time
Dw(ho
Phase
DIP Code
Acti Code
Wty
Time P -T -X
D ration
pe
End Depth (NCB)
7/29/2018
7/29/2018
6.00
PRODS
DRILL
DDRL
X
DDRL 6 118" hole form 9,323' MD
9,323.0
9,798.0
06:00
12:00
3,830' TVD - 9,798' MD 3,840' TVD.
258 GPM 2,105 PSI DPP. 20% F/O,
150 RPM, 8.41K TO with 10K WOB.
ECD'c = 11.3, Off bottom 2,100 PSI,
UP WT= 125K, OWN WT= 71 K.
ROT = 96K. 5.5K TO. ADT .4.47 Bit
bra 9.17, Jar hrs 9.17 Max gas = 109
units
Troubleshooting MWD system while
drilling
SPR's @ 9,323' MD 3,830' TVD MW =
9.1+ PPG hrs 0600
1) 20 SPM 540 PSI 30 SPM -750 PSI
2) 20 SPM 530 PSI 30 SPM - 740 PSI
7/29/2018
7/29/2018
2.00
PRODS
DRILL
DDRL
X
DDRL 6 1/8" hole form 9,798' MD
9,798.0
9,876.0
12:00
14:00
3,840' TVD - 9,876' MD 3,842' TVD.
258 GPM 2,100 PSI DPP. 20% F/O,
150 RPM, 8.41K TQ with 6K WOB.
ECD'c = 11.3, Off bottom 2,100 PSI,
UP WT= 125K, OWN WT=71 K.
ROT= 96K. 5.5KTQ. ADT 1.0 Bit
his 10. 17, Jar hrs 10.17 Max gas =
109 units
7/29/2018
7/29/2018
1.50
PRODS
DRILL
OTHR
XT
Troubleshoot MWD. Sporadic
9,876.0
9,876.0
14:00
15:30
communication.
7/29/2018
7/29/2018
1.50
PROD3
DRILL
BKRM
XT
BROOH from 9,876' MD - 9,514' MD
9,876.0
9,514.0
15:30
17:00
@ 240 GPM 1,860 PSI DPP. F/O =
20%, 100 RPM with 51K TO. UP WT =
UP WT = 124K, DWN WT = 97K.
7/29/2018
7/29/2018
1.00
PROD3
DRILL
CIRC
XT
Pump 60 BBL High Vis pill while
9,514.0
9,800.0
17:00
18:00
rotating from 9,514' Md - to 9,800'
MD. UP WT= 120K, DWN WT= 74K.
Monitor disp via Pits 1-5.
7/29/2018
7/29/2018
0.50
PRODS
DRILL
SVRG
X
Troubleshoot drawworks shut down.
9,800.0
9,800.0
18:00
18:30
7/29/2018
7/30/2018
5.50
PRODS
DRILL
DDRL
X
Ream to bottom and DDRL from
9,800.0
10,465.0
18:30
00:00
9,876' MD 3,842 TVD - 10,465' MD
3,885' TVD. @ 250 GPM 2,160 PSI
DPP. 18% NO, 150 RPM 8K TO,
4.5K WOB. ECD's = 11.78 PPG. Off
BTM =2,150 PSI. UP WT=130K,
DWN WT = 68K, ROT = 95K. 7K TO.
Max gas = 67 units, ADT = 3.37, Bit
hrs = 13.54, Jar = 13.54.
SPR's @ 9,895' MD 3,843' TVD MW =
9.1 PPG, hrs = 1915
1) 20 SPM = 550 PSI 30 SPM = 760
PSI
2) 20 SPM = 550 PSI 30 SPM = 780
PSI
Page 28135 Report Printed: 811012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
Starr lime
End Time
our(hr)
Phase
Op Code
Ac9wty Code
Time P -T -x
Operation
(OKB)
End Depth tftKB)
7/30/2018
7/30/2018
4.50
PRODS
DRILL
DDRL
DDRL from 10,465' MD 3,885' TVD -
10,465.0
10,725.0
00:00
04:30
10,725' MD 3,895' TVD. @ 250 GPM
2,270 PSI DPP. 19% F/0, 150 RPM
7.81K TO, 3K WOB. ECD's = 11.82
PPG. Off BTM = 2,260 PSI. UP WT =
132K, DWN WT = 65K, ROT = 100K.
7K To. Max gas = 60 units, ADT =
1.97, Bit hrs = 15.51, Jar= 15.51.
SPR's @ 10,725' MD 3,895' TVD MW
= 9.0 PPG, hrs = 0509
1) 20 SPM = 640 PSI 30 SPM = 840
PSI
2) 20 SPM = 620 PSI 30 SPM = 640
PSI
7/30/2018
7/30/2018
0.50
PROD3
DRILL
CIRC
XT
Circulae bottoms up while
10,725.0
10,725.0
04:30
05:00
reciprocating from 10,724' MD -
10,656' MD. 250 GPM @ 2,270 PSI
DPP. 19% F/O, 140 RPM, 7K TO,
pumped 2,300 STKs total. POOH to
change out smart tools!
7/30/2018
7/30/2018
0.50
PRODS
DRILL
OWFF
XT
Observe well for flow(droped l").
10,725.0
10,725.0
05:00
05:30
7/30/2018
7/30/2018
6.00
PRODS
DRILL
BKRM
XT
BKRM OOH from 10,725' MD, to
10,725.0
8,468.0
05:30
11:30
8,468' MD @ 250 GPM, 2,067 PSI,
19% F/0. 150 RPM, 5.51K To, 11.21
ECD. UP WT=110, DWN WT=65K.
7130/2018
7/30/2018
1.50
PROD3
DRILL
CIRC
XT
Pump a high vis pill and circulate /
8,468.0
8,468.0
11:30
13:00
recip from 8,468' MD - 8,373' MD. @
250 GPM, 2,260 PSI 19% F/O, ECD =
11.66, 120 RPM 5K To.
7130/2018
7/30/2018
4.00
PROD3
DRILL
TRIP
XT
Monitor well for static (passed), POOH
8,468.0
395.0
13:00
17:00
on elevators to BHA after pumping dry
job from 8,468' MD - 395' MD UP WT
= 118K DWN WT = 79K.
7/30/2018
7/30/2016
1.50
PROD3
DRILL
BHAH
XT
Monitor well and lay down BHA#9 as
395.0
0.0
17:00
18:30
per SLB rep. Standing back DC/JArs.
Monitor disp via TT Clean dg floor.
7/30/2018
7/30/2018
1.00
PRODS
DRILL
BHAH
XT
MU BHA# 10 as per SLB rep to 365'
0.0
365.0
18:30
19:30
MD, Monitor disp via TT.
7/30/2018
7/30/2018
0.75
PROD3
DRILL
TRIP
XT
Trip in hole from 365' MD -2,255' MD.
365.0
2,255.0
19:30
20:15
UP WT=80K. DWN WT=77K.
Monitor disp via TT.
7/30/2018
7/30/2018
0.25
PRODS
DRILL
DHEO
XT
Shallow hole test MWD @ 240 GPM
2,255.0
2,255.0
20:15
20:30
1,430 PSI, 19% F10, 40 RPM.
(GOOD).
7/30/2018
7/31/2018
3.50
PRODS
DRILL
TRIP
XT
Continue to trip in hole form 2,255' MD
2,255.0
8,913.0
20:30
00:00
- 8,913'MD 85K UP WT/42K DWN
WT . Monitor disp via TT fill pipe
every 20 stands.
7131/2018
7/31/2018
0.75
PROD3
DRILL
TRIP
XT
Continue tripping in hole F/ 8,916' MD
8,913.0
10,626.0
00:00
00:45
- T/ 10,626' MD. Monitor displacement
via trip tank
Up 138k. Down 74k.
7/31/2018
7/31/2018
0.75
PROD3
DRILL
REAM
XT
Wash down F/ 10,626'MD - T/ 10,725'
10,626.0
10,725.0
00:45
01:30
MD
250gpm,2,415 psi. 18% flow out, 100
rpm, 5.7k Torque. 11.6 ECD.
SPR's at 10,711' MD 3,897' TVD MW
9.2
MP#1) 20 spm - 680 psi, 30 spm - 880
psi
MP#2) 20 spm - 640 psi, 30 spm - 860
psi
Page 29136 Report Printed: 811012018
Operations Summary (with Timelog Depths)
IH -108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Depth
StartTime
End Time
Dur(m)
Phase
Op Code
Activity Code
Time P -T -X
Operation
(fiIQ))
End Depth (Itl(B)
7/31/2018
7131/2018
4.50
PRODS
DRILL
DDRL
X
Drill 6-118" Production hole section F/
10,725.0
11,097.0
01:30
06:00
10,725' MD - T/11,097' MD, 3,896'
TVD
250 gpm, 2,460 psi. 18% flow out. 150
rpm, 8.5k Torque, 7.5k bit wt. ECD's
11.88 ppg. off bottom psi=2,450. Up
130k, down 64k, rot 92k. 6k. Torque
off bottom,Gas units = 0
ADT - 2.98, Bit hrs. 2.98, jar hrs. -
18.49
7/31/2018
7/31/2018
6.00
PROD3
DRILL
DDRL
X
Drill 6-1/8" Production hole section F/
11,097.0
11,490.0
06:00
12:00
11,097' MD - T/11,490' MD, 3,894'
TVD
250 gpm, 2,400 psi. 19% flow out. 150
rpm, 7k Torque, 3k bit wt. ECD's 11.99
ppg. off bottom psi=2,400.
Upl 23k,down72k, rot 94k.6kTorque off
bottom,Gas units = 0
ADT - 4.2, Bit hrs. 7.18, jar hrs. -
22.69
SPR's at 11,283' MD 3,901' TVD MW
9.2+
MP#1) 20 spm - 740 psi, 30 spm - 960
psi
MP#2) 20 spm - 700 psi, 30 spm - 930
psi
7/3112018
7/31/2018
6.00
PRODS
DRILL
DDRL
X
Drill 6-1/8" Production hole section F1
11,841.0
12,318.0
12:00
18:00
11,841' MD -T/12,318' MD, 3,925'
TVD
250 gpm, 2,630 psi. 18% flow out. 150
rpm, 11 k Torque,20k bit wt. ECD's
12.09 ppg. off bottom psi=2,580.
Up141 k,down 65k, rot 100k.7.5 It,
Torque off bottom,Gas units = 30
ADT - 4.36, Bit hrs. 16.33, jar hrs. -
31.84
12,068' MD drilled through fault stayed
in zone,
SPR's at 11,957' MD 3,917' TVD MW
9.1+
MP#1) 20 spm - 720 psi, 30 spm - 930
psi
MP#2) 20 spm - 720 psi, 30 spm - 400
psi
7/31/2018
8/112018
6.00
PROD3
DRILL
DDRL
X
Drill 6-118" Production hole section F/
11,490.0
11,841.0
18:00
00:00
11,490' MD -T/11,841' MD, 3,914'
TVD
250 gpm, 2,387 psi. 19% flow out. 150
rpm, 8k Torque, 3k bit wt. ECD's 11.82
ppg. off bottom psi=2,380.
Upl 30k,down65k, rot 92k.6kTorque off
bottom,Gas units = 0
ADT - 4.79, Bit hrs. 11.97, jar hrs. -
27.48
Page 30135 ReportPrinted: 8/10/2018
. Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
start TMa
End Tune
Our (hd
Phase
OP Cade
Ac Wity Code
Time P -TA
Operation
Stan Depth
(fli(B)
End Depth (f")
8/1/2018
8/1/2018
6.00
PRODS
DRILL
DDRL
X
Drill 6-1/8" Production hole section F/
12,318.0
12,452.0
00:00
06:00
12,318' MD - T/12,452' MD, 3,939'
TVD
250 gpm, 2,585 psi. 18%flow out. 150
rpm, 8k Torque, 41k bit wt. ECUs 12.19
ppg. off bottom psi=2,580. Up143
k,down73 k, rot 104 k.8.5 kTorque off
bottom,
Gas units = 60
ADT - 4.86, Bit hrs. 21.19, jar hrs. -
36.7
8/1/2018
8/112018
6.00
PRODS
DRILL
DDR L
X
Drill 6-1/8" Production hole section F/
12,452.0
12,900.0
06:00
12:00
12,452' MD - T/12,900' MD, 4,128'
TVD
250 gpm, 2,765 psi. 18% flow out. 150
rpm, 8 k Torque, 4k bit wt. ECUs
12.60 ppg. off bottom psi=2,755.
Up152 k,down 83 k, rot 108 k.8
kTorque off bottom,
Gas units = 238
ADT - 4.32, Bit hrs. 25.51, jar hrs. -
41.02
SPR's @ 12,489' MD 3,949' TVD MW -
9.2+ ppg
MP # 1) 20 spm = 810 30 spm = 1,060
MP # 2) 20 spm = 800 30 spm = 1,020
16 bbl. loss this tour.
8/1/2018
8/1/2018
3.25
PROD3
DRILL
DDRL
X
Drill 6-1/8" Production hole section F/
12,900.0
13,080.0
12:00
15:15
12,900' MD - T/13,080' MD, 4,233'
TVD
250 gpm, 2,950 psi. 18% flow out. 150
rpm, 8k Torque, 10 k bit wt. ECUs
12.58 ppg. off bottom psi=2,930.
Up164 k,down 89 k, rot 113 k.8
kTorque off bottom,
Gas units = 175
ADT - 1.82, Bit hrs. 27.33, jar hrs. -
42.84
MP # 1) 20 spm = 880 30 spm = 1,160
MP # 2) 20 spm = 900 30 spm = 1,170
8/1/2018
8/1/2018
0.25
PRODS
CASING
CIRC
X
Obtain final survey, Take Slow pump
13,080.0
13,080.0
15:15
15:30
rates, Obtain torque and drag data.
8/1/2018
8/1/2018
1.00
PROD3
CASING
CIRC
X
Lay down single drillpipe not in string,
13,080.0
13,040.0
15:30
16:30
Circulate while rotating & reciprocating
F/ 13,080' MD - T/ 13,010' MD, 250
gpm, 2,780 psi, 18% flow out, ECUs =
12.39 ppg. 150 rpm, 7 k. torque, 3,144
total strokes pumped. Lay down 2
joints drillpipe not in string.
8/1/2018
8/1/2018
0.50
PRODS
CASING
OWFF
X
Monitor well for flow (Static)
13,040.0
13,040.0
16:30
17:00
8/1/2018
8/1/2018
4.50
PRODS
CASING
BKRM
X
Beckmann out of hole racking back
13,040.0
11,570.0
17:00
21:30
HWDP and laying down drillpipe to
pipeshed. F/13,040'MD -T/ 11,570
MD, 250 gpm,2,390 psi. 17% flow out,
ECUs = 11.65 ppg. 150 rpm, 6.5 k
torque, up 130 k, Down 70 k. Obtained
surveys at pre -determined depths per
SLB.
Page 31135 ReportPrinted: 811012018
Operations Summary (with Timelog Depths)
11-1-108
,.
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Start Time
End Too
Dur"
Phase
Op Code
Ac"i Code
rime P -T -X
Operation
start Depth
(BKa)
End Depth 00)
8/1/2018
8/2/2018
2.50
PROD3
CASING
BKRM
X
Continue backreaming out of hole
11,570.0
10,626.0
21:30
00:00
laying down drillpipe to pipeshed. F/
11,570' MD -T/10,626' MD. 250 gpm,
2,330 psi. 18% flow out, ECD's =
11.62 ppg. 150 rpm, 6 k. Torque, Up
124 k. Down 75 k.
SPR's @ 13,080.' MD 4,233' TVD MW
-9.2+ pPg
MP # 1) 20 spm = 880 30 spm = 1,160
MP # 2) 20 spm = 900 30 spm = 1,170
Mud losses this tour 7 bbls.
8/2/2018
8/2/2018
5.25
PRODS
CASING
BKRM
X
Back ream out of hole F/10,626' MD -
10,626.0
8,500.0
00:00
05:15
T/8,500' MD, 250 gpm,2,085 psi,18%
Flow out. 150 rpm,4.3 k, Torque.
ECD's 11.16 ppg. Up 114 k. Down 89
k.
8/2/2018
8/212018
1.25
PRODS
CASING
CIRC
X
Circulate at shoe, Rotate &
8,500.0
8,490.0
05:15
06:30
Reciprocate F/8,490' MD - T/ 8,435'
MD. 250 gpm, 2,085 psi. 17% flow
out, 120 rpm, 4 k, Torque. ECD's
11.03 ppg. Up 113 k, Down 89 k.
8/2/2018
8/2/2018
0.25
PRODS
CASING
OWFF
X
Lay down stand #86, Drop 2.0" rabbit
8,490.0
8,442.0
06:30
06:45
W/11 O' wire, Monitor well for 10 min.
(Static)
8/2/2018
8/212018
1.00
PRODS
CASING
TRIP
X
Pull out of hole on elevators F/8,442'
8,442.0
7,491.0
06:45
07:45
MD - T/7,491' MD. Laying down
drillpipe to pipeshed. Monitor hole fill
via trip tank, Calculated 5.5 bbls.
Actual 5.3 bbls. up 113 k, down 87 k.
8/2/2018
8/2/2018
0.50
PRODS
CASING
CIRC
X
Pump 20 bbl. dry job, Blow down
7,491.0
7,491.0
07:45
08:15
topdrive.
8/2/2018
8/2/2018
3.00
PRODS
CASING
TRIP
X
Pull out of hole on elevators, Lay
7,491.0
365.0
08:15
11:15
down drillpipe to pipeshed F/7,491'
MD - T/ 7,206' MD. Continue tripping
out of hole racking pipe in derrick
F/7,206' MD - T/365' MD. Rabbit
recovered at top of jars. Monitor hole
fill via trip tank.
8/2/2018
8/2/2018
0.75
PRO03
CASING
BHAH
X
Monitor well 10 min. (Static) Lay down
365.0
140.0
11:15
12:00
BHA F/ 365' MD - T/140' MD
Monitor well via trip tank.
8/2/2018
81212018
1.00
PRODS
CASING
BHAH
X
Lay down remainder of BHA, F/140'
140.0
0.0
12:00
13:00
MD.
8/2/2018
8/2/2018
0.50
COMPZN
CASING
BHAH
X
Clear and Clean floor, Drain BOP
0.0
0.0
13:00
13:30
Stack.
8/2/2018
8/212018
0.25
COMPZN
CASING
KURD
X
Pull wear bushing.
0.0
0.0
13:30
13:45
8/2/2018
8/2/2018
1.00
COMPZN
CASING
W W WH
X
Make up sub to wash BOP Stack to 4"
0.0
0.0
13:45
14:45
drillpipe, Flush stack at 825 gpm, Lay
down wash sub, Blow down topdrive,
Drain stack.
8/2/2018
8/2/2018
0.75
COMPZN
CASING
RURD
X
Set test plug W/4-112" test joint. Rig up
0.0
0.0
14:45
15:30
test equipment, Flush lines.
Page 32135 Report Printed: 8/10/2018
. Operations Summary (with Timelog Depths)
IH -108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
S Depth
Start Time
End Time
Dur (hr)
Phase
Op Cotle
Activity Code
Tune P -T -X
Operetion
(rt KB)
(
End Depth (flKB)
8/2/2018
8/2/2018
5.00
COMPZN
WHDBOP
BOPE
X
Test BOPE. Tested 250 psi low &
0.0
0.0
15:30
2030
3,500 psi Nigh 5 min. per test all tests
charted. Super and manual operated
chokes tested to 2 k.
Tested with 3-1/2" & 4-1/2" Test joints.
Tested -Annular, lower pipe rams,
Blind rams, Choke valves 1-14, HCR
& Manual choke & kill, Mezzanine kill
line valves, Upper & lower IBOP, 4" XT
-39 Dart & TIW, Koomey drawdown
initial accumulator pressure -2,900 psi.
After function = 1,700 psi. 200 psi
build 8 sec, Full system recovery 57
sec. 6 nitrogen bottle average 1,937
psi. Test PVT's & Methane, H2S
alarms. Test witnessed by AOGCC rep
Austin McLeod. Testing complete
20:30 8/3/2018.
8/2/2018
8/2/2018
0.25
COMPZN
WHDBOP
BOPE
X
Pull test plug, Set Wear ring (9" ID)
0.0
0.0
20:30
20:45
8/2/2018
8/2/2018
1.25
COMPZN
CASING
RURD
X
R/U to run 4-1/2" Lower completion
0.0
0.0
20:45
22:00
liner, Verify tally.
8/2/2018
8/3/2018
2.00
COMPZN
CASING
PUTB
X
Run in hole with 4-1/2" 12.6 ppf L-80
0.0
1,182.0
22:00
00:00
IBT-M liner per detail T/1,182'MD.
Monitor displacement viaa trip tank,
Install 5.88 OD Hyd Centralizers per
tally. Up 54 k. down 58 k.
8/3/2018
8/3/2018
4.25
COMPZN
CASING
PUTB
X
Continue running in hole with 4-1/2"
1,182.0
4730
00:00
04:15
Lower compleflon per tally,
F/1,182'MD - T/4,730' MD. Install 97
hyd centalizers 5.88 OD, Up 81 k.
down 71k.
Monitor displacement via trip tank.
8/3/2018
8/3/2018
1.25
COMPZN
CASING
OTHR
X
Make up seal bore assembly and
4,730.0
4,809.0
04:15
05:30
hanger per baker rep. to 4,809' MD
Up 83k, down 73k.
8/3/2018
8/3/2018
0.50
COMPZN
CASING
CIRC
X
Pick up crossover and 1 stand 4"
4,809.0
4,809.0
05:30
06:00
drillpipe, Circulate to ensure flow path
clear.
4 bpm. - 160 psi. 10% flow out.
8/3/2018
8/3/2018
0.75
COMPZN
CASING
RUNL
X
Run in hole with 4-1/2" Lower
4,809.0
5,854.0
06:00
06:45
completion liner on 4" drillpipe,
F/4,904' MD - T/5,854' MD. Down 85k.
Displacement monitored via trip tank.
8/3/2018
8/3/2018
0.50
COMPZN
CASING
SVRG
X
Service ST -100 Iron Roughneck.
5,854.0
5,854.0
06:45
07:15
8/3/2018
8/3/2018
1.25
COMPZN
CASING
RUNL
X
RIH with 4-1/2" Lower completion liner
5,854.0
7,175.0
07:15
08:30
on4"drillpipe, F/5,854'MID -T/7,175'
MD.
Displacement monitored via trip tank.
8/3/2018
8/3/2018
0.25
COMPZN
CASING
CIRC
X
Fill pipe staging pumps up to 4 bpm.
7,175.0
7,175.0
08:30
08:45
364 psi, 12% flow out, up 103k, down
80k.
8/3/2018
8/3/2018
0.75
COMPZN
CASING
RUNL
X
RIH with 4-1/2" Lower completion liner
7,175.0
8,500.0
08:45
09:30
on 4" drillpipe, F/7,175' MD - 718,500'
MD.
Displacement monitored via trip tank.
8/3/2018
8/3/2018
0.50
COMPZN
CASING
CIRC
X
Circulate drillpipe volume staging
8,500.0
8,500.0
09:30
10:00
pump up to 4 bpm. 410 psi, 12% flow
out, 110k up, 79k down
8/3/2018
8/3/2018
2.00
COMPZN
CASING
RUNL
X
Run in open hole with 4-1/2" Lower
8,500.0
11,360.0
10:00
12:00
completion liner on 4" drillpipe,
F/8,50U MD -T/11,360' MD.
Displacement monitored via trip tank.
131k up 70k down.
Page 33135 Report Printed: 811012018
Operations Summary (with Timelog Depths)
1H-108
Rig: DOYON 142 Job: DRILLING ORIGINAL
Time Log
Stan Depen
Start rare
End Time
Cur (hr)
Phase
Op Code
Activity Code
Time P -T4
Operation
(fiKB)
End Depth (MB)
8/3/2018
8/3/2018
2.25
COMPZN
CASING
RUNL
X
Run in open hole with 4-112" Lower
11,360.0
13,060.0
1200
14:15
completion liner on 4" drillpipe,
F/11,360' MD - T/13,082' MD.
Space out liner hanger w/Shoe
all 3,060' MD. 163k up 84k down.
Displacement monitored via trip tank.
8/3/2018
8/3/2018
1.00
COMPZN
CASING
CIRC
X
Circulate 80 bbls: drillpipe volume,
13,060.0
13,060.0
14:15
15:15
Stage up to 4 bpm. 789 psi, 11 % flow
out, 819 total strokes.
8/3/2018
8/312018
1.25
COMPZN
CASING
HOSO
X
Drop 1.625" setting ball, pump down
13,060.0
13,060.0
15:15
16:30
@ 3 bpm. 610 psi. 12% flow out,
reduce to 1 bpm, 390 psi, ball on seat
659 strokes, Set hanger per baker rep
increasing pressure to 1,900 psi.
Slack off attempt to set hanger
twice,lncrease pressure to 2,135 psi.
setting hanger with 48k down,
increase pressure to 2,400 psi. for 5
min. setting packer, increase pressure
to 4,200 psi. releasing HRDE, bleed
pressure, pick up 7' up wt. 123k. 4-
1/2" Lower completion slotted liner
shoe set at 13,060.14' MD TOL at
8,264.72'.
7" shoe @ 8508.85', 244.13' lap.
8/3/2018
8/312018
0.75
COMPZN
CASING
PRTS
X
Perform packer test 3,400 psi- 30 min.
13,060.0
13,060.0
16:30
17:15
charted test. Pumped down IA with
annular closed and drillpipe open.
8/3/2018
8/3/2018
1.75
COMPZN
WELLPR
DISP
X
Pick up additional 6'- pump 30 bbl.
13,060.0
8,239.0
17:15
19:00
spacer, Start displacement over to 9.2
ppg kill wt. brine, at 3 bpm. pump 102
bbl's. and pick up out of liner top to
8,239' MD. Increase pump rate to 12
bom. 3,200 psi. 3,900 total strokes
pumped.
8/3/2018
8/3/2018
0.50
COMPZN
WELLPR
OWFF
X
Monitor well for flow (Static)
8,239.0
8,239.0
19:00
19:30
8/3/2018
8/312018
1.00
COMPZN
WELLPR
SLPC
X
Slip and cut 88' of drilling line.
8,239.0
8,239.0
19:30
20:30
8/3/2018
8/412018
3.50
COMPZN
WELLPR
TRIP
X
TOOH laying down 4" drillpipe to
8,239.0
4,409.0
20:30
00:00
pipeshed. F/ 8,239' MD - T/4,409' MD.
8/4/2018
8/4/2018
3.50
COMPZN
WELLPR
TRIP
X
TOOH Laying down 4" drillpipe F/
4,409.0
0.0
00:00
03:30
4,490' MD to surface.
8/4/2018
8/4/2018
0.25
COMPZN
WELLPR
BHAH
X
Lay down baker liner running tool.
0.0
0.0
03:30
03:45
8/4/2018
814/2018
1.25
COMPZN
WELLPR
WWWH
X
Pull wear bushing, Clean BOP stack
0.0
0.0
03:45
05:00
with flushing tool.
8/4/2018
8/4/2018
1.50
COMPZN
RPCOMP
RURD
X
Rig up to run 3-1/2" Tubing upper
0.0
0.0
05:00
06:30
completion. Verify tubing tally & count.
PJSM
8/4/2018
814/2018
5.50
COMPZN
RPCOMP
PUTB
X
Make up seal assembly, RIH with 3-
0.0
4,492.0
06:30
12:00
1/2" 9.3 ppf. L-80 Hyd 563 upper
completion per detail to 4,492' MD.
Connections torqued to 2,900 ft/lbs.
Disp monitored via trip tank
Up 70 k. down 66 k.
8/4/2018
8/4/2018
5.00
COMPZN
RPCOMP
PUTB
X
RIH with 3-1/2" 9.3 ppf. L-80 Hyd 563
4,492.0
8,223.0
12:00
17:00
-
upper completion per detail F/4,492'
MD - T/8,223' MD. Disp monitored via
trip tank
Up 84 k. down 61 k.
8/4/2018
8/4/2018
0.50
COMPZN
RPCOMP
PUTB
X
RIH with joints 259 through 262, Tag
8,223.0
8,326.0
17:00
17:30
no go at 8,326.51 MD. Lay down joint
#262
Page 34135 ReportPrinted: 81110120181
Operations Summary (with Timelog Depths)
IH -108
Rig:
DOYON 142
Job:
DRILLING ORIGINAL
Time Log
Start nine
EM Time
W(hr)
Phase
Op Code
Activity CnEe
Time P -T -X
Operation
Start Depth
(Itl(a)
End Depth(r1Ka)
8/4/2018
8/4/2018
1.75
COMPZN
RPCOMP
CRIH
X
Make up crossover, Pick up to 8,270'
8,326.0
8,270.0
17:30
19:15
MD. Pump 161 bbl's. corrosion
inhibited brine at 3 bpm, 190 psi. 7%
flow out. Spot inhibited brine with 82
bbl's 9.2 ppg. brine.
8/4/2018
8/4/2018
1.25
COMPZN
RPCOMP
HOSO
X
Lay down 3 joints, (161-159) Pick up
8,270.0
8,324.0
19:15
20:30
space out pups. 3.8579.8479.85'- 1.33'
crossover, Joint 4-1/2"Hyd 563 tubing
38.07' pup 3.05 & hanger, Make up to
landing joint and land hanger at
8,324.37' MD. 86 k up 61 k down
2.25' off fully located.
8/4/2018
6/4/2018
1.25
COMPZN
RPCOMP
W WSP
X
Rig up and test hanger seals 5,000 psi
8,324.0
8,324.0
20:30
21:45
upper and lower tests. Test good.
8/4/2018
8/4/2018
1.25
COMPZN
RPCOMP
PRTS
X
Rig up and test IA and hanger. 1,500
8,324.0
8,324.6-
21:45
23:00
psi F/10 min. 21 strokes. Pump up to
2,000 psi F/30 min 25 strokes,
Pressure up to 2,787 psi to shear
SOV, 32 strokes. 3 bbl's received on
bleed back
8/412018
8/5/2018
1.00
COMPZN
WHDBOP
NUND
X
Remove flow riser, Choke and kill
8,324.0
0.0
23:00
00:00
1
1
1 hoses, Unbolt BOPE flanges.
8/512018
8/5/2018
1.00
COMPZN
WHDBOP
NUND
X
Set back BOP Stack, Remove Spacer
0.0
0.0
00:00
01:00
spools.
8/512018
8/5/2018
3.00
COMPZN
WHDBOP
NUND
X
Nipple up Tree, Install test dart, Test
0.0
0.0
01:00
04:00
hanger void 5 k. 15 min. Test tree
body 5 k. 15 min. (Charted) Remove
test dart and BPV.
8/5/2018
8/5/2018
3.75
COMPZN
WHDBOP
FRZP
X
Rig up and pump 93 bbls. diesel
0.0
0.0
04:00
07:45
freeze protect. with Little Red
Services. Pump down IA returns up
tubing to open top tank holding back
pressure with choke skid. Rate .8
bpm, 2,000 psi. Shut in tubing 220 psi.
Blow down and rig down. OA= 140
8/5/2018
8/5/2018 -T-psi.
1.25
DEMOB
MOVE
KURD
X
Secure tree and Cellar. OA= 140 psi,
0.0
0.0
07:45
09:00
IA = 0.0 psi. TBG = 200 psi.
Release Rig @ 09:00
Page 35135
Report Printed: 811012018
NADConversion
Kuparuk River Unit
Kuparuk 1H Pad
1 H-108
NAD 2
ConocoPhillips
Definitive Survey Report
05 July, 2018
Final Definitive Survey
Verified and Signed -off
All targets and/or well position objectives have been achieved.
Q Yes ❑ No
1 have checked to the best of my ability that the following data is correct:
Q Surface Coordinates
Q Declination & Convergence
Q GRS Survey Corrections pigs„lysigmd br vlrKent Dun
❑ Survey Tool Codes
Vincent Osara
�hlum ,e,,o _ScNumbe ,,
emai-vosangsUcan,<=°S
SLB DE” DaM2m&07.losv1s3s4sas
Nick Lehman Digbily sgned by Nick Lehman
Client Representative' DaW:2018.oz09 17a5n-08'W
Date:
ConocoPhillips
Schlumberger
Definitive Survey Report
Company:
NADConversion
Local Coordinate Reference:
Well 11-1-108
Project:
Kuparuk River Unit
TVD Reference:
1H-108 actual @ 92.99usft (Doyon 142)
Site:
Kuparuk 1H Pad
MD Reference:
1H-108 actual @ 92.99usft (Doyon 142)
Well:
1H-108
North Reference:
True
Wellbore:
1 H-108
Survey Calculation Method:
Minimum Curvature
Design:
1 H-108
Database:
OAKEDMP2
'reject Kuparuk River Unit, North Slope Alaska, United States
Rap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Rap Zone: Alaska Zone 04 Using geodetic scale factor
L
DNtgn 1H-108
Audg Notes:
Version: 1.0
Vertical Seeflon:
BGGM2017 6/1/2018
5,980,752.52 usft Latitude: 70° 21'29.515 N
549,570.98 usft Longitude: 149" 35'50.595 W
usft Ground Level: 54.00 usft
Declination Dip Angle Field Strength
V) 1°) (nT)
17.08 80.93 57,468
Phase:
1H-108
Tie On Depth:
38.99
Depth From (ND)
+NIS
0.00 usg
Northing:
LP.,tp...
+E/ -W
0.00 usg
Easting:
ncertainty
0.00
0.00 usft
Wellhead Elevation:
1,266.381H-108 Srvy 1- SLB _GWD70(1H-108)
GYD-GC-SS
Gyrodata gyro single shots
6/18/2018 8:51:
Wellbore
1H-108
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
Magnetics
Model Name
6,462.951H-108 Srvy 3- SLB _MWD+GMAG(1 H-
Sampte Date
L
DNtgn 1H-108
Audg Notes:
Version: 1.0
Vertical Seeflon:
BGGM2017 6/1/2018
5,980,752.52 usft Latitude: 70° 21'29.515 N
549,570.98 usft Longitude: 149" 35'50.595 W
usft Ground Level: 54.00 usft
Declination Dip Angle Field Strength
V) 1°) (nT)
17.08 80.93 57,468
Phase:
ACTUAL
Tie On Depth:
38.99
Depth From (ND)
-NIS
+E/ -W
Direction
(usft)
(usft)
(usft)
(°)
38.99
0.00
0.00
112.00
Vey Program
Data
From
To
(usfo
(usft) Survey (Wellbors)
Tool Name
Description
Survey Date
120.48
1,266.381H-108 Srvy 1- SLB _GWD70(1H-108)
GYD-GC-SS
Gyrodata gyro single shots
6/18/2018 8:51:
1,361.99
1,750.031H-108 Srvy 2-SLB_MWD+GMAG(1 H-
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
6/16/2018 8:5C
1,847.94
6,462.951H-108 Srvy 3- SLB _MWD+GMAG(1 H-
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
6/19/2018 8:55:
Survey
Map
Map
Vertical
MD
Inc
Aid
TVD
TVDSS
+WS
+EI -W
Northing
Essting
OLS
Section
(usft)
(')
C)
(usft)
(usft)
(usft)
(usft)
(ft)
Ift)
(°1100)
(it) Survey Tod Name
38.99
0.00
0.00
38.99
54.00
0.00
0.00
5,980,752.52
549,570.98
0.00
0.00 UNDEFINED
120.48
0.15
315.17
120.48
27.49
0.08
-0.08
5,980,752.60
549,570.90
0.18
-0.10 GYD-GC-SS(1)
147.84
O.OB
176.35
147.84
54.85
0.0B
-0.10
5,980,752.60
549,570.88
0.79
-0.12 GYD-GC-SS(1)
239.63
0.20
174.22
239.63
146.64
-0.14
-0.OB
5,980,752.38
549,570.90
0.13
-0.02 GYD-GC-SS(1)
336.20
0.12
174.23
336.20
243.21
-0.41
-0.05
5,98,752.11
549,570.93
0.08
0.11 GYD-GCSS(1)
429.26
1.29
146.15
429.25
336.26
-1.38
0.54
5,980,751.15
549,571.53
1.27
1.02 GYD-GCSS(1)
519.62
1.88
132.82
519.58
426.59
5.23
2.20
5SW,749.31
549,573.20
0.77
3.24 GYD-GCSS(1)
610.87
2.81
125.22
610.75
517.76
5.54
5.12
5,980,747.02
549,576.14
1.07
6.82 GYD-GCSS(1)
700.99
4.86
123.76
700.66
607.67
5.93
10.10
5,980,743.66
549,581.14
2.28
12.71 GYD-GCSS(1)
791.48
7.14
12025
790.65
697.66
-13.90
18.15
5,980,738.75
549,589.21
2.55
22.03 GYDGCSS(1)
886.41
10.45
122.90
884.45
791.46
-21.55
30.47
5,980,731.18
549.601.59
3.51
36.33 GYDGCSS(1)
981.60
12.58
121.52
977.72
884.73
31.66
46.56
5,98,721.18
549,617.74
2.26
55.03 GYD-GC-SS(1)
71WO18 8:56:07AM Page 2 COMPASS 5000.14 Build 85
Schlumberger
Definitive Survey Report
Company:
NADConversion
Local Co-ordinate Reference:
Well IH -108
Project:
Kuparuk River Unit
TVD Reference:
1 H-108 actual @ 92.99usR (Doyon 142)
She:
Kuparuk 1 H Pad
MD Reference:
1 H-108 actual (d1 92.99usR (Doyon 142)
Well:
IH -108
North Reference:
True
Wellbore:
1H-108
Survey Calculation Method:
Minimum Curvature
Design:
IH -108
Database:
OAKEDMP2
Survey
MD
(uaR)
1,077.17
1,171.65
1,286.38
1,361.99
1,422.20
1,516.33
1,611.98
1.707.27
1,750.03
Ile
(1)
14.17
15.91
18.99
21.79
23.55
25.66
25.72
26.11
27.12
Azi
(1)
121.38
122.81
124.39
123.25
123.41
123.18
122.60
123.45
123.75
TVD
(uslq
1,070.70
1,161.94
1,252.30
1,341.91
1,397.46
1,483.04
1,569.24
1,654.94
1,693.17
TVDSS
(usft)
977.71
1,068.95
1,159.31
1,248.92
1,304.47
1,390.05
1,476.25
1,561.95
1,600.18
+W -S
(ustt)
43.19
56.23
-71.97
50.49
-103.24
-124.76
-147.27
-169.97
-180.57
+EI -W
(uslt)
65.42
WAS
109.82
137.50
156.89
189.65
224.46
259.38
275.33
Map
Northing
(ft)
5,980,709.77
5,980,696.87
5,980,681.28
5,980,662.95
5,980,650.33
5,980,629.03
5,980,606.75
5,980,584.29
6.W,573.79
Map
Easgng
Im
549,636.68
549,657.52
549,681.26
549,709.05
549,728.53
549,761.43
549,796.39
549,831.45
549,847.48
DLS
("11001
1.66
1.88
3.29
2.96
2.92
2.24
0.27
0.57
2.38
Vertical
Section
(R) Survey Tool Name
76.84 GYD-GCSS(1)
100.97 GYD-GCSS(1)
128.78 GYD.GCSS(1)
161.39 MWD+IFR-AK-CAZSC(2)
184.14 MWD+IFR-AK4;AZSC (2)
222.57 MWD+IFR-AK-CAZ-SC (2)
263.29 MM+IFR-AK-CAZ-SC(2)
304.16 MWD+IFR-AK-CAZ-SC (2)
322.93 MWD+IFR-AK-CAZ-SC(2)
1,834.00
29.50
121.43
1,767.10
1,674.11
-201.99
308.89
5,980,552.60
549,881.17
3.12
362.07
NOT an Actual Survey
10 314" z 13112'
1,847.94
29.90
121.08
1,779.21
1,686.22
-205.57
314.80
5,980,549.05
549,887.10
3.12
36B.eB MWD+IFR-AK-CAZSC(3)
1,916.52
31.62
122.51
1,838.14
1,745.15
-224.06
344.60
5,980,530.77
549,917.02
2.73
403.44 MWD+IFR-AK-C ZSC (3)
1,960.69
33.15
122.32
1,875.43
1]82.44
-236.74
364.57
5,980,518.22
549,937.08
3.47
426.71 MWD+IFR-AK-CAZSC(3)
2,055.87
37.16
120.95
1,953.24
1,860.25
-ME45
411.24
5,980,489.82
549,983.92
4.29
480.73 MWD+IFR-AK-CAZSC(3)
2,151.50
41.81
119.40
2,027.03
1,934.04
-295.97
463.81
5,980,459.65
550,036.69
4.97
540.91 MWD+IFR-AK-CAZSC(3)
2,246.62
45.62
121.71
2,095.77
2,002.78
329.42
520.37
5,980,426.59
550,093.47
4.34
605.88 MWD+IFR-AK-CAZSC (3)
2,341.58
48.54
123.65
2,160.43
2,067.44
-366.98
578.88
5,980,389.41
550,152.22
3.42
674.20 MWD+IFR-AK-CAZSC (3)
2,438.05
51.84
124.97
2,222.19
2,129.20
408.76
640.07
5,980,348.04
550,213.68
3.58
746.58 MWD+IFR-AK-CAZ-SC(3)
2,532.72
54.06
124.75
2,279.23
2,186.24
-451.94
702.06
5,980,305.28
550,275.95
2.35
820.24 MWD+IFR-AK-CAZ-SC(3)
2,627.43
53.72
123.92
2,335.04
2,242.05
495.10
765.24
5,960,262.54
550,339.41
0.79
894.99 MWD+IFR-AK-CAZ-SC(3)
2,722.24
54.07
124.43
2,390.91
2,297.92
538.13
828.62
5,980,219.94
550,403.06
0.57
%9.87 MWD+IFR-AK-CAZSC(3)
2,816.74
53.75
123.97
2,446.58
2,353.59
581.05
891.78
5,980,177.44
550,466.49
0.52
1,044.51 MWD+IFR-AK-CAZSC(3)
2,911.88
53.92
123.50
2,502.72
2,409.73
523.71
955.65
5,980,135.21
550,530.64
0.44
1,119.71 MWDAFR-AK-CAZSC(3)
3,007.18
54.22
12381
2,558.64
2,465.65
666.47
1,019.88
5,980,092.88
550,595.15
0.41
1,195.29 MWD+IFR-AK-CAZSC(3)
3,103.39
54.08
123.56
2,614.99
2,622.00
-709.73
1,084.77
5,980,050.06
550,680.32
0.26
1.271Z5 MWD+IFR-AK-CAZ-SC (3)
3,197.96
54.09
123.34
2.670.46
2,577.47
-751.94
1,148.68
5,980,008.27
550,724.50
0.19
134672 MWD+IFR-AK-CAZ-SC(3)
3,292.19
54.21
122.85
2,725.65
2,632.66
-793.65
1,212.67
5,979,966.99
550,788.75
0.44
1,421.67 MWD+IFR-AK-CAZSC(3)
3,387.87
55.16
119.94
2,780.97
2,687.98
534.30
1,279.30
5,979,926.78
550,855.65
2.67
1,498.58 MWD+IFR-AK-CAZ-SC(3)
3,482.93
56.78
116.83
2,834.17
2,741.18
571.73
1,348.60
5,979,889.82
550,925.19
3.20
1,576.96 MWD+IFR-AK-CAZ-SC(3)
3,578.37
59.88
114.68
2,884.28
2,791.29
506.99
1,421.76
5,979,855.05
550,998.57
3.77
1,658.00 MWD+IFR.AK-CAZSC (3)
3,673.43
63.82
112.73
2,929.12
2,836.13
540.65
1,498.49
5,979,821.89
551,075.52
4.52
1,741.75 MWD+IFR-AK-CAZSC(3)
3,768.07
67.02
110.14
2,968.49
2,875.50
572.07
1,578.59
5,979,791.01
551,155.82
4.20
1,827.79 MWD+IFR-AK-CAZSC(3)
3,863.57
66.89
108.97
3,005.87
2,912.88
-1,001.49
1,661.40
5,979,762.14
551,238.81
1.14
1,915.59 MWD+IFR-AK-CAZSC(3)
3,956.13
67.09
107.05
3,042.06
2,949.07
-1,027.93
1,742.42
5,979,736.35
551,319.99
1.92
2,000.57 MWD+IFR-AK-CA -SC (3)
4,053.25
67.22
106.31
3,079.76
2,986.77
-1,053.52
1,828.15
5,979,711.23
551,405.89
0.71
2,089.69 MWD+IFR-AK-CAZ-SC(3)
4,148.61
65.92
105.25
3,116.92
3,023.93
-1,077.40
1,912.67
5,979,687.91
551,490.55
1.07
2,176.99 MWD+IFR-AKCAZ+9C(3)
4,242.48
66.99
105.27
3,153.66
3,060.67
-1,100.13
1,996.00
5,979,665.72
551,574.02
0.08
2,262.78 MWD+IFR-AK-CAZSC(3)
4,339.38
66.86
105.48
3,191.64
3,098.65
-1,123.77
2,081.96
5,979,642.66
551,660.12
0.24
2,351.33 MWD+IFR-AK-CAZSC(3)
4,432.48
66.92
105.98
3,228.18
3,135.19
-1,146.98
2,164.38
5,979,619.99
551,742.69
0.50
2,436.44 MWD+IFR-AK-CAZSC(3)
7/5/2018 8:56:07AM Page 3 COMPASS 5000.14 Build 85
Schlumberger
Definitive Survey Report
Company:
NADConversion
Local Coordinate Reference:
Well 1H-108
Project:
Kuparuk River Unit
TVD Reference:
1 H-108 actual @ 92.99usft (Doyon 142)
Site:
Kuparuk 1 H Pad
MD Reference:
1 H-108 actual @ 92.99usft (Doyon 142)
Well:
11-1-108
North Reference:
True
Wellbore:
1 H-108
Survey Calculation Method:
Minimum Curvature
Design:
1 H-108
Database:
OAKEDMP2
Survey
Map
MHP
Vertical
MD
Inc
AZI
TVD
TVDSS
+WS
+E/ -W
Northing
Easting
DLS
Section
(usft)
(*)
(°)
Well)
(usft)
(usft)
(usft)
(1t)
(ft)
(°/100')
(fy Survey Toot Name
4,526.56
67.31
104.52
3,264.77
3,171.78
-1,169.78
2,248.00
5,979,597.75
551 826.45
1.49
2,522.52 MWD+IFR-AK-CAZ-SC (3)
4,621.42
67.40
104.6
3,301.29
3,208.30
-1,191.39
2,332.84
5,979,576.71
551,911.42
0.46
2,609.27 MWD+IFR-AK-CAZ-SC(3)
4,717.95
67.00
103.35
3,338.70
3,245.71
-1,212.47
2,419.29
5,979,556.20
551998.00
0.79
2,697.33 MWD+IFR-AK-CAZSC(3)
4,813.47
67.31
104.64
3,375.79
3,282.80
-1,233.76
2,504.70
5.979,535.48
552983.55
1.29
2,784.49 MWD+IFR-AK-CAZSC(3)
4,909.30
67.49
104.41
3,412.61
3,319.62
-1,255.95
2,590.34
5,979,513.05
552,169.33
0.29
2,872.21 MWD+IFR-AK-CAZSC(3)
5,004.05
67.52
104.71
3,44B.87
3,355.88
-1,277.96
2,675.07
5,979,492.42
552,254.19
0.29
2,959.2 MWD+IFR-AK-CAZSC(3)
5,099.46
67.55
104.68
3,485.32
3,392.33
-1,300.32
2,760.36
5,979,470.62
552,339.61
0.04
3,046.47 MWD+IFR-AK-CAZ-SC (3)
5,195.35
67.35
105.69
3,522.10
3,429.11
-1,323.52
2,845.82
5,979,447.99
552,425.22
0.99
3,134.40 MWD+IFR-AK-CAZSC(3)
5,288.94
67.45
105.83
3,558.06
3,465.07
-1,346.99
2,928.98
5,979,425.07
552,508.52
0.17
3,220.29 MWD+IFR-AK-CAZSC(3)
5,384.13
67.34
106.66
3,594.65
3,501.66
-1,371.57
3,013.35
5,979,401.05
552,593.04
0.81
3,307.73 MWD+IFR-AK-CAZ-SC (3)
5,479.24
67.85
106.17
3,630.90
3,537.91
-1,30.42
3,097.69
5,979,376.77
552,677.54
0.72
3,395.24 MWD+IFR-AK-CAZ-SC (3)
5,574.44
67.59
104.86
3,667.00
3,574.01
-1,419.98
3,182.57
5,979,353.77
552,762.57
1.30
3,482.76 MWD+IFR-AK-CAZSC(3)
5,669.23
67.04
104.74
3,703.55
3,610.57
-1,442.32
3,267.13
5,979,331.99
552,847.26
0.59
3,569.53 MWD+IFR-AK-CAZSC(3)
5,764.47
65.70
104.38
3,740.97
3,647.98
-1,464.34
3,351.90
5,979,310.53
552,932.17
0.50
3,656.38 MWD+IFR-AI(-CAZSC(3)
5,859.25
66.78
105.22
3,778.40
3,685.41
-1,486.58
3,4%.09
5,979,288.85
553,016.49
0.82
3,742.77 MWD+IFR-AK-CAZSC (3)
5,955.19
66.74
104.77
3,816.25
3,723.26
-1,509.39
3,521.24
5,979,266.61
553,101.79
0.43
3,830.26 MWD+IFR-AK-CAZSC(3)
6,050.94
66.91
105.34
3,853.94
3,760.95
-1,532.26
3,606.24
5,979,244.31
553,186.93
0.58
3,917.64 MWD+IFR-AK-CAZSC(3)
6,145.08
66.74
106.41
3,890.98
3,797.99
-1,555.93
3,689.48
5,979,221.19
553,270.32
1.06
4,003.69 1AWD+IFR-AK-CAZ-SC(3)
6,240.70
66.72
107.30
3,928.76
3,835.T/
-1,581.40
3,773.55
5,979,196.28
553,354.54
0.86
4,091.18 MWD+IFR-AK-CAZ-SC(3)
6,336.23
66.55
108.83
3,966.65
3,873.66
-1,608.59
3,856.92
5,979,169.64
553,438.08
1.48
4,178.66 MWD+IFR-AK-CAZ-SC(3)
6,431.16
65.60
108.60
4,004.39
3,911.40
-1,636.54
3,939.42
5,979,142.24
553,520.76
0.23
4,265.63 MWD+IFR-AK-CAZSC(3)
6,462.95
66.82
10B.40
4,016.96
3,923.97
-1,645.81
3,967.11
5,979,133.16
553,548.51
0.90
4,294.77 MWD+IFR-AK-CAZSC(3)
6,527.00
66.82
108.40
4,042.17
3,999.18
-1,664.39
4,022.98
5,979,114.95
553,604.49
0.00
4,353.53 PROJECTED WTD
7152018 856:07AM Page 4 COMPASS 5000.14 Build 85
Cement Detail Report
11-1-108
Job:
String: Conductor
DRILLING ORIGINAL, 6/4/201800:00
Cement Details
Description
Conductor
Cementing Start Date
1116/2016 10:30
Cementing End Data
11/6/2016 1800
Wellbore Name
1 H-108
Comment
10 yards (5.5 sacks) of aggregate cement poured into backside by AFC. CMT/aggregate ratio of 564/3520 per yard
Cement Stages
Stage # 1
Description
Conductor Cement
Objective
Top Depth (ftKB)
39.0
Bottom Depth (ftKB)
119.0
Full Return?
No
Vol Cement...
Top Plug?
No
Btm Plug?
No
O Pump Ink (bbUm...
O Pump Final (bbl/...
Q Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip7
No
Stroke (ft)
Rotated?
No
Pipe RPM (rpm)
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Cement Fluids 8 Additives
Fluid
Fluid Type
Conductor Cement
Fluid Description
Estimated Top (ftKB)
39.0
Est Btm (ftKB)
119.0
Amount (sacks)
6
Class
G
Volume Pumped (bbl)
60.0
Yield (ft'/sack)
2.13
Mix H2O Ratio (gal/sa...
5.24
Free Water (YO)
Density (Ib/gal)
15.00
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Type
Additive
Concentration
Conc Unit label
Page 1/1
ReportPrinted: 8/1012018
Type
Concentration
Conc Unit label
Cement Detail Report
11-1-108
String: Surface Casing Cement
Job: DRILLING ORIGINAL, 6/4/201800:00
Cement Details
Description
Surface Casing Cement
Cementing Start Date
6/18/2018 11:15
Cementing End Date
6/18/2018 14:15
Wellbore Name
1 H-108
Comment
PJSM w/ all involved parties for cementing. Pump 5 We of H2O to flood lines. Test cement lines to 3500 psi, good. Pump 40 bbls of CW -100, 5 bpm, 120 psi,
FO 13%. Pump 76 bbis of 10.5 ppg Mud Push II w/ red dye, 5 bpm, ICP 152 psi, FCP 130 psi, FO 16%. Drop bottom plug. Pump 328 bbls of 11 ppg Lead
Cement, 6 bpm, 171 psi, FO 15%. Pump 65 bble of 12 ppg Tail Cement, 5-6 bpm, ICP 220 psi, FCP 274 psi, FO 15%, PU 117K, SO 97K. Drop top plug. Kick out
plug w/ 10 We of H2O. Swap to dg & pump treated 9.6 ppg mud, 7 bpm, ICP 250 psi, FCP 391 psi, FO 17%. Reciprocate casing w/20 strokes throughout job &
land casing on hanger w/ 1000 strokes pumped by rig pump. Slow pump rate to 3 bpm at 1300 strokes, 250 psi, FO 11%. Bump the plug with 1569 strokes,
pressuring up to 750 psi. Hold pressure for 5 minutes, bleed off, & floats holding. CIP @ 14:13 his. Total of 84 bbls of 11 ppg lead cement back to surface.
Cement Stages
Stage # 1
Description
Surface Casing Cement
Objective Top Depth (ftKB)
43.5
Bottom Depth (ftKB)
1,840.0
Full Return?Vol
No
Cement...
84.0
Top Plug?
I Yes
Brim Plug?
Yes
Q Pump Ink (bbllm...
4
Q Pump Final (bbl/...
3
Q Pump Avg (bbll...
6
P Pump Final (psi)
240.0
P Plug Bump (psi)
750.0
Recip?
1 Yes
Stroke (ft)
20.00
Rotated?
No
I Pipe RPM (rpm)
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Pump 40 bbis of CW -100, 76 bbis of 10.5 ppg Mud Push II, 328 bbls of 11 ppg Lead Cement, & 65 bbis of 12 ppg Tail. Cement.
Cement Fluids & Additives
Fluid
Fluid Type
Pre Flush
Fluid Description
Estimated Top INKS)
0.0
Est Bbn (ftKB)
0.0 1
Amount (sacks)
Class
1
Volume Pumped (bbl)
40.0
Yield (fP/sack)
Mix H2O Ratio (gages...
Free Water (%)
Density (Ib/gal)
8.33
Plastic Viscosity (OP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Cone Unit label
Fluid
Fluid Type
Spacer
Fluid Description
Estimated Top (ftKB)
0.0
Est Btm (ftKB)
0.0 1
Amount (sacks)
Class
Volume Pumped (bbl)
76.0
Yield (ft'/sack)
Mix H2O Ratio (gallsa...
Free Water (%)
Density (Ib/gal)
10.50
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Cone Unit label
Fluid
Fluid Type
Lead Cement
Fluid Description
Estimated Top (ftKB)
43.5
Est Btm (ftKB)
1,335.0
Amount (sacks)
969
Class Volume
G 328.0
Pumped (bbl)
Yield (ft /sack)
1.90
Mix H2O Ratio (gal/sa...
6.70
Free Water (%)
1
Density (lb/gal)
11.00
Plastic Viscosity (cP)
100.7
Thickening Time (hr) CmprStr
3.75
1 (psi)
Additives
Additive
Type
Concentration
Cone Unit label
Fluid
Fluid Type
Tail Cement
Fluid Description
Estimated Top (ftKB)
1,335.0
Est Btm (ftKB)
1,84%
Amount (sacks)
221
Class Volume
G 65.0
Pumped (bbl)
Yield (ft'/sack)
1.65
Mix H2O Ratio (gallsa...
5.47 1
Free Water (%)
Density (Ib/gal)
12 1 100.4
Plastic Viscosity (cP)
Thickening Time (hr) CmprStr
3.00
1 (psi)
Additives
Additive
Type
Concentration
I Cone Unit she
Stage # 2
Description
Objective Top Depth (1tKB)
Bottom Depth (ftKB)
Full Return?
No
Vol Cement...
I
Top Plug? I
No
Elm Plug?
No
Q Pump Init (bbl/m... Q
Pump Final (bb0...FTagMepttod
Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
No
Stroke (ft)
Rotated?
Nc
Pipe RPM (rpm)
Tagged Depth (ftKB)
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Page 112 ReportPrinted: 8110120181
Cement Detail Report
1 H-108
String: Surface Casing
Job: DRILLING ORIGINAL, 6/4/2018
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (MB)
Amount (sacks)
Class
Volume Pumped (bbl)
Yield (W/sack)
Mix H2O Ratio (gallsa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
Additives
Additive
Type
Concentration
Con; Unit label
Page 212 ReportPrinted: 811012018
Cement Detail Report
e
11-1-108
String: Cement Plug
Job: DRILLING ORIGINAL, 6/4/2018 00:00
Cement Details
Description
Cementing Start Date
Cementing End Date
Wellbore Name
Cement Plug 16/22/201811:00
6122/201819:45
1H-108
Comment
Begin 1st cement plug testing lines to 800 - 3000 PSI, Pump 26 BBLS 12.5 PPG mud push @ 3 BPM ICP = 150 PSI DPP, FCP = 50 PSI DPP. cose bag and
batch up cement. Open bag and pump 50 BBLS of 15.8 Class G cement @ 3.5 BPM ICP = 50 PSI DPP, FCP = 102 PSI DPP. Close bag and drop foam ball. /
Open bag to pump 4 BELS 12.5 PPG mud push, Swap to rig pumps and pump 58 BBLS LSND @ 7 BPM, ICP = 60 PSI DPP, FCP = 300 PSI DPP. catch up to
vement after 400 stks away reduce rate to 4 BPM 12% F/O. PUH on elevators at 1300 hrs from 5,722' MD to 5,206' MD. UP WT = 111 K. Stage up pumps to 7
BPM With ICP 196 PSI DPP, FCP - 420 PSI DPP. 18% F/O. pump 3400 stks.
Begin 2nd cement plug pumping 26 BBLS 12.5 PPG mud push Il. @ 3 BPM with ICP 222 PSI DPP, FCP - 50 PSI DPP. 10%F/0. Close bag and batch up
cement. Open bag pump 50 BBLS of 15.8 PPG Class G cement. with ICP 50 PSI DPP. FCP 120 PSI DPP. 14% F/O. Close bag drop foam ball, Open bag and
pump 4 BBLS 12.5 PPG Mud push ii Swap to rig pumps. pump 51 BBLS of -SND @ 7 BPM. ICP = 153 PSI, catch cement @ 260 stks. Reduce rate to 4 BPM
FCP = 374 15% F/O. PUH on elevators from 5206'- 4,610' MD. UP WT = 104K. Circulate staging pumps up to 650 GPM @ ICP 1,230 PSI FCP - 600 PSI
DPP. 31 % F/O, Reduce rate due to contaminated mud returning to surface at 350 GPM. 352 PSI DPP. 22% F/O, 3,575 STKS pumped.
Begin 3rd cement isolation plug pump 25 BBLS 12.5 PPG Mud push ii. 4 BPM @ 220 PSI, 12% F/O, Gose bag. Batch up cement. CEMENT WET 1852 HRS.
Pump 70.3 BBLS 15.8 PPG class G cement at 4 BPM, 390 PSI DPP. Close bag drop foam ball, Open bag and pump 5 BBLS of 12.5 PPG Mud push II then
swap to rig pumps pumping 33 BBLS of 9.3 PPG LSND @ 7 BPM, catch cement at 180 STKS ICP = 300 PSI DPP FCP = 750 PSI. PUH from 4,132' MD - 3,400'
MD monitor disp via pit 05, UP WT = 85K. DWN WT = 80K. Break over weight at 119K.
Cement Stages
Stage # 1
Description
Objective Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
Top Plug?
Ron Plug?
Cement Plug
P&A iH-108 mother bore 5,057.0
5,557.0
No
0.0
No
No
Q Pump [nit (bbl/m...
Q Pump Final (bbl/...
Q Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
4
4
4
300.0
1 Yes
30.00
No
I
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Begin 1st cement plug testing lines to 800 - 3000 PSI, Pump 26 BBLS 12.5 PPG mud push @ 3 BPM ICP = 150 PSI DPP, FCP = 50 PSI DPP. cose bag and
batch up cement Open bag and pump 50 BBLS of 15.8 Class G cement @ 3.5 BPM ICP = 50 PSI DPP, FCP = 102 PSI DPP. Close bag and drop foam ball. /
Open bag to pump 4 BBLS 12.5 PPG mud push, Swap to rig pumps and pump 58 BBLS -SND @ 7 BPM, ICP = 60 PSI DPP, FCP = 300 PSI DPP. catch up to
vement after 400 stks away. reduce rate to 4 BPM 12% F/O. PUH on elevators at 1300 hrs from 5,722' MD to 5,206' MD. UP WT = 111K. Stage up pumps to 7
BPM With ICP 196 PSI DPP, FCP - 420 PSI DPP. 18% F/O. pump 3400 stks.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Abandonment
5,057.0
5,557.0
G
50.2
Cement
Yield (ft'lsack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (0)
Thickening Time (hr)
CmprStr 1 (psi)
1.16
5.05
1
15.80
24.00
Additives
Additive
Type
Concentration
Cone Unit label
Stage # 2
Description
Objective Top Depth (ftKB)
Bottom Depth (ftKB)
Full Realm?
Vol Cement...
Top Plug?
Btm Plug?
Cement Plug
P&A 1H-108 mother bore 4,557.0
5,057.0
No
No
No
Q Pump Inft (bbl/m...
Q Pump Final (bbll...
Q Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rDm)
4
4
4
352.0
Yes
30.00
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
Comment
Begin 2nd cement plug pumping 26 BBLS 12.5 PPG mud push If. @ 3 BPM with ICP 222 PSI DPP, FCP - 50 PSI DPP. 10% F/O. Close bag and batch up
cement. Open bag pump 50 BBLS of 15.8 PPG Class G cement. with ICP 50 PSI DPP. FCP 120 PSI DPP. 14% F/O. Close bag drop foam ball, Open bag and
pump 4 BBLS 12.5 PPG Mud push ii Swap to rig pumps. pump 51 BBLS of LSND @ 7 BPM. ICP = 153 PSI. catch cement @ 260 stks. Reduce rate to 4 BPM
FCP = 374 15% F/O. PUH on elevators from 5206'- 4,610' MD. UP WT = 104K. Circulate staging pumps up to 650 GPM @ICP 1,230 PSI FCP - 600 PSI
DPP. 31% F/O, Reduce rate due to contaminated mud returning to surface at 350 GPM. 352 PSI DPP. 22% F/O, 3,575 STKS pumped.
Cement Fluids E Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Bon (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Abandonment
4,557.0
5,057.0
G
50.2
Cement
Yield (ft'/sack)
Mix H2O Ratio (gal/sa...
Free Water (%)
Density (lb/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
1.16
5.05
15.80
124.00
Additives
Additive
Type
Concentration
Conc Unit label
Page 112 ReportPrinted: 8/1 012 01 8
a Cement Detail Report
11-1-108
String: Cement Plug
Job: DRILLING ORIGINAL, 6/4/2018 00:00
Cement Stages
Stage # 3
Description
Objective Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...
I Top Plug?
Bfm Plug?
Cement Plug
PBA 1H-108 mother bore 3,550.0
4,155.0
No
No
No
O Pump [nit (bbl/m...
O Pump Final (bbl/...
O Pump Avg (bbl/...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
Stroke (ft)
Rotated?
Pipe RPM (rpm)
4
4
4
560.0
Yes
30.00
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill Out Diameter (in)
3,402.0
Tubing
Comment
Begin 3rd cement isolation plug pump 25 BBLS 12.5 PPG Mud push ii. 4 BPM @ 220 PSI, 12% F/O, close bag. Batch up cement. CEMENT WET 1852 HRS.
Pump 70.3 BBLS 15.8 PPG class G cement at 4 BPM, 390 PSI DPP. Close bag drop foam ball, Open bag and pump 5 BBLS of 12.5 PPG Mud push II then
swap to rig pumps pumping 33 BBLS of 9.3 PPG LSND @ 7 BPM, catch cement at 180 STKS ICP = 300 PSI DPP FCP = 750 PSI. PUH from 4,132' MD - 3,400'
MD monitor disp via pit #5, UP WT = 85K. DWN WT = 80K. Break over weight at 119K.
Cement Fluids & Additives
Fluid
Fluid Type
Fluid Description
Estimated Top (ftKB)
Est Btm (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Abandonment
3,550.0
4,155.0
G
70.3
Cement
Yield (ft/sack)
M[t H2O Ratio (gallsa...
Free Water I%)
Density (Ib/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr t (psi)
1.16
5.05
15.80
124.00
Additives
Additive
Type
Concentration
Cone Unit label
Page 212 Report Printed: 811012018
Cement Detail Report
4W
11-1-108
String: KOP
Job: DRILLING ORIGINAL, 6/4/2018 00:00
Cement Details
Description
Cementing Start Date
Cementing End Date
Wellbore Name
1
KOP
6/24/2018 01:15
6/24/2018 02:30
1 H-108
Comment
Cement Stages
Stage # 1
Description
Objective
Top Depth (ftKB)
Bottom Depth (ftKB)
Full Return?
Vol Cement...Top
Plug?
Btm Plug?
KOP
No
0.0
No
No
Q Pump Init (bbilm...
Q Pump Final (bbll...
Q Pump Avg (bbil...
P Pump Final (psi)
P Plug Bump (psi)
Recip?
IStroke (ft)
Rotated?
I Pipe RPM (rpm)
3
3
3
270.0
No
I
No
Tagged Depth (ftKB)
Tag Method
Depth Plug Drilled Out To (ftKB)
Drill out Diameter (in)
8 3/4
Comment
Pump kick off plug.
Pressure test all lines to 3,500 PSI. Pump 25 BBLS of 12.5# at 3.3 BPM 90 PSI DPP, close bag and batch up cement. pump 50 BBLS of
17# class G cement @ 3.3 BPM 70 PSI, Close bag and drop foam wiper ball. Open bag and pump 4 BBLS 12.5# Mud push II, chase with 1 BBL afresh water to
clear surface lines.
Swap to rig pumps and displace with 13 BBLS @ 4 BPM 215 PSI. Catch cement at 8 BBLS into displacement. Cement wet at 0138 hrs.
Cement in plae 0228 hrs.
Cement Fluids & Additives
Fluid
Fluid Type
Fluitl Description
Top (ftKB)
Est Bim (ftKB)
Amount (sacks)
Class
Volume Pumped (bbl)
Kick off plug
IF 'ad
1,784.0
2,284.0
G
50.0
Yield (ft'/sack)
Mix H2O Ratio (gallsa...
Free Water I%)
Density (Ib/gal)
Plastic Viscosity (cP)
Thickening Time (hr)
CmprStr 1 (psi)
1.00
3.90
1
17.00
Additives
Additive
Type
Concentration
Conc Unit label
Page 1/1 ReportPrinted: 917/2018
2 180 67
29533
cnlumnerger Transmittal#: 18JUL18-SP01
Drilling & Measurements
Product Delivery
Customer: ConocoPhillips Alaska, Inc. Dispatched To: AOGCC: Natural Resources Tech
Well Name: 1H-108
Date Dispatched: 18 -Jul -18
Service Order #: 18AKA0012 Dispatched By: Stephanie Pacillo
Product
Description
Hardcopy
Digital Copy
Logging Date
Color Log Prints:
N/A
Contents on CD
22 -Jun -18
VISION Service
2" MD
x
5" MD
x
2" TVD
x
5" TVD
ECtI
ED
JUL 1 8 2
8
AOGC
Digital Data
NIA
Contents on CD
LAS/DLIS Data
x
Surveys
N/A
Contents on CD
Directional Survey Nad27
x
Directional Survey Nad83
x
Gyrodata Survey
x
CD
1
Contents on CD
Data: DLIS/ LAS
x
Graphics: PDF
x
Surveys: PDF/TXT
x
Please sign and email a copy to: Please sign and email a copy to:
Tom.Osterkam conoco hilli s.com IaskaPTSPrintCenter slb.com
Attn Tom Osterkamp At n. Stephanie Pacillo
C /IjLyp
Received By: %
KQ.0 l 14- IC8
,P� 21(j(367c,
Regg, James B (DOA)
From: Doyon 142 Company Man <dl42cm@conocophillips.com> 7efq 71 (i
Sent: Monday, July 2, 2018 2:10 AM f
To: Shumway, Kelsey; Lehman, Nick R; Alexa, Kurt J; Jones, Jeffery B (DOA); Regg, James B
(DOA)
Subject: 11-1-108
Attachments: Scan0004jpg
Good morning all,
Please find the casing pressure test from 1H-108. A Baker K-1 30 %" cement retainer was set at 1,784' MD / 1,723' ND.
Rig is currently POOH laying down DP in preparation for 3 W L-80 EUE kill string.
Thank you,
Granville Rizek / Rock Rouchenstein
Doyon 142 Drilling Supervisors
Office 907-670-6001
Doghouse 907-670-6012
1
�Z(A 114- -1 OC
P'Tb 2l6067o
Ca &I .— 7/7-/j 8
��ycti� (4z
Loepp, Victoria T (DOA)
From:
Sent:
To:
Cc:
Subject:
Follow Up Flag:
Flag Status:
Mel,
ATD ;?/8-626,7-
Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Wednesday, June 27, 2018 5:31 PM
Rixse, Melvin G (DOA)
Loepp, Victoria T (DOA); Davies, Stephen F (DOA); Regg, James B (DOA); Fair, Holly S
(DNR); Schwartz, Guy L (DOA)
RE: (EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Follow up
Flagged
As discussed, we would like to utilize 15.7ppg AS1 cement slurry for the top abandonment plug as well as for the kickoff
plug on 1H -108A instead of using Class G due to the colder temperatures we have at these shallow depths. We have
successfully used this in the past for P&A as well as for kickoff plugs at shallow depths. Please let me know if you have
any other questions or concerns.
Thanks for your time,
Nick Lehman
Drilling Engineer I Conoco Phillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick.R.Lehman@ConocoPhillios.com
From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Sent: Friday, June 22, 2018 3:45 PM
To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Regg,
James B (DOA) <jim.regg@alaska.gov>; Fair, Holly S (DNR) <holly.fair@alaska.gov>; Schwartz, Guy L (DOA)
<guy.schwa rtz @a laska.gov>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Nick,
AOGCC grants verbal approval for the planned lateral 1H -108A as in the attached document with the following
additional requirements:
1. Bi -weekly BOPE test to 3500 psi
2. The final uppermost kick off plug must extend a minimum of 100' below the 10-3/4" casing shoe
A completed PTD will be provided to CPA[ early next week when business hours allow final processing.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.Rov).
cc. Steve Davies, Victoria Leopp, Jim Begg, Holly Fair, Guy Schwartz
From: Lehman, Nick R [mailto:Nick. R.Leh man@conocophillips.comj
Sent: Friday, June 22, 201812:21 PM
To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Mel,
Attached is signed PTD for 1H -108A. I am currently printing out extra copies and will deliver the original & 1 x copy to
AOGCC office here shortly.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 ( Cell (832)499-6739
Nick.R.Lehman@ConocoPhillips.com
From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Sent: Thursday, June 21, 2018 3:05 PM
To: Lehman, Nick R <Nick.R.Leh man@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaskg goy>; Regg, James B (DOA) <lim.regg@alaska.gov>; Schwartz, Guy L
(DOA) <guv.schwa rtz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Doyon 142 Company Man
<d142cm@conocophiIlips. com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>; Seamount, Dan T (DOA)
<dan.seamount@alaska.gov>; French, Hollis (DOA) <hollis.french@alaska.gov>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Nick,
You have approval to proceed with the cement abandonment, as described in your attached scanned sundry request
for 1H-108 PB1. AOGCC will expect to see your original sundry request later today. I will review your revised 10-401 for
the alternate sidetrack after you deliver it tomorrow.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.RixseCdalaska.zov).
cc. Victoria, Jim Regg, Guy Schwartz, Steve Davies, Dan Seamount, Hollis French
From: Lehman, Nick R [mailto: Nick. R. Lehman@conocophillips.com]
Sent: Thursday, June 21, 2018 2:35 PM
To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <iim.regg@alaska.gov>; Schwartz, Guy L
(DOA) <guv.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Doyon 142 Company Man
<d142cm@conocophillips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Melvin,
Thanks for your feedback. Attached is finalized sundry request, the application will be submitted here shortly. Currently,
we are backreaming OOH at -4300' MD. I'm expecting we'll be out of hole ready to start running in hole sometime late
tonight. We are currently working the directional plan for the sidetrack- as soon as I have that finalized, I will submit
the 10-401 for 1H -108A sidetrack.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
NickR.Lehman(@ConocoPhillips.com
From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Sent: Thursday, lune 21, 2018 12:20 PM
To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <lim regg alaska.gov>; Schwartz, Guy L
(DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Nick,
As discussed on the phone, AOGCC will need the following:
1) Revised 10-401 if bottom hole location for new lateral is > 500' from the planned wellbore
2) 10-403 for the cement plug back of P81
3) 24 hour notice to AOGCC for an inspector to witness of tag of cement plug at 3550' MD.
The cement plug back drawing you submitted below shows adequate cementing for abandonment of the PB1 lateral. I
would expect an approval for the 10-403 you will be submitting soon.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.RixsePalaska.zovI.
cc. Victoria Loepp, Jim Regg, Guy Schwartz, Steve Davies
From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.com]
Sent: Thursday, June 21, 2018 10:26 AM
To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Cc: Brunswick, Scott A <Scott A Brunswick@conocophillips.com>
Subject: FW: 1H-108 Plugback and Sidetrack Proposal
Melvin,
Based on Victoria's out -of -office reply, you are her point of contact until July 9th. Please see email below, I will give you
a call shortly to discuss.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman@ConocoPhillips. cam
From: Lehman, Nick R
Sent: Thursday, June 21, 2018 10:23 AM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov>
Cc:'Scott Brunswick' <Scott.A.Brunswick@conocophillips.com>
Subject: 1H-108 Plugback and Sidetrack Proposal
Victoria,
Early this morning while drilling the 1H-108 WestSak injector, we encountered water in the WestSak sands. Based on
what we've seen, we would like to plugback and sidetrack below surface casing to help with planning path forward for
next producer. Below is a proposed schematic for cement plug depths with as -drilled formation tops listed to the side. I
am working on the 10-403 sundry form, but I would like to discuss this with you when you have a minute. I will give you
a call shortly.
3.75' &-
1H-108 Abandonment / Sidetrack Plan
38 bbfs / 500' kickoff plug
1784 ft 50' above shoe
1834 ft Previous shoe
2284 ft 450' below shoe
3550 ft 250' TVD above Ugnu
38 bbfs / 500'
abandonment plug 4155 ft Top of Ugnu - hydrocarbons
OEM
4557 ft 250'TVD above N -sand
38 bbfs / 500'
abandonment pl
38 bbfs / Soo,
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman @ConocoPhillips. com
5208 ft Top of N -Sand -
5735 ft
Top of WestSak D - wet
5845' ft
Portion of WestSak D - h
5926 ft
Top of WestSak B - wet
6023 ft
Top of WestSak A4 - wet
6134 ft
Top of WestSak A3 - wet
6359 ft
Top of WestSak A2 - hyd.
6527 ft TD
5
THE STATE
°fALASKA
11.
GOVERNOR BILL WALKER
Chip Alvord
Alaska Drilling Manager
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, West Sak Oil Pool, KRU 1H-108
Permit to Drill Number: 218-067
Sundry Number: 318-261
Dear Mr. Alvord:
Alaska Oil and Gas
Conservation Commission
333 west Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.00gcc.alaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Hollis S. French
Chair
AL
DATED this ZI day of June, 2018.
RBDMS�` JUN 2 7 2018
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
9n AAr. 9S 9Rn
RECEIVED
JUN 21 2018
®TS &/i//e
Ao ,r.
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑
2. Operator Name:
4. Current Well Class:
5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.
Exploratory ❑ Development ❑
Stratigraphic ❑ Service
218-067
3. Address:
6. API Number:
P.O. Box 100360 Anchorage, AK 99510-0360
(
50-029-23608-00-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
KRU IH -108
Will planned perforations require a spacing exception? Yes ❑ No Q
9. Property Designation (Lease Number):
10. Field/Pool(s):
ADL025639
Kupawk River Field /West Salk Oil Pool '
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD:
MPSP (psi):
Plugs (MD): Junk (MD):
6527' 4217'
Casing Length Size MD
TVD
Burst Collapse
Structural
Conductor 80 20" 119
119
Surface 1795 10-3/4" 1834
1767
5210 psi 2470 psi
Intermediate
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
Packers and SSSV Type:
Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Strati ra hic
g p ❑ Development Service L✓�
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 6/22/2018
t� ❑ f
OIL E]WINJ ❑ /7_s' WDSPL Suspended
GAS ❑ WAG %��,pi�l/i2 y GSTOR ❑ SPLUG ❑(,
16. Verbal Approval: Date:
Commission Representative: Z� S✓�-208
GINJ ❑ Op Shutdown ❑ Abandoned
r 5.
❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval. .�s�'/ r
/6'�
Authorized Name: Chip Alvord Contact Name: Nick Lehman y7fNrt
Authorized Title: Alaska illing Ma er Contact Email: nick.r.lehman Conoco hilli S.com
{1 L / Contact Phone: 907-263-4951
V 9 Q
Authorized Signature: e; I
COMMISSI N USt ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r
{✓` _ �U I
BOP Test ❑ Mechanical Integrity Test ❑
Plug Integrity �rj
Clearance) ❑
t c
-Are
Other: !r �'f ROarr N. O't-. CK— +. XaCrOX -ee iv ,�h.t•35
p lwq ® '3--75-0 'kb
Post Initial Injection MIT Req'd? Yes ❑ No ❑
Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required:
APPROVED BY '
1ln
Z�
Approved by: COMMISSIONER THE COMMISSION Date: blip,
�� r►lariz►-s,,,o-ig RBDMS� JUN 2 /� W ds-ig
■/�1 1U� ///��� f Submd Form and
Form 10-403 Revised 412017 Approved aprfiritp� i��yl � rr tta from the date of approval.
"A-91 , ` v H Attachments in Duplicate
1$
UM
Application for Sundry to PlugBack, Well 1H-108
Saved: 21 -Jun -18
June 21, 2018
Alaska Oil and Gas Conservation Commission
333 West Th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Sundry to PlugBack Well IH -108, a West Sak Sand Injector
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to plugback 1H-108, an onshore grassroots injector well
from the 1 H pad, with the intent of using the existing surface casing and wellhead to set a kick off plug for sidetrack
operations. Future drilling operations will be for 1H -108A injector. The expected operational date for plugback is June
22nd, 2018. It is planned to use rig Doyon 142.
The sidetracking procedures will be covered in a separate Application for a Permit to Drill 1 H-1 08A.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
1. Form 10-403.
2. Proposed abandonment program.
3. IH -108 Post Plugback Schematic.
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20
ACC 25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Nick Lehman at 907-263-4951
(nick.r.lehman@cop.com) or Chip Alvord at 265-6120.
Sincerely
Nick Lehman
Drilling Engineer
Doyon 142 1H-108 Plugback Procedure
The proposed scope of work for this sundry application is included below.
1. Doyon 142 is currently rigged upon 11-1-108. Finish pulling out of hole and laying down 8-3/4" BHA.
2. RIH with 3.5" cement stinger on 4-1/2" drill pipe to pump cement to isolate hydrocarbon bearing
zones.
3. Pump 3 balanced 15.8 ppg cement plugs, 1 to isolate 250' TVD above the Ugnu sand and 2 to isolate ✓
the WestSak sands with top of plug 250' TVD above the N -sand, using gelled pill to support upper
plug and lower plug.
4. Circulate clean and wait on cement based on results from UCA.
5. RIH and tag top abandonment cement plug. Notify AOGCC inspector 24 hours prior to witness tag.
6. Pull OOH to shoe and pump 17.0 ppg kickoff cement plug +/- 50' inside surface casing for sidetrack
(IH -108A).
7. Pull out of hole and lay down 3.5" cement stinger.
8. Pick up 8-3/4" drilling BHA and TIH to drill the 1H-I08A WestSak slant injector.
9. Tag up on cement plug, polish off cement, and drill cement in casing to within 10' of shoe.
10. Transfer to PTD for 1H -108A.
1 H-108 Post Abandonment Schematic
1H-108 Abandonment / Sidetrack Plan
10 3/4" SURF >
P-50WO'kickq[1834
784 ft
50' above shoe
ft
Previous shoe
8.75" C
2284 ft
450' below shoe
Hi -Vis Spacer
Plug#3 top at3550'MD
3550ft
2SYIVDaboveUgnu
Abandonment plug #3
Plug#3 btm at 4155' MD
4155 ft
Top of Ugnu -hydrocarbons
Hi -Vis Spacer
Plug #2 top at 4557' MD
4557 ft
250' TVD above N -sand
Abandonment plug #2
Plug #2 btm at 5057' MD
5208 ft
Top of N -Sand -hydrocarbons
Plug #1 top at 5057' MD
Abandonment plug#1
Plug #1btm at 5557' MD
5735 ft
Top of WestSak D - wet
Hi-Vispace =
5818'- 5845' ft
Portion of WestSak D - hydrocarbons
5926 ft
Top of WestSak B - wet
6023 ft
Top of WestSak A4- wet
6134 ft
Top of WestSak A3 - wet
6359 ft
Top of WestSak A2- hydrocarbons
6527 ft
TD
Sundry Application
Plug for Re -drill Wells
Work Flow
This process is used to identify wells that are suspended for a very short time prior to being re -
drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a
current status of"Suspended."
Step
Task
Responsible
1
The initial reviewer will check to ensure that the "Plug for Redrill" box
Geologist
in the upper left corner of Form 10-403 is checked. If the "Abandon" or
/
"Suspend" boxes are also checked, cross out that erroneous entry and
V
initial it on both copies of the Form 10-403 (AOGCC's and operator's
copies).
2
If the "Abandon" box is checked in Box 15 (Well Status after proposed
Geologist
work) the initial reviewer will cross out that erroneous entry and initial
then
/
it on both copies of the Form 10-403 (AOGCC's and operator's copies).
l/
Instead, check the "Suspended" box and initial that change.
Drilling
Engineer
The drilling engineers will serve as quality control for steps 1 and 2.
(QC)
3
When the Stat Tech receives a Form 10-403 with a check in the "Plug
Stat Tech
for Redrill" box, they will enter the Typ_Work code "IPBRD" into the
History tab for the well in RBDMS. This code automatically generates
a comment in the well history that states "Intent: Plug for Redrill."
4
When the Stat Tech receives any Form 10-407, they will check the
Stat Tech
History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD).
If present and there is no evidence that a subsequent re -drill has been
COMPLETED, the Stat Tech will assign a status of SUSPENDED to
the well bore in RBDMS no matter what status is listed on the 10-407.
The Stat Tech will also change the status on the 10-407 form to
SUSPENDED, and date and initial this change. If the Stat Tech does
not see the "Intent: Plug for Redrill" comment or code, they will enter
the status listed on the Form 10-407 into RBDMS.
5
When the Form 10-407 for the redrill is received, the Stat Tech will
Stat Tech
change the original well's status from SUSPENDED to ABANDONED.
6
The first week of every January and July, the Stat Tech and one of the
Stat Tech
Geologists will check the "Well by Type Work Outstanding" user query
Geologist
in RBDMS to ensure that all of the Plug for Redrill wells have been
handled properly. At this same time, they will also review the list of
suspended wells for accuracy.
ISE
Schwartz, Guy L (DOA)
From: Rixse, Melvin G (DOA)
Sent: Friday, June 22, 2018 3:45 PM
To: Lehman, Nick R
Cc: Loepp, Victoria T (DOA); Davies, Stephen F (DOA); Regg, James B (DOA); Fair, Holly S
(DNR); Schwartz, Guy L (DOA)
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Attachments: 1H -108A PTD Appllcat o _Signed_6-22-18.pdf
Nick,
AOGCC grants verbal approval for the planned lateral 1H -108A as in the attached document with the following
additional requirements:
1. Bi -weekly BOPE test to 3500 psi
2. The final uppermost kickoff plug must extend a minimum of 100' below the 10-3/4" casing shoe
A completed PTD will be provided to CPAI early next week when business hours allow final processing.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixse(&alaska.govJ.
cc. Steve Davies, Victoria Leopp, Jim Regg, Holly Fair, Guy Schwartz
From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.com]
Sent: Friday, June 22, 201812:21 PM
To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Mel,
Attached is signed PTD for 11-1-108A. I am currently printing out extra copies and will deliver the original & 1 x copy to
AOGCC office here shortly.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick.R.Lehman@ConocoPhillips.com
From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.xov>
Sent: Thursday, June 21, 2018 3:05 PM
To: Lehman, Nick R <Nick. R. Lehman@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@a'-)ska. ov>; Regg, James B (DOA) <]im.regg(@alaska.gov>; Schwartz, Guy L
(DOA) <guy.schwa rtz@aIaska.aov>; Davies, Stephen F (DOA) <steve.davies@alaska.aov>; Doyon 142 Company Man
<d142cm@conocophiIlips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocovniIIips.com>; Sea mount, Dan T (DOA)
<dan.seamount@alaska.gov>; French, Hollis (DOA) <hollis.french@alaska.gov>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Nick,
You have approval to proceed with the cement abandonment, as described in your attached scanned sundry request
for IH -108 PB1. AOGCC will expect to see your original sundry request later today. I will review your revised 10-401 for
the alternate sidetrack after you deliver it tomorrow.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixse(dalaska.gov).
cc. Victoria, Jim Regg, Guy Schwartz, Steve Davies, Dan Seamount, Hollis French
From: Lehman, Nick R fmailto:Nick.R.Lehman@conocophillips.com]
Sent: Thursday, June 21, 2018 2:35 PM
To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.eov>; Regg, James B (DOA) <iim.regg@alaska.gov>; Schwartz, Guy L
(DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>; Doyon 142 Company Man
<d142cm@conocophillips.com>; Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com>
Subject: RE: [EXTERNAL]PTD(218-067) RE: 1H-108 Plugback and Sidetrack Proposal
Melvin,
Thanks for your feedback. Attached is finalized sundry request, the application will be submitted here shortly. Currently,
we are backreaming OOH at 4300' MD. I'm expecting we'll be out of hole ready to start running in hole sometime late
tonight. We are currently working the directional plan for the sidetrack — as soon as I have that finalized, I will submit
the 10-401 for 1H -108A sidetrack.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman @ConocoPhillips. cam
From: Rixse, Melvin G (DOA) <melvin.rixseCr@alaska.gov>
Sent: Thursday, June 21, 201812:20 PM
To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Cc: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>; Regg, James B (DOA) <iim.regg@alaska.gov>; Schwartz, Guy L
(DOA) <guy.schwartz@alaska.gov>; Davies, Stephen F (DOA) <steve.davies@alaska.gov>
Subject: [EXTERNAL]PTD(218-067) RE: IH -108 Plugback and Sidetrack Proposal
Nick,
As discussed on the phone, AOGCC will need the following:
1) Revised 10-401 if bottom hole location for new lateral is > 500' from the planned wellbore
2) 10-403 for the cement plug back of PB1
3) 24 hour notice to AOGCC for an inspector to witness of tag of cement plug at 3550' MD.
The cement plug back drawing you submitted below shows adequate cementing for abandonment of the PB1 lateral. I
would expect an approval for the 10-403 you will be submitting soon.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-223-3605 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),
State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or
disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,
and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.Rixse(&alaska.Rov).
cc. Victoria Loepp, Jim Regg, Guy Schwartz, Steve Davies
From: Lehman, Nick R fmailto:Nick.R.Lehman@conocophillips.com]
Sent: Thursday, lune 21, 2018 10:26 AM
To: Rixse, Melvin G (DOA) <meMn.rixse@alaska.gov>
Cc: Brunswick, Scott A<S Avick@conocophillips.com>
Subject: FW: 11-1-108 Plugback and Sidetrack Proposal
Melvin,
Based on Victoria's out -of -office reply, you are her point of contact until July 9th. Please see email below, I will give you
a call shortly to discuss.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehmon@ConocoPhillips.com
From: Lehman, Nick R
Sent: Thursday, June 21, 2018 10:23 AM
To: Loepp, Victoria T (DOA) <victoria.loeppCa@alaska.gov>
Cc: 'Scott Brunswick' <Scott.A.Brunswick@conocophillips.com>
Subject: 1H-108 Plugback and Sidetrack Proposal
Victoria,
Early this morning while drilling the 111-108 WestSak injector, we encountered water in the WestSak sands. Based on
what we've seen, we would like to plugback and sidetrack below surface casing to help with planning path forward for
next producer. Below is a proposed schematic for cement plug depths with as -drilled formation tops listed to the side. I
am working on the 10-403 sundry form, but I would like to discuss this with you when you have a minute. I will give you
a call shortly.
10 3/4" SURF
11-1-108 Abandonment / Sidetrack Plan
1784 ft 50' above shoe
38 bbls / S00' kickoff plug 1834 ft Previous shoe
8.75" OH > 2284 ft 450' below shoe
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman @ConocoPhillips. com
5926 ft Top of WestSak B - wet
6023 ft Top of WestSak A4 - wet
6134 ft Top of WestSak A3 - wet
6359 ft Top of WestSak A2 - hyd
6527 ft TD
4
3550 ft
250' TVD above Ugnu
38 bbls / 500'
abandonment plug
4155 ft
Top of Ugnu - hydrocarbons
Hi -Vis Spacer
4557 ft
250' TVD above N -sand
38 obis / S00'
abandonment plug
5208 ft
Top of N -Sand - hydrocarbons
38 bbls / 500'
abandonment plu
5735 ft
Top of WestSak D - wet
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman @ConocoPhillips. com
5926 ft Top of WestSak B - wet
6023 ft Top of WestSak A4 - wet
6134 ft Top of WestSak A3 - wet
6359 ft Top of WestSak A2 - hyd
6527 ft TD
4
s FATE OF ALASKA Reviewed By: p
OIL AND GAS CONSERVATION COMMISSION P.I.SuprQ_Lllq't'V
DIVERTER Test Report for: KUPARUK RIV U WSAK IH -108 " Comm
Contractor/Rig No.: Doyon 142 PTD#: 2180670 " DATE: 6/16/2018 - Inspector Guy Cook " Insp Source
Operator: CONOCOPHILLIPS ALASKA, INC. Operator Rep: Ben Tolman Rig Rep: Johnny Newman Inspector
Well Class: DEV Inspection No: divGDCI80616192957
Related Insp No:
MISC. INSPECTIONS:
GAS DETECTORS:
Visual Alarm
Methane: P P
Hydrogen Sulfide: P _.P
Gas Detectors Misc: NA NA _
TEST DATA
MUD SYSTEM:
Visual Alarm
Trip Tank:
P/F
Location Gen.:
P
Housekeeping:
P "..
Warning Sign
P
24 hr Notice:
P
Well Sign:
P
Drlg. Rig.
P
Misc:
NA
GAS DETECTORS:
Visual Alarm
Methane: P P
Hydrogen Sulfide: P _.P
Gas Detectors Misc: NA NA _
TEST DATA
MUD SYSTEM:
Visual Alarm
Trip Tank:
P
P
Mud Pits:
P
P
Flow Monitor:
P
P "
Mud System Misc:
NA
NA
ACCUMULATOR SYSTEM:
Time/Pressure P/F
Systems Pressure: 3050
P
Pressure After Closure: 1950
P
200 psi Recharge Time: 6 -
P
Full Recharge Time: 45
P '
Nitrogen Bottles (Number, of): 6 -
P
Avg. Pressure: 2033 -
P '
Accumulator Misc: 0
NA
DIVERTER SYSTEM:
Size P/F
Designed to Avoid Freeze-up?
P
Remote Operated Diverter?
P
No Threaded Connections?
P
Vent line Below Diverter?
P '
Diverter Size: 21.25
- P '
Hole Size: 13.5
P '
Vent Line(s) Size: 16
P
Vent Line(s) Length: 202
P
Closest Ignition Source: 85
P
Outlet from Rig Substructure: 191
P
Vent Line(s) Anchored:
P '
Turns Targeted / Long Radius:
NA
Divert Valve(s) Full Opening:
P '
Valve(s) Auto & Simultaneous: _
P
Annular Closed Time: 30
P '
Knife Valve Open Time: 7
P
Diverter Misc: 1
FP ✓
Number of Failures: 1 ✓ Test Time: 2
Remarks: The knife valve on the divener did not have fire rated hoses on it. The hoses were replaced with fire rated hoses. This was the only
noncomp lance found during the inspection and is captured under Diverter Misc.
THE STATE
°fALASKA
GOVERNOR BILL WALKER
Chip Alvord
Alaska Drilling Manager
ConocoPhillips Alaska, Inc.
PO Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, West Sak Oil Pool, KRU I H-108
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 218-067
Surface Location: 50' FSL & 770' FEL, Sec. 28, TI 2N, RI OE,
Bottomhole Location: 1675' FNL & 1750' FEL, Sec. 34, T12
Dear Mr. Alvord:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
N
UM
, R10E, UM
Enclosed is the approved application for permit to 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.
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.
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,
Hollis S. French
Chair
DATED this2i day of May, 2018.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
HiLUEIVED
MAY 2 2 2018
1a. Type of Work:
ib. Proposed Well Class: Exploratory -Gas ❑
Service - WAG Q • Service - Disp ❑
1c. Specify if well is proposed for:
Drill Q - Lateral ❑
Stratigraphic Test ❑ Development -Oil ❑
Service- Winj ❑ Single Zone ❑
Coalbed Gas ❑ Gas Hydrates ❑
Redrill ❑ 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:
ConocePhillips Alaska, Inc.
Bond No. 59-52-180 •
KRU 111-108
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 6,839 - TVD: 4,160
Kuparak River Field
West Salk Oil Pool
4a. Location of Well (Governmental Section):
7. Property Designation:
Surface: 50' FSL & 770' FEL, Sec 28, T12N, R10E, UM
ADL025639
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
1360' FNL & 2551 FWL, Sec 34, T1 2N, R10E, UM
80-261
6/4/2018
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property:
1675' FNL & 1750' FEL, Sec 34, TI 2N, R10E, UM
2560 acres
1749' to ADL025638
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 93.0'
.
15. Distance to Nearest Well Open
Surface: x- 549570.98 - y- 5980752.52 - Zone- 4
GL / BF Elevation above MSL (ft): 54.0'
-
to Same Pool: 570' to 1H-103
16. Deviated wells: Kickoff depth: 460 feet
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle. 67.4 degrees
Downhole: 1,782 psi - Surface:
1,384 psi ,
18. Casing Program: Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole Casing Weight Grade Coupling Length
MD TVD MD TVD
(including stage data)
42" 20" 94# H-40 Welded 80'
Surf Surf 119' 119'
Existing, cement to surface
13-1/2" 10-3/4" 45.5# L-80 HYD563 1796'
Surf Surf 1835' 1767'
666 sx 11.0 ppg, 193 sx 12.0 ppg
8-3/4" 7" 26# L-80 HYD563 6800'
Surf Surf 6839' 4160'
414 sx 15.8 ppg Class G
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured):
Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured):
Casing Length Size
Cement Volume
MD TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Hydraulic Fracture planned? Yes❑ No Q
20. Attachments: Property Plat BOP Sketch
V
Drilling Program
V
Time v. Depth Plot
hallow Hazard Analysis
Diverter Sketch
Seabed Report
Drilling Fluitl Program
t 20 AAC 25.050 requirements
�/
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 aVal.
ppr
Contact Name:
Nick Lehman
Authorized Name: Chip Alvord G _ aill
Contact Email: nick os.com
Authorized Title: Alaska Drilli g Manager
Contact Phone: 907-263-4951
Authorized Signature:
Date: 5.1(Q$ (2,p( 6
Commission Use Only
Permit to Drill��Q�
API Number:
Permit Approval
See cover letter for other
Number: OO `-'��
50-
Date: 1q '
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: Z30 P ��S f- ;f-0 ?S6 0 S 1
Samples req'd: Yes ❑ Ni
Mud log req'd: Yes ❑ No Ftr
,1?7 1'7 ✓ 0J- e' D f r h -
i measures: Yes [d iDirectional
i Inclination
svy req'd: Yes ED/ iD
Yes No ff
Z$FO psi q Spacing
exception req'd: Yes ❑
-only svy req'd:
✓
Post initial
injection MIT req'd: YesEl No❑
APPROVED BY
Approved by:
COMMISSIONER THE COMMISSION
Date:
Submit Form and
Foam 10401 Revised 512017 This permit is valid for 24 months from the date of approval per 20 AAC 25.005(g) Attachments in Duplicate
ORIGINALt"�5�3��3.16
Application for Permit to Drill, Well 1 H-108
Saved: 18 -May -18
May 21, 2018
Alaska Oil and Gas Conservation Commission
333 West Th Avenue, Suite 100
Anchorage, Alaska 99501
Re: Application for Permit to Drill Well 111-108, a West Sak Sand Injector
Dear Commissioner:
ConocoPhillips Alaska, Inc. hereby applies for a permit to drill an onshore grassroots injector well from the IH pad. The
expected spud date for this well is June 4s', 2018. It is planned to use rig Doyon 142. .
1H-108 is planned to be a slant well thru the West Sak sands. The surface section will be drilled with 13-1/2" bit and run
10-3/4" casing to ±1,835' MD / 1,767' TVD. The production section will be drilled with 8-3/4" bit and run 7" casing to
±6,839' MD / 4,160' TVD. The upper completion will be run with 3-1/2" tubing.
Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent
information attached to this application includes the following:
1. Form 10401 Application for Permit to Drill per 20 ACC 25.005 (a).
2. Pressure information as required by 20 ACC 25.035 (d) (2).
3. Casing and cementing program.
4. A drilling fluids program summary.
5. A proposed drilling program.
6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b).
7. A proposed completion diagram.
Information pertinent to the application that is presently on file at the AOGCC:
1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20
ACC 25.035 (a) and (b).
2. A description of the drilling fluids handling system.
3. Diagram of riser set up.
If you have any questions or require further information, please contact Nick Lehman at 907-263-4951
(nick.r.lehman@cop.com) or Chip Alvord at 265-6120.
Sincerely,
Chip Alvord
Drilling Manager
Application for Permit to Drill Document
Kuparuk Well IH -108
Well Name
Requirements of 20 AAC 25.005 (fl
The well for which this application is submitted will be designated as KRU 1H-108
Drilling
&wells
Conxo!'hillips
Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the follmring items, except for an item already on file with the commission and
identified in the application:
(2) a plat identify ing the property and the property's owners and shaming
(A) the coordinates of the proposed location of the well at the surface. at top of each objective fornmtion, and at total depth. referenced to
governmental section lines.
(B) the coordinates of the proposed location of the well at the snrf ice, referenced to the state plane coordinate slstenh for this stale as maintained by the
National Geodetic Surrey in the National Oceanic and Atmospheric Admimslrationr
(C) the proposed depth of the well at the top of each objective.formation and at total depth;
Location at Surface 50' FSL & 770' FEL, Sec 28, T12N, R10E, UM
NGS CoordinatesRKB
Northings: 5,980752.52' Eastings: 549,570.98
Elevation
93.0' AMSL
Pad Elevation
54.0'AMSL
Location at Top of 1360' FNL & 2551 FWL, Sec 34, T12N, R10E, UM
Productive Interval
est Sak D Sand
NGS Coordinates Measured De th, RKB: 5,721'
Northings: 5,979,366.16' Eastings: 552,904.32' Total Vertical Depth, RK& 3,723'
Total Vertical De th, SS: 3,630'
Location at Total Depth 1675' FNL & 1750' FEL, Sec 34, T12N, R10E, UM
NGS Coordinates
Northings: 5,979,058.25' Eastings: 553,886.56'
Measured De th, MB: 6,839'
Total Vertical De th, R" 4,160'
Total Vertical De th, SS: 4,067'
and
(D) other information t'egntred by 20 AAC 25.050(6):
Requirements of 20 AAC 25.050(6]
If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) ,must
(1) include a plat, drmmnt to a suitable scale, shmving t e path of the proposed wellbore, including all adjacent wellbm'es within 200 feel of any portion of
the proposed well;
Please see Attachment: Directional Plan
And (2) for -all wells within 200 feet of the proposed wellbore
(A) list the names of the operator's of those wells, to the extent that those names are known or discoverable m public records, and show that each
named operator has been f trnished a cope of the application by certified mail: a,-
(B)
r(B) state that the applicant is the only affected rammer.
The Applicant is the only affected owner.
Blowout Prevention Equipment Information
_Requirements of 20 AAC 25.005(c)(31
An application fm' a Pe) mil to Drill must be accompanied by each of the follmring items, e'cep for an item ah'eady on file a ith the commission and
identified in the application:
(3) a diagram and description of rite blmvout prevention equironent (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036. or 20 AAC 25.037, as
applicable;
Please reference BOP schematics on file for Doyon 142 and attachment.
Drilling Hazards Information
Requirements of 20 AAC 25.005 (c)(4)
An application for a Permit to Drill must be accomponied by each of the following items. except for an item ab'eady on file with the commission and
identified in the application:
(4) information on drilling ha=ards, including
(A) the maximum downhole pressure that may be encountered criteria used to determine it, and maximum potential surface pressure based on a
methane gradient
The maximum potential surface pressure (MPSP) while drilling 1 H-108 is calculated using an estimated
maximum reservoir pressure of 1,782 psi (based on 1H-105 MDT pressure of 1749 psi, 8.6 ppg
equivalent, and corrected to depth), a gas gradient of 0.10 psi/ft, and the estimated depth of the West Sak
A2 sand at 3,984' TVD:
A Sand Estimated. BHP = 1,782 psi
A Sand estimated depth = 3,984' TVD
Gas Gradient — 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A)
Hydrostatic of full gas column = 398 psi (3,984' TVD * 0.10 psi/ft)
MPSP = BHP — gas column =1,384 psi • (1,782 psi — 398 psi)
(B) data on potential gas cones:
The well bore is not expected to penetrate any shallow gas zones.
And (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation cones, and cones that (tare a
propenst0, for differential slicking:
See attached 1H-108 Drilling Hazards Summary
Requirements of 20 AAC 25.005 (c)(51
An application for a Permit to Drill must be accompanied by each of the following loans, except for an hem already on file with the commission and
identified in the application:
(5) a description of die procedure for conducting formation Mtegrity tests, as required under 20 AAC 25.03069:
A procedure is on file with the commission for performing LOT'S.
Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(61
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file a ith the commission and
identified in the application:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of arty slotted liner. pre -perforated liner, at
screen to be installed
Casing and Cement Program
Casing and ementing Program
Cs91Tbg OD
Hole
Weight
Length
Top MD/TVD
Bim MD/TVD
(in)
sine
ab/ft)
Grade
Conn
(ft)
(fi)
(ft)
Cement Program
20
42
94
H-40
Welded
80
Surf
119/119
Existing
Cement to Surface with
10-3/4
13-1/2
45.5
L-80
HYD563
1,796
Surf
1,835 /1,767
666 sx LiteCRETE Lead 11.0 ppg
193 sx LiteCRETE Tail 12.0ppg
7
8-3/4
26
L-80
HYD563 /
6,800
Surf
6,839 / 4,160
414 sx Class G at 15.8 ppg
7XP
.'TOC at 4,602' MD
10-3/4" Surface casing run to 1,835' MD / 1,767' TVD
Cement from 1,835' MD to 1,335' (500' of tail) with 12.0 ppg LiteCRETE, and from 1,335' to surface with 11.0 ppg
LiteCRETE. Assume 150% excess annular volume for lead and 50% excess for tail, and 0% excess in 20" conductor.
10-3/4" SURFACE CEMENT CALCS
Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of N Sand
Design: 500' of Tail Cmt @ 50% excess in OH & Lead Cmt to surface @ 150% excess in OH
Tail Cement yield =
r 1.65 ft^3/sk Lead Cement yield =r
1.91 ft^3/sk
4602' MD
11.0 ppg LiteCRETE Lead Slurry
120'x 0.0383 bbl/ft x 1.0 (0% excess)
CONDUCTOR =
119'x 0.2477 bbl/ft x 1.0 (0.5 excess)
29.5
bbls
Btm of Lead to CON D =
(1335'- 119') x 0.0648 bbl/ft x 2.5(150% excess)
196.9
bbls
Total Lead Cement=
226.4bbls
I or
1271.2ftA3
or
666sks
(6839'- 120') x 0.0383 bbl/ft =1
257.1 bbls
12.0 ppg LiteCRETE Tail Slurry
Shoetrack =
500'x 0.0962 bbl/ft x 1.0 (0% excess)
8.2 bbls
Shoe to Top of Tail =
(1835'- 1335') x 0.0648 bbl/ft x 1.5 (505/6 excess)
48.6 bbls
Total Tail Cement =
56.8 bbls I or 1318.7 ftA3 I or 1193 sks
Displacement =
(1835'- 85') x 0.0962 bbl/ft =
168.3 bbls
7" Production casing run to 6,839' MD / 4,160' TVD
Single stage slurry is designed to be placed from TO to 4,602' MD, which is 250' TVD above top of West Sak Pool
(base of Ugnu); 35% excess annular volume. --
7" Production Cement Calculations
Design: UniSLURRY Class G 15.8 ppg Cement to 250' TVD above Top of N Sand
Cement yield =
1.16
ft^3/sk
Planned TOC=
4602' MD
Shoe Track
120'x 0.0383 bbl/ft x 1.0 (0% excess)
4.6
bbls
Shoe to Top of Cement=
(6839'-4602')x 0.0268 bbl/ftx 1.35 (35% excess)
80.9bbls
Total Cement Volume =
85.5 bbls
or
479.8ft^3 I
or
414 sks
Displacement = 1
(6839'- 120') x 0.0383 bbl/ft =1
257.1 bbls
Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
Ars application for a Permit to Drill must be accompanied by each of the following uenu, ercepl for an item already on file vah fire commission and
identified in the application:
(7) a diagram and description of the direrier system as required by 20 AAC 25.035, unless this requirement is maired by the commission :miler 20 AAC
25.035(h)(2):
Please reference diverter schematic attached.
Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each of the following items, except for arc item already ori file ii ah the commission and
idem fed in the application:
(8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033;
Mud Program Summary
Diagram of Doyon 142 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (0(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application fm -a Permit to Drill must be accompanied by each ofthe following items. except for an net,, already on file with the commission and
identified in the application:
Surface
13-1/2" Hole
10-3/4" Casing
Production
8-3/4" Hole
7" Casing
Mud System
Spud
WBM
LSND
WBM
Density
8.8-9.5
9.0-10.0
PV
ALAP
ALAP
YP
30-80
20-30
Funnel Viscosity
250-300
Permafrost Base
100-150 to TD
N/A
Initial Gel
30-50
9-11
10 -minute Gel
30-50
<20
API Filtrate
NC
< 6
HTHP Fluid Loss at 160° F
N/A
< 10
H
10.8-11.2
9.5-10.0
Diagram of Doyon 142 Mud System is on file with AOGCC.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
N/A - Application is not for an exploratory or stratigraphic test well.
Seismic Analysis
Requirements of 20 AAC 25.005 (c)(10)
N/A - Application is not for an exploratory or stratigraphic test well.
Seabed Condition Analysis
Requirements of 20 AAC 25.005 (0(11)
N/A - Application is not for an offshore well.
Evidence of Bonding
Requirements of 20 AAC 25.005 (c)(12)
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application fm -a Permit to Drill must be accompanied by each ofthe following items. except for an net,, already on file with the commission and
identified in the application:
The proposed drilling program is included below. Please refer to attachment for proposed well schematic.
1. Move in / rig up Doyon Rig 142. Install Annular with 16" diverter line and function test. Notify AOGCC 24 hrs
before test.
2. Spud and directionally drill 13.5" hole to surface TO at +/- 1,835' MD / 1,767' TVD as per directional plan. Run
MWD tools and required for directional monitoring (gamma ray).
3. Run and cement 10.75", 45.5#, 1-80, HYD563 casing to surface. Displace cement with mud and check floats
upon bumping plug. Notify AOGCC if top job is required.
4. Remove diverter system and install wellhead. Install and test 13-5/8" x 5,000 psi BOP'S to 250 psi low and 3,500
psi high (annular preventer to 3,500 psi). Notify AOGCC 24 hrs before test.
5. PU 8.75" bit and 6.75" drilling assembly, with MWD/LWD (gamma ray, resistivity, and density). RIH, clean out
cement to top of float equipment and test casing to 3,000 psi for 30 min.
6. Drill out cement and between 20' of new hole. Perform leak off test to a minimum of 11.5ppg EMW LOT/FIT,
recording results.
7. Displace to 9.0 - 9.2 ppg LSND water-based drilling fluid.
S. Directionally drill to production TD at 6,839' MD / 4,160' TVD.
9. Circulate hole clean. POOH.
10. Run 7", 26#, L80, HYD563/TXP casing to surface. (Top of cement to be 4,602' MD / 3,292' TVD which
corresponds to 250' TVD above top of the West Sak Pool.)
11. Install 7" packoff and test to 3,500 psi.
12. Flush 10.75" x 7" annulus with water, followed by isotherm.
13. Pressure test production casing to 3,500 psi (48.35% of published burst rating) for 30 min. o b vV a C
14. Run CBL on wireline. /.Z C V l -e' W re S o f C /3 L J
15. RIH with TCPs and perforate zones.
16. Close annular and reverse circulate perforations (circulate out gas from perf guns any potential hydrocarbons).
17. Make clean out run if needed.
18. Run 3.5" upper completions with packers and gauges.
19. Land hanger, run in lock screws, and test seals to 5,000 psi.
20. Set BPV and test in the direction of flow.
21. Nipple down BOPE, nipple up tree and test. Pull BPV.
22. Freeze protect 3.5" x 7" annulus (if the schedule and equipment availability allows, the Wells Group will freeze
protect the well post rig).
23. Set BPV and move off rig.
Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill must be accompanied by each of the follmving ae,n5,, except for an iter,, ah'eady on file with the commission and
identified in the application:
(14) a general description ofhow the operator plans to dispose of drilling mud and cuttings and a statement ofu hether the operator intends to
request authori_ation under 20 AAC 25.080 for an annular disposal operation in the ,,'ell.;
Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class Il disposal well
(DS IB CRI) or Prudhoe DS -4. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for
temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous
substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit
from the State of Alaska.
Attachments:
Attachment 1 AOR
Attachment 2 Directional Plan
Attachment 3 Drilline Hazards Summary
Attachment 4 Well Schematic
Attachment 5 Diverter Layout Dia¢ram
Attachment 6 BOP Confieuration
Attachment 1 AOR
An Area of Review plot is shown below of the 1 H-108 planned wellpath and offset wells. The included table identifies any of
the offset wellbores within (or approximate to) the '/e -mile review.
1
EMU1
I
W.
�Sk.�I
\
ME
Iq•
i
Well
Top of West
TOC
TOC
Reservoir
Cementmarry ns
Name
Status
SakD Sand
(�/TVD)
Determined
Stilus
Zonal lsolatlor
Summary
(MD/TVD)
By
1 H-108
Proposed
5,721' MD /
4,602 MD /
CBL
Not Yet Drilled
Column of cement to be 250' ,
Well docs not exist yet
Injector
3,723'TVD
3,292' TVD
TVD above pool top.
Producing from OH
Active
5,545' MD /
3,387 MD /
Calculated
Production
Laterals are open hole w/
laterals.
Pumped 850 sks Class G.
1H-101
Producer
3,654' TVD
2,642' TVD
with 30%
from Laterals
liner hung off at intermediate
Cement job went as
washout
Westsak
casing.
planned. Saw good lift i
pressures.
Producing from OH
Active
7,367' MD /
V1,750' MD /
Production
Laterals are open hole w/
laterals.
IH-102
CBL
from Laterals
liner hung off at intermediate
Intermediate casing cement
Producer
3,735' TVD
1,673' TVD
WestSak
casing.
top 5,141' (1926'
vertically) above pool top.
Producing from OH
Active
6,837' MD /
-3,169' MD /
Calculated
Production
Laterals are open hole w/
laterals. Pumped 1,210 sks
1 H-103 •
with 30%
from Laterals
liner hung off at intermediate
Class G. Cement job went
Producer
3,806' TVD
2,583' TVD
washout
WestSak
casing.
as planned. Saw good lift
ressures.
Shut-in
5,301' MD /
Circ cement to
West Sak behind surface
1260 sks Permafrost "C" &
IH-09
Injector
3706' TVD
Surface
surface.
Shut-in
casing cemented to surface
520 sks Class G. Ciro
(Kupamk)
,
cement to surface.
IH-13
Shut-In
5,328' MD /
Surface
Circ cement to
Shut-in
West Sak behind surface
'
1330 sks Permafrost "E" &
500 sks Class G. Cire
producer,
3,728' TVD
surface.
casing cemented to surface.
cement to surface.
Active1170
5,022' MD /
Cite cement to
Producing
West Sae behind surface
sks Permafrost "E" &
1H-15
Producer
3,689' TVD
Surface
surface.
Kuparuk
casing cemented to surface.
470 sks Class G. Cine
cement to surface.
496 sks Class G pumped.
✓
Good returns through job.
�
Active
6,087' /
4294'
Injecting in
Reservoir zone isolated by
i
Saw good lift pressure.
IH-109
Injector
TV
3,715' TVD
D
/2860'TVD
CBL
West Sak
cement placed 1344' (65T
CBL results indicate
TVD) above pool top.
cement through and above
reservoir.
Active
4,972' MD /
Circ cement to
Producing
West Sak behind surface
1190 sks Permafrost "E" &
IH-11
Producer
3 672, TVD
Surface
surface.
Kupamk
casing cemented to surface.
500 sks Class G. Ciro
(Kupamk)
cement to surface
Attachment 1 AOR
An Area of Review plot is shown below of the IH -108 planned wellpath and offset wells. The included tableid tifies any of
the offset wellbores within (or approximate to) the '/a -mile review.
f991, Wyf]3x6
1H-108wp22
we.
nn
Quarter
Mile
View
�Q$
RJ rrxg9
in lOiLt
750
I
, na
a
iH•i
�)
rNgO
99
M
ice'
j
99
C
o
N
�
Z
C-750
Zn
500
x.
_
J
O
-2250
—
---
—
— —
--
-3000--._._----
3
I
0 750\U1500 2250 3000 3750 '500 5250 6000
/ Fastl+) (750 a
34�
Well
Top of West
TOC
TOC
Reservoir
Cement Operations
Name
Status
SakD Sand
(MD/TVD)
Determined
Status
Zonal Isolation
Summary
(MD/TVD)
By
IH-108
Proposed
5,721' MD /
4,602 MD /
CBL
Not Yet Drilled
Column of cement to be 250'
Well does not exist yet
Injector
3,723'TVD
3,292' TVD
TVD above pool top.
Producing from OH
laterals.
Active
5,545' MD /
3,387' MD /
Calculated
30%
Production
Laterals are open hole w/
liner hung off at intermediate
Pumped 850 sks Class G.
IH-101
Producer
3,654' TVD
2,642' TVD
with
washout
from Laterals.
casing.
Cement job went as
planned. Saw good lift
pressures.
Producing from OH
Laterals are open hole w/
laterals.
1H-102
Active
7,367' MD /
1,750' MD /
CBL
Production
liner hung off at intermediate
Intermediate casing cement
Producer
3,735' TVD
1,673' TVD
from Laterals
casing.
top 5,141' (1926'
vertically) above pool top.
Producing from OH
Calculated
Laterals are open hole w/
laterals. Pumped 1,210 sks
1H-103
Active
6,837' MD /
3,69' 1MD /
with 30%
Production
liner hung off at intermediate
Class G. Cementjob went
Producer
3,806' TVD
2,583' TVD
washout
from Laterals.
casing.
as planned. Saw good lift
pressures.
Shut-in
5,301' MD /
Surface
Circ cement to
Shut-in
West Salk behind surface
1260 sks Permafrost "C" &
520 sks Class G. Circ
IH-09
Injector
3 , .LVD
706
surface.
casing cemented to surface
cement to surface.
(Kupmuk)
1330 sks Permafrost "0'&
]H-13
Shut-In
5,328' MD /
Surface
Circ cement to
Shut-in
West Salk behind surface
500 sks Class Circ
.
Producer
3,728' TVD
surface.
casing cemented to surface.
cement to surrff ace.
1H-I5
Active5,022'
Producer
MD /
Surface
Circ cement to
Producing
West Sak behind surface
1170 sks Permafrost "E" &
470 sks Class G. Circ
(Kuparuk)
3,689' TVD
surface.
casing cemented to surface.
cement to surface.
S
0
1 H-1081'4Fp22
Plan Summa
_ 20" x 42"
10-3/4" x 13-1/2" Measured Depth
L
0060
- Plan: 54+39 @ 93.00usft (Doyon 142)
d
N
�
I
I
1
rZ0
�
O
25
L 25--
00
:9 J
J
F
IH 1Ds
0 1H9W 1H-11 Oa
28
39 - 460
'
0
650
1300 1950 2600
3250 3900 4540
'�
460 - 650
tw981 330 30
650 -640
20" x 42"
10-3/4" x 13-1/2" Horizontal Departure
7" x 8-3/4'
"
�� x
840 - Iwo
low - 1220
1Ym 4200
C
o
H-
300
60
1420 - 1610
15
e 55
p2
_ _ _ _
1 H-
_
-
1610 1300
-
164wP ,
1600 and
N.
"r•`
2010 2230
Mad - 2440
70
90
-
2440 2850
-
0 28
2650
2860L
m
Equivalent Magnetic
Distance
2860 - W70
_
3070 - 3290
�
3290 3500
I
3500 - 3940
0
S3940
240
120
43M
0
1000
2000 3000 4000
5000 6000 7000
4390 - 4830
Measured Depth
o
4830 - 5270
5270 5]20
SUAVU PROGRAM
Surface Location
DepN From DepM To
Survey/Ren
Tool
North /Y:
Fest/x.
210 150 1H�103
5720 61W
6160 6600
39.00 800.00
1H-108wp221Pier:
1H-1061 GYDGC-SS
Pad Elevation: 54.00
800.00 1800.00
1H-t18wp22(Plan:
1H-106) MWD
1H-10]wp9 160
6500 7045
800001635.27
iH-100wp22(P1an:
1H-108) MWDaIFR-AK-CPZ-SC
TVD MD Name
1H-102
1835.2) 3335.9
1H-ID6wp221Pion:
1H-108) MWD
118.00 118.00 20'%42'
1635.2) 6639A1
1H-106wp22
tPWl: 1H-108) MWDaIFR-AK-CPZSO
1767.00 1835.27 10-314-x 13-12
Magnetic Model & Date: BGGM2017
01 -Jun -18
4159.75 6839.41 7'x 6-3/4"
Magnetic North is 17.080 East of True North (Magnetic Declination)
Magnetic Dip & Field Strength: 80.93°
57467nT
ec MD Inc
Azi
TVD +N/ -S +E/ -W Dleg
TFace VSecl Target
Annotation
Lithology
Column
1 39.00
0.00
0.00
39.00 0.00 0.00 0.00
0.00 0.00
2 460.00
0.00
0.00
460.00 0.00 0.00 0.00
0.00 0.00
KOP: Start 1.51100' DLS, 120'TF, for 140.03'
3 600.03 2.10
120.00
600.00 -1.28 2.22 1.50
120.00 2.22
Start 2.5-/100' DLS, 0° TF, for 301.8'
4 901.83
9.65
120.00
900.00 -16.71 28.95 2.50
0.00 28.95
Adjust TF to 5°, for 701.59
lmeo
5 1629.20 27.81 123.34 1586.00 -141.47 225.09 2.50 5.00 225.09
Base PFRC
6 1742.25
27.81
123.34
1686.00 -170.46 269.15 0.00
0.00 269.15
va
B0T-3
7 1835.27 31.06 123.34 1767.00 -195.58 307.32 3.50 0.00 307.32
8 1855.27
31.06
123.34
1784.13 -201.25 315.95 0.00
0.00 315.95
9 2510.67
54.00
123.34
2263.89 -443.15 683.60 3.50
0.00 683.60
10 3290.05
54.00
123.34
2722.00 -789.71 1210.34 0.00
0.00 1210.34
1 3901.91
67.38
104.06
3022.99 -996.78 1696.71 3.50
-56.601696.71
12 5609.80
67.38
104.06
3679.81 -1379.83 3226.01 0.00
0.00 3226.01
13 5708.31
67.01
107.78
3718.00 -1404.73 3313.32 3.50
96.89 3313.32
14 5721.11
67.01
107.78
3723.00 -1408.33 3324.54 0.00
0.00 3324.54 1H-108wp22 TOt 051418 RP
15 6389.41
67.01
107.78
3984.00 .1596.19 3910.38 0.00
0.00 3910.38 1 H-108wp22 TO2 001418 RP
K-15
16 6839.41
67.01
107.78
4159.75 -1722.70 4304.85 0.00
0.00 4304.85
UG -C
MvuG B
UG A
esno -
Na
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1
I144
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aW°1S A3
+wl°W�A1
ier cnaiiengmg By signing this I acknowledge that I have been informed of all risks, checked that the data is correct, ensured is, t's
orientation �mpretens and all surrounding wells are assigned to the proper position, and I approve the scan and collision avoidance
plan as set out in the audit pack.) approve it as the basis for the final well plan and wellsite drawings. I also acknowledge that
unless notified otherwise all targets have a l 00 feet lateral tolerance.
repared by heckled by ccepted by Approved by:
B. Temple V. Osara E. Sterk N. Lehman
1H-401
1 H-108Wp22 39.00 To 6839.41 I Spider
Easting (700 usft in)
1H-109
1H-106wp22
No
H-13
116
H-1(
1 H-108wp22
7
Plan View
While drilling production section, stay within 100 feet laterally of plan, unless notified otherwise.
500-
000
0-
20"
20"
x 42"
-500
+
00°
M
10-3/4" x 13-1/2"
0
Z
0
000
51000-
0
0
0
U
h
o '
'
co
-1500
iH-108wp22 T01 051418 P
-2000-
1 H-108wp22 T02 051418 1 7" x 8-3/4"
0 500
1000 1500
2000 2500 3000 3500 4000
West(-)/East(+)
y H'y 08Wp22 Section View
0-
20" x 42" 0
700
Base PFROST
1000
T-3
1400
-c
CL
I
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CD
K-15
9'
-----°000
2
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10-3/4" x 13-1 /2" ,h� O�
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0
2800 `�O o0o UG_A W S -D WS B
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WS � 1
17 WS -A4,,
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-----------------------------------------------------
3500 --- ------------ ------
--------------- - - - -- -----------------------------------------------------
----------------------------------------------------------------------------- - ------ --_ _
-------------------------------------------------------------------------------------------------�'-__�
0 500 1000 1500 2000 2500 3000 3500 4000
Vertical Section at 90.00 0 7" x 8-3/4"
is
Plan Report
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Kuparuk 1H Pad
Plan: 1 H-108
50029xxxxx00
Plan: 1 H-108
Plan: 1 H-108wp22
Standard Proposal Report
15 May, 2018
ConocoPhillips
ConocoPhillips
Database:
OAKEDMP2
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kupawk River Unit
Site:
Kuparuk 1H Pad
Well:
Plan: 1H-108
Wellbore:
Plan: 114-108
Design:
1H-108wp22
( ConocoPhillips
Standard Proposal Report
Local Co-ordinate Reference:
Well Plan: 1H-108
TVD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
MD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: System Datum: Mean Sea Level
Geo Datum: Using Well Reference Point
Map Zone: Using geodetic scale factor
Site Kupamk 1 H Pad
Site Position: Northing: Latitude:
From: Map Easting: Longitude:
Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 °
Well
Plan: 11HA08
Tie On Depth:
39.
Depth From (TVD)
Well Position
+N/S
781.33 usft
Northing:
Latitude:
(usft)
+E/ -W
378.96 usft
Easting:
Longitude:
Position Uncertainty
1H-108wp22(Plan: 1H-108)
0.00 usft
Wellhead Elevation:
Ground Level: 54.00 usft
Wellbore Plan: 1H-108
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
P) (') (nn
BGGM2017 6/1/2018 17.08 80.93 57,467
Design
Audit Notes:
Version:
Vertical Section:
1H-108wp22
Phase:
PLAN
Tie On Depth:
39.
Depth From (TVD)
+N/ -S
+E/ -W
Directi
(usft)
(usft)
(usft)
(I
39.00
0.00
0.00
90.0(
1H-108wp22(Plan: 1H-108)
GVD-GC-SS
Plan Survey Tool Program
Date 5 /1 412 01 8
Depth From
Depth To
(usft)
(usft)
Survey (Wellbore)
Tool Name Remarks
1
39.00
800.00
1H-108wp22(Plan: 1H-108)
GVD-GC-SS
Gyrodata gyro single shots
2
800.00
1,800.00
1 H-1 08wp22 (Plan: 1 H-1 08)
MWD
MWD - Standard
3
800.00
1,835.27
1H-108wp22(Plan: 1H-108)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
4
1,835.27
3,335.27
1H-108wp22(Plan: 1H-108)
MWD
MWD - Standard
5
1,835.27
6,839.41
1 H-108wp22 (Plan: 1 H-108)
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
5%52018 8:12:11AM Page 2 COMPASS 5000.14 Build 85
ConocoPhillips
Database:
OAKEDMP2
Local Coordinate Reference:
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Project:
Kuparuk River Unit
MD Reference:
Site:
Kuparuk 1H Pad
North Reference:
Well:
Plan: 1H-108
Survey Calculation Method:
Wellbore:
Plan: 1H-108
Dogleg
Design:
1H-108wp22
ConocoPhillips
Standard Proposal Report
Well Plan: 1 H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft(Doyon 142)
True
Minimum Curvature
Plan Sections
Measured
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(1
(°)
(usft)
(usft)
(usft)
(°1100usft)
(°1100usft)
(°/t00usft)
(°)
Target
39.00
0.00
0.00
39.00
0.00
0.00
0.00
0.00
0.00
0.00
460.00
0.00
0.00
460.00
0.00
0.00
0.00
0.00
0.00
0.00
600.03
2.10
120.00
600.00
-1.28
2.22
1.50
1.50
0.00
120.00
901.83
9.65
120.00
900.00
-16.71
28.95
2.50
2.50
0.00
0.00
1,629.20
27.81
123.34
1,586.00
-141.47
225.09
2.50
2.50
0.46
5.00
1,742.25
27.81
123.34
1,686.00
-170.46
269.15
0.00
0.00
0.00
0.00
1,835.27
31.06
123.34
1,767.00
-195.58
307.32
3.50
3.50
0.00
0.00
1,855.27
31.06
123.34
1,784.13
-201.25
315.95
0.00
0.00
0.00
0.00
2,510.67
54.00
123.34
2,263.90
443.15
683.60
3.50
3.50
0.00
0.00
3,290.05
54.00
123.34
2,722.00
-769.71
1,210.34
0.00
0.00
0.00
0.00
3,901.91
67.38
104.06
3,022.99
-996.78
1,696.71
3.50
2.19
-3.15
-56.60
5,609.80
67.36
104.06
3,679.81
-1,379.83
3,226.01
0.00
0.00
0.00
0.00
5,708.31
67.01
107.78
3,718.00
-1,404.73
3,313.32
3.50
-0.38
3.77
96.89
5,721.11
67.01
107.78
3,723.00
-1,408.33
3,324.54
0.00
0.00
0.00
0.00
1 H-1 08wp22 T0t 051
6,369.41
67.01
107.78
3,984.00
-1,596.19
3,910.38
0.00
0.00
0.00
0.00
1H-108wp22T02051
6,839.41
67.01
107.78
4,159.75
-1,722.70
4,304.86
0.00
0.00
0.00
0.00
51152018 6: 12: IIAM Page 3 COMPASS 5000.14 Build 85
ConocoPhillips
ConocoPhillips Standard Proposal Report
Database:
OAKEDMP2
Local Co-ordinate Reference:
Well Plan: 1H-108
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
Project:
Kuparuk River Unit
MD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
Site:
Kuparuk 1H Pad
North Reference:
True
Well:
Plan: 11-1-108
Survey Calculation Method:
Minimum Curvature
Wellbore:
Plan: 1H-108
Azimuth
Depth
Design:
1H-108wp22
Section
Rate
Planned Survey
Measured
Vertical
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
+N/ -S
+E/ -W
Section
Rate
Rate
Rate
(usft)
(°)
V)
Waft)
(usft)
(usft)
(usft)
(°1100usft)
(°/100usft)
(°/10ousft)
39.00
0.00
0.00
39.00
0.00
0.00
0.00
0.00
0.00
0.00
100.00
0.00
0.00
100.00
0.00
0.00
0.00
0.00
0.00
0.00
200.00
0.00
0.00
200.00
0.00
0.00
0.00
0.00
0.00
0.00
300.00
0.00
0.00
300.00
0.00
0.00
0.00
0.00
0.00
0.00
400.00
0.00
0.00
400.00
0.00
0.00
0.00
0.00
0.00
0.00
460.00
0.00
0.00
460.00
0.00
0.00
0.00
0.00
0.00
0.00
500.00
0.60
120.00
500.00
-0.10
0.18
0.18
1.50
1.50
0.00
600.00
2.10
120.00
599.97
-1.28
2.22
2.22
1.50
1.50
0.00
600.03
2.10
120.00
600.00
-1.28
2.22
2.22
1.50
1.50
0.00
700.00
4.60
120.00
699.79
-4.20
7.28
7.28
2.50
2.50
0.00
800.00
7.10
120.00
799.26
-9.30
16.11
16.11
2.50
2.50
0.00
900.00
9.60
120.00
898.19
-16.56
28.68
28.68
2.50
2.50
0.00
901.83
9.65
120.00
900.00
-16.71
28.95
28.95
2.50
2.50
0.00
1,000.00
12.09
121.02
996.40
-26.13
44.88
44.88
2.50
2.49
1.04
1,100.00
14.59
121.71
1,093.69
-38.14
64.58
64.58
2.50
2.49
0.69
1,200.00
17.08
122.21
1,189.89
-52.59
87.72
87.72
2.50
2.50
0.49
1,300.00
19.58
122.58
1,284.81
-69.45
114.27
114.27
2.50
2.50
0.37
1,400.00
22.08
122.87
1,378.27
-88.67
144.18
144.18
2.50
2.50
0.29
1,500.00
24.58
123.10
1,470.08
-110.23
177.40
177.40
2.50
2.50
0.23
1,600.00
27.08
123.29
1,560.09
-134.08
213.85
213.85
2.50
2.50
0.19
1,629.20
27.81
123.34
1,566.00
-141.47
225.09
225.09
2.50
2.50
0.17
1,700.00
27.81
123.34
1,648.63
-159.63
252.68
252.68
0.00
0.00
0.00
1,742.25
27.81
123.34
1,686.00
-170.46
269.15
269.15
0.00
0.00
0.00
1,800.00
29.83
123.34
1,736.60
-185.76
292.40
292.40
3.50
3.50
0.00
1,635.27
31.06
123.34
1,767.00
-195.58
307.32
307.32
3.50
3.50
0.00
1,855.27
31.06
123.34
1,784.13
-201.25
315.95
315.95
0.00
0.00
0.00
1,900.00
32.63
123.34
1,822.13
-214.22
335.66
335.66
3.50
3.50
0.00
2,000.00
36.13
123.34
1,904.65
-245.25
$82.82
382.82
3.50
3.50
0.00
2,100.00
39.63
123.34
1,983.58
-278.99
434.10
434.10
3.50
3.50
0.00
2,200.00
43.13
123.34
2,058.60
-315.32
489.32
489.32
3.50
3.50
0.00
2,300.00
46.63
123.34
2,129.45
-354.10
548.25
548.25
3.50
3.50
0.00
2,400.00
50.13
123.34
2,195.87
-395.18
610.69
610.69
3.50
3.50
0.00
2,500.00
53.63
123.34
2,257.59
-438.41
676.40
676.40
3.50
3.50
0.00
2,510.67
54.00
123.34
2,263.90
-443.15
683.60
683.60
3.50
3.50
0.00
2,600.00
54.00
123.34
2,316.40
-482.87
743.97
743.97
0.00
0.00
0.00
2,700.00
54.00
123.34
2,375.18
-527.33
811.55
811.55
0.00
0.00
0.00
2,800.00
54.00
123.34
2,433.96
-571.80
879.14
879.14
0.00
0.00
0.00
2,900.00
54.00
123.34
2,492.74
-616.27
946.72
946.72
0.00
0.00
0.00
3,000.00
54.00
123.34
2,551.51
-660.74
1,014.31
1,014.31
0.00
0.00
0.00
3,100.00
54.00
123.34
2,610.29
-705.20
1,081.89
1,081.89
0.00
0.00
0.00
3,200.00
54.00
123.34
2,669.07
-749.67
1,149.48
1,149.48
0.00
0.00
0.00
3,290.05
54.00
123.34
2,722.00
-789.71
1,210.34
1,210.34
0.00
0.00
0.00
3,300.00
54.19
122.98
2,727.84
-794.12
1,217.08
1,217.08
3.50
1.93
-3.60
3,400.00
56.18
119.48
2,784.94
-836.65
1,287.28
1,287.28
3.50
1.99
-3.51
3,500.00
58.27
116.13
2,839.08
-875.83
1,361.65
1,361.65
3.50
2.08
-3.35
3,600.00
60.43
112.94
2,890.07
-911.52
1,439.90
1,439.90
3.50
2.17
-3.20
3,700.00
62.67
109.88
2,937.71
-943.58
1,521.75
1,521.75
3.50
2.24
-3.06
3,800.00
64.98
106.94
2,981.83
-971.89
1,606.89
1,606.89
3.50
2.30
-2.94
3,900.00
67.34
104.11
3,022.25
-996.35
1,695.01
1,695.01
3.50
2.36
-2.83
3,901.91
67.38
104.06
3,022.99
-996.78
1,696.71
1,696.71
3.50
2.39
-2.78
4,000.00
67.38
104.06
3,060.71
-1,018.78
1,784.55
1,784.55
0.00
0.00
0.00
4,100.00
67.36
104.06
3,099.17
-1,041.21
1,874.09
1,874.09
0.00
0.00
0.00
4,200.00
67.38
104.06
3,137.63
-1,063.64
1,963.63
1,963.63
0.00
0.00
0.00
4300.00
67.38
104.06
3176.09
-1,086.06
2,053.18
2,053.18
0.00
0.00
0.00
5/15,2018 8: 1211AM Page 4 COMPASS 5000.14 Build 85
t
I
ConocoPhillips
ConocoPhillips Standard Proposal Report
Database:
OAKEDMP2
Local Coordinate Reference:
Well Plan: 11-1-108
Company:
ConocoPhillips (Alaska) Inc. -Kupt
TVD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
Project:
Kuparuk River Unit
MD Reference:
Plan: 54+39 @ 93.00usft (Doyon 142)
Site:
Kuparuk 1H Pad
North Reference:
True
Well:
Plan: 1H-108
Survey Calculation Method:
Minimum Curvature
Wellbore:
Plan: 11-1-108
Depth
Inclination
Design:
1H-108wp22
-N/-S
+E/ -W
Planned Survey
Target Name
Measured
Vertical
Vertical
Dogleg
Build
Turn
Depth
Inclination
Azimuth
Depth
-N/-S
+E/ -W
Section
Rate
Rate
Rate
(usft)
(^)
V)
Longitude
(usft)
(usft)
(usft)
(usft)
(°1100usft)
('/100usft)
('1100usft)
4,400.00
67.38
104.06
3,214.54
-1,108.49
2,142.72
2,142.72
0.00
0.00
0.00
4,500.00
67.38
104.06
3,253.00
-1,130.92
2,232.26
2,232.26
0.00
0.00
0.00
4,600.00
67.38
104.06
5,979,000.00
3,291.46
-1,153.35
2,321.81
2,321.81
0.00
0.00
0.00
4,700.00
67.38
104.06
- Circle (radius 100.00)
3,329.92
-1,175.78
2,411.35
2,411.35
0.00
0.00
0.00
4,800.00
67.38
104.06
3,984.00
3,368.38
-1,198.20
2,500.89
2,500.89
0.00
0.00
0.00
4,900.00
67.38
104.06
3,406.83
-1,220.63
2,590.44
2,590.44
0.00
0.00
0.00
5,000.00
67.38
104.06
3,445.29
-1,243.06
2,679.98
2,679.98
0.00
0.00
0.00
5,100.00
67.38
104.06
3,483.75
-1,265.49
2,769.52
2,769.52
0.00
0.00
0.00
5,200.00
67.38
104.06
3,522.21
-1,267.92
2,859.07
2,859.07
0.00
0.00
0.00
5,300.00
67.38
104.06
3,560.67
-1,310.34
2,948.61
2,948.61
0.00
0.00
0.00
5,400.00
67.38
104.06
3,599.12
-1,332.77
3,038.15
3,038.15
0.00
0.00
0.00
5,500.00
67.38
104.06
3,637.58
-1,355.20
3,127.70
3,127.70
0.00
0.00
0.00
5,600.00
67.38
104.06
3,676.04
-1,377.63
3,217.24
3,217.24
0.00
0.00
0.00
5,609.80
67.38
104.06
3,679.81
-1,379.83
3,226.01
3,226.01
0.00
0.00
0.00
5,700.00
67.04
107.47
3,714.76
-1,402.41
3,306.03
3,306.03
3.50
-0.38
3.77
5,708.31
67.01
107.78
3,718.00
-1,404.73
3,313.32
3,313.32
3.50
-0.34
3.78
5,721.11
67.01
107.78
3,723.00
-1,408.33
3,324.54
3,324.54
0.00
0.00
0.00
5,800.00
67.01
107.78
3,753.81
-1,430.50
3,393.70
3,393.70
0.00
0.00
0.00
5,900.00
67.01
107.78
3,792.86
-1,458.61
3,481.36
3,481.36
0.00
0.00
0.00
6,000.00
67.01
107.78
3,831.92
-1,486.73
3,569.02
3,569.02
0.00
0.00
0.00
6,100.00
67.01
107.78
3,870.97
-1,514.84
3,656.68
3,656.68
0.00
0.00
0.00
6,200.00
67.01
107.78
3,910.03
-1,542.95
3,744.34
3,744.34
0.00
0.00
0.00
6,300.00
67.01
107.78
3,949.08
-1,571.06
3,832.00
3,832.00
0.00
0.00
0.00
6,389.41
67.01
107.78
3,964.00
-1,596.19
3,910.38
3,910.38
0.00
0.00
0.00
6,400.00
67.01
107.78
3,988.14
-1,599.17
3,919.66
3,919.66
0.00
0.00
0.00
6,500.00
67.01
107.78
4,027.19
-1,627.28
4,007.33
4,007.33
0.00
0.00
0.00
5,600.00
67.01
107.78
4,065.25
-1,655.40
4,094.99
4,094.99
0.00
0.00
0.00
6,700.00
67.01
107.78
4,105.30
-1,683.51
4,182.65
4,182.65
0.00
0.00
0.00
6,800.00
67.01
107.78
4,144.35
-1,711.62
4,270.31
4,270.31
0.00
0.00
0.00
6,839.41
67.01
107.78
4,159.75
-1,722.70
4,304.86
4,304.86
0.00
0.00
0.00
Design Targets
Target Name
-hit/miss target Dip Angle
Dip Dir.
TVD
+N/ -S
+E/ -W
Northing
Easting
-Shape (')
(°)
(usft)
(usft)
(usft)
(usft)
(usft)
Latitude
Longitude
1H-108wp22 T01 05141 0.00
0.00
3,723.00
-1,408.33
3,324.54
5,979,118.00
1,692,936.00
70° 21' 14.610 N
149' 34'24.630 W
- plan hits target center
- Circle (radius 100.00)
1 H-111 A3 072914 DL 0.00
0.00
3,907.00
-1,529.76
3,845.81
5,979,000.00
1,693,458.00
70° 21' 13.413 N
149° 34'9.394 W'
- plan misses target center by 58.42usft
at 6284.06usft MD
(3942.86 TVD, -1566.58 N,
3818.03 E)
- Circle (radius 100.00)
1 H-108wp22 T02 05141 0.00
0.00
3,984.00
-1,596.19
3,910.36
5,978,934.00
1,693,523.00
70° 21' 12.760 N
149° 34'7.508 W
- plan hits target center
- Circle (radius 100.00)
5/15/2018 812a1AM Page 5 COMPASS 5000.14 Build 85
ConocoPhillips
Database:
OAKEDMP2
Local Coordinate Reference:
Company:
ConocoPhillips (Alaska) Inc. -Kupl
TVD Reference:
Project:
Kuparuk River Unit
MD Reference:
Site:
Kuparuk 1H Pad
North Reference:
Well:
Plan: 1H-108
Survey Calculation Method:
Wellbore:
Plan: 1H-108
118.00 20"x42"
Design:
1H-108wp22
1,835.27
ConocoPhillips
Standard Proposal Report
Well Plan: 1H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft (Doyon 142)
True
Minimum Curvature
Casing Points
Local Coordinates
Depth
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
usft) Name
KOP: Start 1.5°/100' DI -S, 120' TF, for 140.03'
600.00
118.00
118.00 20"x42"
20
42
1,835.27
1,767.00 10-3/4" x 13-1/2"
10-3/4
13-1/2
6,839.41
4,159.75 7" x 8-3/4"
7
8-3/4
Formations
258.84
Start 3.5°/100' DLS, 0° TF, for 766.83'
2,247.22
Measured
Vertical
Hold for 819.65'
Dip
Depth
Depth
Dip
Direction
(usft)
(usft) Name
Lithology (%
(%
1,665.72
1,636.00 Base PFROST
Start 3.5°/100' DLS, -90.73" TF, for 396.98'
3,943.69
1,884.45
1,809.00 T-3
Hold for 758.52'
2,178.75
2,043.00 K-15
TD: 7044.7' MD, 4185' TVD
3,979.95
3,053.00 UG -C
4,669.01
3,318.00 UG_B
4,942.03
3,423.00 UG_A
5,254.06
3,543.00 Na
5,721.11
3,723.00 WS_D
5,849.14
3,773.00 WS_C
5,915.71
3,799.OD WS -13
6,020.69
3,840.00 WS -A4
6,135.92
3,885.00 WS -A3
6,389.41
3,984.00 WS -A2
6,694.11
4,103.00 WS -Al
[Plan Annotations
Measured
Depth
(usft)
460.00
600.03
901.83
1,603.42
1,715.81
2,482.64
3,302.29
3,908.60
5,889.20
6,286.18
7,044.64
Vertical
Local Coordinates
Depth
+N/ -S
+FJ -W
(usft)
(usft)
(usft)
Comment
460.00
0.00
0.00
KOP: Start 1.5°/100' DI -S, 120' TF, for 140.03'
600.00
-1.28
2.22
Start 2.5°/100' DLS, 0° TF, for 301.8'
900.00
-16.71
28.95
Adjust TF to 5°, for 701.59'
1,563.13
-134.94
215.15
Hold for 112.39'
1,662.61
-163.68
258.84
Start 3.5°/100' DLS, 0° TF, for 766.83'
2,247.22
-430.76
664.77
Hold for 819.65'
2,729.18
-795.13
1,218.64
Start 3.5°/100' DLS, -53.72" TF, for 606.31'
3,025.56
-998.28
1,702.71
Hold for 1980.6'
3,788.65
-1,455.58
3,471.89
Start 3.5°/100' DLS, -90.73" TF, for 396.98'
3,943.69
-1,567.18
3,819.89
Hold for 758.52'
TD: 7044.7' MD, 4185' TVD
5/15/2018 8:12: 11AM Page 6 COMPASS 5000.14 Build 85
AC Summary
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1H Pad
Plan: 11-1-108
Plan: 11-1-108
50029xxxxx00
1 H-108wp22
ConocoPhillips
Clearance Summary
Anticollision Report
15 May, 2018
Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference)
Reference Design: Kuparuk 1H Pad -Plan: 1H -108 -Plan: 11-1-106-1H.108wp22
Well Coordinates:
Datum Height: Plan: 54+39 @ 93.oausft (Doyon 142)
Scan Range: 0.00 to 6,839.41 usft. Measured Depth.
Scan Radius is 880.04 sft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited
Geodetic Scale Factor Applied
Version: 5000.14 Build: 85
Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Scan Type: 25 00
ConocoPhillips
ConocoPhillips
1,883.54
81.27
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Anticollision Report for Plan: 1H-108 - 1 H-108wp22
1,925.00
1.798
Clearance Factor
Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference)
Major Risk
1H -05 -1H -105-1H-105
1,900.41
Reference Design: Kuparuk 1H Pad -Plan: 1H -108 -Plan: 1H-108-iH-108wp22
1,900.41
36.17
1,950.00
Scan Range: 0.00 to 6,839A1 usft. Measured Depth.
Clearance Factor
Pass -
Major Risk
Scan Radius is 880.04 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited
4,125.66
644.25
4,125.66
Measured Minimum @Measured
Ellipse
@Measured Clearance
Summary Based on
Site Name Depth Distance Depth
Separation
Depth Factor
Minimum Separation Warning
Comparison Well Name - Wellbore Name - Design (usft) (usft) (usft)
(usft)
usft
4,450.00
Kuparuk 1 H Pad
1H -05 -1H -05-1H-05
1,883.54
81.27
1,883.54
36.07
1,925.00
1.798
Clearance Factor
Pass -
Major Risk
1H -05 -1H -105-1H-105
1,900.41
81.27
1,900.41
36.17
1,950.00
1.802
Clearance Factor
Pass -
Major Risk
1H-09-iH-09-iH-09
4,125.66
644.25
4,125.66
528.89
3,725.00
5.585
Centre Distance
Pass -
Major Risk
1H-09-1H-09-iH-09
4,829.30
565.11
4,829.30
513.65
4,450.00
4.392
Clearance Factor
Pass -
Major Risk
1H-101 - 1H-101 - 11-1-101
124.91
150.25
124.91
148.00
125.00
66.901
Centre Distance
Pass -
Major Risk
1H-101-1H-101-iH-101
4,709.48
214.03
4,709.48
116.66
5,125.00
2.198
Clearance Factor
Pass -
Major Risk
11-1-101 - 1H-1011-1 - iH-10111
124.91
150.25
124.91
148.00
125.00
66.901
Centre Distance
Pass -
Major Risk
1H-101-11-1-10111-11-1-1011-1
4,709.48
214.03
4,709.48
116.66
5,125.00
2.198
Clearance Factor
Pass -
Major Risk
1H-101-11-1-10112-11-1-10112
124.91
150.25
124.91
148.00
125.00
66.901
Centre Distance
Pass -
Major Risk
1H -101-1H-101 L2 -1H-101 L2
4,709.48
214.03
4,709.48
116.65
5,125.00
2.198
Clearance Factor
Pass -
Major Risk
1H -101-1H-101 L3 -1H-101 L3
124.91
150.25
124.91
148.00
125.00
66.901
Centre Distance
Pass -
Major Risk
1H -101-1H-101 L3 -1H-101 L3
4,709.48
214.03
4,709.48
116.66
5,125.00
2.198
Clearance Factor
Pass -
Major Risk
1H -101-1H-101 L4 -1H-101 L4
124.91
150.25
124.91
148.00
125.00
66.901
Centre Distance
Pass -
Major Risk
1H -101-1H-101 L4 -1H-101 L4
4,709.48
214.03
4,709.48
116.66
5,125.00
2.198
Clearance Factor
Pass -
Major Risk
1H-102-1H-102-iH-102
100.38
90.14
100.38
87.05
100.00
29.220
Centre Distance
Pass -
Major Risk
1H -102 -1H -102-1H-102
275.37
91.39
275.37
86.50
275.00
18.688
Clearance Factor
Pass -
Major Risk
1H-102-1H-10211-iH-1021.1
100.38
90.14
100.38
87.05
100.00
29.220
Centre Distance
Pass -
Major Risk
1H -102 -1H -1021-1-1H-1021_1
275.37
91.39
275.37
86.50
275.00
18.688
Clearance Factor
Pass -
Major Risk
1H -102 -1H -10212-1H-1021.2
100.38
90.14
100.38
87.05
100.00
29.220
Centre Distance
Pass -
Major Risk
1H -102 -1H -1021-2-1H-1021.2
275.37
91.39
275.37
86.50
275.00
18.688
Clearance Factor
Pass -
Major Risk
1H -102 -1H -1021-3-1H-10213
100.38
90.14
100.38
87.05
100.00
29.220
Centre Distance
Pass -
Major Risk
1H -102 -1H -102L3 -1H-1021.3
275.37
91.39
275.37
86.50
275.00
18.688
Clearance Factor
Pass -
Major Risk
1H -102 -1H -10214-1H-1021-4
100.38
90.14
100.38
87.05
100.00
29.220
Centre Distance
Pass -
Major Risk
1H -102 -1H -102L4 -1H-10214
275.37
91.39
275.37
86.50
275.00
18.688
Clearance Factor
Pass -
Major Risk
1H -103 -1H -103-1H-103
49.97
30.06
49.97
27.30
50.00
10.914
Centre Distance
Pass -
Major Risk
1H -103 -1H -103-1H-103
274.96
30.97
274.96
25.31
275.00
5.470
Clearance Factor
Pass -
Major Risk
1H -103 -1H -1031-1-1H-1031_1
49.97
30.06
49.97
27.30
50.00
10.914
Centre Distance
Pass -
Major Risk
1 H-103 - 1 H-1031_1 - 1H-1031.1
274.96
30.97
274.96
25.31
275.00
5.470
Clearance Factor
Pass-
Major Risk
15 May, 2018 - 8:13 Page 2 of 6 COMPASS
ConocoPhillips
Anticollision Report for Plan: 1H-108 -1 H-108wp22
Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference)
Reference Design: Kuparuk lH Pad -Plan: 1H -108 -Plan: 1H-108-1H-108wp22
Scan Range: 0.00 to 6,839.41 usft. Measured Depth.
Scan Radius is 880.04 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
15 May, 2018 - 8:13 Page 3 of 6 COMPASS
Measured
Minimum
@Measuretl
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name -Design
(usft)
(usft)
(usft)
(usft)
usft
1H -103 -1H -10312-1H-10312
49.97
30.06
49.97
27.30
50.00
10.914
Centre Distance
Pass - Major Risk
1 H-103 - 1 H-1031-2 - 1H -103L2
274.96
30.97
274.96
25.31
275.00
5.470
Clearance Factor
Pass - Major Risk
1H -103 -1H -10313-1H-1031-3
49.97
30.06
49.97
27.30
50.00
10.914
Centre Distance
Pass - Major Risk
1H -103 -1H -1031-3-1H-10313
274.96
30.97
274.96
25.31
275.00
5.470
Clearance Factor
Pass - Major Risk
1 H-103 - 1 H-1031-4 - 1 H-1 03L4
49.97
30.06
49.97
27.30
50.00
10.914
Centre Distance
Pass - Major Risk
1 H-103 - 1 H-1031-4 - 1H-1031.4
274.96
30.97
274.96
25.31
275.00
5.470
Clearance Factor
Pass - Major Risk
1H-109-1H-109-iH-109
921.54
46.09
921.54
29.95
925.00
2.856
Centre Distance
Pass - Major Risk
1 H-109 - 1 H-109 - IH -109
996.06
46.72
996.06
29.56
1,000.00
2.722
Clearance Factor
Pass - Major Risk
11-1-111 - 11-1-111 - 1H-111
300.28
119.07
300.28
113.83
300.00
22.731
Centre Distance
Pass - Major Risk
11-1-111 - 1H-111 - 11-1-111
962.73
123.80
962.73
108.23
975.00
7.955
Clearance Factor
Pass - Major Risk
1 H-113 - 1 H-113 - 1 H-113
644.48
173.86
644.48
163.12
650.00
16.190
Centre Distance
Pass - Major Risk
1 H-113 - 1 H-113 - 1 H-113
692.81
174.32
692.81
162.95
700.00
15.339
Clearance Factor
Pass - Major Risk
1 H-114 - 1 H-114 - 1 H-114
50.06
209.94
50.06
207.59
50.00
89.318
Centre Distance
Pass - Major Risk
1 H-114 - 1 H-114 - 1 H-114
474.58
213.52
474.58
205.20
475.00
25.692
Clearance Factor
Pass - Major Risk
1H-12-1H-12-iH-12
2,469.82
182.09
2,469.82
113.69
2,450.00
2.662
Clearance Factor
Pass - Major Risk
1H -13 -1H -13-1H-13
4,900.06
271.38
4,900.06
120.93
4,550.00
1.804
Centre Distance
Pass - Major Risk
1H-13-1H-13-iH-13
5,189.34
278.89
5,189.34
110.81
4,850.00
1.659
Clearance Factor
Pass - Major Risk
1H-15-1H-15-iH-15
3,804.38
328.75
3,804.36
210.33
3,900.00
2.776
Centre Distance
Pass - Major Risk
1H -15 -1H -15-1H-15
3,846.42
329.52
3,846.42
209.57
3,950.00
2.747
Clearance Factor
Pass - Major Risk
1 H401 (UGNU) - 1 H-401 - 1 H-401
1,326.55
83.90
1,326.55
50.40
1,450.00
2.504
Clearance Factor
Pass - Major Risk
Plan: 1 H-104 - Plan: 1 H-104 - 1 H-104wp23
524.42
28.35
524.42
19.49
525.00
3.200
Centre Distance
Pass - Major Risk
Plan: 1H -104 -Plan: 1 H-104 - 1 H-1 04wp23
549.21
28.49
549.21
19.27
550.00
3.091
Clearance Factor
Pass - Major Risk
Plan: 1H -104 -Plan: 1H-1041_1-1H-104Liwp23
524.42
28.35
524.42
19.49
525.00
3.200
Centre Distance
Pass - Major Risk
Plan: 1H -104 -Plan: 1H-1041_1-iH-104Liwp23
549.21
28.49
549.21
19.27
550.00
3.091
Clearance Factor
Pass - Major Risk
Plan: 1H -104 -Plan: 1H-104L2-1H-104L2wp23
524.42
28.35
524.42
19.49
525.00
3.200
Centre Distance
Pass - Major Risk
Plan* 1H -104 -Plan: 1H -104L2 - 1H-104L2wp23
549.21
28.49
549.21
19.27
550.00
3.091
Clearance Factor
Pass - Major Risk
Plan: 1H -104 -Plan: 1 H-1 041-3 - 1 H-1 04L3wp23
524.42
28.35
524.42
19.49
525.00
3.200
Centre Distance
Pass - Major Risk
Plan: 1H-104- Plan 11-1-1041-3-11-1-1041-3wp23
549.21
28.49
549.21
19.27
550.00
3.091
Clearance Factor
Pass - Major Risk
Plan : 1H-104- Plan: 11-1-1041-4-1H-104L4wp23
524.42
28.35
524.42
19.49
525.00
3.200
Centre Distance
Pass - Major Risk
Plan: 1H -104 - Plan : 1 H-1 0414 - 1 H-1 04L4wp23
549.21
28.49
54921
19.27
550.00
3.091
Clearance Factor
Pass - Major Risk
15 May, 2018 - 8:13 Page 3 of 6 COMPASS
ConocoPhillips
Anticollision Report for Plan: 1H-108 -I H-108wp22
Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference)
Reference Design: Kupamk lH Pad - Plan: 1H -108 -Plan: 1H-108-1H-108wp22
Scan Range: 0.00 to 6,839.41 usft. Measured Depth.
Scan Radius is 880.04 usft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method.
15 May, 2018 - 8:13 Page 4 of 6 COMPASS
Measured
Minimum
@Measured
Ellipse
@Measured
Clearance
Summary Based on
Site Name
Depth
Distance
Depth
Separation
Depth
Factor
Minimum
Separation Warning
Comparison Well Name - Wellbore Name - Design
(usft)
(usft)
(usft)
(usft)
usft
Plan: 1 H-106 - Plan: 1 H-106 - iH-10Swp22
300.00
120.01
300.00
114.66
300.00
22.462
Centre Distance
Pass- Major Risk
Plan: 1H -106 -Plan: 1 H-1 06 - 1 H-1 06wp22
375.00
120.65
375.00
114.11
375.00
18.453
Clearance Factor
Pass - Major Risk
Plan: 1H -107 -Plan: 1 H-1 07 - 1 H-1 07wp22
250.00
60.39
250.00
55.92
250.00
13.513
Centre Distance
Pass - Major Risk
Plan: 1H -107 -Plan: 1 H-1 07 - 1 H-1 07wp22
325.00
61.03
325.00
55.39
325.00
10.810
Clearance Factor
Pass - Major Risk
Plan: 1H -110 -Plan: 1H-110-1H-110wp28
671.91
86.71
671.91
75.60
675.00
7.805
Centre Distance
Pass - Major Risk
Plan: IH -110 -Plan: IH-110-1H-110wp28
844.12
88.02
844.12
74.11
850.00
6.330
Clearance Factor
Pass - Major Risk
Plan: 1H-112 - Plan: 1H-112 - IH-112wp21
450.00
149.98
450.00
142.02
450.00
18.834
Centre Distance
Pass- Major Risk
Plan: 1H -112 -Plan: 1H-112-iH-112wp21
764.59
151.24
764.59
138.79
775.00
12.148
Clearance Factor
Pass - Major Risk
Plan: 1 H-115 - Plan: 1 H-115 - 1H-115wp21
449.90
239.83
449.90
231.87
450.00
30.122
Centre Distance
Pass- Major Risk
Plan: 1H -115 -Plan: 1H-115-1H-115wp21
595.14
240.93
595.14
230.77
600.00
23.718
Clearance Factor
Pass - Major Risk
Survey tool program
From
To
Survey/Plan
Survey Tool
(usft)
(usft)
39.00
800.00
1H-108wp22
GYD-GC-SS
800.00
1,800.00
1 H-108wp22
MWD
800.00
1,835.27
iH-108wp22
MWD+IFR-AK-CAZ-SC
1,835.27
3,335.27
1H-108wp22
MWD
1,835.27
6,839.41
1H-108wp22
MWD+IFR-AK-CAZ-SC
Ellipse error terms are correlated across survey tool tie -on points.
Calculated ellipses incorporate surface errors.
Separation is the actual distance between ellipsoids.
Distance Between centres is the straight line distance between wellbore centres.
Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation).
All station coordinates were calculated using the Minimum Curvature method.
15 May, 2018 - 8:13 Page 4 of 6 COMPASS
1 H -108V Wp22
I idder View
N
6
3
_
N
I
285
I
C
rvp.I..jfI�i
N 90
I
i
d
N �
C
0 N
r
Q
c 95
I
may.
Equivalent Magnetic Distance
0
0
1000 2000
3000 4000
5000 6000 700
Measured Depth
SURVEY PROGRAM
CASING DETAILS
pth From
Depth To Survey/Plan
Tool
T
D MD Nam
39.00
800.00 1 H-108wp22 (Plan: 1 H-108)
GYD-GC-SS
118.00 118.00 20" x 42"
800.00
1800.00 iH-108wp22 (Plan: 1H-108)
MWD
1767.00 1835.27 10-3/4" x 13-1/2"
800.00
1835.27 1H-108wp22 (Plan: 1H-108)
MWD+IFR-AK-CAZ-SC
4159.75 6839.41 7" x 8-3/4"
1835.27
3335.27 1 H-108wp22 (Plan: 11-1-108)
MWD
1835.27
6839.41 1H-108wp22 (Plan: 11-1-108)
MWD+IFR-AK-CAZ-SC
a
x
a
0
60--
0
O
.03
N
al
CL
n
N
J
Qi30
'..
U
0
Equivalent Magnetic Distance
�
I
U
I
0-
0
300 600 900
1200 1500
Partial Measured Depth
Errors Report
ConocoPhillips (Alaska) Inc.
-Kup1
Kuparuk River Unit
Kuparuk 1H Pad
Plan: 1 H-108
50029xxxxx00
Plan: 11-1-108
Plan: 1 H-108wp22
Error Ellipse
Survey Report
15 May, 2018
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project.
Kuparuk River Unit
Site:
Kupamk 1H Pad
Well:
Plan: iH-108
Wellbore:
Plan: iH-108
Design:
iH-108wp22
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Well Plan: 1 H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft (Doyon 142)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Project Kuparuk River Unit, North Slope Alaska, United States
Map System: System Datum: Mean Sea Level
Geo Datum: Using Well Reference Point
Map Zone: Using geodetic scale factor
Site Kuparuk 1H Pad
Site Position: Northing: Latitude:
From: Map Easting: Longitude:
Position Uncertainty: 0.00 usft Slot Radius: 0" Grid Convergence: 0.37 °
Well Plan: 11-1-108
Well Position +N/ -S 0.00 usft Northing: Latitude:
+E/ -W 0.00 usft Easting: Longitude:
Position Uncertainty 0.00 usft Wellhead Elevation: Ground Level: 54.00 usft
Wellbore Plan: 1H-108
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(') (') (nT)
BGGM2017 6/112018 1708 60.93 57,467
Design 1H-108wp22
Audit Notes:
Version:
Phase:
PLAN
Tie On Depth: 39.00
Vertical Section:
Depth From (TVD)
+N/ -S
+E/ -W Direction
(usft)
(usft)
(usft) (°)
39.00
0.00
0.00 90.00
To
(usft) Survey (Wellbore)
800.00 1H-108wp22 (Plan: 1H-108)
1,800.00 1H-108wp22 (Plan: iH-108)
1,835.27 1H-108wp22 (Plan: iH-108)
3,335.27 1H-108wp22 (Plan: 1H-108)
Tool Name Description
GYD-GC-SS Gyrodata gyro single shots
MWD MWD -Standard
MWD+IFR-AK-CAZ-SC MWD -FR AK CAZ SCC
MWD MWD -Standard
5%52018 8: 12'32AM Page 2 COMPASS 5000.14 Build 85
Company:
ConocoPhillips (Alaska) Inc. -Kupt
Project:
Kupamk River Unit
Site:
Kuparuk 1H Pad
Well:
Plan: 1H-108
Wellbore:
Plan: 1H-108
Design:
1H-108wp22
Plan Survey Tool Program Date 5/14/2018
Depth From Depth To
(usft) (usft) Survey (Wellbore)
1 39,00 800.00 1 H-108wp22 (Plan: 1 H-108)
2 800.00
1,800.00
1 H-108wp22 (Plan:
1 H-108)
3 800.00
1,835.271H-108wp22(Plan:
1 H-108)
4 1,835.27
3,335.271H-108wp22(Plan:
1 H-108)
5 1,835.27 6,839.41 1 H-1 08wp22 (Plan: 1 H-108)
ConocoPhillips
Error Ellipse Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Tool Name Remarks
GYD-GC-SS
Gyrodata gyro single shots
MWD
MWD - Standard
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
MWD
MWD- Standard
MWD+IFR-AK-CAZ-SC
MWD+IFR AK CAZ SCC
Well Plan: 1 H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 a 93.00usft (Doyon 142)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Position uncertainty and bias at survey station
Measured
inmineeon
ABmutt,
Vesical
aighside
lAYml
Veniwl
Magnitude
8emimalor
9emMntlnor
Depth
DepM
Error
BW
Error
Bias
Eno,
Biu
of Bias
Evor
E,mr
Azimuth TW
W)
1°I
(°)
lean)
(um)
lural
lass)
(usft)
(ess)
(usft)
lain)
lain)
(usts)
19
3900
aw
000
3900
000
000
0.00
000
0.00
0.00
000
000
000
000
UNDEFINED
10000
000
0.00
100.00
004
D.00
004
000
1.15
000
ew
004
004
000
GYD-GC-ISS(1. 1)
20000
000
0.00
20D.00
0.19
0.00
0.19
000
1.15
0.00
0.00
0.19
0.19
000
GYD-GC-S$(1, 1)
30000
ew
0.00
300.00
0.33
0.00
0.33
000
1.15
0.01
001
0.33
0.33
0.00
GYD-GC-ss(1, 1)
400.00
ew
0.00
400.00
0.48
0.00
0.48
ON
1.15
a01
0.01
048
0.48
000
GYD-GC-SS(1. 1)
430.00
ew
0.00
460.00
0.57
000
0.57
000
1.15
0.02
0.02
0.57
0.57
0.00
GYD-GC-SS(1, 1)
500.00
060
Mee
5D000
0.60
0.00
0.60
000
1.15
002
DIM
0Be
0.60
4500
GYD-GC-SS(1, 1)
800.00
2.10
120.00
599.97
0.67
0.00
0.67
0.00
1.15
003
0.03
0.67
0.67
45.00
GYD-GC-SS(1, 1)
600.03
2.10
120.00
600.00
0.67
000
0.67
0.00
1.15
0.03
0.03
0.67
0.67
45.00
GYD-GC-SS(1, 1)
700.00
460
12000
699.79
075
0.00
075
0.00
1.16
0.05
0.05
075
0.75
31.09
GYD-GC-SS(1, 1)
800.00
7.10
12000
79928
0.85
-0.01
0e6
0.00
1.15
007
0.07
0.86
Des
32.11
GYD-GC-SS(1, 1)
90000
960
12000
898.19
0.91
-0.01
0.93
0.01
1.15
0.09
0.09
0.93
093
45.00
AM (1, 2)
901.83
9.85
120.00
90000
091
-0.01
0.93
0.01
1.15
009
0.09
0.93
0.93
45M
AM (1. 2)
100000
1209
121.02
998.40
092
-0.01
102
0.03
1.15
0.11
0.11
1.02
a98
122.11
AM (1. 2)
1,100.00
14.59
12171
1,09369
0.95
-0.02
1.23
0.06
114
0.13
0.15
1.23
101
12229
MWD(1. 2)
1,200.00
17,08
12221
1,189.09
1.01
-GD2
1.55
0.10
1.14
0.16
0.19
155
1.00
12284
MWD N. 2)
1.300.00
1956
122.58
1.284.81
1.00
-003
1.98
0.15
1.14
0.19
025
1.90
1.16
122.77
MWD(1, 2)
1,400.00
22.08
122.87
137827
1.18
-004
2.50
0.22
1.14
0.22
0.32
2.50
127
12297
MwD(1. 2)
1,500.00
2/58
123.10
1,47008
129
-0.05
3.11
031
1.14
025
0.40
3.11
1.39
123.13
MWD N. 2)
1,800.00
27.08
123.29
1.560.e9
1.42
-008
3.79
0.42
1.15
0.28
051
3.79
1.52
123.28
MM (1. 2)
1.629.20
2781
123.34
1,58800
146
4M
401
0.45
1.15
0.29
0.54
4.01
1.57
12332
M"(1, 2)
1,700.00
27.81
123.34
1,64683
1.58
-0.06
454
0.54
1.18
0.32
063
4.54
156
123.40
MM (1, 2)
1,742.25
27.81
123.34
1.686.00
105
-0.w
4.86
059
1.20
0.33
0.68
4,88
172
123.44
MM (1, 2)
1,800.00
2983
123.34
173880
174
-0.07
5.31
0.66
122
035
076
581
1.00
12349
MM (1, 2)
1,635.27
31.06
123.34
1.787.00
1.44
-0.09
284
000
1.15
0.37
0.39
284
1.58
127.82 MWDHFR-MF-
-SC (2,2)
1.855.7
3108
123.34
1704.13
145
7,.09
270
0.01
1.14
037
0.39
2.70
1.59
127.70
MWD(2.3)
1,9000,)
3263
123.34
1.822.13
1.44
-0.10
2.85
0,06
1,13
0.39
042
286
160
127.04
MWD(2, 3)
2,00000
36.13
123.34
1.904.65
1.45
.0.12
3.39
026
1.13
043
0.52
339
185
125.73
MWD(2. 3)
2.100.00
3983
123.34
1.983.58
1.50
-0.15
4.16
047
1.14
046
0.68
4,16
1.72
124.90
MWD (2. 3)
2,20000
43.13
12134
2,050.60
1.58
-0.18
5.11
071
1.18
0.50
089
5.11
1.81
124.42
MWD(2, 3)
2.300.00
4663
12384
2,129.45
1.71
-0.21
6.21
0.98
1.25
053
1.15
621
191
124.14
MM (2. 3)
5/15/2018 8: 12 32A Page 3 COMPASS 5000.14 Build 85
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Project:
Kuparuk River Unit
Site:
Kuparuk 1H Pad
Well:
Plan: 1H-108
Wellbore:
Plan: 1H-108
Design:
1H-108wp22
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Well Plan: 1 H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft (Doyon 142)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Position uncertainty and bias at survey station
Measurld
Inclination
Az"wh
Venical
Righcide
t ..[
Venoal
Megnitutle
Semimajor
Semiminor
Nmh
Depth
S.,
Bias
Eno,
Blas
Error
sws
of alas
Error
Eoor
Azimuth Tool
(usR)
1°1
(°1
(usR)
J.1n
roan)
(.ft)
loan)
(usR)
Nott)
lusRl
(oaR)
loan)
(°)
2400.00
$0.13
123.34
2,195.82
1.82
-0.25
742
1.29
1.36
056
1.44
142
2.03
12397 MWD(2,3)
2.500.00
53.63
123.34
2,252.58
2.06
-0.29
8.22
1.64
1.50
059
117
8.22
2.15
123.86 MWD (2.3)
2,51062
54.00
123.34
2263 90
2.08
.0.29
8.82
1.82
1.51
060
1.81
8.82
2.12
123.85 MM (2,3)
2,60000
54.00
123.34
2,31640
230
-0.29
10.09
2.00
1.69
082
2.12
10,09
2.22
12319 FAM (2,3)
210000
54.00
123.34
2.315.18
2.52
-029
11.42
2.36
1.90
065
248
11.42
2.39
123.24 MWD (2,3)
2,80000
54.00
12334
2,433.%
2.84
-0.29
12.85
212
2.12
088
2.04
12.85
2.52
12321 MWD (2,3)
2.900.00
54.00
123.34
2,492.24
3.12
-0.29
1C25
3.00
2.35
0.21
320
14.25
2.65
12168 MV X) (2,3)
3.00000
54.00
123.34
2.551.51
340
-029
15.65.
344
2.58
075
3.58
15.65
2.29
123.66 MWD (2. 3)
3,10000
54.00
123.34
281029
369
-029
12.06
3.81
2.81
028
3.93
17,06
2.93
12365 MWD (2,3)
3,200.00
5400
123.34
2,66902
398
-0.29
18.42
4.12
3.05
0.81
4.29
18.42
3.08
12354 mm (2.3)
3.29005
54.00
123.34
2,722.00
4.25
-0.29
19.24
4.49
3.26
085
462
19.24
3.21
Ines MM (2. 3)
3,30000
54.19
inall
?12284
4.20
-031
19.82
453
3.20
0.85
666
19.82
323
123.63 MM (2. 3)
3,40000
56.18
119.48
2,284.94
223
-0.33
9.05
0.05
2.09
088
1.14
909
2.39
12491 MM -IFR -AK -CA -W(3, 3)
3,500.00
58V
116.13
2,839.08
2.92
-0.32
962
0.09
220
0.92
120
9.52
2.45
12463 MWD+IFR-AKCA-SC(3, 3)
3,60000
60.43
112.94
2,890.02
3.12
-042
9.82
a13
2.33
0.95
1.28
10.05
2.52
124.20 MWDHFR-AK-CA-SC(3, 3)
3,200.00
62.62
109.88
2,932.21
330
-042
1026
0.10
2.45
0.98
1.31
10.55
2.58
12353 MWD+1FR-AWCA-SC(3, 3)
3,80000
e4%
1%.94
2.981.03
362
-0.53
10.64
0.22
2.59
1.00
1.32
1104
2.65
122.95 MM+IFR-AH-CA-SC(3, 3)
3,900.00
62.34
104.11
3.022.25
362
-0.58
11.00
0.22
222
103
1.42
11.54
2.21
122.18 MWD+IFR-AK-CA-SC(3, 3)
3,901.91
62.30
10408
3,022.99
383
-0.58
11.01
0.22
2]3
153
142
1155
2]1
122.12 MWD+IFR-AK-CA-W(3. 3)
4,00000
67.38
104.06
3108011
3.28
.0.58
11.55
0.22
2.82
1.05
1,48
12.06
221
12136 MWD+1FR-AK-CA-SC(3, 3)
4,100.00
62.30
104.08
3,099.12
393
-0.58
12.13
0.22
3.02
102
1.53
1262
2.82
120.56 MWD+117R-AK-CA-SC(3. 3)
4,200.00
62.38
104.06
3,137,83
408
-0.58
1221
0.22
3.11
till
1.59
13.18
2.80
119.93 MWDHFR-AK-CA -SC (3,3)
4,300.00
82.38
104.06
3,126.09
624
-0.58
13.30
022
3.32
1.12
1.64
13.25
2.94
119.16 MWD+IFR-AKLA-SC(3,3)
4,400.00
62.30
104.%
3.214.54
440
-0,58
13.88
021
3.48
1.14
130
14.32
3.00
118.55 MWD+1FR-AK-CA -SC (3,3)
4.500.00
62.38
104.06
3,25300
Cos
-0.58
14.42
022
3.63
1.12
116
14.89
3.05
112.98 MWD+I1FR-AK-0 ZSC(3,3)
4,600.00
62.30
104.06
3,29146
4]2
-0.58
15.06
022
339
1.19
1.82
15.42
3.11
112.45 MWD+IFR-AK-CA -SC (3,3)
4,20000
82.38
10408
3,329.92
4.88
-0.58
1565
0.22
3.94
122
1.89
1504
3.12
116.92 MM+IFR-AK-CA -SC (3,3)
4,800.00
62.38
104.06
3.368.38
5.04
-Us
1825
022
4.10
125
1.95
16.62
3.23
116.51 MM+IFR-AK-CA2-SC(3,3)
4,900.00
62.38
10408
3.4%83
520
-058
16.84
0.22
4.25
122
202
1220
3.29
116.09 MWD+IFR-AK-CP -SC (3.3)
5,00000
62,38
10408
3.44529
538
-058
17.43
022
4.41
130
2.00
17,29
3.35
115.10 MM+IFR-AK-CA-$C(3,3)
5,10000
62.38
104.05
3,483.15
5.53
-am
18.03
0.22
4.58
1.33
2.15
10.32
3.41
115.33 MWD+IFR-AK-CA-SC(3.3)
5,200.00
62.38
104.08
3,522.21
5.69
-058
1862
022
422
1.35
2.22
18.%
342
114.99MWD+IFR-AK-CA-SC(3,3)
5.30000
62,38
104.06
3,560.62
565
-0.58
1922
0.22
4.88
138
2.29
19.54
3.52
11662 MWD41FR-AK-CA-SC(3,3)
5.40000
6238
104.06
3.599.12
6.02
-058
19.82
0.21
503
1.41
238
20.13
3.58
114.35 MWD+IFR-AK-CA-SC (3,3)
5,500.00
67,38
104.06
3,632.58
6.19
-0ss
20.41
022
5.19
1.44
243
2012
364
114.08 MW IFR -AK -CP -SC (3.3)
5.6[0.00
6138
104.06
3,626.04
6.35
-0.50
21.01
0.22
535
1.0
2.50
21.31
3]1
113.81 MWD4IFR-AK-CA-SC(3,3)
5,609.80
62.38
104.06
3.62881
6.32
4),58
21.02
022
536
1.42
251
21.32
3.21
113.28 MWWIFR-AK-CAZSC(3,3)
5,20D.00
62.04
101.42
3,21628
640
0.56
21]3
0.15
5.50
1.50
268
2L65
322
113.61 MW IFR AK -CA -SC t3.3)
5.208.31
62.01
102.28
3,218.00
6.40
-0.56
2119
0.14
5.51
150
2.59
21.90
3.22
113.59 MW IFR -AK -CP -SC (3,3)
5.221.11
62.01
101)8
3,22300
6.42
-0.56
21.88
0.14
5.53
1.51
2.60
2192
328
113.52 MM+IFR-AK-CA-SC (3, 3)
5.80000
Val
102.28
3,253.81
e56
-D.06
2233
0.14
565
1.53
2.66
2244
3.83
11346 MWD+IFR--CA-SC (3, 3)
5,900.00
62.01
10278
3,292.86
6]2
-0.56
22.93
0.14
5.82
1.06
223
23.03
389
113.33 MWD+IFR-AK-CA-SC(3,3)
6,000.00
62.01
10238
3,831.92
8.89
-0.56
23.53
0.14
5.92
1.59
2.81
23.63
3.95
11320 MWD+IFR-AKCA-SC(3, 3)
6,100.00
82.01
102]8
3,02092
2.06
-0.56
24.13
0.14
6.13
1.62
2.89
24.23
4.01
11308 MWD+IFR-MK- -SC (3,3)
6,200.011
62.01
102.18
3,91003
2.23
-0.56
24.23
0.14
629
1.88
2.92
2483
402
112.92 MM+1FR-AK-CA-5C(3,3)
6,30000
81.01
10728
3,949D8
140
-0.56
25.33
0.14
644
1.69
3.%
2562
4.13
11286 MWD4IFR-AK-CA-SC(3,3)
6,309.41
62.01
10128
3.984,00
2.55
-0.58
25.86
0.14
6.59
1]2
3.13
25.96
4.19
112.]2 MWD+IFR-AK-CALBC(3,3)
6.400.00
62.01
10128
3,988.14
152
-0,56
25.93
0.14
6.60
122
3.14
26.02
4.20
112.26 MWD+IFR-AK-CA-SC (3.3)
6,50000
62.01
102.28
4,022.19
Z14
-0.56
26.53
0.14
628
136
3.22
28.62
4.26
11268 MM4IFR-AK-C Z-SC(3,3)
6,600.00
67.01
10128
4,088.25
191
-056
22.13
0.14
6.92
139
3.31
22.22
4.32
112.56 MWD+IFR-AK-CAZSC(3,3)
6.200.00
62.01
102]8
4,105.30
808
-0.56
22]3
0.14
108
182
3.39
22.82
4.30
11242 MM+IFR-AK-CA-SC (3.3)
81800.00
6101
102]8
4,14435
825
-056
28.33
0.14
1.23
Ise
3.48
2842
445
112.39 10 i 11`R-AK-CAZSC(3,3)
6,839.41
67.01
10118
4,15925
8.32
-0.56
28.52
0.14
2.30
1.82
352
20.66
442
112.36 MWD+IFR-AK-CA -W(3. 3)
5/152018 8: 12:32AM Page 4 COMPASS 5000.14 Build 85
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kupamk River Unit
Site:
Kupamk 1H Pad
Well:
Plan: 1H-108
Wellbore:
Plan: 1H-108
Design:
1 H-108wp22
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
TVD Reference:
MO Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Well Plan: 1H-108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft (Doyon 142)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Design Targets
Vertical
Casing Hole
Depth
Depth
(usft)
Diameter Diameter
(usft)
Target Name
Name
() C)
118.00
118.00
20"x42"
2D 42
1,835.27
1,767.00
- hit/miss target Dip Angle
Dip Dir.
TVD
+NI -S
+E/ -W
Northing
Easting
3,423.00
UG_A
-Shape (°)
(I
(ueft)
(usft)
(usft)
(usft)
(usft)
Latitude
Longitude
1 H-108wp22 T01 05141 0.00
0.00
3,723.00
-1,408.33
3,324.54
5,979,118.00
1,692,936.00
70° 21' 14.610 N
149° 34'24,630 W
- plan hits target center
3,984.00
WS—A2
6,694.11
4,103.00
WS—Al
- Circle (radius 100.00)
1H-111 A3072914 DL 0.00
0.00
3,907.00
-1,529.76
3,845.81
5,979,000.00
1,693,458.00
70° 21' 13.413 N
149' 34'9.394 W
- plan misses target center by 58.42usft at 6284.06usft MD
(3942.86 TVD, -1566.58 N,
3818.03 E)
- Circle (radius 100.00)
1 H-108wp22 T02 05141 0.00
0.00
3,984.00
-1,596.19
3,910.38
5,978,934.00
1,693,523.00
70° 21' 12.760 N
149° 34'7.508 W
- plan hits target center
- Circle (radius 100.00)
Casing Points
Formations
Measured
Vertical
Casing Hole
Depth
Depth
(usft)
Diameter Diameter
(usft)
(waft)
Name
() C)
118.00
118.00
20"x42"
2D 42
1,835.27
1,767.00
103/4" x 13-1/2"
10-3/4 13-1/2
6,839.41
4,159.75
7" x 8-3/4"
7 8-3/4
Measured
Vertical
Depth
Depth
(usft)
(usft)
Name
1685,72
1,636.00
Base PFROST
1,884.45
1,809.00
T-3
2,178.75
2,043.00
K-15
3,979.95
3,053.00
UG—C
4,669.01
3,318.00
UG_B
4,942.03
3,423.00
UG_A
5,254.06
3,543.00
Na
5,721.11
3,723.00
WS—D
5,849.14
3,773.00
WS_C
5,915.71
3,799.00
WS_B
6,020.69
3,840.00
WS A4
6,135.92
3,885.00
WS—A3
6,389.41
3,984.00
WS—A2
6,694.11
4,103.00
WS—Al
Dip
Dip Direction
Lithology (1) (°)
5/15/2018 8:12'32AM Page 5 COMPASS 5000.14 Build 85
Company:
ConocoPhillips (Alaska) Inc. -Kupi
Project:
Kuparuk River Unit
Site:
Kuparuk I Pad
Well;
Plan: IH -108
Wellbore:
Plan: 1H-108
Design:
1H-108wp22
Plan Annotations
ConocoPhillips
Error Ellipse Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Well Plan: IH -108
Plan: 54+39 @ 93.00usft (Doyon 142)
Plan: 54+39 @ 93.00usft (Doyon 142)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
460.00
460.00
0.00
0.00
KOP. Start 1.5`/100' DLS, 120° TF, for 140.03'
600.03
600.00
-1.28
2.22
Start 2.5°/100' DLS, 0° TF, for 301.8-
901.83
900.00
-16.71
28.95
Adjust TF to 5°, for 701.59'
1,603.42
1,563.13
-134.94
215.15
Hold for 112.39'
1,715.81
1,662.61
-163.68
258.84
Start 3.5°/100' DLS, 0° TF, for 766.83'
2,482.64
2,247.22
-430.76
664.77
Hold for 819.65'
3,302.29
2,729.18
-795.13
1,218.64
Start 3.5°/100' DLS, -53.72° TF, for 606.31'
3,908.60
3,025.56
-998.28
1,702.71
Hold for 1980.6'
5,889.20
3,788.65
-1,455.58
3,471.89
Start 3.5°/100' DLS, -90.73° TF, for 398.98'
6,286.18
3,943.69
-1,567.18
3,819.89
Hold for 758.52'
7,044.64
TD: 7044.7' MD, 4185' TVD
Checked By: Approved By. Date:
5/15/2018 8,12..32AM Page 6 COMPASS 5000.14 Build 85
Pool Report
a: May 1S ��8
1 H-108wp22
WF!.I BORE TARGCT OCTAII S iMAP CO-ORDINATES)
a,„e TVD SM1ape
Quarter Mile View
!R-,oe.nzz To, 051418 RP 372o00cwle iR,a„a,aeo om
,e�,oevpzz roz osa,e RP 390a .00 Circle (Raems. ,azo.00)
1900
g -114'
,o
a
I
S
,
950
1H -,o
1
ro
0
Q
M
0
O
L0
'
ILA
i+
I
3
A
1N'
N
=-950
e,
z
'51900-
0
r
=
-2850
a
o
-1900
-950 0 950
1900
2850 3800 4750
5700
I
1H-110wp28 Surface Location
Q CPAI Coo•dinate Ccm+erter
Rom: ------, To. ----...— -
Datum: FN—AD-83 Region alaska Datum: NAp27 . Regiorn alaska
(" Latitude/Longitude Decimal Degiees r Latitude/Longitude IDecimal Degrees
f UTM Zone: F— r South r UTM Zone: Trr- r South
G Slate Plane Zane: I4 J Units: w.g . F State Plane Zone: [4---J] Units: [is ft
r Legal Desaiption (NAD27 o*) f Legal Description (NAD27 ortly)
- Starting Coordinates: - Ending Coordinates
X 1688602,68 X 549570976245029
Y: 15980504,33 Y: 5980752.52152466
lorm i Quit Help
TranMT—M---JI
1H -110w 28 Surface Location
ra CPAI Coordinate Comrerier
From:_
Datum NAD63 Region alaska Daum INAD27j Recon alaska
r Latitude/Longitude jDecimalDegrees r Latitude/Longitude IDecomalDegrees
r UTM Zone: r— r South r UTM Zone: True r South
G Slate Plane Zone: rq �. Units: urf[ . 7" State Plane Zone: q . Units: us ll
I
C -ecal Desceiptkm (NAD27 only! G Legal Desorption (NAD27 only)
Starting Coordinates:— —, Legal Desorption----------------�
Y' 1699602.60 Township: 012 I"J Range: 010
Y: 590504.33 Meridian: �(1� Section:2g
J
FF. 5230.4878 FEL . 770.33475
�._ Translam �..1 Quit Help
1 H-110wp28 Surface Casing
ti CPA1Coordinate
From. -
Datum INAD83 Region:Alaska
C Latitude/Longitude IDecimalDegrees
r UTM Zone: r South
(•" Slate Plane Zone: I4 _3 Units: urft
C Legal Description (NAD27 only)
Datum: NAD27 - Flagon: alaska
* Latitude/Longitude Dectnal Degrees
* UTM Zorw: True r South !,
R Slate Plane Zone:r'�-] LIntlS w-4
r Legal Description(NAD27 only)
Starting Coordinates: ---- Ending Coordinates: _-
X:1669911.06 X: 549879.430292559 j
i
Y: 1598M10.86 Y: 5980559.05025029
.. Transform ;. Quit Help
11 H-110wp28 Surface Casing I
❑ CPA: Coc-a mate Ccn•:erter
From - -- -- --
Datum:NAD83 Regions alaska
r Latilude/Longkude Deamal Degrees -�
f•UTM Zone: r— r South
F Slate Plane Zone: I" -1 Units: usft
Starting Coordinates: - --- - - ---
X: 1689911.06
Y: 15980311186 I
Ta
Datum INAD27 Regan jalaska
t` Latitude/Longitude Decimal Degrees
C UTM Zone: Tone r South '..
* State Plane Zone: F--]-] Units: us.ft
* Legal Description (NAD27 o*)
Descd*n
Township: I"J 012 Range: olo I`J
Meridian: FL
J Section:r—
FNL , 146.03332 FEL . 463.57101
t''Transform Quit Help
1H-110wp28 Production Casing / TD
Q. CPAI Coordinate Converter �o
From: ..—_—__ To: .._ —..
Datum: NAD83 Region: alaska Datum: NAD27 Region alaska
r Latitude/Longitude Decimal Degrees —� f Latitude/Longitude IDecimal Degrees —�
f UTM Zone: F— r South f UTM Zone: True r South
R State Plane Zone: (q � Units: us.R R State Plane Zone: I4 Units: us It _�
C' Legal Description (NAD27 only) r Legal Description (NAD27 only)
-Starting Coordinates: - Ending Coordinates: - -- — _
X: 11693918.26 X: 553886.558829203
Y: 1597MO.10 Y: 97909.25006501
i
QUO He
1H-110wp28 Production Casing/TD
M CPAI Coordinate Converter
From: - _... ___ ___ .... -To:
Datum: NAD83 Region: alaska Datum: NAD27 Region: alaska
f LatitudeiLongkode jDacimalDegrees f Latitude/Longitude IDecimalDegiees —�
I
r' UTM Zone: F— r South f UTM Zone: True r South
C. Stale Plane Zone: 'q Units: us-ft t' State Plane Zone:[4---:,:] Units: Fu-, -ft
f: Legal Description(NAD27ori
- Starling Coordnates: Legal Description
X: 1693918.26 Township: 012 Rmi9e: 010 F J
Y: 5978810.10 Meridian: U . Section:Fr—
FNL . 1674.6970 FEL 1749.4643
ETransform Quit Help J
Tollerable Collision
Risk Worksheet
As -built
1 2/05/0 MRT I CC I
Rev. Per K05014ACS
2 02/01/11 JAH
I LGM I
Rev. Per K170005ACS
1.
BASIS OF LOCATION AND ELEV. IS DS1H
25
30 29
28 27
125
DS1 H
N
COORDINATES SHOWN ARE ALASKA STATE
]G
PLANE, ZONE 4, N.A.D. 27, AND GEODETIC
36
KCS
31
T521
1H
33 34
�T
3536
ELEVATIONS ARE B.P.M.S.L.
y0
•UGNU
01 4•
ALL CONDUCTORS ARE LOCATED WITHIN
m
•14
T11N
OE
•5
UMIAT MERIDIAN, ALASKA.
�
5
g
4
3
2
1
•11
0120
DATES OF SURVEY: 12-26-16 THRU
le
010
c
ASP GRID NORTH
0119
2
79
6
CPF1 10
•21
0118
e13
6.
tiF�
•1
12
0117
•2
•7
°
•3
•18
0116
GRAPHIC SCALE
0115
0
18 7
16 15
14
13
0114
•4
1E
0113
1F
ID
24
LEGEND
0112
24
19 20
21 2 23
0 AS -BUILT CONDUCTOR
0111
0110
& ASSOCIATES, INC.
VICINITY MAP
_
• EXISTING CONDUCTOR
0109
SCALE:
1" = 2 MILES
MODULE: XXXX UNIT: D1
ConocoPhilli
0104
DS1H
0108
I, S
0103
Alaska, Inc.
26
27
ASBUILT LOCATIONS
CAD KF ORdot
7/n5/05
DRAWING No.
CEA—DIHX-6108D31
33
PART. 1 OF 3
RE V:2
0102
•106
134
0101
NOTES:
1.
BASIS OF LOCATION AND ELEV. IS DS1H
MONUMENTATION PER LOUNSBURY & ASSOC.
DS1 H
2.
COORDINATES SHOWN ARE ALASKA STATE
PLANE, ZONE 4, N.A.D. 27, AND GEODETIC
COORDINATES ARE NAD 27.
3.
ELEVATIONS ARE B.P.M.S.L.
•UGNU
01 4•
ALL CONDUCTORS ARE LOCATED WITHIN
PROTRACTED SECTIONS 28 AND 33,
•14
TOWNSHIP 12 NORTH, RANGE 10 EAST,
•5
UMIAT MERIDIAN, ALASKA.
•20
•12
019
•11
5.
DATES OF SURVEY: 12-26-16 THRU
•22
010
1-31-17 FIELD BOOKS L16-35, L16-40,
917
06
L17-02 & L17-03.
•16
•21
•15
e13
6.
ALL DISTANCES SHOWN ARE GROUND.
•1
•9
•2
•7
•3
•18
GRAPHIC SCALE
0
100 200 400
•S
•4
1 inch = 200 ft.
SEE SHEET
2 & 3 FOR COORDINATE
TABLE
LOUNSBURY
& ASSOCIATES, INC.
_
SUMYoRS ENGINEERS PWNNER9
AREA: IH
MODULE: XXXX UNIT: D1
ConocoPhilli
DS1H
I, S
WELL CONDUCTOR
Alaska, Inc.
ASBUILT LOCATIONS
CAD KF ORdot
7/n5/05
DRAWING No.
CEA—DIHX-6108D31
PART. 1 OF 3
RE V:2
1 1 102/01/171 JAH I LGM I (Create Per K170005ACS I I I I I
CONDUCTORS ARE LOCATED IN PROTRACTED SECTION 28,
T. 12 N., R. 10 E., UMIAT MERIDIAN
Well
No.
NAD 27
ASP Coordinates
NAD 27
Geo ra hic Coordinates
Section
Offset.
Elev.
Y
X
Lot.
Long.
F.S.L
F.E.L.
O.G.
PAD
*103
5,980,722.55'
549,573.20'
N 70' 21' 29.220"
W 149' 35' 50.536"
19'
768'
48.0'
54.1'
*104
5,980,782.43'
549,568.74'
N 70' 21' 29.809"
W 149' 35' 50.655"
79'
772'
48.0'
54.1'
*108
5,980,752.52"
549,570.98'
N 70' 21' 29.515"
W 149' 35' 50.595"
49'
770'
48.0'
54.0'
*109
5,980,812.20'
549,566.50'
N 70' 21' 30.102"
W 149' 35' 50.714"
109'
774'
48.0'
54.0'
*110
5,980,842.21'
549,564.40'
N 70' 21' 30.398"
W 149' 35' 50.770"
139'
776'
48.0'
54.0'
*111
5,980,872.05'
549,562.21'
N 70' 21' 30.691"
W 149' 35' 50.828"
169'
778'
48.0'
54.1'
*112
5,980,902.08'
549,559.94'
N 70' 21' 30.987"
W 149' 35 50.889"
199'
780'
48.0'
54.0'
*113
5,980,932.00'
549,557.76'
N 70' 21' 31.281"
W 149' 35' 50.947"
229'
782'
48.0'
54.0'
*114
5,980,961.86'
549,555.50'
N 70' 21' 31.575"
W 149' 35' 51.006"
259'
784'
48.0'
54.1'
*115
5,980,991.68'
549,553.43'
N 70' 21' 31.868"
W 149' 35' 51.062"
289'
786'
48.0'
54.1'
*116
5,981,021.61'
549,551.58'
N 70' 21' 32.163"
W 149' 35' 51.110"
319'
787'
48.0'
54.1'
*117
5,981,051.73'
549,548.80'
N 70' 21' 32.459"
W 149' 35' 51.185"
349'
790'
48.0'
54.0'
*118
59981,081.22'
549,546.95'
N 70' 21' 32.750"
W 149' 35' 51.234"
378'
791'
48.0'
54.0'
*119
5,981,111.42'
549,544.52'
N 70' 21' 33.047"
W 149' 35' 51.299"
408'
794'
48.0'
54.2'
*120
5,981,141.33'
549,542.48'
N 70' 21' 33.341"
W 149' 35' 51.353"
438'
795'
48.0'
54.1'
* CONDUCTOR ASBUILT THIS SURVEY
!♦♦ SURVEYOR'S CERTIFICATE
s} ♦♦ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND
LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF
ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY
DONE BY ME OR UNDER MY DIRECT SUPERVISION AND
THAT ALL DIMENSIONS AND OTHER DETAILS PER THIS REVISION
ARE CORRECT AS OF JANUARY 31, 2017.
hillIpS
Alaska. Inc.
LOUNSBURY
8 ASSOCIATES, INC.
tY GR9 BNGWEMS PW NE
DS1H
WELL CONDUCTOR
ASBUILT LOCATION'.
UNIT: D1
CADD FILE NO. IDRAWWING N0. CEA-DIHX-6108D31 (PART: (REV: I
IK6108d31 12/27/16 3 OF 3 1
Appendix
■ Tier 1: Standard
■ Intervals without issues noted for Tier 2 or 3
■ Tier 2: Challenging Orientation
■ Drilling within 30° of horizontal inclination AND drilling within 30' of magnetic
East/West azimuth in extreme northern or southern locations
■ Tier 3: Critical Steering
■ Driller's Target of 50' Radius or Less
■ Lease line constraint
■ Small Geologic Target
■ Failure of Major Risk Rule (Close Approach)
■ Defined during directional planning, based on the positional uncertainty
■ Theoretical intersection of the path of the well being planned with an offset well
■ If HSE risks are eliminated, the Tolerable Collision Risk assessment can be implemented
■ Tier 4: Single section containing both Tier 2 and Tier 3 challenges
6 ConocoPhillips
■ Tier 1 (Standard):
■ Directional interval across which no special mitigations are needed
■ Tier 2 (Challenging Orientation):
■ Increase non-magnetic insulation of MWD tool in the BHA
■ Take rotational check shots and/or increase survey frequency at the start of a BHA run
■ Alter well directional plan, if feasible
■ Consider gyro surveys where feasible
■ Tier 3 (Critical Steering):
■ Increase survey frequency across critical interval
■ Increase correction frequency across critical interval
■ Take rotational check shots and/or increase survey frequency if the critical interval is at the
start of a BHA run
■ Define escalation based on deviation from plan
■ Minor Risked close approach intervals with a high financial or scope risk should strongly
consider the use of relevant mitigations
■ Tier 4 (Critical Steering & Challenging Orientation):
■ Consider all Tier 2 & 3 mitigations
IH -108 Drilling Hazards Summary
13-1/2" Open Hole / 10-3/4" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Broach of conductor
Low
Monitor cellar continuously during interval.
Control drill, reduced pump rates, reduced drilling fluid
Gas hydrates
Moderate .
temperatures, additions of ScreenKleen.
Maintain planned mud parameters, increase mud weight,
Running sands and gravels
Low
use weighted sweeps.
Hole swabbing on trips
Moderate
Trip speeds, proper hole filling (use of trip sheets),
Differential sticking
Moderate
pumping out
Anti -collision
Moderate
Cool mud temperatures, minimize circulating times when
Washouts / hole sloughing
Low
possible.
8-3/4" Open Hole / 7" Casing Interval
Hazard
Risk Level
Mitigation Strategy
Running sands and gravels
Low
Maintain planned mud parameters, increase mud weight,
use weighted sweeps.
Stuck pipe
Low
Good hole cleaning, pre-treatment with lost circulation
material, stabilized BHA, decreased mud weight.
Abnormal reservoir pressure
Low
BOP training and drills, increased mud weight.
Lost circulation
Moderate ,
Reduced pump rates, mud rheology, add LCM.
Differential sticking
Moderate
Follow mud program, keep pipe moving when able.
Anti -collision
Moderate
Follow real time surveys very closely.
Hole swabbing on trips
Moderate
Trip speeds, proper hole filling (use of trip sheets),
pumping out or back reaming.
Getting casing to bottom
Moderate
Utilize proper drilling and hole cleaning practices, follow
mud program.
Fault crossings and concretions
Moderate,
Use developed best practices for concretion drilling.
1H-108 Drilling Hazards.doc
5/14/2018
0
3
Wellhead / Tubing Hanger / Tree
13-3/8" x 4-%2" MTM, 5M
Insulated Conductor:
Crossover below TH : 4-1/2" x 3-1/2" Tubing
_
20" Casing —RMP17
F� 10-3/4" 45.5#, L-80 HYD563
@ 1,835' MD
RA/PIP Tags @ 3,000'& 5,500' MD
3-1/2", 9.2 #, L-80, Hyd 563 - 3-1/2" MMG with SOV
Feed Through Packer 45: 5,680'MD
Multi Drop Gauge Mandrel
2.812" Cameo D Nipple
Upper MMG
Lower MMG
Feed Through Packer 94: 5,880' MD --
Multi Drop Gauge Mandrel —
Upper MMG
Lower MMG
Feed Through Packer 93: 6024' MD
Multi Drop Gauge Mandrel —
Upper MMG
Lower MMG
"D" Sand Perforations: 5721' - 5850' MD
Feed Through Packer 42: 6,180' MD
Multi Drop Gauge Mandrel
Upper MMG
Lower MMG
Feed Through Packer #1: 6,320"MD
Single Drop Gauge Mandrel
2.813" Cameo XN Nipple
Upper MMG
Lower MMG
Baker WIV
"B" Sand Perforations: 5916'- 6001' MD
Scraper/Magnet Assy
Dumb iron muleshoe
1H-108 Injector Well Design
PTD Wellbore Schematic
A4 Sand Perforations: 6059'- 6101' MD
A3 Sand Perforations: 6220'- 6274' MD
A2 Sand Perforations: 6395' - 6441' MD
r� 7" 26#, L-80, HYD563/TXP
@ 6,839' MD
Drill
7ma-MEWMam
DRAWN BY: ALKET MICI
ConocoAhllllps TLE: MIH LAYOUTRA4h1NG
DRON 3Y: ALHET VICl I :we ma, A. s e[e: ,
Attachment 6 BOP Confieuration
The following ram configuration will be utilized for the West Sak wells. Further details regarding the BOPE specifications can
be found with the Doyon 142 documentation on file with the State.
Loepp, Victoria T (DOA)
From:
Loepp, Victoria T (DOA)
Sent:
Thursday, May 24, 2018 8:14 AM
To:
'Tolman, Ben V'
Cc:
Bearden, J Daniel
Subject:
RE: [EXTERNAL]RE: Expedited PTD for 11-1-108, 1H-115
These two PTDs will be ready by June 1, likely sooner.
From: Tolman, Ben V <Ben.V.Tolman @conocophillips.com>
Sent: Wednesday, May 23, 2018 8:59 AM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov>
Cc: Bearden, J Daniel <J.Daniel. Bea rden@conocophillips.com>
Subject: RE: [EXTERNAL]RE: Expedited PTD for 1H-108
The 11-1-115 would be the next well after the 1H-108. Best estimate would be 6/16..
Ben Tolman
Drilling Engineer I ConocoPhillips, Alaska
(907)265-6828(o)1(307) 231-3550(m)
From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.aov]
Sent: Wednesday, May 23, 2018 8:19 AM
To: Tolman, Ben V <Ben.V.Tolman@conocophillips.com>
Cc: Bearden, J Daniel <J.Daniel Bearden conocophillips.com>
Subject: [EXTERNAL]RE: Expedited PTD for 11-1-108
What is the revised spud date for 1H-115? Will there be revisions to the submitted PTD package?
From: Tolman, Ben V <Ben.V.Tolman@conocophillips.com>
Sent: Wednesday, May 23, 2018 7:17 AM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.aov>
Cc: Bearden, J Daniel <1 Daniel.Bearden@conocophillips.com>
Subject: Expedited PTD for 1H-108
Victoria,
Good morning. We wanted to reach out this morning and contact you regarding a PTD for the 1H-108 that was
delivered to the AOGCC yesterday. Due to a last second change in the rig schedule, we are asking for an expedited PTD
approval on the 1H-108 (planned spud date of 6/4).
We are currently drilling the 1H-110 injector, which is the first well placed in the "south' block of our 1H NEWS
development program (see red outlined of "South Block" in 1H NEWS Development Nap below). While drilling the 8-
3/4" production section late Monday night and early Tuesday morning, we drilled though our 5 reservoir sands and
encountered 2 sands with oil, 2 sands that were wet, and 1 sand with what we believe is an oil/water contact. We are
needing an additional data point and time to adjust/calibrate our understanding of the southern fault block and any
knock-on effects that has on the last pent -lateral to be drilled (1H-104). Because of this, we are asking the state to help
us fast track the permit for the 1H-108 so we can drill the 1H-108 next. This will allow for a data point (up structure)
within the "south" block and give us some time to delineate where is the oil/water contact within each of these
sands. Knowing that information, will oe critical to help ConocoPhillips prudently dnd responsibly develop the south
block.
We would like to have a follow-up phone call today to further discuss any questions you might have. Please let us know
if there is any further info we can provide to help assist the 1H-108 in moving through the system.
1H NEWS Development Map
South Block where is extent of
oil/water contact?
Thanks,
Ben Tolman
Staff Drilling Engineer I ConocoPhillips, Alaska
(907) 265-6828 (o) 1 (307) 231-3550 (m)
H21
1H-110 IH -113
2
Lill
1
i
2
Davies, Stephen F (DOA)
From: Lehman, Nick R <Nick.R.Lehman @conocophillips.com>
Sent: Wednesday, May 23, 2018 8:52 AM
To: Davies, Stephen F (DOA)
Subject: RE: [EXTERNAL]RE: KRU 1 H-108 (PTD #218-067) - Question
Attachments: 1H-108 Updated AOR.PDF
Steve,
Thanks for the email. The 11-1-109 is outside of the quarter -mile plot from 11-1-108, but I went ahead and attached the
information for it below. The 1H-11 is inside the quarter -mile plot from 1H-108 but was mistakenly left off the quarter -
mile summary since it didn't flag any anti -collision. I updated the AOR to include 11-1-11's details. My apologies for this.
Please let me know if you have any questions.
Thanks,
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman@ConocoPhillips. com
From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov]
Sent: Tuesday, May 22, 2018 5:07 PM
To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Subject: RE: [EXTERNAL]RE: KRU 11-1-108 (PTD #218-067) - Question
Nick,
Do the tops of West Sak in KRU 1H-11 or 11-1-109 lie within the''/. -mile Area of Review for KRU 1H-108? If so, please
update the Zonal Isolation and Current Operations Summary table that accompanies CPAI's Attachment 1 to the Permit
to Drill application for 11-1-108.
Thanks,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(@alaska.eov.
From: Lehman, Nick R [mailto:Nick.R.Lehman@conocophillips.com]
Sent: Tuesday, May 22, 2018 4:24 PM
To: Davies, Stephen F (DOA) <steve.davies@alaska.Rov>
Subject: RE: [EXTERNAL]RE: KRU 1H-108 (PTD #218-067) - Request
Steve,
Apologies forjust now getting back to you. I've been in meetings non-stop since lunchtime. I went ahead and attached
11-1-108 WP22 above in case you still needed it. And no, 1H-108 will not be pre -produced.
Nick Lehman
Drilling Engineer I ConocoPhillips Alaska
Office (907)263-4951 1 Cell (832)499-6739
Nick. R. Lehman @ConocoPhillips.com
From: Davies, Stephen F (DOA)[mailto:steve.davies@alaska.eovl
Sent: Tuesday, May 22, 2018 3:57 PM
To: Lehman, Nick R <Nick.R.Lehman@conocophillips.com>
Subject: [EXTERNAL]RE: KRU 1H-108 (PTD #218-067) - Request
Nick,
Will this planned injection well be pre -produced for 30 days or longer, or will it be simply flowed back for cleanup?
Thanks,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(dalaska.gov.
From: Davies, Stephen F (DOA)
Sent: Tuesday, May 22, 2018 3:24 PM
To:'nick.r.lehman@cop.com' <nick.r.lehman@cop.com>
Subject: RE: KRU 1H-108 (PTD #218-067) - Request
Nick,
Never mind, I scanned the 1H-108 survey.
Thanks,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(dalaska.vov.
From: Davies, Stephen F (DOA)
Sent: Tuesday, May 22, 2018 2:54 PM
To: 'nick.r.lehman@cop.com' <nick.r.lehIna n@cop. com>
Subject: RE: KRU IH -108 (PTD #218-067) - Request
Nick,
Could I trouble you for an electronic file of the planned directional survey for the 1H-108 well? Having survey data in
Excel or ASCII -table format saves me about 20 minutes per Permit to Drill application.
Thank you,
Steve Davies
AOGCC
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.daviesPalaska.eov.
From: Davies, Stephen F (DOA)
Sent: Friday, May 4, 2018 12:20 PM
To: 'nick.r.lehman@cop.com' <nick.r.lehman@cop.com>
Subject: KRU 1H-115 (PTD #218-053) - Request
Nick,
I would like to ask a favor of you. There are two staff geologists at AOGCC, but one retired last week, so --for the near
term --I will be the geologist reviewing all Permit to Drill and Sundry applications for Alaska. It will save me time if CPAI
could provide proposed directional survey data in electronic form in addition to the printed survey provided with each
Permit to Drill application. Having survey data in Excel or ASCII -table format saves me about 20 minutes per application
(else I have to scan and convert each page to spreadsheet -format in order to load the data into my geoscience
workstation). If this is inconvenient, don't worry about it; it just cuts down application permit -processing time for
everyone.
Thank you,
Steve Davies
AOGCC
CONFIDENTIAUTY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission
(AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use
or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding
it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies(aalaska.cov.
Remark:
AOGCC
PTD No. 218-067 Coordinate Check
22 May 2018
INPUT
Geographic, NAD27
OUTPUT
State Plane, NAD27
5004 -Alaska 4. U.S. Feet
t/1
Northing/Y: 5980752. 521
Easting/X: 549570.972
Convergence: 0 22 45.09024
Scale Factor: 0.999902991
Corpscon v6.0.1, U.S. Army Corps of Engineers
KRU 1 H-108
Latitude:
70 21
29.51500
Longitude:
149 35
50.59500
OUTPUT
State Plane, NAD27
5004 -Alaska 4. U.S. Feet
t/1
Northing/Y: 5980752. 521
Easting/X: 549570.972
Convergence: 0 22 45.09024
Scale Factor: 0.999902991
Corpscon v6.0.1, U.S. Army Corps of Engineers
TRANSMITTAL LETTER CHECKLIST
WELL NAME:
PTD:
Development Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
No. , API No. 50- _
be function of the original
(If last two digits
Production should continue to reported as a
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 caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
PTD#:2180670
_.-_._... _.... �..,
A INC ..,a�n vii-4eV IDV
Company CONOCOPHILLIPS ALASK.
Well Name: KUPARUK RIV r WSAK 1H
Administration
17 Nonconven, gas conforms l4 AS31.05,030(j,1.A),(j.2.A_D) - - -
Initial Class/Type
NA
108 Program SER
SER / PFND GeoArea 890 Well bore seg
Unit 11160 On/Off Shore On
- -
1 Permit fee attached. - � �
- " " � � - "
Annular Disposal
Lease number appropriate
" - . � � - NA
_ _
- pique welt name and number
- -. Yes
-.-.--
- - - - - - - - - - " - - - - " -
4 Well located in.adefined_pool- - - - " - -
- �
- - - - - - - - -
- . _Entire Well IteS within ADL0025639.- - -
5 Well located proper distance from drilling unitboundary.
Yes
... - - - Kuparuk River, West Sak Oil Pool - 490150, governed by CO 406C - -
- _ _ _
6 Well located proper distance from other wells - - - - - - - - - -
_ _ _ Yes
Yes
- -
CO 406C, Rule 3; no restrictions as to well spacing except that no Ray shall be opened in a well closer
7 Sufficient acreage available in dolling unfit- - - - - - - -
- - � - -
--
. - .. . then 500.feet to"an extemal-property line where ownership or landownership changes.
-- -
8 If deviated, is wellbore platincludedWell
- -.
� - _ Yes
is moe than,
- - - - - - - - - -
- . _ more 500 feet from an external property line.
9 Operator only affected Darty. _ - - - . - . - . _ _
.... - Yes
-- -
- - - - - - -
10 Operator has.appropriate bond in force
- - - - - Yes
---.-- -
Appr Date
.- . -.. ---- -
11 -Permit can be issued without Conservation order
__ Yes
--
c� � 5/23/2018
- - _ _ _
12 Permit can be issued without administrative. approval
- - - - - Yes-
-
13 Canermit be ----------
P approved befpre 15 -day wait-
----"-- Yes..-.-
- - - - - - - " -
Yes
14 Well located within area andstrata authorized by Injection Order # (put 10# in. comments For-; Yes
) (
- - - - -
15 All wells. within 114 mileerea-of review Identified (For service well only)-
- - - - Area Injection Order No. 28 - " -
- . - . Yes .
16 Pre -produced injector: duration of pre production less than 3 months" (For service well only) No
- ... - . KRU 1H-09..1Hr11, 1H-13, 1H -15,_1-H 101, 1-H-102, 1H-103, 1H-109
18 Conductor stringprovided..
-
.. - 1 H-108 will not be Preprodueed..
Engineering
- - - " - - - I - _
- � - " - � - � - -
19 Surfacecagingprotects all"known USDWs
_ _ _ Yes -
- -
- - - 80' conductor set. --
20 CMT vol adequate"to circulate -on conductor $surf csg
e$ -
- " - " -surface casing shoe at 1835' MD - - -
21 CMT vol adequate to tie-tn long string to surf csg.
- Yes
_ - - - - 138% excess cement
-
22 CMT will cover. all known productive horizons
- NO
23 Casing designs adequate for C, T, B & permafrost- - . - -
- - - " - Yes -
- - - Productive_ interval will be -completed with cemented Productioncasingand perforated
24 Adequate tankage or reserve pit -
- - - . - . - . - Yes
25 If.a re -drill, has. a 10-403 for abandonment been approved - -
- - - . - I - . - Yes -
- _ - Rig has steel tanks; all waste to approved disposal wells
- - - - .
26 Adequate wellbore separation_ Proposed
- - . _ _ .. _ NA
_ _ _ _
27 If diverter r - uir - - - " - "
. eq. ed, does it meet regulations
- " - - - - - - "Yes
- Annti-collision analysis complete; no major risk failures
y 1
Appr Date
28 Drilling fluid program schematic $equip list.adequate
_ - . Yes
_
- - - -and
Diverter route meet regulations-
VTL 5/24/2018
29 ROPES, do they meet r - - - - - - - - - -
regulation - - - . - . -
- - " - - - " - - Yes
-
- - - - Max formation pressure is1782psig(8,6 Ppg EMW); willdrill w/ 8.8 to 10.0 -
PP9 EMW
30 ROPEPressrating appropriate; test to (put psig in comments)
_-
-
31 Choke manifold complier WAPI. RP -53 (May 84)
- - - - " - Yes _
- _ - MPSP is 1384 Psig; will test BOPs to 35Q0-psig"
32 Work will occur without operation shutdown
_ -.
. � . Yes-
- -.- -
" - -.-- -----.
33 Is presence of H2$ gas probable
Yes.
- - - - -
-----..
_ _ _
34 Mechanical.condition of wells within AOR verified -
-es (For service well only)
- - - - - - - -Yes -
H2S measures required.
Geology
35 Permit can be issued w/o hydrogen sulfide measures
_ - _ Yes . _
—
- - - All wells in AOR verified - -
_
36 Datapresentedon potential overpressure zones
- - - . - .No
- - H2S measures required, Well 1H -102 -measured 20RPm H2S on November 20, 2017.-
Appr Date
37 Seismic.analysis of shallow gas.zones
- - - - " - - Yes
Expect " -
- - -ed Ceservoirpressure is 8,6.ppg EMW; will be drilled with 8.8 10.0
SFD 5/22/2018
38 Seabed condition survey (if off -shore) _ -
- - - NA
r ppg, Mud.
-
39 Contact name/phone for weekly.
Y ogress reports [exploratory only]
NA
- - - " - "NA
Geologic
Corr missioner:
Engineering
Date: Date P c
Commissioner:
Date
IC
S(Ly Ii C,
V
