Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout217-083DATA SUBMITTAL COMPLIANCE REPORT
10/24/2017
Permitto Drill 2170830 Well Name/No. KUPARUK RIV UNIT 1C-04AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20547-60-00
MD 10808 TVD 6429 Completion Date 7/15/2017 Completion Status 1-0I1- Current Status 1-0I1- UIC No
REQUIRED INFORMATION
Mud Log No ✓ Samples No Directional Survey Yes
DATA INFORMATION
Types Electric or Other Logs Run: GR/Res
(data taken from Logs Portion of Master Well Data Maint)
Well Log Information:
Log/
Electr
Data
Digital
Dataset
Log Log Run Interval OHI
Type
Med/Frmt
Number Name
Scale Media No Start Stop CH Received
Comments
ED
C
28449 Digital Data
7/31/2017
Electronic File: 1C-04AL1 EOW - NAD27.pdf
ED
C
28449 Digital Data
7/31/2017
Electronic File: 1C-04AL1 EOW - NAD27.txt
ED
C
28490 Digital Data
6930 10808 8/11/2017
Electronic Data Set, Fitename: 1C-04AL1
GAMMA RES,Ias
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04ALl 21VID Final.cgm
ED
C
28490 Digital Data
8/1112017
Electronic File: 1C-04ALl 5MD Final.cgm-
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04ALl 5TVDSS Final.cgm-
ED
C
28490 Digital Data
P 8/11/2017
Electronic File: lC-04AL1 21VID Final.pdf.
ED
C
28490 Digital Data
a 8/11/2017
Electronic File: 1C-04AL1 5MD Final.pdf
ED
C
28490 Digital Data
P8/11/2017
Electronic File: 1C-04AL1 5TVDSS Final.pdf
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1 EOW - NAD27.pdf
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1 EOW - NAD27.txt '
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04ALl Final TO 10808.csv
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1 Final TO 10808.xlsx
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1 Survey Listing.txL
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1 Surveys.txt -
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-
04AL1 _25_tapescan_BH I_CTK.txt •
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-
04AL t _5_tapescan_BH I_CTK.txt '
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04AL1_output.tap .
ED
C
28490 Digital Data
8/11/2017
Electronic File: 1C-04ALl 21VID Final.tif•
AOGCC
Pagel of 2
Tuesday, October 24, 2017
DATA SUBMITTAL COMPLIANCE REPORT
10/24/2017
Permit to Drill 2170830 Well Name/No. KUPARUK RIV UNIT 1C-04AL1 Operator CONOCOPHILLIPS ALASKA, INC. API No. 50-029-20547-60-00
MD 10808 TVD 6429 Completion Date 7/15/2017 Completion Status 1 -OIL Current Status 1 -OIL UIC No
ED C 28490 Digital Data 8/11/2017 Electronic File: 1C-04AL7 5MD Final.tif
ED C 28490 Digital Data 8/11/2017 Electronic File: 1C-04AL1 5TVDSS Final.tif -
Log C 28490 Log Header Scans 0 0
Well Cores/Samples Information:
Name
INFORMATION RECEIVED
Completion Report YD
Production Test Informatiodo NA
Geologic Markers/Tops O
COMPLIANCE HISTORY
Completion Date: 7/15/2017
Release Date: 6/7/2017
Description
Comments:
Compliance I
Interval
Start Stop
Directional / Inclination Data O
Mechanical Integrity Test Information Y NA
Daily Operations Summary
Date Comments
Sample
Set
Sent Received Number Comments
Mud Logs, Image Files, Digital Data Y JA Core Chips Y
Composite Logs, Image, Data Files O Core Photographs Y / AA
Cuttings Samples Y NA Laboratory Analyses Y / A
Date:
AOGCC Page 2 of 2 Tuesday, October 24, 2017
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
RECEIVED
AUG 15 2017
WELL COMPLETION OR RECOMPLETION REPORT ANUAMU
la.Well Status: Oil❑ Gas❑ SPLUG❑ Other ❑ Abandoned ❑ Suspended❑
20AAC 25.105 20AAC25.110
GINJ❑ WINJ❑ WAGE] WDSPL❑ No. of Completions:
1b. Well Class:
Development 21 Exploratory ❑
Service❑ Stratigraphic Test El
2. Operator Name:
ConocoPhillips Alaska, Inc.
6. Date Comp., Susp., or
Abend.: 7/15/2017
14. Permit to Drill Number/ Sundry:
217-083
3. Address:
P.O. Box 100360 Anchorage, AK 99510-0360
7. Date Spudded:
7/11/2017
15. API Number:
50-029-20547-60.00
4a. Location of Well (Governmental Section):
Surface: 1509' FNL, 4221' FEL, Sec 12, T11 N, R10E, UM
Top of Productive Interval:
1982' FNL, 2252' FEL, Sec 11, T1 1N, R10E, UM
Total Depth:
4999' FNL, 3529' FEL, Sect, T11N, R10E, UM
8. Date TD Reached:
7/13/2017
16. Well Name and Number:
1C-04AL1
9. Ref Elevations: KB:94
GL: 61 BF:
17. Field / Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool -
10. Plug Back Depth MDfrVD:
N/A
18. Property Designation:
ADL 25649
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 562065 y- 5968727 Zone- 4
TPI: x- 558759 y- 5968228 Zone- 4
Total Depth: x- 557463 y- 5970481 Zone- 4
11. Total Depth MD/TVD:
10808/6429 '
19. DNR Approval Number:
ALK 467
12. SSSV Depth MD17 VD:
N/A
20. Thickness of Permafrost MDfrVD:
1834/1788
5. Directional or Inclination Survey: Yes 0 (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:
8148/6436
22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days
of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential,
gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and
perforation record. Acronyms may be used. Attach a separate page if necessary
GR/Res
23. CASING, LINER AND CEMENTING RECORD
WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT
CASING FT TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED
20 94 H-40 34 80 34 80 32 245 sx AS II cmt
133/8 72 N-80 33 2910 33 2708 171/2 1800 sx Fondu & 300 sx AS 11
95/8 47 L-80 30 6936 30 6258 121/4 800 sx Class G
23/8 4.7 L-80 6955 10808 6277 6429 3 Slotted Liner
24. Open to production or injection? Yes ❑� No ❑
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
SLOTTED LINER @ 7549 -10808 MD and 6544 - 6429 TVD
.,ONIPl_ET�ON
!7P7 "Per
Tit - 1_7
qtF Fp
L�
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD/TVD)
31/2 6986 6799/6122
6945/6268
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No ❑Q
20 AAC 25.283 (i)(2) attach electronic and printed information
DEPTH INTERVAL (MD) JAMOUNT AND KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production:
7/19/297
Method of Operation (Flowing, gas lift, etc.):
FLOWING
Date of Test:
7124/2017
Hours Tested:
12hrs
Production for
Test Period
Oil -Bbl:
371
Gas -MCF:
865 mscf
Water -Bbl:
1498
Choke Size:
28/176
Gas -Oil Ratio:
2,326
Flow Tubing
Press. 372 SI
ICasinq Press:
1 1220 psi
Calculated
24 -Hour Rate
Oil -Bbl:
Gas -MCF:
1725mc f
Water -Bbl:
2995
Oil Gravity - API (corr):
1 22.
Form 10-407 Rev' ed 5/2017 V 917,011 CONTINUED ON PAGE 2 RBDMS V,- UG 1 7 2017 Submit ORIGINIAL only
l �-t3 7122-117--lli!'7
28. CORE DATA Conventional Corals): Yes ❑ No 0 Sidewall Cores: Yes ❑ No 21
If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this 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
TVD
Well tested? Yes ❑ No ❑�
If yes, list intervals and formations tested, briefly summarizing test results.
Permafrost - Top
Surface
Surface
Permafrost - Base
1834
1788
Attach separate pages to this form, if needed, and submit detailed test
Top of Productive Interval
8148
6436
information, including reports, per 20 AAC 25.071.
Formation @ TPI - Kuparuk C
TO
10808
6335
Formation at total depth:
Ku aruk C
31. List of Attachments: Daily Operations Summary, Definitive Survey, SchematicS
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
cialeontolpoical repoct. production25.070.
32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: J. Ohlin er Contact Name: Keith Herrin /.i/7
Authorized Title: Staff CTD Engineer Contact Email: Keith.E.Herrifigdcop.com
Authorized Contact Phone: 263-4321
8
Signature: Date: 1-/�
INSTRUCTIONS
General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram
with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical
reports regarding samples or tests from a 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 -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Item 4b: TPI (Top of Producing Interval).
Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in 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 10-407 Revised 5/2017 Submit ORIGINAL Only
1C-06 Final CTD Schemati0
swan LdUSM.
®W36•MD
B'MD
1' MO
r
2611"Sahoe
0 ]916' MD
gas lM MAMrd®R631', 39M. 4997,
B617RKB
3.1? Cameo MMG gas lift mandrel ® 6712' RKB
B sksr 6040 &W pay @ 6]]0 R KB
Baker PSR®6]]6'RKB
Bakm FMLPoIun®6]9BRKB
312• Cam m OS MPPIn Q 6849 Rn w13.61111
Sakar Poor Boy OversM1ot®WOY RKB
3-1?IuWlg tall® WBS RK6(698iPOC)
x37 a�vNUMm Na`4<pml Wn
ipM WN nv��MSY�pNN
KUP PROD 1C-04
Lonocorr ti't(ps -
Na",Inc.
Weil Atlribllles
Max ogle & MD TD
WellbOrygpNUWI Fkltl Xame WallGom 81x0¢
500292051]00 KUPARUK RIVER UNIT PROD
ncl (°) MOIXKBI AGBUnpi
3]98 4,3pp.00 7,575.0
Comment 1-12alepm) el
SSSV: NONE 40 W101201fi
Mndalwn Entl wk KBGN pS pIB ReIMNOHe
URIZ, 1/2412015 39.01 22/1981
1PW,M16COne83;58AN
perke.mcIxN&
--""""'- -Last
xAXGEa va-
_ ................................:...°,55,,,55.
CONDUCTORIinn Awn S;
aAe.a
GASUFT:0,631J
SURFACE;3J.0.z.61ad
GASLIFT;3.9M<
GAS LIFi:gA82d
GABLIFTI0,67ae
GABDFT:8.34.1
GAauFr; 6pI1A
LOGTOR; 8.789)
B AGBr,s.770a
PeR;an..r
PACKEA:d.71se
xIPPLe qMa J
LvsasxDT. a,60v
.RNlExT a.t..z
PROYUCTION; 301{,8339-
PACKER ep"e]
APERF: 6.1e<A8.9M0-
_
UplS8.8e35
sOs;eAeaq C
IPERR7AS8.67,1400
ut LI NER:BAMF1aape.-
wxmackdz; 7,118A
w'Inedp pt:bw9
I'Idell.3Mp-,RIa.D-
Ceneeped......
LINER; 0.611.1-7.345..-
MnoYlbn w 11
pl (N(B) Eng DXB
Tag: SLA 7,24fi.0 121112018
/nnelallon LaGMaE BY
=%..son: CEMENT PLUG, TAG(CEMENT), ppenen
MILLED CEMENT Io6,B]4'
Entl wM
6,6 1]
casing s
Casing 0escnptwn Be In) IDje) Top OUR) Set OeptippRU) Se1Dleth"o)...W%Len11.,. Grant Top Tlini
CONDUCTOR Insulated 2D 10.940 34.0 80.0 800 94.00 H40 WELDED
32"
Casing wacnplien 00 On) IOOR) TOP MISS) 8N NOR OVUQ 8etwpm (rvO)... W.Lw Q.. Oni TeP Th.,
SURFACE 13318 12.34] 330 2,910.0 2,]0]. 8 72.00 N40 BTC
CssinB waniplion OD 6n) IO(In) TOPIXKBI BM"n"IXXB) 8e1"Pm RVD1-wLin g... S. Top Tlw4
PRODUCTION 9518 8.861 30.1 6.935.6 6,258.1 47.00 L-80 BTC
wsi., Deoripwn OO Un) ID(S) Top(ryKB) 8."penn dere .-PMTry01... WPLsn U... GR40 Top TMotl
LINER 7 6,276 6.612,1 7,5455.0 6,866.3 2800 K55 BTO
Liner Details ..
Tap UKBI Top RVD) (XKBI Top Incl V) I IMm eb Conn
NwM0.1 IS
(n)
ERTIEBACKSLEEVE
6,fii2.1 5935.8 5.85 TIEBACK BAKiIJ
6.151
6,618.2 3,941] 5.80 NIP BAKERSEALNIPPLE
6.151
8,821.5 5,945.0 55 HAIIUNGER B4KER LINER HANGER
6.151
6,631.6 5,9550 550 XO BUSHING BAKER XO CENTRALIZER BUSHING
6151
Tubing Strings
TubRwcaiPXon SNn9 Ma...
TUBING -WO -2015 3112
-4112 x3112 Qfi2.S
ID (I.)
2.992
TeP IKK81
27.8
ed wpm(M1..Sel
6,910.0
Dion, RVO)(...
6,2325
WIIIWh)
9.30
Grak
L -BD
iop Lonnmflan
BOB SN Mad
Cpppfe6wl Details 5555
_.
Top 1x118) Tap ITVD16U(0) TeP InU I'1 Item Des ]bonne lD
Cmn (in)
27.8 27.8 0.06 HANGER FMC GEN 3 HANGER WITH ON ACME LIFT THREAD 3.958
62.8 618 0.13 XOReducing CmMnver Pup4112"0TMx31)2-EUE8RJ 2992
6,769.3 6092.2 4.38 LOCATOR GBHLO SUB 2980
6,770.2 6 0932 438 SEALASSV 8040 SEAL ASSEMBLY 2.990
6,775.7 6,098.8 4.33 PBR BAKER 80-00 PBR(W) 4.000
6,798.0 6,1217 4.14 PACKER BAKER 4702 FHL RETRIEVABLE PACKER 2.960
6,849.3 6,1720 4.10 NIPPLE CANDO DS NIPPLE 2.813
6,901.7 6,224.3 412 OVERSHOT BAKER POOR BOY OVERSHOT 3.590
TUWn9 w%np4on 8din9 Na... to pn11 Tep nIK81 flet Oepm (H.. Selw 0
p1 jIVD)I... WIIIOfln GraOe Top ConnMlen
TUBING -ORIGINAL 3112 2.992 6,904.0 6,986.4 63D80 9.20 K-55 BTC
Culnpleflon Details
NominaNO
-'(dSM 'PlTVD11XKB) Tepmu r, item wa Com Un)
619192 6,241.7 4.00 SBRwIEXT BAKER KIMSBR 3.000
6,945.3 B, 81.8 4.04 PACKER BAKER FHL PACKER 3.000
6,983.5 6,305. 4.02 NIPPLE CAMCO O NIPPLE NO W(1.81-NIPPLERED R 2750
SET 911]114 -PULLED 2182015)
6,98 4 6,306.8 I 4.02 50.5 BAKER SHEAR OUT BOB 2.992
Ogler In Hole (Wireline retrievable pfuga. WIVes, pumps, fish. etc.)
Top(rvD) Topincl
Top (M1KB) (hK9 1°) ws Com Run Mk ID9n)
],126.0 6,448.0 3.80 Wh'PMktl2 SOTMOncb..XLWn W'z '52017 6000
7,150A 6472.0 3.90 WTlpstocksl BOT Renobota XL001Pstnck 132017 0000
6,5931 3.50 FISH E -LINE SPINNER 2'Long x IN- wide 8I20I2014
Perforations & Slots
Top VKS)
OUROKBI
ToM aO)
(aRB))
ame
wle
Spin,
(MOW
TYN
Com
,964.0
6,966.0
6,2864
8,280.4 G1,
10-04
UNR B,
W117
3.0
APERF
CHHES ARGES IS LE
CHARGESIS
120'PHASE)
7,008.0
],143.0
6, 10.1
6,470.0 10.
1044
C3, F2,
2R/1981
4.0
(PERF
],200.
7,2180
6,529.9
6,539.8 F1,
IC
UNIT O,
-04
Tl]/1981
4.0
IP RF
Cement SglMPSede
Top(M1KG1
BIm MKa)
Top (1VD)
MKB)
BM TND)
(XI(a)
Des
SIMDab
Com
fi,960.0
],268.0
6.282.4
6,539.1Cemenl
Plug
5282017
MILLEDWI BAKER MOTOR ANO TURNED DOWN
2.W BI -CENTER HYCALOn MIL L. MILL CEMENT
T06,974'RKB
Mandrel lnaen$
8n
N
Top pVD) wile Okh PMffiu TRORun
N Top(M1KB) MKS) MdM Model Be (in) 8M TYpe Two, (In) IW6 Ren.. Co.
1 2,831.1 2.411.5 CAMCO MMG 1112 GAB LIFT GLV RN 0.188 1,178.0 5222017
2 3,920.0 3,551.9 CAMC MMG 1 tl2 GAS LIFT OV RK 0250 0.0 522201]
9 4.982.21 4,39].] ICANICO M 1112 GAS LIFT DMV RK 0000 0.0 5211201]
d 5,678.0 5,010.9 CAMCO MISS 1112 GAB LIFT DMY RK0.000 0.0 17)12015
5 8.348] 5,6]1.0 CAMW MM 1112 GAS LIFT DMV RK 0.000 0.0 11 ilmi5
8 6,7124 I 6,035.5 I CA CO MMG t 112 GAUD" D RK 0.000 0.0 512VM17
Notes General & Safety
End D.I. Annotation
1VZ512002 NOTE: WAIVEREOWELLWXOACOMMUNICATION
WIW2010 NOTE: View SGlamaliCwl Alaska Sawenta.0
8/162014 NOTE LEAK AT 5763'; 3 SPINNER STILL IN HOLE.
1242015 NOTE: WORKO 9,11
KUP PROD
1C -04A
Lon000N11IIIIpS
Weil Attributes
Max Angle&MD
TD
a s in0.
WNIEore ApUNVI Field Xame
W¢IlOore StaWx
nd (•)
MO(ttRGI
AlB n10011
500292054]01 XUPARUKRIVERUNIT
PROD
102.fi4
;04505
10,875.0
Comment .1ppm) OW
SSSV: NONE 40 9/102010
pnnoNNon End Wle
LesIWO:
XBGM(XI
38.01
Big Helve Dais
21/11981
iC IN&.1.11. U:WAM
VeM MY
AMOlybn D9pIX 111X8) End OMe
ennaWbn
ay
End DMe
NwvGER 2)A __- -
asf Tag:
Rev Reason: SIGETRACK
CMI
lennalt
8114201]
35 rwvs
Casing 0e5crlpllan 00 911 IG (In) Top (XXB) bel wePies) SBt OepIM1 (IVU)...
WVLen (I... Gale
Top TR
ALINER 23/8 1992 8,149.3
10,6300 64024
4.60L410
STL
Liner Details
Nomlral JD
Tnp(XXB)
Top(NO)(NXB)
Top Incl(•)
Ikm gss
Com
(II
8,1493
S. 363
9].15
ALUMINUM
OHMorb Alulrinum Billet
1.920
BILLET
.ONDUCTOH mveaW 32:
34.aepA
B,1>1.4
8,433.4
9].5]
CASING
HANGER
SHOXy0epioyment5leeve
1.920
9,MIG
8,414.8
91.89
CASING
SXo4y Oepioymenf Sleeve
1.920
HANGER
GABOR;2.031.1
Notes: General&Safety
End Oeb
An -neon
NOTE:
SIIRFACE13.191ne
GA4 LIR: 3y2O.e
GASLIR:I,98t1
GAS LIR;5,8>80
Gp6LgT;Q%6.]
GA9LIR;6,)12,1
REILARiti
.Il B)]6]
PACKER:e,19n8
NIPRE: BM99
OVERSNOT:0.9O1.)
WVEXT;6.9168
PRODIJ PDM W I-G.Tee—
PACKER; 8,9058
APEAR".B ABABS.O
NIPPLE; BAB3.5
805; 6.900P
IPERF: ].098.0.].1<60
LeNNFIg8,900-0M(e
LINER; 0,612.1-7.605A
All LINER; 6A50110,00a0
A LINER'.0,14B310,0]OA��
KUP PROD
1 C-04AL1
L.QnQCQrjuRt}$
Well Attributes
IMaxAngle&MD
jT13
Ala9ka, InC.
xame
WPZZ"Slvaa
nd(') MO(M188(
"t
pd 9lm (10%,
500292054]fi0 KUPgRUK RIVER UNIT
W029054760l KU
PROD
10264 ),645.05
10,808.0
COI—IR NE(ppm) BWMnO1MIOn
401S/11112016
EaE Odle
Last VrV:
OBLN eIj
3901
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Tag: Rev Reason: SIDEfMCK jennalt
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Lasing 0escnplion 00 (int 10 (In( TOp (h'(8( SN
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10,1308.0 6,428.8 4S0 L-80
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9,D38.5
6,4208
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1.920
Notes: General Safety
En40ate
pnnOUliOn
NOTE: Blank liner6955b 1549' AAD
GA88FT; 3,091.1
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GASLIFT:33 A
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.11-INER:090411e.&EEII
1
EV I DATEBY CK I APP I DESCRIPTION RT-7-5-7-77-9-77 u< IAPP I DESCRIPTION
12 7/17/1 1 JAH I SZ I Rev. Per K150013ACS 13 8/21/1 NRB JAH Rev. Per K150013ACS
LEGEND ¢ ffiC 2
• EXISTING CONDUCTOR R53 PR C7:
Q AS—BUILT CONDUCTOR THIS SURVEY K pRUK; LOCAiION
GRAPHIC SCALE CPF1 C
o, 100 zoo coop
--�—j °2
PC A�yF 11
1 inch = 200 ft.
O
11+12 v
16 15 14
;..........
..:..:r ..,, D
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• y
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• •� ,,may^,� • (V 0 ^yyy
s •^°jry,��y y • : • ry^ o p : wry'\40,
• e ^ry ry 0 • : ^y • : p'p
• ry� � �83'
�30'
SEE SHEETS 2 & 3 FOR NOTES AND
LOCATION INFORMATION. S/�
70
.� (E, �...•• l 4
G:°♦1♦ SURVEYOR'S CERTIFICATE.
9th ° ♦ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERD 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 NEW DIMENSIONS AND
c JEREMIAH F. CORNELL Q� OTHER DETAILS PER THIS REVISION
♦i Jj. LS-12663
♦ F�'•., `,;S. ARE CORRECT AS OF JULY 16. 2015. LOUNSBURY
♦♦♦Fo Pf�o`�s & ASSOCIATES, INC.
1,,,,,��000j/.-'E'SSIONAI-� oxs encmeeas vurvrvew
AREA: IC MODULE: XXXX UNIT: D1
ConocoPhilli S DS1C
WELL CONDUCTORS
Alaska, Inc. ASBUILT LOCATIONS
CADD FILE N0. I DRAWING NO. __ , ,.,, _„ _. PART: I REV:
Haggerty -Sherrod, Ann (North(i. _rd Staffing Services)
From: Herring, Keith E
Sent: Tuesday, August 08, 2017 4:10 PM
To: Haggerty -Sherrod, Ann (Northland Staffing Services)
Subject: FW: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application
Attachments: 1C Pad As-Built-Revl3.pdf
Ann,
The numbers from the most recent as built should be used as this is the most up to date information.
Thanks,
Keith
From: Herring, Keith E
Sent: Thursday, May 25, 2017 3:37 PM
To: 'Bettis, Patricia K (DOA)' <patricia.bettis@alaska.gov>
Subject: RE: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application
Good afternoon Patricia,
Attached is the as built from 8/21/15. When placed into the CPAI Coordinate Converter I get the following for the surface
location of well 1C-04.
1509.93' FNL, 4221.83' FEL, Section 12, T11N, R10E, UM
So going off the most recent as built the numbers provided on the permit to drill would be correct. If you need further
information please let me know.
Thanks,
Keith Herring
CTD Engineer
907.263.4321 (Office)
907.570.2410 (Mobile)
700 G Street, ATO — 664
Keith.E.Hcrring@conocophillips.com
Ccntcc illips
Naska
From: Bettis, Patricia K (DOA)[mailto:patricia.bettis@alaska.eovl
Sent: Thursday, May 25, 2017 3:11 PM
To: Herring, Keith E <Keith.E.Herring@conocophillips.com>
Subject: [EXTERNAL]KRU 1C -04A (PTD 217-078): Permit to Drill Application
Good afternoon Keith,
On Form 10-403, Box 4A, it states the surface location of the well to be 1509 FNL, 4221' FEL, Section 12, T11N, R10E, U.M.
On the Well Completion or Recompletio- Report and Log Form 10-407, Box 4, the sur`ace location for the well is 1515' FNL,
1066' FWL, etc. Please verify which f� age is correct.
Thank you,
Patricia
Patricia Bettis
Senior Petroleum Geologist
Alaska Oil and Gas Conservation Commission
333 West 7th Ave., Ste 100
Anchorage, AK 99501
Tel: (907) 793-1238
CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation
Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged
information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended
recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to
you, contact Patricia Bettis at (907) 793-1238 or patricia.bettisPalaska.eov.
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
scan Time
End Time
Our (hr)
Phase
Op Code
Activity Corte
Time P -T -X
Operation
Start Oepm
(ftKB)
End Oepm (ftKa)
6/30/2017
6/30/2017
4.00
MIRU
MOVE
MOB
P
Continue check list, prep for Rig Move
0.0
0.0
14:00
18:00
6/30/2017
6/30/2017
2.50
MIRU
MOVE
MOB
P
Begin rig move to 1C -pad
0.0
0.0
18:00
20:30
6/30/2017
6/30/2017
2.00
MIRU
MOVE
MOB
P
Arrive on location, prep well for rig .
0.0
0.0
20:30
22:30
6/30/2017
7/1/2017
1.50
MIRU
MOVE
MOB
P
Spot sub module over well, and lay
0.0
0.0
22:30
00:00
RM
7/1/2017
7/1/2017
2.50
MIRU
MOVE
RURD
P
PJSM, follow post move check list,
0.0
0.0
00:00
02:30
secure cellar, landings, and walkways,
spot shop and Halfway house.
7/1/2017
7/1/2017
2.50
MIRU
MOVE
RURD
P
MU PUTTS, nipple up stack, energize
0.0
0.0
02:30
05:00
Komey unit, get RKB's
7/1/2017
7/1/2017
0.00
MIRU
WHDBOP
NUND
P
RIGACCEPT
0.0
0.0
05:00
05:00
7/1/2017
7/1/2017
1.30
MIRU
WHDBOP
RURD
P
Check all surface lines, perform valve
0.0
0.0
05:00
06:18
checklist.
7/1/2017
7/1/2017
2.40
MIRU
WHDBOP
RURD
P
Change out deployment line spool on
0.0
0.0
06:18
08:42
BOP
7/1/2017
7/1/2017
7.30
MIRU
WHDBOP
BOPE
P
Perform Initial BOPE test, test waivied
0.0
0.0
08:42
16:00
by Matt Herrera, 250 psi Low/4,000
psi High/2,500 psi annular. Test gas
alarms, Test PVT system. No Failures
7/1/2017
7/1/2017
2.50
MIRU
WELLPR
CTOP
P
PJSM, Stab coil, circulate, Test inner
0.0
0.0
16:00
18:30
reel iron
7/1/2017
7/1/2017
4.00
MIRU
WELLPR
CTOP
P
RU and trim 2,000' ft of coiled tubing
0.0
0.0
18:30
22:30
from reel #51196. length 14,956'
7/1/2017
7/1/2017
1.00
MIRU
WELLPR
CTOP
P
Test a -line, < 550 m -ohms, 65 ohms,
0.0
0.0
22:30
23:30
dress and ream end of coiled tubing,
install CTC, pull test CTC 35 k
7/1/2017
7/2/2017
0.50
MIRU
WELLPR
CTOP
P
Rehead BHI Upper Quick, test a -line
0.0
0.0
23:30
00:00
7/2/2017
7/2/2017
1.50
MIRU
WELLPR
CTOP
P
FIII surface lines, MU/test PDL's and
0.0
0.0
00:00
01:30
tiger tank line, 250 psi Low/1,500 psi
High
7/2/2017
7/2/2017
0.80
MIRU
WELLPR
MPSP
T
Phone service out, paging system
0.0
0.0
01:30
02:18
working, no response call valve shop
supervisor, unable to find valve crew,
found crew out at 2L, wait on
equipment to arrive.
7/2/2017
7/2/2017
0.50
MIRU
WHDBOP
MPSP
P
Valve shop truck on location, load/MU
0.0
0.0
02:18
02:48
lubricator and extentions, PJSM
7/2/2017
72/2017
0.70
MIRU
WHDBOP
MPSP
P
Stab Lubricator, PT 500 psi, pull BPV,
0.0
0.0
02:48
03:30
WHP 0 psi, RD equipment.
7/2/2017
7/2/2017
1.40
PROD1
RPEQPT
PULD
P
PJSM, WU BHA #1, Cement pilot
0.0
62.5
03:30
04:54
hole milling BHA with .9° AKO motor,
D331 slick gauge mill, M/U to coil and
surface test tools
7/2/2017
7/2/2017
1.70
PROD1
RPEQPT
TRIP
P
Trip in hole, EDC open pumping 1.5
62.5
6,970.0
04:54
06:36
BPM, post slack mgmt
7/2/2017
72/2017
0.50
PROD1
RPEQPT
DLOG
P
6970 Tie in, Tag TOC @ 6984
6,970.0
6,984.0
06:36
07:06
uncorrected, P/U and close EDC,
RBIH mill cement
7/2/2017
7/2/2017
0.50
PROD1
RPEQPT
MILL
P
6984 Mill Cement, 1.8 BPM Q 2714
6,984.0
6,995.0
07:06
07:36
PSI FS, BHP=3068, ROP=20 FPH.
with 1.8K DHWOB.
Page 1120 Report Printed: 711712017
. Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Stat Time
End Time
Our (hr)
Phase
Op Corte
Activity Code
Time P -T -X
Opeiabon
(flKB)
EM Depth (flKB)
7/2/2017
7/2/2017
0.10
PROW
RPEQPT
MILL
P
Stall at 6985, PUH. Stall again @
6,995.0
6,975.0
07:36
07:42
6995 Possible 7" contact, PUH to tie in
7/2/2017
7/2/2017
0.20
PROD1
RPEQPT
DLOG
P
Log K1 for -4' correction
6,975.0
6,994.0
07:42
07:54
7/2/2017
7/2/2017
0.10
PROD1
RPEQPT
TRIP
P
PUH, RBIH to mill
6,994.0
6,990.0
07:54
08:00
7/2/2017
7/2/2017
2.50
PROD1
RPEQPT
MILL
P
6990, Tag and stall, PUH, Roll TF to
6,990.0
7,034.0
08:00
10:30
105R, RBIH and mill .5', then roll TF
back to 285 ROHS, 1.77 BPM @ 2519
PSI FS
7/2/2017
7/2/2017
0.10
PROD1
RPEQPT
WPRT
P
Observed posible gamma spikes
7,034.0
6,975.0
10:30
10:36
match K1 when milling by, PUH to tie
in, PUW=36K
7/2/2017
7/2/2017
0.20
PROD1
RPEQPT
DLOG
P
Log K1 for -10' correction (total
6,975.0
7,002--
10:36
10:48
correction -14)
7/2/2017
7/2/2017
0.10
PROD1
RPEQPT
WPRT
P
Trip in to mill
7,002.0
7,024.0
10:48
10:54
7/2/2017
7/2/2017
3.80
PROD?
RPEQPT
MILL
P
7024', Mill, 1.81 BPM @ 2671 PSI FS,
7,024.0
7,125.0
10:54
14:42
BHP=3119, ROP=25 with 1.7K WOB
7/2/2017
7/2/2017 -
2.85
PROD1
RPEQPT
MILL
P
7125- 7155 ROP up to 39FPH slowed
7,125.0
7,210.0
14:42
17:33
back down to 30-34 FPH all with 1.7K
WOB, Possibly from pert interval, TD
cement Pilot Hole
7/2/2017
7/2/2017
4.30
PROD1
RPEQPT
REAM
P
PU at 10 fpm, dry drift pilot hole,
7,210.0
6,975.0
17:33
21:51
weight bobble at 6,989', ream
transition area 5 times @ 60 fph, initial
wieght bobble 1 k, ream clean to 05 k,
7/2/2017
7/2/2017
1.00
PROD1
RPEQPT
DLOG
P
Log the K1 correction of plus 1.5',
6,975.0
6,994.0
21:51
22:51
PUH Log the HRZ @ 6,810', don't
correct (minus 1.257), log the K1
correction of plus 0.5',
7/2/2017
7/2/2017
0.25
PROD1
RPEQPT
TRIP
P
PUH to log CCL, PUW 34 k
6,994.0
6,730.0
22:51
23:06
7/2/2017
7/2/2017
0.40
PROD1
RPEQPT
DLOG
P
Log CCL 16 fpm, continue IH tag TO
6,730.0
7,210.0
23:06
23:30
on depth
7/2/2017
7/3/2017
0.50
PROW
RPEQPT
TRIP
P
POOH, purring 1.78 bpm at 1999 psi,
7,210.0
6,810.0
23:30
00:00
open choke, performing FC @ 7,099',
no -flow
7/3/2017
7/3/2017
1.00
PRODt
RPEOPT
TRIP
P
Continue POOH
6,810.0
62.5
00:00
01:00
7/3/2017
7/3/2017
0.25
PROD1
RPEQPT
OWFF
P
Perform flow check, (no -flow), PJSM
62.5
62.5
01:00
01:15
7/3/2017
7/3/2017
0.75
PROD1
RPEQPT
PULD
P
LD, Milling BHA# 1
62.5
0.0
01:15
02:00
7/3/2017
7/3/2017
0.50
PROD1
RPEQPT
PULD
P
PJSM, load/MU Haliburton caliper on
0.0
0.0
02:00
02:30
skate. program tools, mark highside
7/3/2017
7/3/2017
0.50
PROD1
RPEQPT
PULD
P
MU BHI Coiltrak tools, hang off in
0.0
70.3
02:30
03:00
stump, MU INJH, surface test tools,
(good test)
7/3/2017
7/3/2017
1.25
PROD1
RPEQPT
TRIP
P
RIH w/ HAL caliper, filling trip sheet
70.3
6,975.0
03:00
04:15
every 1,000'
7/3/2017
7/3/2017
0.28
PROD1
RPEQPT
DLOG
P
Log the K1 marker correction of minus
6,975.0
7,300.0
04:15
04:31
1
13.5'
7/3/2017
7/3/2017
0.25
PRODt
RPEQPT
TRIP
P
Continue RIH
7,300.0
7,205.0
04:31
04:46
Page 2120 Report Printed: 7/1712017
Operations Summary (with Timelog Depths)
IC -04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
I
Stmt Time
End Tim
Dur (hr)
Phase
Op Code
Activity Code
Tme P -T -X
Operation
(W)
End Dep1h MKS)
7/3/2017
7/3/2017
0.25
PROD1
RPEQPT
DLOG
P
Heisitate for caliper arms.
7,205.0
7,205.0
04:46
05:01
7/3/2017
7/3/2017
0.20
PROD1
RPEQPT
DLOG
P
Log up at 50 fpm
7,205.0
6,598.6-
05:01
05:13
7/3/2017
7/3/2017
1.30
PROD1
RPEQPT
TRIP
P
6598 Stop and let Caliper arms close,
6,598.0
58.0
05:13
06:31
POOH
7/3/2017
7/3/2017
2.00
PRODt
RPEQPT
PULD
P
At surface, Flow Check, Lay down
58.0
0.0
06:31
08:31
BHA#2 from dead well, Stab on and
jet BOP stack
7/3/2017
7/3/2017
0.70
PROD1
WHPST
PULD
P
M/U BHA #3 3 1/2" monobore XL
0.0
72.4
08:31
09:13
whipstock with OH anchor, M/U to coil
and surface test
7/3/2017
7/3/2017
1.50
PROD1
WHPST
TRIP
P
trip in hole with whipstock, EDC open
72.4
6,985.0
09:13
10:43
7/3/2017
7/3/2017
0.20
PROD1
WHPST
DLOG
P
Log K1 for -13.5'
6,985.0
7,017.0
10:43
10:55
7/3/2017
7/3/2017
0.20
PROD1
WHPST
TRIP
P
Continue in to setting depth 7060.75,
7,017.0
7,060.0
10:55
11:07
Close EDC. Get P/U Weight @ 38K,
RBIH to set depth, Oriented to 90°
LOHS, Pumps on, See tool shift @
3993. Set down 3K - Looks good
7/3/2017
7/3/2017
1.30
PROD1
WHPST
TRIP
P
POOH, Stop at 6966 open EDC,
7,060.0
60.0
11:07
12:25
Continue OOH
7/3/2017
7/3/2017
0.60
PROD1
WHPST
PULD
P
Tag up at surface, Flow check well,
60.0
0.6-
12:25
13:01
PJSM, Lay down BHA #3
7/3/2017
7/3/2017
1.00
PROD1
WHPST
PULD
P
M/U BHA #4 Window milling BHA
0.0
72.0
13:01
14:01
with .6° Motor, 2.80 window mill, 2.79
String reamer, M/U to coil and surface
test Coil
7/3/2017
7/3/2017
1.40
PROD1
WHPST
TRIP
P
Trip in hole, EDC open.
72.0
6,985.0
1401
15:25
7/3/2017
7/3/2017
0.20
PROD1
WHPST
DLOG
P
Log K1 for -13.5', Close EDC,
6,985.0
7,020.0
15:25
15:37
7/3/2017
7/3/2017
0.20
PROD1
WHPST
TRIP
P
Continue trip in, Dry tag top of
7,020.0
7,150.0
15:37
15:49
whipstock @ 7150.4, Roll hole to
window milling fluid
7/3/2017
7/4/2017
8.17
PROD1
WHPST
MILL
P
PUH, Bring pumps online 1.8 BPM @
7150.0
7,162.0
15:49
00:00
3237 PSI FS. Make contact @ 7150.3,
Start milling window. No stalls getting
on tray
7/4/2017
7/4/2017
1.00
PROD1
WHPST
MILL
P
Mill/Drill rathole, 1.8 bpm at 3,874' psi,
7,162.0
7,171.0
00:00
01:00
BHP 3,806, WHP 402, IA 0, OA 696
7/412017
7/4/2017
2.00
PROD1
WHPST
REAM
P
Backream window area, 1.8 bpm at
7,171.0
7,151.0
01:00
03:00
3,664 psi, BHP 3,792, WHP 396, IA 0,
OA 698, As milled, 180° TF, 30° R and
-
L, dry drift dean.
7/4/2017
7/4/2017
1.00
PROD1
WHPST
TRIP
P
POOH
7,151.0
74.3
03:00
04:00
7/4/2017
7/4/2017
1.75
PROD1
WHPST
PULD
P
PJSM, PUD milling BHA#4, Crew
74.3
0.0
04:00
05:45
Change
7/4/2017
7/4/2017
1.50
PROD1
DRILL
PULD
P
PJSM, PD Build BHA# 5
0.0
72.3
05:45
07:15
7/4/2017
7/4/2017
1.75
PROD1
DRILL
TRIP
P
RIH, w/build section BHA, 2.5" ako
72.3
6,985.0
07:15
09:00
motor and RS HCC bi-center bit
7/4/2017
7/4/2017
0.30
PRODi
DRILL
DLOG
P
Log the Kt correction of minus t5'.
6,985.0
7,006.0
09:00
09:18
PUW 35 k
7/4/2017
714/2017
0.25
PROD1
DRILL
TRIP
P
Continue RIH thru window
7,006.0
7,171.0
09:18
09:33
Page, 3120 Report Printed: 7/1712017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Thee
EM Time
our (ho
Phase
Op Cade
Activity Cade
Time P -T -x
Operation
(Po(a)
End Depth (flKB)
7/4/2017
7/4/2017
2.50
PROD1
DRILL
DRLG
P
Working on TF, (a lot of interference)
7,171.0
7,211.0
09:33
12:03
OBD, 1.8 bpm at 3,700' psi, BHP
3,825.
7/4/2017
7/4/2017
0.25
PROD1
DRILL
DRLG
T
PUH, perform check survey from top
7,211.0
7,198.6
12:03
12:18
of WS down to 7,193', no change in
INC
7/4/2017
7/4/2017
0.25
PROD1
DRILL
DRLG
T
Attempt to reach bottom, 1.6 bpm at
7,198.6
7,198.6
12:18
12:33
3,400 psi, High vibrations level 3-4.
stalling motor at 7,198.6
7/4/2017
7/4/2017
0.25
PROD1
DRILL
DLOG
T
Log the for the RA, couldn't see RA,
7,198.6
6,964.0
12:33
12:48
WS might of went down hole, PUH
above WS
7/4/2017
7/4/2017
0.50
PROD1
DRILL
WAIT
T
Wait on orders
6,964.0
6,964.0
12:48
13:18
7/4/2017
714/2017
1.25
PROD1
RPEQPT
TRIP
T
POOH, for caliper min
6,964.0
72.3
13:18
14:33
7/4/2017
7/412017
0.50
PRODt
RPEQPT
OWFF
T
Check well for flow, PJSM
72.3
72.3
14:33
15:03
7/4/2017
7/4/2017
0.75
PROD1
RPEQPT
PULD
T
LD Build BHA# 5
72.3
0.0
15:03
15:48
7/4/2017
7/4/2017
0.50
PROD1
RPEQPT
SVRG
T
Service choke A and B, and Out MM
0.0
0.0
15:48
16:18
7/4/2017
7/4/2017
0.80
PROD1
RPEQPT
WAIT
T
WOH
0.0
0.0
16:18
17:06
7/4/2017
7/4/2017
1.00
PROD1
RPEQPT
PULD
T
PU BHA #6, HES,'Sondex MIT,
0.0
70.0
17:06
18:06
indexed to BHI coiltrack.
7/4/2017
7/4/2017
1.10
PROD1
RPEQPT
TRIP
T
RIH, adjust RIH speed to 115 ft/min
70.0
- 6,990.0
18:06
19:12
and did not slow for jewelry due to
memory tool program setting
7/4/2017
7/4/2017
0.20
PROD1
RPEQPT
DLOG
T
Attempt toTie into the K1, ran out of
6,990.0
7,008.0
19:12
19:24
time, fingers opening 19:17, stop RIH/
logging.
7/4/2017
7/4/2017
1.40
PROD1
RPEQPT
TRIP
T
POOH, PU Wt 32 k lbs.
7,008.0
70.0
19:24
20:48
7/4/2017
714/2017
0.60
PROD1
RPEQPT
TRIP
T
Flow check - good, PJSM, LD BHA
70.0
0.0
20:48
21:24
#6, memory caliper, over a dead well.
7/4/2017
714/2017
0.70
PROD1
RPEQPT
TRIP
T
Reconfigure MIT for 145 min, 135 min
0.0
70.0
21:24
22:06
from HES to Nabors hand off.
Function test in shed, PU BHA # 7 and
run over a dead well, stab on, bump
up, set counters.
7/4/2017
7/412017
1.10
PROD1
RPEQPT
TRIP
T
RIH,
70.0
6,985.0
22:06
23:12
7/4/2017
7/4/2017
0.20
PROD1
RPEQPT
DLOG
T
Tie into the Kt for a -15.5' correction.
6,985.0
7,017.0
23:12
23:24
7/4/2017
7/5/2017
0.60
PRODi
RPEQPT
TRIP
T
Continue to RIH to logging dept,
7,017.0
7,193.0
23:24
00:00
bottom of tool, 7193, fingers @ 7188'.
Wait for 26 min for fingers to open up.
7/5/2017
7/5/2017
0.20
PROD?
RPEQPT
TRIP
T
Continue to RIH to logging dept,
7,017.0
7,193.0
00:00
00:12
bottom of tool, 7193, fingers @ 7188'.
Wait for 26 min for fingers to open up.
7/5/2017
7/512017
0.30
PROD1
RPEQPT
DLOG
T
POOH @ 50 ft/min, logging w MIT,
7,193.0
6,600.0
00:12
00:30
-
park for 2 min.
7/5/2017
7/5/2017
1.00
PROD1
RPEQPT
TRIP
T
Continue to POOH.
6,600.0
70.0
00:30
01:30
i
Page 4/20 ReportPrinted: 711712017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Start Time
End Time
Dw(hn
Phase
Op Code
ActivityG de
Time P -T -X
Operation
(WB)
End Depth (111<13)
7/5/2017
7/5/2017
0.50
PROD1
RPEQPT
PULD
T
@ surface, flow check, PJSM, LD
70.0
0.0
01:30
02:00
BHA V. Clean floor
7/5/2017
7/5/2017
1.00
PRODi
RPEQPT
PULD
T
PJSM, PU BHA #8, BOT 3.5"
0.0
73.0
02:00
03:00
Monobore Whipstock XL W OH
anchors, stab on, open EDC.
7/5/2017
7/5/2017
0.20
PROW
RPEQPT
CTOP
T
Reset BHI database
73.0
73.0
03:00
03:12
7/5/2017
71512017
1.70
PROD1
RPEQPT
TRIP
T
RIH W whipstock.
73.0
6,952.0
03:12
04:54
7/5/2017
7/5/2017
PROD1
RPEQPT
WAIT
T
Wait for memory data processing
6,952.0
6,990.0
04:54
04:54
7/5/2017
7/5/2017
0.20
PROD1
RPEQPT
TRIP
T
Tie into the K1 for minus 13.5'
6,990.0
7,006.0
04:54
05:06
7/5/2017
7/5/2017
0.30
PROD1
RPEQPT
WPST
T
Contin to RIH w whipstock,
7,006.0
7,136.8
05:06
05:24
7/5/2017
7/5/2017
0.25
PROD1
RPEQPT
WPST
T
PUW 35 k, Close EDC, bring pump on
7,136.8
7,126.0
05:24
05:39
-line, shear at 5,200 psi, 5 k DHWOB,
set down additional 2 k DHWOB
7/5/2017
7/5/2017
1.00
PROD1
RPEQPT
TRIP
T
PUW 35k, POOH, w/tdpsheet and
7,126.0
60.3
05:39
06:39
manual straps
7/5/2017
7/5/2017
0.50
PROD1
RPEQPT
OWFF
T
At surface, check well for flow, PJSM
60.3
60.3
06:39
07:09
laying done BHA
715/2017
715/2017
0.50
PROD1
RPEQPT
PULD
T
LD BHA# 8
60.3
0.0
07:09
07:39
7/5/2017
7/5/2017
0.50
PROD1
WHPST
PULD
T
PU/MU window milling BHA# 9, move
0.0
74.3
07:39
08:09
INJH over MU to Coiltrak tools,
surface test was good, MU lubricator,
tag up, reset counters
7/5/2017
715/2017
1.20
PROD1
WHPST
TRIP
T
RIH, with Milling BHA# 9 second
74.3
6,990.0
08:09
09:21
attempt to make casing exit
7/5/2017
7/5/2017
0.25
PROD1
WHPST
DLOG
T
Log the K1 marker correction of minus
6,990.0
7,008.0
09:21
09:36
14.5', PUW 33 k
7/5/2017
7/5/2017
0.25
PROD1
WHPST
TRIP
T
Continue IH
7,008.0
7,126.0
09:36
09:51
7/5/2017
715/2017
3.75
PROD1
WHPST
MILL
T
Dry tag TOWS, PUH, bring pump up
7,126.0
7,128.0
09:51
13:36
to 1.8 bpm at 3,375 psi, BHP 3468,
WHP 0, IA 0, OA 476
7/5/2017
7/5/2017
5.20
PROD1
WHPST
MILL
T
OB Milling window 1.8 bpm at 3505
7,128.0
7,146.5
13:36
18:48
psi, BHP 3,452, WHP 0, IA 0, OA 611.
Bottoms up sample confirmed sand
and dark dirt, no evidence of cement.
Last 4 sample collected had
increasing percentages of dirt vs
metal.
7/5/2017
7/5/2017
1.60
PROD1
WHPST
REAM
T
Start reaming passes as milled (245*
7,128.0
7,146.5
18:48
20:24
ROHS) plus 1x @ 180 & +/- 30 from
as milled. Low WOB as well as
minimal mnotor work, time out and
send 5x5 sweeps. Dry drift - 25 ft/min
Clean.
7/5/2017
7/5/2017
1.20
PROD1
WHPST
TRIP
T.
POOH chasing sweeps to surface
7,146.0
55.0
20:24
21:36
7/5/2017
7/6/2017
2.40
PROD1
WHPST
PULD
T
Bump up, space out, PJSM, PUD&LD
55.0
0.0
21:36
00:00
BHA#9,
7/6/2017
7/6/2017
1.00
PROD1
WHPST
PULD
T
Continue to PUD and LD BHA #9.
0.0
0.0
00:00
01:00
Speed mill 2.80 go, 2.79 no go, string
reamer 2.80 no go. Good whorl
pattern on bottom of speed mill.
Page 5120 ReportPrinted: 7117/2017
e Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
slant Oeph
Stan Time
End Time
our (m)
Phase
Op Cade
Aadvity Cade
Time P -T -x
operation
WB)
End Deplh(KKB)
7/6/2017
7/6/2017
1.20
FROM
DRILL
PULD
T
PU & PD BHA #10, build drilling BHA,
0.0
70.0
01:00
02:12
2.5 °AKO, Break open return
micromotion, snake, flush, and blow
down. inspoect pack offs, stab on,
bump up, reset counters
7/6/2017
7/6/2017
1.60
FROM
DRILL
TRIP
T
RIH
70.0
6,980.0
02:12
03:48
7/6/2017
7/6/2017
0.20
PROD1
DRILL
DLOG
T
Tie into the K1 for -15' correction
6,980.0
7,000.0
03:48
04:00
7/6/2017
7/6/2017
0.20
FROM
DRILL
TRIP
T
Wt C1k29 k lbs, Close EDC, Continue
7,000.0
7,146.5
04:00
04:12
to RIH.
7/6/2017
7/6/2017
1.00
PROD1
DRILL
DRLG
P
Set rate 1.73 bpm in, 1.73 bpm out,
7,147.0
7,200.0
04:12
05:12
Free spin diff 524 psi CT 4073
OBD, CT Wt 15.5 k lbs, WOB 1.35 k
lbs. ROP 40 ft/hr.
Pick up and restart, Pu Wt=31 k lbs,
set rate 1.8 bpm, CT 4032 psi, free
spin 511 psi.
OBD, CT 3940 psi, CT Wt 13 k lbs,
WOB 1.2 k Itis, ROP 35 fl/ hr
7/6/2017
7/6/2017
0.20
FROM
DRILL
TRIP
P
PU 30 k lbs PUH to K1
7,200.0
6,975.0
05:12
05:24
7/6/2017
7/6/2017
0.30
FROM
DRILL
DLOG
P
Log Kt for a correction plus 15, Log
6,975.0
7,164.0
05:24
05:42
the RA @ 7132.5'
Offical Window Depths
TOW 7125.5'
BOW 7130.5'
RA 7132.5'
7/6/2017
7/6/2017
0.25
FROM
DRILL
TRIP-
P
RIH
7,164.0
7,200.0
05:42
05:57
7/6/2017
7/6/2017
2.50
FROM
DRILL
DRLG
P
BOBD 1.8 bpm at 3850 psi, BHP
7,200.0
7,322.0
05:57
08:27
3970, WHIP 436, IA 0, OA 675
7/6/2017
7/6/2017
0.20
FROM
DRILL
WPRT
P
Geo Wiper
7,322.0
7,322.0
08:27
08:39
7/6/2017
716/2017
0.20
FROM
DRILL
DRLG
P
BOBD 1.8 bpm at 4,106 psi, BHP
7,322.0
7,330.0
08:39
08:51
4,372, WHIP 328, IA 0, OA 673
7/6/2017
7/6/2017
1.25
FROM
DRILL
TRIP
P
TD Build section, pump 10x10 sweep,
7,330.0
72.2
08:51
10:06
POOH, open ECD @ 6,960'
7/6/2017
7/6/2017
0.25
FROM
DRILL
SFTY
P
At surface, space out, PJSM
72.2
72.2
10:06
10:21
7/6/2017
7/6/2017
1.00
FROM
DRILL
PULD
P
PUD, Build Section BHA# 10
72.2
0.0
10:21
11:21
7/6/2017
7/6/2017
1.25
FROM
DRILL
PULD
P
PD lateral BHA# 11, surface test tools,
0.0
78.2
11:21
12:36
good test
7/6/2017
7/6/2017
1.25
PRODt
DRILL
TRIP
P
Tag up reset counters, RIH
78.2
6,985.0
12:36
13:51
7/6/2017
7/6/2017
0.25
FROM
DRILL
DLOG
P
Log the K1 marker correction of minus
6,985.0
7,008.0
13:51
14:06
16.5', PUW 32 k
7/6/2017
7/6/2017
0.25
FROM
DRILL
TRIP
P
Continue IH
7,008.0
7,330.0
14:06
14:21
7/6/2017
7/6/2017
1.90
PROD1
DRILL
DRLG
P
BOBD 1.8 bpm at 3650 psi, BHP
7,330.0
7,458.0
14:21
16:15
3896, WHIP 294, IA 0, OA 639
716/2017
7/6/2017
0.25
FROM
DRILL
WPRT
T
PUH, BHI computer locked up, reboot
7,458.0
7,458.0
16:15
16:30
system computers.
716/2017
7/6/2017
1.00
PRODi
DRILL
DRLG
P
BOBD, 1.76 bpm, CT Wt 9.6 k Ibs,
7,458.0
7,523.0
16:30
17:30
WOB 2.57 k lbs, ROP 96 fUhr. Taking
influx, pinched in choke.
Page 6120 Report Printed: 7/1712017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
start Depth
SW Time
End TM
DurOil
Phase
Op Code
Activity Code
Time P -T -X
operation
MQ3)
Pse Depth (re(e)
7/6/2017
7/6/2017
4.00
PROD1
DRILL
DRLG
P
Drilling ahead, Well wore still showing
7,523.0
7,704.0
17:30
21:30
pit gains, pit sensors showing stable to
slight loss, shaker losses?, continue to
monitor and adjust choke. Hard stall
@ 7557'35k lbs PU, worked through
and ROP increased to 140 fUhr, sailed
5x5 sweep, Drill ahead to hard stall @
7571' PU Wt 35 k lbs. multiple hard
spots, near stalls to 7580'. Pull short
BHA wiper (100) as sweeps exit, PU
37 k lbs. 6 stalls total, clean drilling
with lower ROPs's-40-30fUhr. Pump
5x5, Short (100') BHA wiper as
sweeps transits the open hole, PU Wt
32k lbs, BOBD, ROP over interval on
bottom 45 fUhr
7/6/2017
7/7/2017
2.50
PRODi
DRILL
DRLG
P
OBD, free spin diff 1155 psi, CT Wt,
7,704.0
7,860.0
21:30
00:00
12.45k lbs, WOB 2.17 k lbs, ROP 70 k
lbs, annular 4410 psi, Continue to
monitor return rate, suspect MM out
may be reading 0.2 bpm high, Stall@
22:10 - 7729' appears to have surged
MM out and cleared up flow issue.
Another stall 7779', PU 36 k lbs. looks
like it took a drink, 7822', losses start
@ -0.25 bpm. healed in minutes by
7833'. ROP over interval 62 ft/hr
7/7/2017
7/72017
1.70
PROD1
DRILL
DRLG
P
OBD, Drilling break at 7898', ROP
7,860.0
8,006.0
00:00
01:42
-150 -120 fUhr. CT Wt 9.73 k lbs,
WOB 1.8k Ibs, Annular 4498, returns 1
for 1. Sent 5x5 sweeps, losses
started at 7944' climbed to 0.75 bpm
@ 7977' Multiple stalls @ 7979', PU
Wt 33 k lbs. sweeps out the bit.
Losses healed slightly to .5-.6 bpm.
ROP over interval 85 ft/min
7/7/2017
7/7/2017
0.60
PROD1
DRILL
WPRT
P
Wiper -850'. PU slowly to allow
8,006.0
7,170.0
01:42
02:18
sweeps to exit the well. PU Wt 27 k
lbs, slow for missed log data, 7473-
7422'. continue up hole, slow to 5
fit/min to calibrate annular friction loss.
attempt to target 11.4 ppm at window,
taking 0.25 bpm influx, pinch in choke
for 1-1. Pump rale 1.81 bpm in, 1.77
bpm out, 8.74 ppg in 8.79 ppg out,
annular 4050 psi, choke pressure 550
psi.
7/7/2017
7/7/2017
0.40
PROD1
DRILL
WPRT
P
RBIH, following new tripping schedule
7,170.0
8,006.0
02:18
02:42
1
for 12.3 ppg
7/7/2017
717/2017
2.80
PROD1
DRILL
DRLG
P
Rate 1.80 bpm in, 1.80 bpm out, Free
8,006.0
8,262.0
02:42
05:30
spin diff 1150 psi, CT 5200 psi
OBD, CT Wt 9.36 k lbs, WOB 2.30 k
lbs, ROP 104 fUhr. stall 8066, PU 32 k
lbs, stall 8197, 32k lbs.
717/2017
7/7/2017
0.65
PROD1
DRILL
WPRT
P
100wiper up hole
8,262.0
8,262.0
05:30
06:09
7/7/2017
7/72017
3.36
PROD1
DRILL
DRLG
P
BOBD 1.8 bpm at 5,258 psi, BHP
8,262.0
8,400.0
06:09
09:30
4303, WHIP 477, IA 0, OA 814
Page 7120 Report Printed: 711712017
- Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Siert Time
End Time
Ow(hr)
Phase
op Code
Activity Code
7me P -T -X
Operetion
SWA Dep h
MIKE)
End DepMWS)
7/712017
7/7/2017
0.50
PROM
DRILL
WPRT
P-
Wiper up hole for tie in and pressure
8,400.0
7,150.0
09:30
10:00
check, PUW 30 k
7,180' Choke Calibration
Pump rate=1.8 bpm
Return rate=1.79 bpm
MW IN=8.78 ppg
MW Out=8.84 ppg
Annular Press.=4146 psi
Choke Pressure=585 psi
WHP=545 psi
7/7/2017
717/2017
0.15
PROM
DRILL
DLOG
P
Log the RA correction of plus 2.0'
7,150.0
7,169.0
10:00
10:09
7/7/2017
7/7/2017
0.15
PROM
DRILL
WPRT
P
PUH above window, open ECD
7,169.0
6,978.0
10:09
10:18
7/7/2017
7/7/2017
0.45
PROD?
DRILL
CIRC
P
Pumping 2.02 bpm at 5000 psi, circ
6,978.0
6,978.0
10:18
10:45
bottoms up,
7/7/2017
717/2017
0.60
PROM
DRILL
WPRT
P
Shut down pump, close choke, after
6,978.0
6,978.0
10:45
11:21
pressure check still trending down on
pressure, go back to holding 11.4 ppg
at the window.
3792 psi=11.43
3868 psi=11.67
3849 psi= 11.61
3820 psi=11.55
7/7/2017
7/7/2017
3.25
PROD1
DRILL
TRIP
P
Close EDC, RIH to bottom
6,978.0
8,400.0
11:21
14:36
7/7/2017
7/7/2017
0.25
PRODt
DRILL
DRLG
P
BOBD 1.8 bpm at 5,000 psi, BHP
8,400.0
8,558.0
14:36
14:51
4032, WHP 257, IA 0, OA 768
7/7/2017
7/7/2017
0.25
PRODt
DRILL
WPRT
P
Wiper up hole, PUW 34 k
8,558.0
8,058.0
14:51
15:06
7/7/2017
7/7/2017
0.25
PROD1
DRILL
WPRT
P
Wiper back in hole RIW 14
8,058.0
8,556.0
15:06
15:21
7/7/2017
7/7/2017
1.90
PROD1
DRILL
DRLG
P
BOBD, 1.8 bpm at 5050 psi, BHP
8,558.0.
8,763.0
15:21
17:15
3992, WHP 191, IA 0, OA 832
7/7/2017
7/7/2017
5.60
PROD1
DRILL
DRLG
P
Quick pick up to get restarted, PU Wt
8,763.0
8,982.0
17:15
22:51
39 k IDS. RBIH, OBD, pump 5x5
sweep. CT Wt 9 k IDS, WOB 1.36 k
IDS, ROP 139 fl/hr. Encountered 0.35
bpm losses @ 8792', ROP dropped to
-20 111m. Losses fluctuating between
0.3-0.6 bpm. Losses healed to -0.1
bpm. Pumped another 5x5 and
regained string weight, neutral to +8 k
IDS. WOB 1.52 K ROP 90 it/ hr. PU to
restart 3x, PU Wt's 37 k lbs, Pumped
5x5, Allow sweep to exit the bit. CT
Wt -2.0 klbs, WOB 2.3 k IDS, ROP 30
ft/hr, CT 4911 psi, @ 1.75 bpm in,
1.68 bpm out. CT Wt 8.8 k IDS, as high
vis exits, ROP over interval drilled 39
ft/hr
717/2017
7/7/2017
0.30
PROM
DRILL
WPRT
P
Wiper trip 850', PU Wt 34k IDS. Saw
8,982.0
8,150.0
22:51
23:09
1
slight pulls at 8700 and 8650'.
7/7/2017
7/72017
0.30
PROM
DRILL
WPRT
P
RBIH, CT RI Wt 12.2 k IDS, clean trip
8,150.0
8,982.0
23:09
23:27
Page 8120 Report Printed: 711712017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stmt Depth
Start Time
End Time
Dir (hr)
Phase
Op code
Ac WW Cods
Time P-T-X
Operation
(ftKB)
Eml Depth (rtl(B)
7!7/2017
7/8/2017
0.54
PROD1
DRILL
DRLG
P
1.78 bpm in, 1.70 bpm out, CT 4872
8,982.0
9,031.0
23:27
00:00
psi, free spin diff 956 psi.
OBD, CT W17.5 k lbs, WOB 1.64 k
lbs, ROP 85 fUmin. CT weight
dropped to - 3 k lbs, w 2.3 k lbs WOB
after drilling 70 feet. Organized mud
swap. ROP over interval drilled 89 ft/hr
7/8/2017
7/8/2017
2.50
PROD1
DRILL
DRLG
P
Drilling ahead,
9,031.0
9,147.0
00:00
02:30
CT Wt 0 k lbs, WOB 1.67 k lbs, ROP
35 ft/hr, conver to 2 pit system, start
exporting mud outside. Multiple PU's
to restart, PU Wt 32-38 k Itis. new'
mud down the coil @ 1:39. New mud
@ the bit 9119'. ROP over interval on
bottom 46 ftlhr
7/8/2017
7/8/2017
2.00
PROD1
DRILL
DRLG
P
New mud all the way around, off
9,147.0
9,230.0
02:30
04:30
bottom CT 4580 psi, free spin diff
1070 psi
CT Wt 0.52, WOB 1.99 k lbs, ROP
150-20 ft/hr Ct 4866 psi, Annular
3877 psi, WH 127 psi. ROP over
interval 41 fUhr
7/8/2017
j 7/8/2017
3.00
PROD1
DRILL
DRLG
P
OBD, CT 5044 psi, CT Wt 6 k lbs,
9,230.0
9,350.0
04:30
07:30
WOB 1.7 k lbs, ROP 81 N hr
7/8/2017
7/8/2017
0.75
PROD1
DRILL
WPRT
P
Wiper up hole, PUW 34 k, perform jog
9,350.0
7,150.0
07:30
08:15
back in hole 100' from EOB
7/8/2017
7/8/2017
0.25
PROD1
DRILL
DLOG
P
Log the RA marker correction of plus
7,150.0
7,168.0
08:15
08:30
3.5',
7/8/2017
7/8/2017
0.85
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 15 k
7,168.0
9,350.0
08:30
09:21
7/8/2017
7/8/2017
1.00
PROD1
DRILL
DRLG
P
BOBD, 1.8 bpm at 4,931 psi, Diff=880
9,350.0
9,395.0
09:21
10:21
psi, BHP 4,103, WHIP 323, IA 0, OA
814, CTSW=4k, DHWOB=2.5 k, ROP
48 mph,
7/8/2017
7/8/2017
0.25
PROD1
DRILL
WPRT
P
"' 100% losses "`, PUW 50 k, PUH
9,395.0
9,295.0
10:21
10:36
1
100'
7/8/2017
7/8/2017
0.25
PROD1
DRILL
WPRT
P
RBIH
9,295.0
9,395.0
10:36
10:51
7/8/2017
7/8/2017
2.50
PROD1
DRILL
DRLG
P
BOBD, 1.8 bpm at 3840 psi, BHP
9,395.0
9,625.0
10:51
13:21
2916, WHP 0, IA 0, OA 820,
CTSW=15 k, DHWOB=1.2 k,
ROP=100 fph
7/8/2017
7/8/2017
1.10
PROD1
DRILL
DRLG
P
OBD, 1.77 bpm at 4,248 psi, BHP
9,625.0
9,701.0
13:21
14:27
3,301, WHP 101, IA 0, OA 757,
CTSW=O, DHWOB=1.8 k, ROP=83
fph
7/8/2017
7/8/2017
0.75
PROD1
DRILL
WPRT
P'
Wiper up hole, PUW 50 k
9,701.0
8,400.0
14:27
15:12
7/8/2017
7/8/2017
0.50
PROD1
DRILL
WPRT
P
Wiper back in hole RIW 15 k
8,400.0
9,701.0
15:12
15:42
7/8/2017
7/8/2017
1.00
PROD1
DRILL
DRLG
P
BOBD, 1.8 bpm at 4,594 psi, BHP
9,701.0
9,782.0
15:42
16:42
3,597, WHP 342, IA 0, OA 767,
CTSW=6.2 k, DHWOB=1.8 k,
ROP=77 fph
7/812017
7/8/2017
2.30
PROD1
DRILL
DRLG
P
B5,1.8 bpm at 4318 psi, BHP
9,782.0
9,870.0
16:42
19:00
3,569, WHP 435, IA 0, OA 748,
CTSW=minus 2 k, DHWOB=1.7 k,
ROP=69 fph, pick ups to get restarted,
55k increasing to 591k lbs.
Page 9/20 ReportPrinted: 711712017
-, Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Sten Depth
Slav Time
End Time
our (to
Phase
Op Code
Activity Code
Time P -T -X
Operabon
htl(B)
Ehd Deplh(RKB)
7/812017
7/8/2017
2.20
PROM
DRILL
WPRT
P
PU Wt 53 k IDS, pull wiper to window,
9,870.0
6,960.0
19:00
21:12
2750'trip. Saw some negative WOB
spikes from 9539 to 7992 and agian in
the build at 7155' as well as slight coil
weight overpulls from 9492-9136
around the loss zone.
7/8/2017
7/8/2017
0.30
PROM
DRILL
WPRT
P
Line up down the back side and pump
6,960.0
6,900.0
21:12
21:30
40 bbls stock power pro flush and 48
bbls lubed(1.5%) beaded (2 ppb)
stock power pro
7/8/2017
7/8/2017
0.40
PRODi
DRILL
DLOG
P
RBIH, attempt to log the K1, some
6,960.0
7,078.0
21:30
21:54
confusion with possibly a large
correction, RIH to log RA tag for a + 9
'correction.
7/8/2017
7/8/2017
1.00
PROD1
DRILL
TRIP
P
RBIH, carried 16-13 k CT weight until
7,078.0
9,870.0
21:54
22:54
- 9100' where there's a sharp tum
uphill. RIH Wt 8 kl bs,
718/2017
7/9/2017
1.10
PROM
DRILL
DRLG
P
Off bottom, 1.80 bpm in, closed choke,
9,870.0
9,906.0
22:54
00:00
free spin diff 1000 psi, CT 4440 psi,
annular 3910 psi. OBD, CT Wt 0 k
lbs, WOB 2 k lbs, ROP 90 Whir. Drill
10 feet, PU Wt 52 k lbs. Seeing
some 4's on vibration @ 9888'. PU's
52 climbing to 62 k lbs, five to ten
minutes OBD, for each PU. ROP
over interval 33 ft/hr
7/9/2017
7/9/2017
2.00
PROM
DRILL
DRLG
P
At 9907' PU 75k x2, cycled pipe to
9,906.0
9,951.0
00:00
02:00
80k pulled free. Drill ahead pumping 5
bbl lubed sweeps for every - 60 bbls
of power pro lite pumped. Able to stay
on bottom while lubes are coming out
and for - 10-20 min after. Lube up
active system to 1%. ROP over
interval 22 ft/hr.
7/9/2017
719/2017
0.80
PRODi
DRILL
DRLG
P
Drilled into something hard @ 9951'.
9,951.0
9,960.0
02:00
02:48
WOB 3.5 k CT Wt 0, 1300 psi diff.
ROP over interval 11 fVhr.
7/9/2017
7/912017
1.20
PROM
DRILL
DRLG
P
Drilling break @ 9960, 1.80 bpm, CT
9,960.0
10,024.0
02:48
04:00
Wt 5.2 k lbs, WOB 2.3 k lbs, ROP 110
fl/m, CT 4846 psi, annular 3797 psi.
Resistivity climbed significantly after
_
9940'. Sending 5 bbls beaded pills as
necisary. Weight transfer vastly
improved. ROP over interval 53 ft/hr
7/9/2017
7/9/2017
1.80
PROD?
DRILL
DRLG
P
OBD, CT Wt 0 klbs, WOB 2.7 k lbs,
10,024.0
10,090.0
04:00
05:48
ROP 60 ft/hr, CT 4885 psi, WH 750
PSI. ROP over interval 38t/hr
7/9/2017
7/9/2017
0.25
PROD1
DRILL
WPRT
P
Geo wiper up hole, PUW 41 k
10,090.0
8,975.0
05:48
06:03
7/9/2017
7/9/2017
0.25
PRODt
DRILL
WPRT
P
Geo wiper back in hole, RIW 13 k
8,975.0
10,090.0
06:03
06:18
719/2017
7/9/2017
4.70
PROD!
DRILL
DRLG
P
BOBD, 1.8 bpm at 4,500 psi,
10,090.0
10,400.0
06:18
11:00
DIFF=820 psi, BHP 3748, WHP 720,
IA 0, OA 817, CTSW=minus 2 k,
DHWOB=1.4 k, ROP 92 fph
DHD, here bleed down OA from 817
psi - 298 psi.
7/9/2017
7/9/2017
0.50
PROM
DRILL
WPRT
P
Wiper up hole, PUW 38 k, Pulled
10,400.0
9,400.0
11:00
11:30
heavy at fault/loss zone 9,400
Page 10120 Report Printed: 7117/2017
Operations Summary (with Timelog Depths)
1 C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Tans
End Time
Our (h)
Phase
Op Code
Actirny Code
Time PJX
Opanefbn
Stan Depth
(HKB)
End Depth (IIKB)
7/9/2017
7/9/2017
0.50
PROD1
DRILL
WPRT
P
Wiper back in hole, RIW 8 k
9,400.0
10,400.0
11:30
12:00
7/9/2017
7/9/2017
2.00
PROD?
DRILL
DRLG
P
BOBD, 1.8 bpm at 4,100 psi, BHP
10,400.0
10,595.0
12:00
14:00
3615, WHP 744, IA 0, OA 330,
CTSW=minus 4 k, DHWOB= 1 k, ROP
30 fph
Pumping 10 bbl beaded pills
frequently
7/9/2017
7/9/2017
0.75
PROM
DRILL
DRLG
P
OBD, 1.5 bpm at 3,486 psi, BHP
10,595.0
10,602.0
14:00
14:45
3637, WHP 690, IA 0, OA 331,
-
CTSW=3.3 k, DHWOB=2.1 k,
ROP=38 fph
7/9/2017
7/9/2017
2.60
PROD1
DRILL
DRLG
P
OBD, 1.8 bpm at 4,079 psi, BHP
10,602.0
10,675.0
14:45
17:21
3,815, WHP 720, IA 0, OA 331,
CTSW=3.3 k, DHWOB=1.9 k,
R0P=16 fph Drilled into hot gamma,
169 API. Called TD
719/2017
7/9/2017
1.30
PRODt
DRILL
WPRT
P
PUH wiping to window, PU 42 k lbs.
10,675.0
7,142.0
17:21
18:39
Pull heavy at 9455', CT weight up to
55k lbs, clean running is 35k lbs, RBIH
to 947Y PU Wt 58 k pull clean until
9415, then 44k lbs, continue to POOH.
7333', motor work and annular
fluctuations,
7/912017
7/9/2017
0.20
PROM
DRILL
DLOG
P
Tie into the RA tag for a + 15.5'
7,142.0
7,155.0
18:39
18:51
correction.
7/9/2017
7/9/2017
0.40
PRODi
DRILL
DISP
P
Pump 15 bbls clean mud down the.
7,155.0
6,947.0
18:51
19:15
back side,
7/9/2017
7/9/2017
1.70
PROD?
DRILL
TRIP
P
RBIH
6,947.0
10,630.0
19:15
20:57
slack CT weight—/ -3k lbs @ 9108' &
9148' continue in hole
stack CT weight 1-6k lbs plus WOB
spike to 1.2k Ibs @ 9397' continue in
hole
stack CT weight /-3k lbs @ 9399'&
9410' PU and RBIH to clean up 3
times
Continue to RIH clean passage
through the loss zone 9400'.
slack CT weight_b3kl lbs @ 10,000'
PU and continue in hole, appears to
be clean simply pushing BHA up hill.
CT RIH Wt fell of steadily from 145 k
lbs, to 10 k lbs @ 10,000 then fell off
more quickly as we pushed up hill to
10,630' and 5 k Ibs CT Wt.
-
7/9/2017
7/9/2017
1.40
PROD1
DRILL
DISP
P
PUH slowly while completing
10,630.0
9,180.0
20:57
22:21
construction of liner running pill. start
pumping @ 21:17, lay in 20 bbls of
beaded tubed liner running pill
from ... 10630 to above the loss zone
@ 9400'. Pulled 43 k from 9435 -
9415' clean was 38 k lbs. Painting
Yellow TD flag @ 9388.25'
Page 11120 Report Printed: 7/1712017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
stmt Depth
Start nme
End Time
Dir (M)
Phase
Op Code
Adivlty Code
Time P -T -X
Opmew
(WIG)
End Depth (10(9)
7/9/2017
7/10/2017
1.65
PROD1
DRILL
TRIP
P
POOH pumping PowerPro lite.
9,180.0
2,828.0
22:21
00:00
Pressure check at the window, parked
7,170' bit depth, annular pressure
3176 psi while pumping 8.8 ppg @ 0.5
bpm. sensor depth 6472 TVD, 9.4 ppg
EMW. Paint WhiteWindow flag @
5778.21' continue to POOH
7/10/2017
7/10/2017
0.50
PROD1
DRILL
TRIP
P
Contiue to POOH.
2,828.0 j
78.0
00:00
00:30
7/10/2017
7/10/2017
1.60
PROD1
DRILL
DISP
P
Complete dilution of stock KW fluid. @
78.0
78.0
00:30
02:06
1:09 start bullhead 90 bbls 10.0 ppg
KW (NaCl/NaBr) @ 1.63 bpm and WH
of 862 psi.
PJSM
7/10/2017
7/10/2017
1.20
PROD1
DRILL
PULD
P
Flow check, Well on a vac, LD BHA 11
78.0
0.0
02:06
03:18
over a dead well. lost 5 bbis in first 5
min. continue to fill hole. Examine
pipe for flat spots - good.
7/10/2017
7/10/2017
0.40
PROD1
DRILL
BOPE
P
Perform BOPE function test.
0.0
0.0
03:18
03:42
7/10/2017
7110/2017
0.50
COMPZI
CASING
PUTB
P
Prep floor for running liner, PJSM, .
0.0
0.0
03:42
04:12
total hole fill 35 bbls in last two hours.
7/10/2017
7/10/2017
1.40
COMPZI
CASING
PUTB
P
Makeup liner 32 joints, (1266.87') 2-
0.0
633.3
04:12
05:36
3/8" 4.6 #/rt L-80 slotted liner. Perform
safety joint drill, time 2:55 min - AAR
comments- good job, smooth,
efficient.
7110/2017
7/10/2017
0.40
COMPZI
CASING
PUTB
P
Clean up rig floor for crew change
633.3
633.3
05:36
06:00
7/10/2017
7/10/2017
1.00
COMPZI
CASING
PUTB
P
PJSM, continue PU lower liner
633.3
1,267.0
06:00
07:00
assembly 12 jts, close 2-3/8" combi's
7/10/2017
7/10/2017
0.75
COMPZI
CASING
PULD
P
PJSM, MU Coiltrak tools, surface test,
1,267.0
1,312.3
07:00
07:45
strip down and stab INJH, open 2-3/8"
combi's
7110/2017
7/10/2017
1.25
COMPZI
CASING
RUNL
P
Tag up, reset counters, RIH wtih
1,312.3
7,037.0
07:45
09:00
BHA# 12, 32 jts of slotted liner ported
bull nose and shorty deployment
sleeve.
7/10/2017
7/10/2017
0.15
COMPZI
CASING
RUNL
P
Stop and correct to the 6,000' EOP
7,037.0
7,012.3
09:00
09:09
flag, minus 24.78', PUW 35 k
7/10/2017
7/10/2017
0.40
COMPZI
CASING
RUNL
P
Continue RIH
7,012.3
8,225.0
09:09
09:33
7/10/2017
7110/2017
0.25
COMPZI
CASING
DLOG
P
Log the Kt marker correction of plus
8,225.0
8,245.1
09:33
09:48
8.0'
7/10/2017
7/10/2017
0.90
COMPZ1
CASING
RUNL
P
Continue RIH
8,245.1
10,630.0
09:48
10:42
7/10/2017
7/10/2017
0.25
COMPZ1
CASING
RUNL
P
PUW 44 k, bring pump up to 1.8 bpm
10,630.0
10,630.0
10:42
10:57
at 4,500 psi, open choke 1.0 bpm
returns, PUW 33
7/10/2017
7/10/2017
2.25
COMPZI
CASING
TRIP
P
Remove BHA from Counters, POOH,
10,630.0
44.2
10:57
13:12
1
pumping .72 bpm
7/10/2017
7110/2017
0.50
COMPZI
CASING
OWFF
P
Al surface, PJSM, Check well for flow
44.2
44.2
13:12
13:42
7/10/2017
7/10/2017
0.751C
MPZ1
CASING
PULD
P
LD setting tools
44.2
0.0
13:42
14:27
-
Page 12120 Report Printed: 7117!2017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Start Depth
Start Time
EM Time
Dur(hr)
Phase
Op Code
A vfty Code
Time P -T -X
operation
Mal
EM Depth (llKB)
7/10/2017
7/10/2017
1.50
COMPZI
CASING
PUTB
P
PJSM, MU upper liner section with 30
0.0
1,189.3
14:27
15:57
jts of slotted liner. Gose 2-318" combi's
7/10/2017
7/10/2017
0.50
COMPZI
CASING
PULD
P
PJSM, MU CoilTrak tools, surface test
1,189.3
1,234.7
15:57
16:27
tools (good test), open 2-3/8" combi's
7/1012017
7/10/2017
1.10
COMPZI
CASING
RUNL
P
Tag up, reset counters, RIH with
1,234.7
7,058.0
16:27
17:33
second liner assembly. BHA# 13
7/10/2017
7/10/2017
0.15
COMPZI
CASING
RUNL
P
Corrected to the EDP flag 5,800',
7,058.0
7,058.0
17:33
17:42
minus 18.5', PUW 35 k
7/10/2017
7/10/2017
0.30
COMPZI
CASING
RUNL
P
Continue RIH
7,058.0
8,145.0
17:42
18:00
7/10/2017
7/10/2017
0.25
COMPZI
CASING
DLOG
P
Log the K1 marker correction of plus
8,145.0
8,163.0
18:00
18:15
4.0'
7/10/2017
7/10/2017
0.40
COMPZI
CASING
RUNL
P
Continue RIH, work pipe from 8,414'
8,163.0
9,362.0
18:15
18:39
to 8,450'.
7/10/2017
7/10/2017
0.20
COMPZI
CASING
RUNL
P
Tag bottom at 9362', PUW 45 k, set
9,362.0
8,149.6
18:39
18:51
back down, bring pump up to 1.7 bpm,
open choke, 1.0 bpm returns, PUW 35
k
7/10/2017
7/1012017
1.50
COMPZI
CASING
TRIP
P
POOH, pumping 0.8 bpm at 1128 psi,
8,149.6
44.2
18:51
20:21
following MP 10.0 ppg schedule
7/10/2017
7/10/2017
0.50
COMPZI
CASING
OWFF
P
At surface, fill the hole, shut down
44.2
44.2
20:21
20:51
monitor well for flow, PJSM
7/10/2017
7/10/2017
0.25
COMPZI
CASING
PULD
P
LD setting tools
44.2
0.0
20:51
21:06
7110/2017
7/10/2017
0.50
COMPZI
CASING
PUTB
P
PU/MU Open Hole Anchored Billet
0.0
22.1
21:06
21:36
and 10' perforated pup joint.
7/10/2017
7/10/2017
0.25
COMPZI
CASING
PULD
P
PU/MU CoilTrak tools, stab INJH,
22.1
84.0
21:36
21:51
surface test tools (good lest). check
pac-offs
7/10/2017
7/1012017
0.60
COMPZI
CASING
SVRG
P
Tighten levelwind CTES counter
84.0
84.0
21:51
22:27
housing and encoder
7/10/2017
7/11/2017
1.55
COMM
CASING
RUNL
P
Tag up, reset counters, RIH with OH
84.0
6,370.0
22:27
00:00
Anchored Billet. Park @ 6925', PU Wt
33 k Its. SID pumps, Gose EDC.
continue to RIH.
7/11/2017
7/11/2017
0.20
COMPZI
CASING
RUNL
P
Continue to RIH
6,370.0
6,690.0
00:00
00:12
7111/2017
7/11/2017
0.20
COMPZI
CASING
DLOG
P
Lag the Kt for -14.5' correction
6,690.0
7,028.0
00:12
00:24
7/11/2017
7111/2017
0.60
COMPZ1
CASING
RUNL
P
Continue to RIH
7,028.0
8,170.9
00:24
01:00
7/11/2017
7/11/2017
0.10
COMM
CASING
RUNL
P
Tag up TOL„ PU Wt 38 k, RBIH, lag
8,171.0
8,171.0
01:00
01:06
up SID 3 k Its WOB, PU 35k to
neutral, orient to 180` ROHS.
sheared at 3400 psi, WOB climbed
from .9 k to 5k lbs. PU slightly RBIH,
S/D 5.8 k
7/11/2017
7/11/2017
1.60
COMPZI
CASING
TRIP
P
POOH, park @ 6636, open EDC,
8,171.0
81.0
01:06
02:42
continue to POOH holding 10.0 ppg
pressure schedule.
7/11/2017
7/11/2017
1.00
COMPZI
CASING
PULD
P
PJSM, bump up, flow check, on vac,
81.0
0.0
02:42
03:42
LD BHA#14 Billet setting assembly
over a dead well.
7/11/2017
7/11/2017
1.20
PROD2
STK
PULD
P
PU BHA #15, AL1 tat build drilling
0.0
72.0
03:42
04:54
assembly, stab injector, check 'tipper -
good, tag up, set counters. test tools
Open EDC.
Page 13120 ReportPrinted: 711 712 01 7
(, Operations Summary (with Timelog Depths)
a
1C-04
NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
smkoepfin
Sian Time
End Time
NOW)
Phe.
op code
Activity (:Ode
Time P -T -X
Operation
ME)
End Depth M(B)
7/11/2017
7/11/2017
1.40
PROD2
STK
TRIP
P
RIH holding 10.0 ppg EMW schedule
72.0
6,970.0
04:54
06:18
while turning coil over to PowerProw
light drilling system.
7111/2017
7/11/2017
0.20
PROD2
STK
DLOG
P
Tie into the K1 for a -13' correction.
6,970.0
6,990.0
06:18
06:30
7/11/2017
7/11/2017
0.60
PROD2
STK
TRIP
P
PU Wt 34k lbs, park, down on pumps,
6,990.0
8,150.0
06:30
07:06
close EDC. continue to RIH.
7/11/2017
7/11/2017
2.30
PROD2
STK
KOST
P
Dry tag TOB @ 8150'. PU, set rate,
8,150.0
8,150.5
07:06
09:24
1.80 bpm, CT 4130 psi, annular 4079
psi, WH 748 psi, free spin diff 425 psi,
RIH Wt 13 k lbs, OBD, Stall 7 times,
pump 10 bbl beaded pill, stall 3 more
times, fan pump to get started, beads
all going down the A hat, no benifit
seen with weight transfer. A hat
bridging off with aluminum billet
cuttings, annular pressure up to 4400
psi, WH 1100 psi. Crack choke to
maintain 11.4 ppg EMW at the
window. 1 bpm return rate.
Unloading 10.0 ppg KW fluid off the
back side, divert returns to the tiger
tank. Returns built to 100% as cuttings
were generated. Converting Power
Pro light to full system, viscing up
fluid.
7111/2017
7/11/2017
0.30
PROM
STK
KOST
P
Time drill ahead for 3 feet at - 0.9 k
8,150.5
8;151.5
09:24
09:42
lbs WOB and 1 f 1hr.
7/11/2017
7/11/2017
0.80
PROD2
STK
KOST
P
Time drill ahead at 3.6 Mr. 8.8 ppg
8,151.5
8,163.8
09:42
10:30
Power Pro light returns, brought fluid
back inside. Increase WOB to 2 k lbs,
ROP 18 Mr.
7/11/2017
7/11/2017
0.20
PROD2
STK
KOST
P
PU, Wt 33 k Ibs, dry drift billet clean.
8,163.0
8,163.0
10:30
10:42
7/11/2017
7/11/2017
2.00
PROD2
DRILL
DRLG
P
Set rate, 1.78 bpm in, 1.73 bpm out,
8,163.0
8,239.0
10:42
12:42
CT 4199 psi, free spin diff 425 psi- Ct
wt 7.32k Ibs, WOB 2.69 k lbs, ROP 14
-140 ft/hr.
7/11/2017
7/11/2017
1.20
PROD2
DRILL
DRLG
P
Having a difficult time dropping. Time
8,239.0
8,249.0
12:42
13:54
drill in an effort to drop.
7/11/2017
7/11/2017
1.00
PROM
DRILL
DRLG
P
Drilled ahead w good weight transfer
8,249.0
8,392.0
13:54
14:54
at - 129 fl/hr.
7/11/2017
7/11/2017
0.80
PROD2
DRILL
DRLG
P
Encountered losses of 0.2-0.3 bpm @
8,392.0
8,453.0
14:54
15:42
1 8392 - TO build section.
7/11/2017
7/11/2017
0.80
PROD2
DRILL
WPRT
P
PU wt 35 k lbs. PUH, sweep exiled
8,453.0
7,095:0
15:42
16:30
the bit @ 8042'. Chase sweeps
through build
7111/2017
7/11/2017
0.30
PROD2
DRILL
CIRC
P
Park, Open EDC, pump 1.7 bpm
8,453.0
7,095.0
16:30
16:48
through pilot hole, 2.0 bpm once
above the cement pilot hole.
7/11/2017
7/11/2017
0.30
PROD2
DRILL
DLOG
P
Park a the window, 6448' ND,
8,453.0
7,100.0
16:48
17:06
measure BHP @ 3918 psi, bleed the
well to 11.4 EMW and observe
pressure climb and stabilize at 3885
psi -11.6 ppg EMW.
7/11/2017
7/11/2017
1.30
PROD2
DRILL
TRIP
P
Continue to POOH holding one for
7,100.0
72.0
17:06
18:24
one returns, tag up, space out.
-fit 1120-17
7/11/2017
1.50
PROD2
DRILL
PULD
P
PJSM, PUD BHA#15, checks not
72.0
0.0
18:24
19:54
holding, close EDC, continue to PUD
with EDC closed.
Page 14120 Report Printed: 711712017
Operations Summary (with Timelog Depths)
1 C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
and Time
End Tune
Dur(hr)
Phase
Dp code
Activity Code
Time P-T-XOpead
a
(110)
EM Depth (110)
7/11/2017
7/11/2017
1.60
PROM
DRILL
CTOP
P
Slide in cart, remove checks, install
0.0
0.0
19:54
21:30
nozzle, stab cart on WH, pump
backwards, BO nozzle, changeout
UOC, pump forward
7/11/2017
7/11/2017
2.10
PROD2
DRILL
PULD
P
PJSM, PD BHA#16 (agtitator, .5°
0.0
78.0
21:30
23:36
AKO X-Treme motor, HYC C1 -3D bit),
lag -up, test MWD, check packoffs
7/11/2017
7/12/2017
0.40
PROD2
DRILL
TRIP
P
Begin RIH, surface test agitator, good,
78.0
3,960.0
23:36
00:00
open EDC
7/12/2017
7/12/2017
0.50
PROM
DRILL
TRIP
P
Continue RIH, holding increased
3,960.0
6,968.0
00:00
00:30
choke to maintain 1 -for -1
7/12/2017
7/12/2017
0.30
PROD2
DRILL
DLOG
P
Tie-in for a -15' correction
6,968.0
7,007.0
00:30
00:48
7/12/2017
7/12/2017
0.70
PROD2
DRILL
TRIP
P
Continue RIH
7,007.0
8,453.0
00:48
01:30
7/12/2017
7/12/2017
2.20
PROD2
DRILL
DRLG
P
OBD AL2 lateral, rate in = 1.75 bpm,
8,453.0
8,883.0
01:30
03:42
rate out = 1.78 bpm, BHP = 4165,
CWT = 1 OK, WOB = 1.4K, PU at
8684', PUW = 47K, average ROP
-130 fph
7/12/2017
7/12/2017
2.50
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 35K (geo
8,883.0
7,575.0
03:42
06:12
wiper to discuss pulling for a higher
bend)
7/12/2017
7/12/2017
0.60
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 13 k lbs (geo
7,575.0
8,883.0
06:12
06:48
wiper to discuss pulling for a higher
bend)
7/12/2017
7/12/2017
1.70
PROD2
DRILL
DRLG
P
OBD AL1 lateral, rate in = 1.80 bpm,
8,883.0
9,001.0
06:48
08:30
rate out = 1.60-1.80 bpm, BHP =
4057, CWT = 4K, WOB = 3.5k, POs
48k to 35k average ROP -69 fph
7/1212017
7/12/2017
1.50
PROD2
DRILL
DRLG
P
Broke through ROP up to 150 Mr.
9,001.0
9,138.0
08:30
10:00
OBD, CT 5713, WH 330 psi, 1.80 bpm
1 for 1 returns, Annular 4090 psi
CT Wt 4.6 k lbs, WOB 1.5 k lbs, ROP
20 to 200 ft/hr PU's 43 k - 51 k
Drilling stringers
average ROP -91 fph
7/12/2017
7/12/2017
0.70
PROD2
DRILL
DRLG
P
"' Lost all returns @ 9138'
9,138.0
9,180.0
10:00
10:42
PU, 36k lbs, PUH 100 feet, RBIH
losses healed to 0.5 bpm
OBD, CT 5009 psi, WH 330 psi, 1.80
bpm, returns 0.3 - 1.0 bpm Pump 20
bbl
7/12/2017
7/12/2017
0.20
PROD2
DRILL
WPRT
P
PU, 46 k lbs, wipe up hole above
9,180.0
9,180.0
10:42
10:54
innitial losses, RBIH, stack of @
9100', modulate pump, RBIH.
7/12/2017
7/12/2017
0.60
PROD2
DRILL
DRLG
P
BOBD, Losses worsened, 1.8 in 0.5
9,180.0
9,252.0
10:54
11:30
bpm out. Drilled ahead with little
healing of losses. Consult W town
engineering, decide to close choke.
average ROP -120 fph
7/12/2017
7/12/2017
0.90
PROD2
DRILL
WPRT
P
PU, 38k lbs. to window 33k Itis while
9,252.0
6,949.0
11:30
12:24
PUH. While pulling through the
window and @ min rate WH 310,
Annular 3000 psi, rate in 0.3 rate oy t
0.
Page 15120. Report Printed: 711712017
Summary (with Timelog Depths)
1C-04
lipOperations
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
'nine Log
Start Depth
SlartTime
End Time
0.(M
Phe.
op Code
Activity Code
Time P -T -x
Operation
MUS)
End Depth(M(B)
7/12/2017
7/12/2017
0.80
PROD2
DRILL
DISP
P
S/I choke, Line up to he back side,
9,649.0
9,959.0
12:24
13:12
bullhead 49 bbls bbls liner running pill,
increaded rate from 1 bpm to drilling
rate of 1.8 bpm, WH climbed to 1773
psi, annular climbed to 3934 psi.
7/12/2017
7/12/2017
0.20
PROD2
DRILL
DLOG
P
Log K1 for+6' correction
9,959.0
7,008.0
13:12
13:24
7/12/2017
7/12/2017
0.80
PROD2
DRILL
TRIP
P
RBIH pumping min rate through the
7,008.0
9,252.0
13:24
14:12
build, window clean, WOB spike @
7330', slight bobble at 7512, no motor
work or TF change, SID 9141,
pushed through.
7/12/2017
7/12/2017
2.00
PROD2
DRILL
DRLG
P
Set rate 1.80 bpm against a closed
9,252.0
9,450.0
14:12
16:12
choke, Free spin diff 1400 psi, CT
5600 psi
OBD, CT Wt 5 k lbs, WOB 2.6 k lbs,
ROP 130, WH 1169, Annular 4232 psi
Average ROP = 97.5 f tmin
7/12/2017
7/1212017
0.10
PROD2
DRILL
WPRT
P
PU 39k lbs, wipe to above the loss
9,450.0
9,000.0
16:12
16:18
zone @ 9138'. String weight fell off
above the loss zone.
7/12/2017
7/12/2017
0.10
PROD2
DRILL
WPRT
P
RBIH, RIH Wt 10-11k lbs
9,000.0
9,450.0
16:18
16:24
7/12/2017
7/12/2017
1.10
PROD2
DRILL
DRLG
P
Set Rate @ 1.78 bpm, CT 5050 psi,
9,450.0
9,522.0
16:24
17:30
WH 920 psi, free spin 1261 psi
OBD, CT Wt 5 k Itis, WOB 2.4 k lbs,
ROP 120 fUhr.
in stringers again
65 ft/hr over interval
7/12/2017
7/12/2017
2.60
PROD2
DRILL
DRLG
P
Continue drilling ahead, CWT= 7K,
9,522.0
9,701.0
17:30
20:06
WOB =1 K, BHP = 3748 psi, WHP =
663 psi, ROP -72 fph over interval.
7112/2017
7112/2017
0.30
PROD2
DRILL
WPRT
P
Wiper up -hole, PUW = 38K
9,701.0
8,992.0
20:06
20:24
7/12/2017
7/12/2017
0.30
PROD2
DRILL
WPRT
P
Wiper in-hole, RIW = 11.5K at 9650'
8,992.0
9,701.0
20:24
20:42
7/12/2017
7/12/2017
2.80
PROD2
DRILL
DRLG
P
BOBD, pumping 1.8 bpm, free spin =
9,701.0
10,045.0
20:42
23:30
-
1170 psi, CWT =4K, WOB =2.7K, rip
-
=1410 psi, BHP =3650 psi, WHIP =
570 psi, PUW check at 10,000'= 38K,
conimue drilling waiting for sweep to
exit the bit, ROP -123 fph over
interval
7/12/2017
7/13/2017
0.50
PROD2
DRILL
WPRT
P
Begin wiper up -hole, PUW = 40K
10,045.0
8,534.0
23:30
00:00
7/13/2017
7/1312017
0.60
PROD2
DRILL
WPRT
P
Continue WT to window
8,534.0
6,960.0
00:00
00:36
7/13/2017
7/13/2017
0.20
PROD2
DRILL
DLOG
P
Log K1 for+6' correction
6,960.0
6,960.0
00:36
00:48
7/13/2017
7/13/2017
0.80
PROD2
DRILL
SVRG
T
Remain in cased hole, replace leaking
6,960.0
6,900.0
00:48
01:36
seal on mud pump #1, maintaining
ECD
7/13/2017
7/13/2017
1.20
PROD2
DRILL
WPRT
P
Wiper in-hole to continue drilling, slight
6,900.0
10,045.0
01:36
02:48
weight bobble through window & at
7467', clean past thief zone at 9138',
slight bobble at 8,150' (billet), RIW =
9K at 10,025'
Page 16120 Report Printed: 7/17/2017
Operations Summary (with Timelog Depths)
1C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
SUM Depth
SartTime
End Time
Dur (hr)
Phase
Op Code
Acbvty Code
Time P -T -X
Opemeon
M(a)
End Depth (W-13)
7/13/2017
7/13/2017
1.80
PROD2
DRILL
DRLG
P
BOBD, free spin = 1150 psi, pumping
10,045.0
10,208.0
02:48
04:36
1.78 bpm, closed choke, BHP = 3826
psi, WHP = 728 psi, difficutly dropping
inclination, continue to get bounced up
from -85° to 87°- 88', PUW = 50K,
perform BHA wiper, ROP over interval
= 90 fph
7/13/2017
7/13/2017
1.30
PROD2
DRILL
DRLG
P
Continue drilling ahead attempting to
10,208.0
10,303.0
04:36
05:54
get to & hold 85' inclination, FS =
1141 psi, CWT = 6K, WOB = 1.5K,
BHP = 3600 psi, WHP = 490 psi, ROP
over interval = 95 fph
7/13/2017
7/13/2017
0.60
PROD2
DRILL
WPRT
P
PU Wt 43 k lbs, Pulling weight 38k to
10,300.0
8,980.0
05:54
06:30
36 k lbs above the loss zone, wiper -
1320'
7/1312017
7/13/2017
0.50
PROD2
DRILL
WPRT
P
RBIH, Wt 15 k lbs, saw theif zone at
8,980.0
10,303.0
06:30
07:00
9100, oriented wrond, most likely BHA
geometry.
7/13/2017
7/13/2017
6.10
PROD2
DRILL
DRLG
P
1.77 bpm, CT 4163 psi, free spin diff
10,303.0
10,644.0
07:00
13:06
1146 psi, WH 447 psi, annular 2544
psi.
OBD, CT Wt 4- 1 k WOB 3 - 1 k lbs,
ROP 160 - 20 ft/hr. PU's 41 k last two
56 and 59 it lbs, call wiper
ROP over interval = 56 fph
7/13/2017
7113/2017
0.60
PROD2
DRILL
WPRT
P
PU wt 59 k IDS, wiper ( 1644')
10,644.0
9,000.0
13:06
13:42
7/13/2017
7/13/2017
0.50
PROD2
DRILL
WPRT
P
RBIH, RIH Wt 14 it to 12k lbs
9,000.0
10,644.0
13:42
14:12
7/13/2017
7/13/2017
3.30
PROD2
DRILL
DRLG
P
1.84 bpm, CT 4408 psi, free spin diff
10,644.0
10,800.0
14:12
17:30
1230 psi, WH 447 psi, annular 3609
psi.
OBD, CT Wt3 k lbs k WOB 2.8 k IDS,
ROP 60-140 fl/hr. Grabby, looks to be
differential sticking, PU 58k lbs,
ROP over interval = 47 fph
7/13/2017
7/13/2017
1.60
PROD2
DRILL
WPRT
P
PU Wt 45 k lbs, POOH to window for
10,800.0
7,100.0
17:30
19:06
tie in and SBHP
7/13/2017
7/13/2017
0.20
PROD2
DRILL
DLOG
P
Obtain SBHP, Bit Depth = 7100',
7,100.0
7,132.0
19:06
19:18
sensor depth = 7051', TVD sensor =
6373', EMW of 10 ppg = 3314 psi,
shut down pumps, closed choke, allow
annular pressure to drop below 3314
psi as per procedure, pressure drops
below 10 ppg EMW, 10 ppg kills well
Log RA tag for +14.5' correction
7/13/2017
7113/2017
1.00
PROD2
DRILL
WPRT
P
RBIH, slight set down at -8440',
7,132.0
10,808.0
19:18
20:18
cleaned up area at 9145'& 9514', TD
confirmed at 10,808", begin sending
25 bbl liner running pill
7/13/2017
7/13/2017
3.50
PROD2
DRILL
DISP
P
POOH, lay in liner running pill (25 bbl)
10,808.0
78.0
20:18
23:48
from TO to thief zone at 9138', switch
to drilling fluid to surface, painted EOP
flag(5278.28), tag up, space out
7/13/2017
7/14/2017
0.20
PROD2
DRILL
DISP
P
Atsurface, open EDC, beginto
78.0
78.0
23:48
00:00
I
bullhead 90 bbl KWF down to thief
zone.
Page 17120 Report Printed: 7/1712017
Operations Summary (with Timelog Depths)
1 C-04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
Stan Depth
Stat Time
End Time
Dw (hr)
Phase
Op Code
Activity Corte
Time P -T -X
Dpenalion
MO)
End Depth (f!(S)
7/14/2017
7/14/2017
1.20
PROD2
DRILL
DISP
P
Continue to bullhead KWF to thief
78.0
78.0
00:00
01:12
zone at 9138', PJSM during bullhead
for LD BHA #16, flow -check (-5 min),
on a vac, -18 bbVhr losses, Gose
EDC
7/14/2017
7/14/2017
1.00
PROD2
DRILL
PULD
P
LD BHA #16 over a dead well, bit
78.0
0.0
01:12
02:12
came out a 2-2
7/14/2017
7/14/2017
2.80
COMM
CASING
PUTB
P
PJSM, PU Liner Run #1 (ported bull-
0.0
1,770.0
02:12
05:00
nose, 44 jnts slotted liner)
7/14/2017
7/14/2017
0.70
COMP72
CASING
PULD
P
PJSM (new driller on tour), PU BHA
1,770.0
10,810.9
05:00
05:42
#17 Liner Running Assembly Run #1
(shorty deployment, GS, & BHA), slide
in cart, stab on, bump up set counters,
inspect pack offs.
7/14/2017
7/14/2017
1.70
COMP72
CASING
RUNL
P
RIH with BHA#17, lineup down the
1,814.0
8,710.0
05:42
07:24
back side and start pumping liner
running pill down the back side. Tie
into window flag and correct -21.08'.
PU Wt 36 k lbs.
7/14/2017
7/14/2017
0.10
COMM
CASING
DLOG
P
Tie into K1 for +6' correction.
8,710.0
8,744.0
07:24
07:30
-
7/14/2017
7/14/2017
0.90
COMM
CASING
RUNL
P
Continue to run lowwer completion to
8,744.0
10,808.0
07:30
08:24
bottom. SO 10807.5'. 4.7k WOB PU
Wt 43 k lbs, -4, RBIH SID 5 MOB,
PU to slack CT Wt, Swap from
pumping down the back side to the
coil, increase rate to 1.45 bpm PU 33k
Itis string weight, WOB 0lbs
" Set bottom linersection, top @
9038.5', bottom 10808'
7/14/2017
7/14/2017
1.00
COMPZ2
CASING
TRIP
P
POOH, paint yellow window flag@
10,808.0
6,939.0
08:24
09:24
6954'. Continue to PUH, park at 6939'
bit depth, 6263' TVD, Inteci pressure
3291 psi, SID pumps trapping
pressure, Pressure trended down to
3259 psi in ten minutes. calculated
out at 10.00 ppg EMW.
7/14/2017
7/14/2017
0.20
COMPZ2
CASING
TRIP
P
Continue to POOH, pumping 0.53
6,939.0
6,145.0
09:24
09:36
bpm and pulling 100 ft/min, WH
climbed from 0 to 600 psi and annular
to 3,970 psi. Parked coil, came down
on the pump. Allowed presures to.
relax, BHP fell to - 10 ppg EMW,
verified no flow at surface, well on a
vac.
7/14/2017
7/14/2017
1.50
COMM
CASING
TRIP
P
Weight up KW from 10 ppg to 1.2 ppg.
6,939.0
6,145.0
09:36
11:06
1
1 Open EDC
7/1412017
7/14/2017
0.40
COMM
CASING
TRIP
P
RBIH, turning coil over to 8.92 ppg
6,145.0
7,120.0
11:06
11:30
liner running pill, 17 bbis total,
7/14/2017
7/14/2017
0.10
COMM
CASING
TRIP
P
Tie int othe RA tag for a+7'
7,120.0
7,146.0
11:30
11:36
7/14/2017
7/14/2017
0.80
COMPZ2
CASING
TRIP
P
Continue to RIH. chase the liner
7,146.0
9,029.0
11:36
12:24
running pill w 10.2 ppg, 1.33 bpm in,
1.27 bpm out, annular 3774 psi, choke
wide open, increase rate to 1.6 bpm
chasing pill to bottom, returns fell off
damaticaly.
7/14/2017
7/14/2017
0.60
COMPZ2
CASING
TRIP
P
PUH, laying in 17 bbl beaded liner
9,029.0
7,125.0
12:24
13:00
running pill, pumping 0.49 bpm in 0.11
bpm out,
7/14/2017
7/14/2017
1.80
COMPZ2
CASING
TRIP
P
Contiune to POOH, paint white flag @
7,125.0
45.0
13:00
14:48
4944', continue to POOH
Page 18120 Report Printed: 7/17/2017
Operations Summary (with Timelog Depths)
IC -04
Rig: NABORS CDR3-AC Job: DRILLING SIDETRACK
Time Log
-
Start Depth
Stat Torre
End Tore
Dur(hd
Phase
Op Code
AdV4 Code
Time P -T -X
Operation
(MB)
End Depth(WS)
7/14/2017
7/14/2017
1.00
COMP72
CASING
PULD
P
Bump up, open the stack at the floor,
45.0
0.0
14:48
15:48
flood up to the half drum, ovserve
flow, - none, cycle EDC closed,
opened and closed again after
pumping beads through it. - good.
PJSM, LD BHA #17 over a dead well.
7/14/2017
7/14/2017
0.40
COMPZ2
CASING
PUTB
P
Prep floor to run liner, buck up ported
0.0
22.2
15:48
16:12
bullnose and three pups (21.82'),
7/14/2017
7/14/2017
3.40
COMPZ2
CASING
PUTS
P
PU upper AL1 Lateral, 37 joints of
22.2
2,077.3
16:12
19:36
slotted & 19 joints of blank pipe, filling
hole, 4 bbls/hr hole fill
7/14/2017
7/14/2017
1.90
COMPZ2
CASING
PULD
P.
PJSM, Kick while running liner drill,
2,077.3
2,128.0
19:36
21:30
PU safety joint, monitor well, well is on
-
a vac, PU PBR, GS, & BHA #17,
inspect counter, loose chain, slide cart
back, stab on,
7/14/2017
7/14/2017
2.00
COMPZ2
CASING
RUNL
P
RIH with liner, pumping 8.7 ppg liner
2,128.0
6,955.0
21:30
23:30
pill down back side as per town
request (not to exceed 750 psi WHP,
12.4 ppg EMW with 10.2 ppg in the
hole), tie into EOP pipe flag for a -23'
correction, PUW = 35K at window,
reached setting depth, PUW = 40K at
set depth, RBIH, bring up pumps,
release off liner putting TOL at -6955'
MD (BOL at 9038.5'), PUW = 30K
7/14/2017
7/14/2017
0.30
COMPZ2
CASING
DLOG
P
Obtain SBHP at 6945' MD, TVD
6,955.0
6,945.0
23:30
23:48
sensor = 6245', Annular stabalizes at
- 2938 psi, EWM = -9 ppg
7/14/2017
7/15/2017
0.20
COMPZ2
CASING
TRIP
P
POOH, pumping KWF down backside
6,995.0
5,000.0
23:48
00:00
7/15/2017
7/15/2017
1.60
COMPZ2
CASING
TRIP
P
Continue POOH, stop at 720'& clean
5,000.0
44.0
00:00
01:36
cart/injector for summer maintenance
replacement.
7/15/2017
7/15/2017
0.60
COMPZ2
CASING
PULD
P
PJSM, flow check, LD BHA #18 over
44.0
0.0
01:36
02:12
1
1
dead well
7/15/2017
7/15/2017
0.90
DEMOB
WHDBOP
FRZP
P
Slide in cart, stab on, PJSM, bullhead
0.0
0.0
02:12
03:06
30 bbl diesel at .8 bpm
7/15/2017
7115/2017
0.60
DEMOB
WHDBOP
CIRC
P
Jet stack, displace coil to seawater
0.0
0.0
03:06
03:42
7/15/2017
7/15/2017
1.50
DEMOB
WHDBOP
MPSP
P
PJSM, RU, lubricate in BPV, RD
0.0
0.0
03:42
05:12
7/15/2017
7/15/2017
2.10
DEMOB
WHDBOP
CIRC
P
Slide in cart, stab on, blow down reel,
0.0
0.0
05:12
07:18
PUTZ, & surface lines w/ N2 (SLB)
7/15/2017
7115/2017
6.00
DEMOB
WHDBOP
CIRC
P
Secure reel, remove inner reel
0.0
0.0
07:18
13:18
iron,pressure bulkhead, un stab,
secure pipe.
7/15/2017
7/15/2017
3.70
DEMOB
WHDBOP
CIRC
P
Drop stripper off injector, swap bag
0.0
0.0
13:18
17:00
( annular). blow down steam,
disconnect at the PUTZ. Start ram
swaps. Start motors, swap off high line
power to generators - 4:00 pm
Page 19120 Report Printed: 7/1712017
.
Operations Summary (with Timelog Depths)
1C-04
Rig:
NABORS CDR3-AC
Job: DRILLING SIDETRACK
Time Log
start Depth
Stat Time
End Time
Dur (hr)
Phase
op Cm.
Ad ity Cade
Te P -T -X
opmtti
(fIKB)
End Depth (MB)
7/15/2017
7/15/2017
4.30
DEMOB
WHDBOP
RURD
P
Breakdown TT hard lines, break down
0.0
0.0
17:00
21:18
scaffolding, NES trucks arrive at
-19:30 hours, PJSM, plan moving to
edge of 1C -Pad, raise/roll pits, work
RDMO check list, RU & spot service
module to pad edge, regain COMMS.
7/15/2017
7/16/2017
2.70
DEMOB
WHDBOP
NUND
P
ND BOPE, break tree at flow -cross,
0.0
0.0
21:18
00:00
install Otis quick union on tree, RU,
move, & spot sub module (witnessed
by DSO), begin working to pick reel
out of sub module, begin work on PDL
(summer maintenance).
" Rig Released 24:00 hours
7/15/2017
Page 20120
Report Printed: 711712017
`'
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1C Pad
1 C-04AL1
50-029-20547-60
Baker Hughes INTEQ
Definitive Survey Report
27 July, 2017
BA ER
hUGHES
GE.m,,,
.�
Cono4hillips
ConocoPhillips
Sample Date
Decll0mlon
Definitive Survey Report
Dip Angle
Cannel
ConocoPhillips(Alaska) Inc-Kupt
Local Co-ordinate Reference:
We111C-04
Profess,
Kupamk River Unit
WD Reference'.
1C-04@94.00usft(1C )
Sha:
Kupamk lC Pad
MO reference,
1C -04®94.01(1G04)
Well:
IC -O4
North Reference:
Tme
Weighers:
1004
Suresy Calculation Method:
Minimum Curvature
Ni
1s,-04
Database:
EDT Alaska Sandbox
Preheat
Kupamk River Unit NOM Slape Alaska, United States
Map System:
US State Plane 1927 (ExaU solution)
System Datum: Mean Sea Level
Geo Datum:
NAD 1927 (NAOCON CONUS)
Using W@II Reference Point
Map Zone:
Alaska Zone 04
Using geonetic scale
factor
Wall
1C-04
Vertical Section:
Well Fashion
♦WS 000 usfl
Northing: 5.968,]2).00usfl
.PJ -W
DUeNod
+V.W 0.0 use
Easting: 562O65.00usfl
Position Uncertainty ON usfl
Wellhead Elevation: usfl
Wellesre
1C-04ALl
BA ER
1�UGHE9
Latitude: 20° 19' 30 322 N
Lon9ltbde: 149.29'48.207 W
Ground Level: 0.00 usfl
Magnahcs
Model Name,
Sample Date
Decll0mlon
Dip Angle
Feel StrMpth
I°I
I°I
(ni
BGGM2016
8IV2017
_ ..
.._.
1755
8095
..
57,542.29
Design
1C-04AL1
.._ _ _.
_.. ...
Audit Nates:
Version
10
Phase: ACTUAL
The On Depm:
8,14551
Vertical Section:
Depth From (TVD)
.WS
.PJ -W
DUeNod
both)
(daft)
(nae)
(1)
3350
000
000
320.00
2rz72017 1:45:08PM PBge2 COMPASS50ro.14ew11e5
�-
ConocoPhillips
ConocoPhillipsuyM16s
0
9
Definitive
Survey Report
Rampaay:
ConocoPhlllips(Alaskd)
Inc.-Kup1
Local Co-erdlnale Reference:
Wal 1C-04
Proem:
Kupamk River Unit
WD Raterence:
1C-04@M00us6(IC-04)
SIN,
Kupamk I
Pad
MD Reference:
1C-04@ 94.00usk(1U04)
Well:
1C-04
North Reference:
True
Weillu, ne
1C-04
Survey CMculation Mmhom
Minimum Cwvalure
Oesi9n:
1C-04
Database:
EDT Alaska Sandbox
Survey Program
Wb 71142017
From
To
Sunni
gully
(udal
lusty
Survey ryMliam)
Too Mama
DeaMptlee
Start Data
Eed Dam
100.00
7,12200
1CA4 (1004)
B068-GYR0
Bpa,-Sun BOW 9yro muXishot 812512000
7,125.50
7,17587
1C -04A MWD-INC(1C
A)
MWD4NCQONLY
MW0.1NC ONLY RUDER
]/2@01]
]13201]
720586
8,145.51
iC-04A MWD(1C-0450)
MWD
MWD-6landard
7I3120Y7
7WO17
8,148.30
8,226.75
10-04AL1 MWO-INC (1C-04AL1)
MWD -INC ONLY
MWUINC ONLY_FILLER
]110201]
]1111201]
8254 87
10,765.85
1C-04ALI MWD(1C-04ALl)
MWD
MWD-6landald
]1111201]
]113201]
BurveY
T
-
Map
Map
Vemcal
MO
Inc
An WO
TVD55
-NIS
-V-W
DlS
(draft)
(1)
(°1 tusk)
luck)
(usk)
d.")Ro
Round,
kn9
Easme
auction Survey Tool Na
Annotation
(ft)
(1) MOO
(k)
8145.51
R7 08
280.01 6,436.]2
6342 ]2
<7182
3.30]61
5,988,22]09
55876112 1589
1763.65 MD
TIP
8.148.30
9713
280.39 6,436.37
6.3423]
-071.33
-3,31033
5986.228.35
55875800 1363
1,]66.]0 MW61NC_ONLY (4)
KOP
8,181.39
915]
287.58 6,433.85
6,339.5
-46336
-334231
5,08,20.0
5$8726,95 2].35
1.7044 MVAD-I _ONLY(4)
Illtmp0lmd Aeinlum
8,2119.41
M91
293W (1433.50
6339.5
453.52
3,3x.63
5.9x25.5
558,]03.5 nM
1,817.83 MAN-INC_ONLY (4)
lrtemaleddAzdddnh
8M 75
x.02
N7 32 6,433.54
6.3x.54
446.07
$384.19
5,9x.253.00
55x,684.94 21.52
1,833.60 MND -INC ONLY (4)
Intemlaled kdanutn
8,254.8]
&22
333.39 6,435.00
6,341.00
-,21893,406.40
5,968266,9734 9]
558.WB2 20.
153.03 MNn (5)
First G00d Sune,
8,2&85
5.]3
306.88 6,4WW
6,34363
414.71
-3,432.82
5,58283.0
5586Kx 12.64
1,x9.09 MWD (5)
8,314.60
85.0
313.80 6,439.56
6,U5,%
-395.33
-3,4063
59x,003.14
55861309 orm
1,91839 MWD (6)
8,34507
8570
3180 8,44151
8,34051
-37369
3,47660
5.9x.324.61
550,591& 14.43
1,940.45 MWD 151
8.3]4.]3
5.60
32383 6,44348
6349.48
-35073
3,495.25
5,569,34]41
558,573.10 1060
1.97003 MWD(5)
8,404.83
6].54
M&W 6,44563
8,351.0
325.72
-3511.@
5,9x,372.28
556,556.23 16.M
Z07.0 MWD(5)
8433.83
x36
33366 6,445]8
6351]8
30.32
3,525.5
5,9x,39]%
555,54208 17.82
2,OMn MWD(5)
0,4&.19
8897
Wait 6,MB.W
6,351.95
-272.6]
3,53840
50042510
5x529.32 12.&
2,05.% MM (5)
8,494.27
046
338.65 6.445.5
6,351.85
-24477
354862
5.96d452.91
558,51]8] 4.03
2604.15 MW9(5)
adJZ4 n
91 s4
339.2] 644533
6.35133
31601
-3,560.3]
5968,49) 78
55850.88 416
2121.48 MWD (5)
8,55395
9108
39,69 644465
630.5
-18098
-357079
s,08,5x.5,
558.40.24 2.10
28W49 MWD(5)
8,x395
9175
34020 8,443.91
6349.91
-18081
-3,x107
55x.536.5
Sx,485.M 2.81
21 ]868 MWD(5)
0,61095
91P4
34036 8442.81
6,340.01
-127.80
3,592.60
5.5x,%9.43
558,4)360 052
2.21150 Mi (5)
8.649.03
9185
339.05 6,44189
B,&T89
-060
3.603 31
5,9x597.W
556,482.0 439
2,239.5 MW0(5)
72]2017 1:46 OBPM
Paye 3
COMPASS 5000.14 Build 85
�- CortmoPhillips
Conoa;Phillips Definitive Survey Report
Co.,.,
ComocPhilhps(Nas") Inc, -Kupl
Local CourDlnate Reference:
V✓ell 1C44
Project:
Kopeisk River Unit
ND Reference:
ii -0 @9400usft(1C-04)
Bfta:
Kupamk iC Pad
MD Reference:
1 C04 C 94.00usft(I C44)
Wall:
ic4
Won Reference:
True
""bore:
1,344
Survey calculaOon Me1N90:
Minimum Curvature
OeslBn:
1C-04
Database:
EDT Alaska Sandbox
Survey
Annotation
7X17201? 1:4508PM Pel COMPASS 500014 Bur1E 85
Map
Map
Veroand
MD
(uaft)
Me
pxl
TVD
TVD"
+W4
♦6072
NorelaB
Easton
OLS
SMlon Survey Taal Nano
(1)
(1)
;.-m
(weft)
(ual9)
(up1)
nil
(,MOS')
(ft)
8.6]8.99
9169
3'30.91
6.44102
6,34]02
-71.91
-3,61452
5,96682531
55845,55
6.94
2,2418 Mors)
0.]00.95
092
335.55
6,414.33
6.346 33
-04.49
3,62650
5989,652.52
550,439.26
539
2297.03 1449(51
8,73825
93.14
Mo 76
6,439.08
6,345.80
-1712
383965
5,9[$6]6]9
5561146]
592
2.326.34 hil(5)
8,7015
9132
33205
6,439.32
8345.33
9.50
3.653.16
5,981
550,41224
5.98
2,35540 1(5)
8]9,1.23
92.69
331.03
0,430.43
8344.43
35.0
-3.65)49
5.988]33.59
558.39)89
4.25
2,30194 ~(6)
Al
loo
331.40
8,437,12
6,34312
61.26
-3,681]9
5,969.]59.50
559,383.18
3.15
2,41407 NAND (5)
8.859.34
94.12
330.55
6,43535
6,34125
08.48
3,899.50
5,sss' ea
558369.25
4.74
2443.84 ski
seal
94.65
33111
8.432.93
6,338.93
tt425
3,]10.88
5,968810.55
558353&5
311
24572.83 MNDS)
8,91875
94.61
330.97
6.433.47
6,335.4]
140.24
3,85.26
5,9p83641
558339.4
a%
2501.98 MND(5)
0,948.61
94.%
M273
6,420.01
6.331.01
1447
3.M..W
5944214
560.324.81
5.93
2,531.10 Ned) (5)
8.9784
94.30
33351
6,42550
633158
193."
-3,]52.14
5.986.84.42
55831069
3.15
2,56360 MAN(5)
9,01031
94.05
332.92
8,423.14
6,329.14
221.36
-3,]6]07
5,968.99.18
558'196.59
219
2561199 MWD(5)
9,038.11
95.70
334.99
8.420.81
6,32661
24623
-3,]]9.22
5,668,941.94
558384.23
846
2617 86 MWDIS)
9,069.02
4.60
337 59
6.49.25
6,32326
2]4.36
3,79150
5,986.969.97
558,27165
805
2647.35 MWD(51
9,099.19
9310
339.04
6,41086
Suomi
332.29
4mxre0
5,569,99780
$$0,2811.31
12M
267586 hal
9,10,27
9141
339.72
6,41354
8319.54
329.48
J.81291
5.959,024.91
550,24986
so
'1,]03'19 1(5)
9,14.91
94.18
34267
6,41205
83184
358.45
y.M78
5.49,053.79
559,23975
13.X1
2]31 82 el (5)
rimer
047
344.13
6.41005
6,3164
38704
-383,30
5.96'9.42.30
5583314
542
2T592D AfiND(5)
9,218.20
92.40
34572
8.44.55
6,314.55
41538
-3838.93
5,668110.57
558,223.13
651
2786.82 MND(5)
9,20"
0V
34673
6,14705
6,31305
"502
3.8454
5,9@i,140. 16
55821818
1035
281285 vo l
9,2]8.89
0w
350.04
6,40523
6,31123
474.74
3,85101
584,18 m
55821056
7.11
2039.4 MADS)
9,3M.76
91.93
349.32
6,44.78
6,30978
501.13
3,85615
549,19817
550,2510
778
2,8MB7 MWD(5)
834030
91.17
346.30
640.94
8,34.94
535.02
3862.82
5,969,2304
55819825
9.82
2.892.02 el (5)
9,37040
92.30
34552
6.404
6434.M
56's 12
-3,870.13
5969,255) 04
558, 19371
4.57
2,9,981 MWD(5)
934.01
918
313.45
6,41403
630703
59148
-3,87714
5.491433
558.182.89
].58
2915.65 MND(5l
9428.59
9163
340.81
SAUDIS
6,3416
61901
-3,844
5989.314.58
550,tY3.52
687
girl mvvods
9,459.41
W24
339.74
6,399.12
834.12
64880
3,8425
5,969,34348
558182.89
399
3.002.11 All
94403
9286
338.4
639785
6,303.85
675.55
39074
5,909,37014
54,152.4
376
3,029.10 MWD(5)
1 9,510.89
92.03
33703
6396 54
6,30.54
70.93
3,9184
5,49,3M43
559,140.83
8.55
3,0424 deal (5)
t( 954803
14.69
334.60
83424
6,3012 4
]3140
-3,931.19
%
5,9,42579
559,128.27
8.55
34
,7.21 oll(5)
95]833
91.4
33143
6.39901
8,34.01
]5>M
-3,957
".
Seel 94
55811469
1125
3,11592 MJN(5)
Annotation
7X17201? 1:4508PM Pel COMPASS 500014 Bur1E 85
�- ConocoPhillips y
ConloaWhtll)pS Definitive Survey Report
Campany:
ConacnPhillips(Alaska) Inc. -Kupl
Low] COandlnale Reference:
Wall 1CZ4
Pmlem:
KuNNk River Unit
WO Reference:
10414®94.00ush(I 004)
Sim:
Kupamk I Pad
MO Role..:
10414@ 94.00usft(1 C-04)
Well:
1604
North Rammnae:
Tma
Welibom:
IC -04
Survey Calculation Method:
Minimum Curvature
Oesilm:
1C-04
Dalabow:
EDTAIaska Sandbox
Survey
7272017 1:4598PM
Page 5
COMPASS 5000.14 ea d 85
Map
Map
MD
inc
AM
NO
TVOSS
+WS
♦F3 -y4
NmMinp
OLS
1°I
(1)
(earl
("aft)
(salt)
(.an)
Eastin9
(•n90
Sa411an1 9umrey Tool Wma AnnotationIMaM
Iro
m)
(ft)
9,6575
91.%
32934
6,391.99
6,29099
784.09
-3969.59
5.9094]824
55&093.84
687
3,145.83 MM,(5)
9,63883
91.M
32].35
6.392.00
8,288.01
MON
-3,9]53]
5,938503]0
550.061.45
684
31]5.5] MWD (5)
9,6%.64
92.24
MN
6.391.03
6,29]03
833.84
J990,74
5,961
55&00].89
6.85
3,20319 MM) (5)
9694.56
&'.]0
335.18
8,38934
6,295.34
055.]6
4.M9.56
5,969,549.51
N0,0515
&88
3,230.93 MI
9,7N.W
93 78
323.90
638)15
&393.15
on"
4.OM73
5,900,5]344
waou.51
5.31
3,250.40 MWD(5)
9,75422
9227
32286
8.3&5.56
6,291%
903.89
<.Nl61
5900,597M
52101644
610
3,29032 MWD(5)
9]84.11
93.7
32195
8.w0
6,293.]]
92]5]
4,05904
5,969,620.8]
55].996.01
5.87
3,320.17 MWD (5)
9.81313
%.19
man
6.365.03
6,29103
95023
407.%
5.95964339
557979 71
975
3349.10 MvD (5)
9.643.50
8].30
31643
6,38623
6,2MM
9]3.35
4,00162
5,900.521."
557,9%,%
8.30
337952 MND I5I
9,87124
9021
31742
6,3%90
6,292.90
mie
1,11821
5Nti.W0.97
07,93903
t0.a2
3.410.23 61WD(5)
9,904.21
09.75
317 64
6,Main
629291
1,01826
1,13&45
5,969.71093
55],918.6]
170
3,440.18 MWD(5)
9,93429
67.29
317n
B,MTW
6.293N
1,04049
1,153.00
5,%9,]32%]
557,890.24
3.85
3,470.22 MND (5)
2,954.49
8].$
MO 28
6.38 .04
8,295.04
1,0326
4,,17848
5,%%JW2157
557,6)027
847
350038 25210 (5)
9934.47
6742
32'204
6,39941
6,2WAl
1106.8
4,19726
5,969.m"
57,85933
5.00
3,53332 MWD (5)
18023.21
915
N&N
6,MaN
62%66
1,11061
4,214.05
5,900,002.82
N7,042.31
2479
3,59.52 1&WD(5)
10214.20
No
most
6350.39
6,296.30
1,135.74
4,229.58
5.59828 .61
%2,0(.57
1014
awalil 252121(5)
10,ON.5
IV
33122
6391.10
8,29710
1.18374
4,244.07
5,59,1MIa
557,611.21
7.13
3.610.75 MND (5)
10411400
In.
M78
6,392.39
6,M&N
1tN.42
4,(75
5921.211.5
55],]9776
8,52
3,W0.11 M11V0(5)
10143%
0672
33638
639391
6,221.91
1,21648
4.270.53
5,68,90000
5],784.9]
9.03
38]6.5 MWD(5)
10,168%
21.04
34334
6,35.33
6301.32
1,239.5
4,279.13
5,98,931 .30
N7,M.17
2].7]
3,700.41 MWD(5)
10,15.21
85.14
342 3
6,"740
6,3540
1,2%40
4,20790
5.59959.]]
%7,12.1]
6.47
372721 MVM(5)
10,226.5
N%
341.46
SAWN
6,321.62
1,2584
1,29].17
5.939.95.14
0],]5767
9.21
3,76561 PONT) (5)
10,(101
81.71
]40.]9
54064
6,321.00
1,31752
4,304.23
5,970.0ol75
55],]%43
502
3,]]55 WAR) (5)
1027881
0137
33&07
6,40773
631373
1,343.09
4,314.34
5,970,03.23
SA,740.11
16M
aI 2.W MWD (5)
10,33&47
812,
33373
6,412,22
6,31822
1,321.83
4,3(77
5,9]0,2106]
567 M.M
782
3833.40 MKD(5)
10.%043
IN 17
334.15
6.4165
6,322.%
1.3506
434060
5.970 New
%7713.32
627
3211.13 MKD(5)
10369.0]
%57
333"
6,41987
6.32567
1,423.59
1,35328
5.970.11940
%],]8.52
3.(
3,8%]6 MND (5)
1O,M67
M.37
3318
6423.90
6,3285
1.4972
4,321.21
5,970,140.41
55],65]5
545
391749 MKD (6)
10,42863
21.00
33217
6,42550
6,"450
1,4768
AMO 03
5,970,155
57,62.53
552
3946.21 mmu(5)
10.45&"
8775
332.51
6,42715
6,333.15
158.93
4,391.90
6970,10."
%7,6%24
5.90
3.97830 MAD(5)
10.4828
0963
332"
6,4069
633389
1,533.N
4405.81
5,970,214.23
217,00716
7.93
3,83.% MWD(5)
7272017 1:4598PM
Page 5
COMPASS 5000.14 ea d 85
ConocoPhillips ER gy
ConocoPhillips U
Definitive Survey Report
Company:
ConocoPhiNps(Aleske) Inc.-Kupl
Local Cocrc inate Reactance:
MllIC-04
Prejeat
Kupamk Rlmr Unit
ND Raterence:
4C-04®94.ODuan(1o04)
Site:
Kupamk I Pad
MD Reference:
1C C 94.00usn (1G04)
Well:
IC -()4
North Reference:
Tme
Welibom:
1C-04
Survey Calculaeon Mach"!
Minimum Curvature
Design:
IC04
Database:
EDT Alaska Sandbox
Survey
MD
Inc
Add
TID
1VD93
+WS
+El
Map
Map
OLS
Vertical
NalCI
(11
(cam
(Man)
loan)
(ueat)
Northing
Elating
Section Suave Tool Name
Y
(ft)
(n)
VNOP)
(n)
10,51395
90.64
332.63
6,421.51
6,33361
1,55,66
A 420 27
5,970,241.92
557.632.40
3.28
4,029.95 lel (5)
1054527
9118
XW(n,
6,427.39
5333.39
1,579.24
4436.15
5,970259.35
$),61].37
655
4.950.62 MW (5)
10,573.20
89.12
32650
5427 49
6,377.49
1,60333
!,44920
Son),H3.32
552,801.04
797
4,080.16 MMD (5)
10460931
90.50
32].40
54V39
6,333.39
1,633.94
4,460.42
59]0,323.20
557,503.65
522
4,123.92 MWD(5)
10,63896
92.08
Klin
6,426.82
6,332.62
1,65086
4,484.47
5,970,348f9
557.51
4.14
4,153.32 MWD(M
10,668.41
92.15
324.55
6.42654
8,33,$4
1,683.20
4,501.01
5,970,372.76
557,55065
642
4,18260 MINI
10 6"
99.63
324.12
6,425.07
6,331.07
1,707 77
4,51863
59]0,397.18
SS7,53283
8.43
4,21275 MW0(5)
10,72857
8.82
311.17
11,425.74
6,331.74
1.73155
4,533]6
5970.420 81
557,51450
11.71
4,242.62 MVA (5)
10!6585
87.94
3198
6,427.12
6333.12
1,700,27
4560"
6,970,449.33
557,40%
3.90
4,279.67 MWD(5)
10,50697
87.94
31972
642863
6,33463
I'M 41
4,588
5.970,481 24
5574005
0.00
4, 3R 00 PROJECTED E TD
787&017 1.'45'O8PM Pape 6 COMPASS 5000.14 Bui1E 85
BA ER PRINT DISTRIBUTION LIST
F�UGHES
a GE company
COMPANY ConocoPhillips Alaska, Inc..
WELL NAME 1C-04AL1 RECEIVE
FIELD Greater Kuparuk Area AUG 11 2017
21 7083
28490
se sign and return one copy of this transmittal form to:
ocoPhillips Alaska, Inc.
y Elgarico. ATO 3-334. DATA LOGGED
G Street. S/!6/2017
Torage, Alaska 99510 M. K. BENDER
COUNTY North Slope Borough A ^GCC LOG TYPE GR- RES
BHI DISTRICT Alaska _
LOG DATE July 13, 2017
AUTHORIZED BY Patrick Rider
EMAIL Patrick. RiderCa)bakerhughes. com TODAYS DATE August 8, 2017
STATUS Final Replacement:
COMPANY
ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX)
PERSON ATTENTION
V
1 OP North Slope.
LOA, PBOC, PRB-20 (Office 109)
D&GWO Wells Admin Brenda Glassmaker & Peggy O'Neill
900 E. Benson Blvd.
Anchorage, Alaska 99508
Revision
No Details:
Rev. Requested by: ---
FIELD
FINAL
CD/DVD
FINAL
PRELIM
LOGS
(las, rills, PDF, META,
I
SURVEY
REPORT
LOGS
CGM, Final Surveys)
(Compass)
# OF PRINTSour
PRIN
IF OF COPIES
1# OF COPIES
# OF COPIES
4 19
2 ConocoPhillips Alaska Inc. 0 0 0 0 0
Atm: Ricky Elgarico
A'r0 3-344
700 G Street
Anchorage, AK 99510
3 ExxonMobil, Alaska 0 0 0 0 0
Atm: Lynda M. Vaskell and/or Leonardo Elias
3201 C Street, Suite 505
Anchorage, AK 99503
4 State of Alaska -AOGCC 0 1 1 1 0
Attn: Makana Bender
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
5 DNR - DivisionofOil&Gas *** 0 0 1 1 0
Atm: Resource Evaluation
550 West 7th Avenue, Suite 1100
Anchorage, Alaska 99501
** Stamp "confidential" on all material deliver to DNR
6 BP Exploration (Alaska) Inc.
Petrotechnical Data Center, IR2-1
900 E. Benson Blvd
Anchorage, Alaska 99508
TOTALS FOR THIS PAGE: 0 2 3
..�
ConocoPhillips
RECEIVED
AUG 11 2017
A®GCC
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Kuparuk 1C Pad
1 C-04AL1
50-029-20547-60
Baker Hughes INTEQ
Definitive Survey Report
27 July, 2017
21 7083
28 49 0
BA ER
F�UGHES
a GE coinneoy
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Company:
ConocoPhillips (Alaska) Inc. -Kup1
Local Coordinate Reference.
Project:
Kuparuk River Unit
TVD Reference:
Site:
Kuparuk 1C Pad
MD Reference:
Well:
1 C-04
North Reference:
Wellbore:
1C-04
Survey Calculation Method:
Geo Datum:
1C-04
Database:
Well 1C-04
1 C-04 @ 94 00usft (1 C-04)
1 C-04 @ 94.00usft (1 C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Design.
Project
Kuparuk River Unit, North Slope Alaska, United States
Map System:
US State Plane 1927 (Exact solution)
System Datum:
Mean Sea Level
Geo Datum:
NAD 1927 (NADCON CONUS)
Using Well Reference Point
Using geodetic scale factor
Map Zone:
Alaska Zone 04
Well
1C-04
Well Position
-Ni 0.00 usft
Northing:
5,968, 727.00usft
Latitude:
♦El -W 0.00 usft
Easting:
562,065.00usft
Longitude:
Position Uncertainty
0.00 usft
Wellhead Elevation:
usft
Ground Level:
Wellbore
1C-04AL1
Magnetics
Model Nam Sample Date
Declination
(")
Dip Angie
V)
BGGM2016 8/1/2017
17.55
80.95
Design
iC-04AL1
Audit Notes:
Version:
1.0 Phase: ACTUAL
Tie On Depth:
8,145.51
Vertical Section:
Depth From (TVD)
-N/-S
+E/ -W
Direction
(usft)
(usft)
(usft)
(1)
33.50
0.00
000
320.00
13AER 0
UGHES
70° 19' 30.322 N
149'29 46.207 W
0.00 usft
Field Strength
(nT)
57, 542.29
7/27/2017 1 45: 08PM Page 2 COMPASS 5000 14 Build 85
ConocoPhillips
BAV IE
ConocoPhillips
HES
Definitive Survey Report
Company:
ConocoPhillips
(Alaska) Inc.-Kupl
Local Coordinate Reference:
Well 1C-04
Project:
Kuparuk River Unit
TVD Reference:
1C-04 @ 94.00usft (1C-04)
Site:
Kuparuk I
Pad
MD Reference:
1C-04 @ 94.00usft (1C-04)
Well:
1C-04
North Reference:
True
Wellbore:
1C-04
Survey Calculation Method:
Minimum Curvature
Design:
1C-04
Database:
EDT Alaska Sandbox
Survey Program
Date 7/14/2017
From
To '
Survey
Survey
(usft)
(usft)
Sumay (Wellbore)
Tool Name
Description
Start Date
End Date
100.00
7,122.00
1C-04 (1C-04)
BOSS -GYRO
Sperry -Sun BOSS gyro multishot 8/25/2000
7,125.50
7,175.87
1C -04A MWD -INC (1
C -04A)
MWD -INC -ONLY
MWD -INC -ONLY _ FILLER
7/2/2017
7/3/2017
7,205.86
8,145.51
1C -04A MWD(1 C -04A)
MWD
MWD- Standard
7/3/2017
7/9/2017
8,148.30
8,226.75
1C-04ALl MWD-INC(1C-04AL1)
MWD-INC_ONLY
MWD -INC -ONLY -FILLER
7/10/2017
7/11/2017
8,254.87
10,765.85
1C-04ALl MWD (I C-04AL7)
MWD
MWD- Standard
7/11/2017
7/13/2017
survey
MD
Inc
AN TVD
TVDSS
+N/S
+EI -W
Map
Map DLS
Vertical
(usft)
(°)
(°) (usft)
(usR)
(usft
(usft)
Northing
Easting
(°1100')
Section SurveyTool Name
Annotation
(ft)
(R)
(ft)
8,145.51
97.08
280.01 6,436.72
6.342.72
471.82
-3,307.61
5,968,227.89
558,761.72 15.89
1,764.65 MWD (3)
TIP
8,148.30
97.13
280.39 6,436.37
6,342.37
471.33
-3,310.33
5,968,228.35
558,759.00 13.63
1,766.78 MWD -INC -ONLY (4)
KOP
8,181.39
91.57
287.56 6,433.86
6,339.86
463.36
-3,342.31
5,968,236.06
558.726.95 27.36
1,793.44 MWD -INC ONLY(4)
Interpolated Azimuth
8,209.41
89.91
293.59 6,433.50
6,339.50
453.52
-3,358.53
5,968,245.68
558,700.66 22.32
1,817.83 MWD -INC ONLY(4)
Interpolated Azimuth
8,226.75
89.82
297.32 6,433.54
6,339.54
446.07
-3,384.19
5,968,253.00
558,686.94 21.52
1,833.60 MWD -INC _ONLY (4)
Interpolated Azimuth
8,254.87
84.22
303.39 6,435.00
6,34190
431.89
-3,408.40
5,968,266.97
558,660.62 29.34
1,860.03 MWD (5)
First Good Survey
8,284.85
85.73
306.88 6,437.63
6,343.63
414.71
-3,432.82
5,968,283.95
558,636.06 12.64
1,868.89 MWD(5)
8,314.86
86.90
313.80 6,439.56
6,345.56
-395.33
-3,455.63
5,968,303.14
558,613.09 23.34
1.918.39 MAD (5)
8,345.07
85.70
318.00 6,441.51
6,347.51
-373.69
-3,476.60
5,968,324.61
558,591.94 14.43
1,948.45 MWD (5)
8,374.73
86.68
323.83 6,443.48
6,349.48
350.73
-3,495.25
5,968,347.41
558,573.10 19.89
1,978.03 MAD (5)
8,404.83
87.54
328.82 6,445.00
6,351.00
-325.72
3,511.92
5,968,372.28
558,555.23 16.80
2,007.90 MWD (5)
8,433.83
89.36
333.66 6,445.78
6,351.78
400.32
-3,525.86
5,968,397.56
558,542.08 17.82
2,036.32 MWD(5)
8,464.19
89.97
337.54 6,445.96
6,351.96
-272.67
-3,538.40
5,958,425.10
558.529.32 12.94
2,065.56 MM (5)
8,494.27
90.46
338.65 6,445.85
6,351.65
-244.77
-3,549.62
5968,452.91
558,517.87 4.03
2,094.15 MM (5)
8,524.23
91.54
339.27 6,445.33
6,351.33
-216.81
-3,560.37
5,968,480.76
558,506,88 4.16
2,122.48 MWD (5)
8,553.95
91.08
339.69 6,444.65
6,350.65
-188.98
3570.79
5,968,508.51
558,496.24 2.10
2,150.49 MWD (5)
8,583.95
91.75
340.20 6,443.91
6,349.91
-160.81
-3,581.07
5.968,536.60
558485.72 2.81
2.178.68 MWD (5)
8,618.95
91.84
340.36 6,442.81
6,348.81
-127.88
-3,592.88
5,968,569.43
558,473.65 0.52
2.211.50 MWD (5)
8,649.03
91.66
339.05 6,441.89
6,347.59
-99.68
-3,603.31
5,968,59753
558,462.99 439
2,239.80 MM (5)
7/27/2017 1:45:08PM
Page 3
COMPASS 5000.14 Build 85
ConocoPhillips SO%
ConocoPhillips Definitive Survey Report
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1C-04
Wellbore:
1C-04
Design:
1C-04
Survey
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 1C-04
1C-04 Q 94.00usft (1C-04)
1C-04 @ 94.00usft(1C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Annotation
71272017 1:45:08PM Page 4 COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+NIS
+El-WDLS
Northing
Easting
Section Survey Tool Name
(usft)
(`)
V)
(usft)
(usft)
(usft)
(usft)
(ft)
(ft)
(-/100')
(ft)
8,678.99
91.69
336.97
6,441.02
6.347.02
-71.91
41,614.52
5,968,625.21
558.45155
6.99
2.268.28 MM (5)
8,708.95
90.92
335.55
6.440.33
6,346.33
-44.49
3,626.58
5,968,652.52
558,439.26
5.39
2,297.03 MWD (5)
8,739.25
90.80
333.76
6.439.88
6,345.88
-17.12
3,639.55
5,968,679.79
558,426.07
5.92
2,326.34 MM (5)
8,769.15
91.32
332.05
6,439.32
6,345.33
9.50
3,653.16
5,968.706.28
558,412.24
5.98
2,355.48 MWD(5)
8.799.23
92.09
331.03
6,438.43
6,344.43
35.93
-3,667.49
5,968,732.59
558,397.69
4.25
2,364.94 MWD (5)
8,828.96
92.95
331.40
6437.12
6,343.12
61.96
3,68179
5,968,758.50
558.383.18
3.15
2,414.07 MV4D(5)
8,859.34
94.12
330.56
6,435.25
6.341.25
88.48
3,696.50
5,968,784.89
558,368.25
4.74
2.443.84 MM (5)
8,888.95
94.86
331.11
6,432.93
6,338.93
114.25
-3,710.88
5,968,810.55
558,353.65
3.11
2,472.83 MWD (5)
8,918.75
94.61
330.97
6,430.47
6,336.47
140.24
-3,725.26
5,968,835.41
558,339.06
0.96
2,501.98 MWD (5)
8,948.61
94.86
332.73
6,428.01
6,334.01
166.47
-3,739.30
5,968,862.53
558,324.81
5.93
2,531.10 MWD (5)
8,978.99
94.30
333.51
6,425.58
6,331.58
193.48
-3,752.99
5,968,889.42
558,310.89
3.15
2,56060 MWD (5)
9,010.31
94.65
332.92
6.423.14
6,329.14
221%
3,767.07
5,968,917.18
558,296.59
2.19
2,590.99 MWD (5)
9,038.11
95.78
334.99
6,420.61
6,326.61
246.23
3,779.22
5.968.941.94
558,284.23
8.46
2617.86 MWD (5)
9,069.02
96.68
337.59
6,417.25
6,323.26
274.36
3,791.58
5,968,969.97
558,271.65
8.85
2,647.35 MWD (5)
9,099.19
93.10
339.04
6,414.68
6,320.68
302.29
-3,802.68
5.968,997.80
558,260.31
12.80
2,675.88 MWD (5)
9,128.27
91.41
339.72
6,413.54
6,319.54
329.48
-3,812.91
5,969,024.91
558,249.85
6.26
2,703.29 MWD(5)
9,158.91
94.18
342.67
6,412.05
6,318.05
358.45
3,822.78
5,969,053.79
558,239.75
13.20
2,731.82 MM (5)
9,188.81
93.47
394.13
6,410.05
6,316.05
387.09
3,831.30
5,969,082.30
558,23100
5.42
2,759.20 MWD (5)
9,218.20
92.40
345.72
6,408.55
6,314.55
415.38
3,838.93
5,969,110.57
558.223.13
6.51
2,785.82 MWD (5)
9,248.64
93.23
348.73
6,407.05
6,313.05
445.02
3,845.66
5,969,140.16
558,216.16
10.25
2,812.85 MWD (5)
9.278.89
93.66
350.89
6,405.23
6,311.23
474.74
-3,851.01
5,969,169.83
558,210.56
7.11
2,839.05 MWD (5)
9,308.76
91.90
349.32
6,403.78
6,309.78
504.13
3,856.15
5,969,199.17
558,205.18
7.78
2,864.87 MWD (5)
9,340.38
91.17
346.30
6,402.94
6,308.94
535.02
-3,862.82
5,969,230.00
558,198.25
9.82
2,892.82 MWD (5)
9,370.40
92.30
345.52
6,402.03
6,308.03
564.12
-3,870.13
5,969,259.04
558,190.71
4.57
2,919.81 MIND (5)
9,398.81
91.72
343.45
6,401.03
6,307.03
591.48
-3.877.72
5,969,285.33
558,182.89
7.56
2,945.65 MWD (5)
9,426.59
91.63
340.81
6,400.16
6,306.16
619.81
-3,886.86
5,969,314.58
558,173.52
8.87
2,973.22 MWD (5)
9,459.41
92.24
339.74
6,399.12
6,305.12
648.80
-3,897.25
5,969,393.48
558,162.89
3.99
3,002.11 MM (5)
9,488.03
92.86
338.86
6,39785
6,303.85
675.55
3,907.36
5,969.370.14
558,152.56
3.76
3,229.10 MWD (5)
9,518.69
92.03
337.03
6,396.54
6,302.54
703.93
3,918.86
5,969,398.43
558,140.83
6.55
3,058.24 MWD(5)
9,548.83
92.89
334.60
6,395.24
6,301.24
731.40
3,931.19
5,969,425.79
556128.27
8.55
3,087.21 MWD (5j
9,57833
91.90
33143
6,394.01
6,300.01
757.66
-3,994.57
5,969,45194
558,114.68
11.25
3,115.92 MWD(5)
Annotation
71272017 1:45:08PM Page 4 COMPASS 5000.14 Build 85
Survey
ConocoPhillips
ConocoPhillips
Definitive Survey Report
Company: ConocoPhillips (Alaska) Inc. -Kup1
Local Coordinate Reference:
Well 1C-04
Project: Kuparuk River Unit
TVD Reference:
1C-04 @ 94.00usft (1C-04)
Site: Kuparuk 1C Pad
MD Reference:
1C-04 @ 94.00usft(1 C-04)
Well: 1C-04
North Reference:
True
Wellbore: 1C-04
Survey Calculation Method:
Minimum Curvature
Design: 1C-04
Database:
EDT Alaska Sandbox
Survey
ER
Iu�NEs
712712017 1.:45:08PM Page 5 COMPASS 5000.14 Build 85
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+WS
+E/ -W
Northing
Fasting
DLS
Section Survey Tool Name Annotation
(waft)
(I
(°)
(usft)
(usft)
lust[)
(usft)
(ft)
(n)
("1100')
(ft)
9,608.75
91.96
329.39
6,392.99
6,298.99
784.09
-3,959.59
5,969,478,24
558,099.44
6.87
3,145.83 MWD (5)
9,638.83
91.78
327.35
6,392.00
6,298.01
809.68
-3,975.37
5,969,503.70
558083.45
6.64
3,175.57 MWD(5)
9,666.64
92.24
325.50
6,391.03
6,297.03
832.84
-3,990.74
5,969,526.72
558,06789
6.85
3,203.19 MWD (6)
9,694.56
94.70
325.18
6,389.34
6,295.34
855.76
4,006.58
5,969,549.51
558,051.86
8.68
3,230.93 MWD(5)
9,724.20
93.78
323.90
6,367.15
6,293.15
879.83
4.023.73
5,969,573.44
558,03451
5.31
3,260.40 MWD(5)
9,754.22
92.27
322.86
6,385.56
6,291.56
903.89
4.041.61
5,969,597.35
558,016.44
6.10
3,290.32 MWD(5)
9,784.11
90.77
32195
6.384.77
6,290.77
927.57
4,059.84
5,969,620.87
557,998.01
5.87
3,320.17 MWD (5)
9,813.13
88.19
320.79
6,385.03
6,291.03
950.23
4,077.96
5,969,643.39
557,979.71
9.75
3,349.18 MWD (5)
9,843.50
87.30
318.43
6,386.23
6,292.23
973.35
-0097.62
5,959,666.33
557,959.86
- 8.30
3,379.52 MM (5)
9,874.24
90.21
317.42
6,386.90
6,292.90
996.16
4.118.21
5,969,688.97
557,939.09
10.02
3,410.23 MIND (5)
9,904.21
89.75
317.69
6,306.91
6,292.91
1,018.26
4,138.45
5,969,710.90
557,918.67
1.70
3,440.18 MWD(5)
9,934.29
87.39
317.72
6,387.66
6,293.66
1,040.49
4.158.69
5,969,732.97
557,898.24
7.85
3,470.22 MWD (5)
9,964.49
87.36
320.28
6,389.04
6,295.04
1,063.26
4.178.48
5,969,755.57
557,878.27
8.47
3,500.38 MIND (6)
9,994.47
87.42
322.04
6,390.41
6,296.41
1086.59
4,197.26
5,969,778.73
557,859.30
5.87
3,530.32 MWD (5)
10,023.80
91.50
328.06
6,390.68
6,296.68
1,110.61
4214.05
5,969.802.62
557,842.31
24.79
3,559.52 MWD (5)
10,054.20
89.63
330.51
6,390.38
6,296.38
1,136.74
4.229.58
5,969,828.61
557,826.57
10.14
3,589.51 MWD (5)
10,083.98
B7.63
331.22
6,391.10
6,297.10
1,162.74
4.244.07
5,969,854.49
557,811.86
7.13
3,618.75 MWD (5)
10,114.08
87.45
333.78
6,392.39
6,298.39
1,169.42
4,257.96
5,969,881.05
557,797.76
8.52
3,648.11 MWD (5)
10,143.96
86.72
336.38
6,393.91
6,299.91
1,216.48
4,270.53
5,969,908.00
557,784.97
9.03
3,676.92 MWD(5)
10,166.99
86.84
343.34
6,395.32
6,301.32
1,239.93
4,279.13
5,969,931.38
557,776.17
27.77
3,700.41 MWD (5)
10,198.86
85.14
342.42
6,397.40
6,303.40
1,268.40
4,287.90
5,969,959.77
557,767.17
6.47
3,727.86 MM (5)
10,228.95
82.58
34148
6,400.62
6,306.62
1,296.84
4,297.17
5,969,988.14
557,757.67
9.06
3,755.61 MAD (5)
10,251.01
81.71
340.79
6,403.64
6.309.64
1,317.52
4,304.23
5,970,008.75
557,750.43
5.02
3,775.99 MIND (5)
10,278.81
81.37
336.07
6,407.73
6,313.73
1,343.09
4,314.34
5,970,034.23
557,740.11
16.84
3,802.07 MWD l5)
10,308.47
81.21
333.73
6,412.22
6,318.22
1,369.63
4,326.77
5,970,060.67
557.727.46
7.82
3,830.40 MWD Si
10,340.43
83.17
334.15
6,416.56
6,322.56
1,398.08
4,340.68
5,970,08900
557,713.32
6.27
3,861.13 MM (5)
10,369.07
83.57
333.30
6,419.87
6,325.87
1,423.59
4,353.28
5,970.114.40
557,700.52
3.26
3,888.76 MWD (5)
10,398.67
84.37
331.89
6,422.98
6,328.98
1,449.72
4,366.83
5,970,140.41
557,686.75
5.45
3,917.49 MM (5)
10,428.63
86.00
332.17
6,425.50
6,331.50
1,476.08
4,380.83
5,970,166.66
557,672.53
5.52
3,946.69 MWD (5)
10,456.99
87.76
332.51
6,427.15
6,333.15
1,502.93
4394.90
5,970.193.39
557658.24
5.90
3,976.30 MWD (5)
1048260
8963
332.44
6,427,69
6,33369
1,523.86
4,405.81
5,970,21423
557647.16
7.93
3,999.35 MWD (5)
ER
Iu�NEs
712712017 1.:45:08PM Page 5 COMPASS 5000.14 Build 85
ConocoPhillips
Definitive Survey Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 1 C-04
1C-04 @ 94.00usft (1C-04)
1C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Map
Map
ConocoPhillips
i14/4
+EAW
Company:
ConocoPhillips
(Alaska) Inc. -Kupl
Section
Project:
Kuparuk River Unit
(usft)
(ft)
Site:
Kuparuk 1C Pad
(ft)
Well:
1C-04
5,970,24192
557,632.48
3.28
Wellbore:
1C-04
1,579.24
4,435.15
5,970,269.35
Design:
1C-04 '
4.060.62
MM (5)
1,603.33
Survey
5,970,293.32
557.603.04
7,83
4,088.16
MD
Inc
AA
TVD
TVDSS
(usft)
(I
(°I
(usft)
(usft)
10513.95
90.64
332.63
6,427.61
6,333.61
i 10,545.27
90.18
330.63
6,427.39
6,333.39
10,573.20
89.42
328.58
6,427.49
6,333.49
10,609.31
90.89
327.40
6,427.39
6,333.39
10,638.96
92.06
327.03
6,426.62
6,332.62
10,668.41
92.15
324.55
6,425.54
6,331.54
10,698.65
89.63
324.17
6,425.07
6,331.07
I 10,728.57
87.82
321.17
6,425.74
6,331.74
10.765.85
87.94
319.72
6,427.12
6,333.12
10,808.00
87.94
319.72
6.428.63
6,334.63
ConocoPhillips
Definitive Survey Report
Local Coordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 1 C-04
1C-04 @ 94.00usft (1C-04)
1C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Annotation
erfEs �
7272017 1:45:08PM Page 6 COMPASS 5000.14 Build 85
Map
Map
Vertical
i14/4
+EAW
Northing
Easting
DLS
Section
Survey Tool Name
(usft)
(usft)
(ft)
(ft)
(°/100')
(ft)
1551.68
-0,420.27
5,970,24192
557,632.48
3.28
4,029.95
MWD (5)
1,579.24
4,435.15
5,970,269.35
557,617.37
6.55
4.060.62
MM (5)
1,603.33
4,449.28
5,970,293.32
557.603.04
7,83
4,088.16
MWD(5)
1,633.94
4,468.42
5,970,323.78
557,583.65
5.22
4,123.92
MWD (5)
1,658.88
4.484.47
5,970,348.56
557.56'7.40
4.14
4,153.32
MWD (5)
1683.20
4,501.01
5,970,372.76
557,550.65
6.42
4,182.60
MWD (5)
1,707.77
4,518.63
5,970,397.18
557,532.63
8.43
4,212.75
MWD (5)
1,731.55
4,536.76
5.970.420.81
557,514.50
11.71
4,242.62
MWD (5)
1760.27
4,560.49
5,970.449.33
557,490.55
3.90
4,279.87
MWD (5)
1,792.41
4,587.72
5,970,481.24
557,463.05
0.00
4,322.00
PROJECTEDIOTD
Annotation
erfEs �
7272017 1:45:08PM Page 6 COMPASS 5000.14 Build 85
BA ER �, Date:
tUGHES July 28, 2017
a GE company
To:
Makana Bender
AOGCC
333 West 71h Ave, Suite 100
Anchorage, Alaska 99501
From:
Letter of Transmittal
DATA LOGGED
'a/-? 201-1 JUL 31 2017
K BENDER
Yosha Ragbirsingh / Michael Soper
Baker Hughes, a GE Company
795 East 94th Avenue
Anchorage, Alaska 99515
Please find enclosed the directional survey data forthe following well(s):
1G-15APB1
2 1
7
0
65
28
45
1
1G -15A
2 1
7
0
65
2 9
4 5
0
1G-15AL1
2 1
7
0
70
28
4 5
2
1G-15AL2
2 1
7
0
7 1
28
4 5
3
1c -04A
2 1
7
0
78
28
4 4
8
1c -04A LI
2 1
7
0
83
28
4 4
9
(6) Total prints
CD in 217-078
Enclosed for each well(s):
1 hardcopy print of directional survey reports (NAD27)
1 compact disk containing electronic survey files
Note: Please feel free to send us an email in place of return mail.
Michael Soper, Baker Hughes, Project Engineer
Michael.Soper@BHGE.com
Yosha Ragbirsingh, Baker Hughes, Survey Manager
Yosha.Raebirsineh(a)BHGE.com
ConocoPhillips
RECEIVED
JUL 31 2017
AOGCC
ConocoPhillips (Alaska) Inc. -Kupl
Kuparuk River Unit
Kuparuk 1C Pad
1 C-04AL1
50-029-20547-60
Baker Hughes INTEQ
Definitive Survey Report
27 July, 2017
21
7083
28449
BAF�UGHES
a GE company
Page 2
7/27/2017 1:45:08PM
COMPASS 5000.14 Build 85
a Wcu "Es
t IEGRH,
ConocoPhillips
Definitive Survey Report
ConocoPhillips
-
Local Co-ordinate Reference: Well IC -04
ConocoPhillips(Alaska) Inc.-KuPi
1C -04(a u? 94.00usft 0 C-04)
Company:
TVD Reference:
Kuparuk River Unit
1C-04 @ 94.00usft (1C-04)
'
Project:
MD Reference:
Site: Kuparuk 1C Pad
North Reference: True
Well 1C-04Minimum
Survey Calculation Method: Curvature
Wellborn: 1C-04
Database: EDT Alaska Sandbox
Design: __
d.._ _-._.s-...,._..,.,v..�-.a_.... ._•_--.—_.,. ....,_... _...--..v-_.,.
..�...--- -._.__..°..._.-
_ y Kupamk River Unit, North ^Slope Alaska, United States
Project
Mean Sea Level
US Slate Plane 1927 (Exact solution)
System Datum:
Using Well Reference Point
Map System:
NAD 1927 (NADCON CONUS)
Using geodetic scale factor
Geo Datum:
Map Zone: Alaska Zone 04
�...®. .. _ - - -
__-....e.__......y...�P..�_-._...e..v-
70" 19'30.322 N
Well 1 C 04
Northing: 5,968,727.00 usft
Latitude:
149° 29'48 207 W
Well Position +N/ -S 0 00 usft
562065.00usft
Easting: ,
0.00 usk
,E1 -W 0.00 usft
usft
Grountl Level:
Ground
-
D.00 usft
Wellhead Elevation.
Position Uncertainty `..._-_.__._---------��^_-""_^-
Wellbore 1C-04AL-i
Dip Angle
Field Strength
Sample Date
Declination
(nT)
Magnetics Model Name
(�)
57 54229
800.. 95
8/11201717.55
BGGM2016
Design 1C-04AL1
Audit Notes:
Tie On Depth: 8,145.51
-
1.0 Phase: ACTUAL
Version:
Direction
+E1 -1N
+NcS
(7)
'
Depth From (TVD)
Wait)
Vertical Section:
(usR)
(usft)
320.00
33.50
.o.Do
000
Page 2
7/27/2017 1:45:08PM
COMPASS 5000.14 Build 85
ConocoPhillips SA LIG
ES
o-'
ConocoPhillips Definitive Survey Report
Survey Program
ConocoPhillips (Alaska) Inc. -Kupt
Local Co-ordinate Reference:
Well 1C-04
Company:
(usft)
TVD Reference:
1C-04 @ 94.00usft (1C-04)
Project:
Kuparuk River Unit
MD Reference:
1C-04 @ 94.00usft (IC-04)
Site:
Kuparuk iC Pad
8.254.87
True
Well:
1C-04
North Reference:
Survey Calculation Method:
Minimum Curvature
wellbore:
IC -04
Database:
EDT Alaska Sandbox
Design:
1C-04
15.89
1,76465 MVJO(3)
Survey Program
From
To
(usft)
(usft)
100.00
7,122.00
7,125.50
7,175.87
7,205.86
8,145.51
8,148.30
8,226.75
8.254.87
10,765.85
Survey
Date 7/14/2017
Survey (Wellbore)
1C-04(1 C-04)
1 C -04A MWD -INC (1C -04A)
1 C -04A MWD (1 C -04A)
1C-04AL1 MWD -INC (1C-04AL1)
1C-04ALl MWD (1C-04AL1)
MD Inc Azi TVD
(usft) 0 V) (usft)
8,145.51 97.08 280.01 6,436.72
8,148.30 97.13 280.39 6,436.37
8,181.39 91.57 28756 6,433.86
8,20941 8991 293.59 6,433.50
8,226.75 89.82 297.32 6,433.54
8,254.87 84.22 303.39 6,43500
8,28485 85.73 306.88 6,437.63
8,31486 86.90 313.80 6,439.56
8,345.07 85.70 31900 6,441.51
8,37473 8668 32383 6,443.48
8,404.83 87.54 328.82 6445.00
8,433.83 89.36 33366 6,445.78
8,464.19 89.97 337.54 6,445.96
8,494.27 90.46 338.65 6,44585
8,52423 9154 339.27 6,445.33
8,553.95 91.08 339.69 6,444.65
8,583.95 91.75 390.20 6,44391
I 8,618.95 9184 340.36 6,44281
6649.03 9166 339.05 6,44189
7/27/2017 1:45:08PM
Survey
End Date
7/3/2017 !
3
7/9/2017
7/11/2017 1
i
7113/2017
r
Annotation
TIP
KOP
Interpolated Azimuth
Interpolated Azimuth
Interpolated Azimuth -.
First Good Survey
COMPASS 5000.14 Build 85
Survey
Tool Name
Description
Start Date
BOSS -GYRO
Sperry -Sun BOSS gyro muitishot
8/25/2000
MWD-INC_ONLY
MWD-INC_ONLY_FILLER
7/2/2017
MWD
MWD - Standard
713/2017
MWD -INC ONLY
MWD-INC_ONLY_FILLER
7/10/2017
MWD
MWD- Standard
7/11/2017
Survey
End Date
7/3/2017 !
3
7/9/2017
7/11/2017 1
i
7113/2017
r
Annotation
TIP
KOP
Interpolated Azimuth
Interpolated Azimuth
Interpolated Azimuth -.
First Good Survey
COMPASS 5000.14 Build 85
Map
Map
Vertical
TVDSS
+NI -S
+E/ -W
Northing
Easting
DLS
Section Survey Tool Name
(usft)
(usft)
(usft)
(ft)
(ft)
(.1100')
(ft)
6,34272
471.82
-3,307.61
5,968,22789
558,761.72
15.89
1,76465 MVJO(3)
6,342.37
471.33
-3,310.33
5,968,228.35
558,759.00
13.63
1,766.78 MWD -INC ONLY (4)
6,339.86
463.36
-3,342.31
5,968,23606
558,726.95
27.36
1,793.44 MV)D-INC_ONLY (4)
453.52
-3,368.53
5,968,24568
558,700.66
22.32
1,817.83 MWD-INC_ONLY (4)
6,33950
6,339.54
-046.07
-3,384.19
5,968,253.00
558,68494
21.52
1,83360 MWD -INC -ONLY (4)
6,341.00
431.89
-3,408.40
5,968,266.97
558,660.62
29.34
1,860.03 MWO(5)
6,343.63
414.71
-3,43282
5,968,28395
558,636.06
12.64
1,888.89 MVJD(5)
6,345.56
-395.33
3,455.63
5,968,303.14
558,613.09
23.34
1,918.39 MWD (5)
6,34751
-373.69
-3,476.60
5,968,324.61
558,591.94
1443
1,948.45 MWD (5)
6349.48
-350.73
-3,495.25
5,968,347.41
558,573.10
19.89
1,978.03 MWD(5)
6,351.00
-32572
-3,511.92
5,968,372.28
558,556.23
16.80
2,00790 MWD(5)
6,351.78
-30032
-3,525.86
5,968,397.56
558,542.08
1782
2,036.32 MM (5)
6,35196
-27267
-353840
5,968,425.10
558,529.32
12.94
2,065.56 MWD (5)
6,351.85
-244.77
3,54962
5,968,452.91
558,517.87
4.03
2,094.15 MWD (5)
6,351.33
-216.81
-3.550.37
5,968,480.78
558,506.88
4.16
21122.48 MW) (5)
6,35065
-188.98
-3.570.79
5968,50851
558,496.24
2.10
2,150.49 MWD (5)
6,349.91
-160.81
3,581.07
5,968,536.60
558,485.72
2.81
2,178.68 MWD (5)
6,348.81
-127.88
-3,59288
5.96656943
558.473.65
0.52
2.211.50 MM (5)
6,347.89
-9968
-3,603.31
5,96859753
558,46299
4.39
2,239.80 MWD (5)
Page 3
Survey
End Date
7/3/2017 !
3
7/9/2017
7/11/2017 1
i
7113/2017
r
Annotation
TIP
KOP
Interpolated Azimuth
Interpolated Azimuth
Interpolated Azimuth -.
First Good Survey
COMPASS 5000.14 Build 85
ConocoPhillips
ConocoPhillips
Definitive Survey Report
BA UER S
Company:
Project:
Site:
Well:
Wellbore:
Design:
ConocoPhillips (Alaska) Inc. -Kupi
Kuparuk River Unit
Kuparuk 1C Pad
1C-04
1C-04
1C-04
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 1C-04
1C-04 Q 94.00usft (1C-04)
1C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Survey
Map
Map
Vertical
MD
Inc
Azi
TVD
TVDSS
+N/ -S
-E/-W
DLS
lush)
(1)
(1)
(usft)
(usft)
lush)
lush)
Northing
Easting
(1/100')
Section
Survey Tool Name
Annotation
(ft)
Ihl
tft).
8,678.99
91.69
336.97
6,441.02
6,347.02
-71.91
-3,614.52
5,968,62521
558,451.55
6.94
2,268.28
MWD(5)
8,708.95
90.92
335.55
6,440.33
6,346.33
-04.49
-3,626.58
5,968,652.52
558,439.26
5.39
2,297.03
MM (5)
8,739.25
90.80
33376
6,439.88
6,345.88
-17.12
-3,639.55
5,968,6]9]9
558,426.07
5.92
2,326.34
MWD (5)
i 8,769.15
i
91.32
332.05
6,439.32
6,34533
9.50
-3,653.16
5,968,706.28
558,412.24
5.98
2,35548
MWD(5)
i 8,799.23
92.09
331.03
6,438.43
6,344.43
35.93
-3,667.49
5,968,73259
558,397.69
4.25
2,384.94
MWD (5)
8,828.96
92.95
331.40
6,437.12
6,343.12
61.96
-3,681.79
5,968,758.50
558,383.18
3.15
2,414.07
MWD(5)
t 8,859.34
94.12
330.56
6,435.25
6,341.25
88.48
-3,696.50
5,968,78489
558,368.25
4.74
2,443.84
MWD(5)
8,88895
94.86
331.11
6,432.93
6,338.93
114.25
-3,710.88
5,968,81055
558.353.65
3.11
2,472.83
MWD (5)
y
i 8,918.75
94.61
330.97
6,430.47
6,336.47
14024
-3,725.26
5,968,836.41
558,339.06
0.96
2,501.98
MWD(5)
6,948.61
94.86
332.73
6,428.01
6,334.01
166.47
-3,739.30
5,968,86253
558,324.81
5.93
2,531.10
MWD(5)
8
8,978.99
94.30
33351
6,425.58
6,331.58
19348
-3,752.99
5,968,889.42
558,310.89
3.15
2,560.60
MWD(5)
I
9,010.31
94.65
332.92
6,423.14
6,329.14
221.36
-3,767.07
5,968,917.18
558,296.59
2.19
2,590.99
MWD (5)
I
9,038.11
95.78
334.99
6,420.61
6,32661
246.23
-3,779.22
5,968,941.94
558,284.23
846
2,617.86
MVJD(5)
f
9,069.02
96.68
337.59
6,41].25
6,323.26
274.36
-3,791.58
5,968,969.97
558,271.65
8.85
2,64].35
MWD (5)
i
9,099.19
93.10
339.04
6,414.68
6,320.68
302.29
-3,80268
5,968,997.80
558,260.31
12.80
2,675.68
MM1D(5)
)
4
I 9,128.27
9147
339.72
6,413.54
6,319.54
32948
-3,812.91
5,969,02491
558,249.86
626
2,703.29
MWD(5)
s
9,158.91
94.18
34267
6,412.05
6,318.05
35645
-3,822.78
5,969,053.79
558,239.75
1320
2,731.82
MWD(5)
9,18881
93.47
344.13
6,410.05
6,316.05
387.04
-3,831.30
5,969,08230
558,231.00
542
2,759.20
MM (5)
i
9,218.20
92.40
345.72
6,408.55
6,314.55
415.38
-3,838.93
5,969,110.57
558,223.13
6.51
2,785.82
MWD (5)
i
{ 9,248.64
93.23
34873
6,407.05
6,31305
445.02
-3,845.66
5,969,140.16
558,216.16
1025
2,812.85
MWD(5)
9,278.89
93.66
350.84
6,405.23
6,311.23
47474
-3,851.01
5,969,16983
558,210.56
7.11
2,839.05
MWD (5)
iCl
9,308.76
91.90
349.32
6,403.78
6,309]8
504.13
-3,856.15
5,969,199.17
558,205.18
778
2,864.87
MM (5)
i
9,340.38
91.17
346.30
6,402.94
6,308.94
535.02
-3,862.82
5,969,23000
55619825
9.82
2,892.82
MWD (5)
i
I 9,37040
92.30
34552
6,402.03
6,308.03
564.12
-3,870.13
5,969,259.04
558,190.71
4.57
2,919.81
MWD (5)
0 9,398.81
91.72
343.45
6,401.03
6,307.03
59148
-3,877.72
5,969,286.33
558,182.89
7.56
2,945.65
MW) (5)
F 9,428.59
9163
340.81
6,400.16
6,306.16
619.81
-3,886.86
5,969,314.58
558,17352
8.87
2,973.22
MWD (5)
9,45941
9224
33974
6,399.12
6,305.12
648.80
-3,897.25
5,969,34348
558,162.89
399
3,002.11
MM (5)
9,488.03
92.86
338.86
6,397.85
6,303.85
675.55
-3,907 36
5,969,370.14
558,152.56
3.76
3,029.10
MWD (5)
i 9,51869
92.03
337.03
6,396.54
6,302.54
703.93
-3,918.86
5,969,398.43
558,140.83
6.55
3,058.24
MWD (5)
I 9.548.83
92.89
334.60
6,395.24
6,301.24
731.40
-3,931.19
5,969,425]9
556,128.27
8.55
3,087.21
MM (5)
9,578.33
91.90
331.43
6,394.01
6,300.01
757%
-3,944.57
5,969451 94
558,114.68
11.25
3.11592
MWD(5)
7272017 1 4608P
Page
4
COMPASS 5000.14 Build 85
ConocoPhillips
Company: ConocoPhillips (Alaska) Inc. -Kup1
Project: Kuparuk River Unit
Site: Kuparuk 1C Pad
Weil: 1C-04
Wellbore: 1C-04
Design: 1C-04
ConocoPhillips
Definitive Survey ReportucHFs
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Database:
Well 1C-04
1C-04 @ 94.00usft (1C-04)
1 C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
EDT Alaska Sandbox
BAER
a,.. Survey
Map.
Map
Vertical
_ MD
Inc
Azi
TVD
TVDSS
+NI -S
+E/ -W
Northing
Eaeting
DLS
Section
(usft)
(1)
(1
(usft)
(usft)
(usft)
(usft)
("1100')
Survey Tool Name
Annotation
(ft)
(ft)
(ft)
1 9,608.75
91.96
329.34
6,392.99
6,296.99
784.09
-3,959.59
5,969,478.24
558,099:44
6.87
3,145.83 MWD (5)
9,638.83
91.78
327.35
6,392.00
6,298.01
809.68
-3,975.37
5,969,503.70
558,083.45
6.64
3,175.57 MAD (5)
9,666.64
92.24
325.50
6,391.03
6,297.03
832.84
-3,990.74
5,969,526.72
558,067.89
685
3,203.19 MWD (5)
1 9,694.56
I
94.70
325.18
6,389.34
6,295.34
855.76
-0,076.58
5,969,549.51
558,051,86
8.88
3,230.93 MAD (5)
i
I 9,724.20
93.78
323.90
6,387.15
6,293.15
879.83
4,023.73
5,969,573.44
558,034.51
5.31
3,260.40 MWD (5)
f
i 9,754.22
92.27
322.86
6,385.56
6,291.56
903.89
4,04161
5,969,597.35
558,016.44
6.10
3,290.32 MWD (5)
i
3 9,784.11
90.77
321.95
6,384.77
6,290.77
927.57
4,059.84
5,969,620.87
557,998.01
5.87
3,320.17 MWD (5)
9,813.13
88.19
320.79
6,385.03
6,291.03
950.23
-0,077.96
5,969,643.39
557,979.71
9.75
3,349.18 MWD (5)
9,843.50
STT
318.43
6,386,23
6,29223
973.35
-0,097.62
5,969,66633
557,959.86
8.30
3,379.52 MWD (5)
)
9,874.24
90.21
31742
6,386.90
6,292.90
996.16
4,118.21
5,969,68897
557939.09
10.02
3,410.23 MWD (5)
i
i 9,904.21
89.75
31764
6,386.91
6,292.91
1,018.26
4,138.45
5,969,71090
557,918.67
1.70
3,440.18 MM (5)
S 9,934.29
87.39
317.72
6,387.66
6,293.66
1,040.49
4,158.69
5,969,73297
557,898.24
7.85
3,470.22 MWD(5)
_-
iS 9,964.49
87.36
32028
6,389.04
6,29504
1,063.26
4,17848
5,969,755.57
557,878.27
8.47
3,500.38 MWD(5)
?
9,994.47
87.42
322.04
6,39041
6,296.41
1,086.59
4197.26
5,969,77873
557,859.30
5.87
3,530.32 MWD(5)
10,023.80
91.50
328.06
6.390.68
6,296.68
1,110.61
4,214.05
5,969,802.62
557,842.31
24.79
3,559.52 MWD (5)
)
10,054.20
89.63
330.51
6,390.38
6,296.38
1,136.74
4,229.58
5,969,82861
557,826.57
10.14
3,589.51 MWD (5)
r
10,083.98
87.63
33122
6,391.10
6,297.10
1,162.74
4,244.07
5,969,854.49
557,811.86
7.13
3,618.75 MWD (5)
f
1
I 10,114.08
87.45
333.78
6,392.39
6,298.39
1,189.42
4,257.96
5,969,88105
557,797.76
8.52
3,648.11 MWD (5)
10,143.96
86.72
336:38
6,393.91
6,299.91
1,216.48
4,270.53
5,969,908.00
557,784.97
9.03
3,676.92 MWD (5)
1
I 10,168.99
86.84
343.34
6,395.32
6,301.32
1,239.93
4,279.13
5,969,931.38
557,776.17
27.77
3,700.41 MWD (5)
10,198.86
85.14
342.42
6,397.40
6,303.40
1,268.40
4,287.90
5,969,95977
557,767.17
647
3,727.86 MM (5)
t
II 10,228.95
8258
34148
6,400.62
6,306.62
1,296.84
4,297.17
5,969,988.14
557,757.67
9.06
3,755.61 MWD (5)
1 10,251.01
81.71
340.79
6,403.64
6,303.64
1,317.52
4,304.23
5,970,008.75
557,750.43
5.02
3,775.99 MWD (5)
1
10,278.81
81.37
336.07
6,407.73
6,313.73
1,343.09
4,314.34
5,970,034.23
557,740.11
16.84
3,802.07 MWD(5)
10,30847
81.21
333.73
6,412.22
6,318.22
1,369.63
3,326.77
5,970,060.67
557,727.46
7.82
3,830.40 MM (5)
10,340.43
83.17
334.15
6,416.56
6,322.56
1,398.08
4,340.68
5,970,089.00
557,713.32
6.27
3,861,13 MWD (5)
10,369.07
83.57
333.30
6,419.87
6,325.87
1,423.59
4,353.28
5,970,114.40
557,700.52
3.26
3,888.76 MWD(5)
10,398.67
84.37
331.89
6,422.98
6,328.98
1,449.72
4,366.83
5,970,14041
557,686.75
5.45
3,917.49 MM (5)
i
10,42863
8600
332.17
6,425.50
6,331.50
1,476.08
4,380.83
5,970,166.66
557,672.53
5.52
3,946.69 MWD (5)
10,458.99
87.76
332.51
6427.15
6,333.15
1,502.93
4,394.90
5,970,193.39
557,658.24
590
3,976.30 MWD (5)
10,482.60
89.63
332,4
6,42269
6,333.69
1523.86
-4405.81
5,970.214.23
557647.16
7.93
3,999.35 MWO(5)
7/272017 1:45:08PM
Page
5
COMPASS 5000.14 Build 85
Well 1C-04�V
1C-04 @ 94.00usft (1C-04)
1C-04 @ 94.00usft(1 C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Map
Vertical
Easting
DLS
ConocoPhillips
ConocoPhillips
(R)
0100')
(ft)
557,632.48
3.28
4,029.95
MWD(5)
557,617.37
6.55
4,060.62
Definitive Survey Report
Company:
ConocoPhillips
(Alaska) Inc. -Kup1
MWD (6)
557,583.65
Local Co-ordinate Reference:
Project:
Kupamk River Unit
557,567.40
4.14
4,153.32
TVD Reference:
Site:
Kupamk 1C
Pad
MWD (5)
557,532.83
6.43
MD Reference:
Well:
1C-04
11.71
4,242.62
MM (5)
557,490.55
North Reference:
Wellbore:
1C-04
557,463.05
0.00
4,322.00
PROJECTEDto TD
Survey Calculation Method:
Design:
1C-04
Database:
:Survey.__-_..-_.��.._.,�.
MD
Inc
AN
TVD
TVDSS
«N/ -S
+E/ -W Map
_
(usft)
(°)
(°)
(usft)
(usft)
(usft)
(usft Northing
) 10,513.95
90.64
33263
6,427.61
6,333.61
1,55168
7 24192
-0,420.27 5,070,0,
10,545.27
90.18
33063
6,427.39
6,333.39
1,579.24
4,435.15 5,970,269.35
10,573.20
8942
328.58
6,427.49
6,33349
1,603.33
4,44928 5,970,293.32
10,609.31
90.89
327.40
6,427.39
6,333.39
1,633.94
4,468.42 5,970,323.78
10,638.96
92.06
327.03
6,426.62
6,332.62
1,658.86
-,464.47 5,970,348.56
10,668.41
92.15
324.55
6,425.54
6,331.54
1,683.20
4,501.01 5,970,372.76
10,69865
89.63
324.17
6,425.07
6,331.07
1,707.77
4,518.63 5,970,397.16
10,728.57
87.82
321.17
6,425.74
6,331.74
1,731.55
-0,536.76 5,970,420.81
10,765.85
87.94
319.72
6,427.12
6,333.12
1,760.27
4,560.49 5,970,44933
10,806.00
87.94
319.72
6,42863
6,334.63
1,792.41
4,587.72 5,970,481.24
Well 1C-04�V
1C-04 @ 94.00usft (1C-04)
1C-04 @ 94.00usft(1 C-04)
True
Minimum Curvature
EDT Alaska Sandbox
Map
Vertical
Easting
DLS
Section
Survey Tool Name
(R)
0100')
(ft)
557,632.48
3.28
4,029.95
MWD(5)
557,617.37
6.55
4,060.62
MWD(5)
557,603.04
7.83
4,088.16
MWD (6)
557,583.65
5.22
4,123.92
NIM (5)
557,567.40
4.14
4,153.32
MWD (5)
557,550.65
8.42
4,182.60
MWD (5)
557,532.83
6.43
4,212.75
MWD (5)
557514.50
11.71
4,242.62
MM (5)
557,490.55
3.90
4,279.87
MWD (5)
557,463.05
0.00
4,322.00
PROJECTEDto TD
Annotation
BA ER
ll1GHPS
727/2017 1:45:08PM Page 6 COMPASS 5000.14 Build 85
THE STATE
°fALASKA
GOVERNOR BILL WALKER
K. Starck
CTD Director
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
W W W.00gcc.alaska.gov
Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-04AL1
ConocoPhillips Alaska, Inc.
Permit to Drill Number: 217-083
Surface Location: 1509' FNL, 4221' FEL, SEC. 12, TI IN, R10E, UM
Bottomhole Location: 5199' FNL, 3528' FEL, SEC. 2, TI IN, R10E, UM
Dear Mr. Starck:
Enclosed is the approved application for permit to re -drill the above referenced development well.
The permit is for a new wellbore segment of existing well Permit No. 217-078, API No. 50-029-
20547-01-00. Production should continue to be reported as a function of the original API number
stated above.
This permit to drill does not exempt you from obtaining additional permits or an approval required
by law from other governmental agencies and does not authorize conducting drilling operations
until all other required permits and approvals have been issued. In addition, the AOGCC reserves
the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska
Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply
with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or an AOGCC order, or the terms and conditions of this permit may result in the revocation or
suspension of the permit.
Sincerely,
CaFoerster
Chair
DATED this 7 ' day of June, 2017.
STATE OF ALASKA I
ALP. .A OIL AND GAS CONSERVATION COMML ,ON
PERMIT TO DRILL
20 AAC 25.005
DECEIVED
MAY 2 4 2017
ArV_`rorr
1a. Type of Work:
1 b. Proposed Well Class: Exploratory - Gas ❑ Service - WAG 0 Service - Disp ❑
1c. Specify if well is proposed for:
Drill ❑ Lateral ❑�
Stratigraphic Test ❑ Development - Oil Service - Winj ❑ Single Zone 0 -
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:
ConocoPhillips Alaska Inc
Bond No. 5952180 •
KRU 1C-04AL1-
3. Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 100360 Anchorage, AK 99510-0360
MD: 10800' TVD: 6437'-
437'.4a.
Kuparuk River Pool /
4a.Location of Well (Governmental Section):
7. Property Designation:
Surface: 1509' FNL, 4221' FEL, Sec 12, T71 N, R10E, U
ADL 25649 '
Kuparuk River Oil Pool,
Top of Productive Horizon:
8. DNR Approval Number:
13. Approximate Spud Date:
1836' FNL, 2520' FEL, Sec 11, T11 N, R1 OE, UM
ALK 467
6/6/2017
Total Depth:
9. Acres in Property:
14. Distance to Nearest Property:
5199' FNL, 3528' FEL, Sec 2, T1IN, R10E, UM
2560
9800'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL (ft): 94' •
15. Distance to Nearest Well Open
Surface: x- 562065 y- 5968727 Zone- 4-
GL / BF Elevation above MSL (ft): 61',
to Same Pool: 303', IC -03A
16. Deviated wells: Kickoff depth: 8500 feet .
17. Maximum Potential Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 97 degrees.
Downhole: 3841 Surface: 3194 .
18. Casing Program: Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f. orsacks
Hole Casing Weight Grade Coupling I Length
MD TVD MD TVD (including stage data)
3" 2-3/8" 4.7# L-80 ST -L 3830'
6970' 6292' 10800' 6437' Slotted
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):
7575' 6896' N/A 7456' 6777' 7258'
Casing Length Size Cement Volume MD TVD
Conductor/Structural 46' 20" 245 sx AS II 80' 80'
Surface 2877' 13-3/8" 1800 sx Fondu & 300 sx AS II 2910' 2708'
Production 6906' 9-5/8" 800 sx Class G 6936' 6258'
Liner 933' 7" 210 sx Class G 7545' 6866'
Perforation Depth MD (ft): 7088'- 7148' Perforation Depth TVD (ft): 6410'- 6470'
7208'- 7218' 6530'- 6540'
Hydraulic Fracture planned? Yes ❑ No 7
20. Attachments: Property Plat ❑ BOP Sketch Divertter Sketch
8 Drilling
Report
B
DrillingeFluiv. d Ppogth Pam e✓ 20 AAC 25.050 equi ements8
21. Verbal Approval: Commission Representative: Date
22. 1 hereby certify that the foregoing is true and the procedure approved herein will not be
deviated from without prior written approval.
Contact Name: Keith Herring
Authorized Name: K. Starck Contact Email: Keith. E. Herrin co .cOm
Authorized Title: CTD Director Contact Phone: 263-4321
.^�
Authorized Signature: Date: - - /N6 11
Commission Use Only
-Number:
Permit to DrillTp2
API
Permit Approval
See cover letter for other
Number: - VOJ
C -T�
50- O2 - QJ � - �p0 - �V
Date:
requirements.
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales:
Other:�P rZ51.- 4000 S_-4 Samples req'd: Yes ❑ N,Z Mud log req'd: Yes❑r� No[Z
Y
/�TZ nvGa�/" r�V'Cvr�r 17-5jt f_a ZSUf7�S measures: YesZNo Directional svy req'd: Yes 2 No
r❑] ,❑/
j} va f-7 � Pte -e fp 2b : i-, tc 2J.O 15-( ( b) 1S'pacing e2eption req'd: Yes ❑ No Lr� Inclination -only svy req'd: Yes ❑ No,L�vr
%5 U iG hte�� lJ R l UW �� It k-ickO F 17Gt ✓� f to lJC a ✓l�'ost initial injection MIT req'd: Yes No LST
J / n o 'V7, tavlcJ rh < Pare- 1%i a l-rr-cr 1,
APPROVED BY
Approved by COMMISSIONER THE COMMISSION Date: _7 - 17
Submit Form and
Form 10-40 �v�vipe� 6110 / /l j�i� (�ri� I�IIr/yOr�4 mont from the Qate of approval per 20 AAC 25.005(8) Attach ems in Duplicate
RZA Sit U R v' H L / ✓ll/ (�
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
May 23, 2017
Commissioner - State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Dear Commissioner:
RECEIVED
MAY 2 4 2011
.I OGCV
ConocoPhillips Alaska, Inc. hereby submits applications for permits to drill two laterals out of the KRU 1C-04
(PTD# 180-155) using the coiled tubing drilling rig, Nabors CDR3-AC.
CTD operations are scheduled to begin in June 2017. The objective will be to drill the 2 laterals KRU 1C -04A
and 1C-04AL1 targeting the Kuparuk C -sands.
To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC
25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being
limited to 500' from the original point.
Attached to this application are the following documents:
- Permit to Drill Application Forms (10-401) for 1C -04A & 1C-04AL1
- Detailed Summary of Operations
- Directional Plans for 1C -04A & 1C-04AL1
- Current wellbore schematic
- Proposed CTD schematic
The application for sundry approval (10-403) for 1C-04 was approved on 5/17/2017.
If you have any questions or require additional information, please contact me at 907-263-4321.
Sincerely,
Keith Herring
Coiled Tubing Drilling Engineer
ConocoPhillips Alaska
Kuparuk CTD Laterals
1 C -04A & 1 C-04AL1
Application for Permit to Drill Document
1. Well Name and Classification........................................................................................................ 2
(Requirements of 20 AAC 25.005(1) and 20 AAC 25.005(b))......................_..._......................................................................................2
2.
Location Summary.......................................................................................................................... 2
(Requirements of 20 AAC 25.005(c)(2))..................................................................................................................................................2
3.
Blowout Prevention Equipment Information.................................................................................
2
(Requirements of 20 AAC 25.005(c)(3)).................................................................................................................................................2
4.
Drilling Hazards Information and Reservoir Pressure..................................................................
2
(Requirements of 20 AAC 25.005(c)(4)).................................................................................................................................................2
5.
Procedure for Conducting Formation Integrity tests...................................................................
2
(Requirements of 20 AAC 25.005(c)(5))..................................................................................................................................................2
6.
Casing and Cementing Program....................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
7.
Diverter System Information..........................................................................................................3
(Requirements of 20 AAC 25.005(c)(7))..................................................................................................................................................3
8.
Drilling Fluids Program..................................................................................................................
3
(Requirements of 20 AAC 25.005(c)(6))..................................................................................................................................................3
9.
Abnormally Pressured Formation Information.............................................................................4
(Requirements of 20 AAC 25.005(c)(9))..................................................................................................................................................4
10.
Seismic Analysis.............................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(10))................................................................................................................................................4
11.
Seabed Condition Analysis............................................................................................................4
(Requirements of 20 AAC 25.005(c)(11))................................................................................................................................................
4
12.
Evidence of Bonding......................................................................................................................
4
(Requirements of 20 AAC 25.005(c)(12))................................................................................................................................................4
13.
Proposed Drilling Program.............................................................................................................4
(Requirements of 20 AAC 25.005(c)(13))................................................................................................................................................4
Summaryof Operations...................................................................................................................................................4
LinerRunning...................................................................................................................................................................6
14.
Disposal of Drilling Mud and Cuttings.......................................................................................... 6
(Requirements of 20 AAC 25.005(c)(14))................................................................................................................................................
6
15.
Directional Plans for Intentionally Deviated Wells.......................................................................
6
(Requirements of 20 AAC 25.050(b))......................................................................................................................................................
6
16.
Attachments....................................................................................................................................6
Attachment 1: Directional Plans for 1C -04A & 1C-04AL1...............................................................................................6
Attachment 2: Current Well Schematic for 1C-04............................................................................................................6
Attachment 3: Proposed Well Schematic for 1 C -04A & 1 C-04AL1.................................................................................6
Page 1 of 6 May 23, 2016
PTD Application: 1C -04A & 1C-04AL1
Well Name and Classification
(Requirements of 20 AAC 25.005(f) and 20 AAC 25.005(b))
The proposed laterals described in this document are 1C -04A & 1C-04AL1. All laterals will be classified as
"Development -Oil" wells.
2. Location Summary
(Requirements of 20 AAC 25.005(c)(2))
These laterals will target the C sand package in the Kuparuk reservoir. See attached 10-401 form for surface
and subsurface coordinates of the 1C -04A & 1C-04AL1.
3. Blowout Prevention Equipment Information
(Requirements of 20 AAC 25.005 (c)(3))
Please reference blowout prevention (BOP) schematics on file with the Commission for Nabors CDR3-AC.
BOP equipment is as required per 20 AAC 25.036 for thru-tubing drilling operations.
- Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4,000 psi. Using the
maximum formation pressure in the area of 3,841'psi in 1C-02 (i.e. 11.4 ppg EMW), the maximum
potential surface pressure in 1C-04, assuming a gas gradient of 0.1 psi/ft, would be 3,194 psi. See
the "Drilling Hazards Information and Reservoir Pressure" section for more details.
- The annular preventer will be tested to 250 psi and 2,500 psi.
4. Drilling Hazards Information and Reservoir Pressure
(Requirements of 20 AAC 25.005 (c)(4))
Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a))
The formation pressure in KRU 1C-04 was measured to be 3,087 psi (9.2 ppg EMW) on 12/7/2016. The
maximum downhole pressure in the 1C-04 vicinity is to the southeast in the 1C-02 at 3,841 psi (11.4 ppg EMW)
from January of 2016.
Potential Gas Zones (Requirements of 20 AAC 25.005 (c)(4)(b))
Offset injection wells to 1 C-04 have injected gas, so there is a chance of encountering free gas while drilling the
1 C-04 laterals. If gas is detected in the returns the contaminated mud can be diverted to a storage tank away
from the rig.
Potential Causes of Hole Problems (Requirements of 20 AAC 25.005 (c)(4)(c))
The major expected risk of hole problems in the 1C-04 laterals will be shale instability across faults. Managed
pressure drilling (MPD) will be used to reduce the risk of shale instability associated with fault crossings.
5. Procedure for Conducting Formation Integrity tests
(Requirements of 20 AAC 25.005(c)(5))
The 1 C-04 laterals will be drilled under 20 AAC 25.036 for thru-tubing drilling operations so a formation integrity
test is not required.
Page 2 of 6 May 23, 2016
PTD Application: 1C -04A & 1C-04AL1
6. Casing and Cementing Program
(Requirements of 20 AAC 25.005(c)(6))
New Completion Details
Lateral Name
Liner Top
Liner Btm
Liner Top
Liner Btm
Liner Details
Btm
MD
MD
MD
TVDSS
TVDSS
Conductor
1C -04A
8500'
10800'
6438'
6412'
2-3/8", 4.7#, L-80, ST -L slotted liner;
0'
80'
1530
520
Surface
aluminum billet on to
1 C-04AL1
6970'
10800'
6292'
6437'
2-3/8", 4.7#, L-80, ST -L slotted liner;
2708'
1730
770
Production
9-5/8"
up into 3-1/2" tubing
Existing CasinglUner Information
Category
OD
Weight
(ppf)
Grade
Connection
Top
MD
Btm
MD
Top
TVD
Btm
TVD
Burst
psi
Collapse
psi
Conductor
20"
94.0
H-40
Welded
0'
80'
0'
80'
1530
520
Surface
13-3/8"
72.0
N-40
BTC
0'
2910'
0'
2708'
1730
770
Production
9-5/8"
47.0
L-80
BTC
0'
6936'
0'
6258'
6870
4760
Liner
7"
26.0
K-55
BTC
6612'
7545'
5936'
6866'
4980
4320
Tubing
3-1/2"
9.3
L-80
EUE 8rd MOD
0'
6986'
0'
6309'
10160
10540
7. Diverter System Information
(Requirements of 20 AAC 25.005(c)(7))
Nabors CDR3-AC will be operating under 20 AAC 25.036, for thru-tubing drilling operations. Therefore, a
diverter system is not required.
8. Drilling Fluids Program
(Requirements of 20 AAC 25.005(c)(8))
Diagram of Drilling System
A diagram of the Nabors CDR3-AC mud system is on file with the Commission.
Description of Drilling Fluid System
Window milling operations: Chloride -based RoVis mud (8.6 ppg)
Drilling operations: Chloride -based RoVis mud (8.6 ppg) This mud weight will not hydrostatically
overbalance the reservoir pressure; overbalanced conditions will be maintained using MPD practices
described below.
— Completion operations: The well will be loaded with 11.4 ppg NaBr completion fluid in order to provide
formation over -balance and wellbore stability while running completions.
Managed Pressure Drilling Practice
Managed pressure drilling (MPD) techniques will be employed to maintain a constant overbalanced pressure on
the open hole formation and promote wellbore stability throughout the coiled tubing drilling (CTD) process. Mud
weight is not, in many cases, the primary well control barrier. This is satisfied with the 5,000 psi rated coiled
tubing pack off and MPD choke. BOPE equipment provides the secondary well control as detailed in section 3
"Blowout Prevention Equipment Information".
In the 1C-04 laterals we will target a constant BHP of 11.4 ppg EMW at the window. The constant BHP target
will be adjusted through choke pressure and/or mud weight increases to maintain overbalanced conditions if
increased reservoir pressure is encountered. Additional choke pressure or increased mud weight may also be
employed for improved borehole stability. Any change of circulating friction pressure due to change in pump rates
or change in depth of circulation will be offset with back pressure adjustments.
Page 3 of 6 May 23, 2016
PTD Application: 1C -04A & 1C-04AL1
Pressure at the 1C-04 Window (7150' MD. 6472' TVD) Usina MPD
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 1C-04 is a Kuparuk C -sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize two laterals to target the C sands to the northwest of the 1 C-04 parent
wellbore. The laterals will add new resources and improve existing recovery.
Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 6984'
MD will be milled out to a 2.80" ID. The existing C -sand perforations will be squeezed with cement and
the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing.
Following the cement squeeze Nabors CDR3-AC will mill a pilot hole to 7180' MD and set a mechanical
whipstock in the 2.80" pilot hole to kick off at 7150' MD. A window will be milled in the 7" casing at
7150' MD to drill and complete the 1C-04 laterals.
The 1 C -04A sidetrack will exit the cement pilot hole at 7150' MD and TD at 10800' MD, targeting the C4
sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8500'MD with an
aluminum billet for kicking off the 1C-04AL1 lateral.
The 1 C-04AL1 lateral will drill to the northwest to a TD of 10800' MD targeting the C4 sand. It will be
completed with 2-3/8" slotted liner from TD up to 6970' MD with a deployment sleeve inside the 3-1/2"
tubing.
Page 4 of 6 May 23, 2016
Pumps On 1.5 bpm)
Pumps Off
C -sand Formation Pressure 9.2
3096 psi
3096 psi
Mud Hydrostatic 8.6
2894 psi
2894 psi
Annular friction i.e. ECD, 0.08psi/ft)
572 psi
0 psi
Mud + ECD Combined
no chokepressure)
3466 psi
overbalanced -370psi)
2894 psi
underbalanced -202psi)
Target BHP at Window 11.4
3837 psi
3837 psi
Choke Pressure Required to Maintain
Target BHP
371 psi
943 psi
9. Abnormally Pressured Formation Information
(Requirements of 20 AAC 25.005(c)(9))
N/A - Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
(Requirements of 20 AAC 25.005(c)(10))
N/A - Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
(Requirements of 20 AAC 25.005(c)(11))
N/A - Application is for a land based well.
12. Evidence of Bonding
(Requirements of 20 AAC 25.005(c)(12))
Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
(Requirements of 20 AAC 25.005(c)(13))
Summary of Operations
Background
Well KRU 1C-04 is a Kuparuk C -sand producer equipped with 3-1/2" tubing and 7" production casing.
The CTD sidetrack will utilize two laterals to target the C sands to the northwest of the 1 C-04 parent
wellbore. The laterals will add new resources and improve existing recovery.
Prior to CTD operations, E -line will punch 2' of holes in the 3-1/2" tubing tail and the D nipple at 6984'
MD will be milled out to a 2.80" ID. The existing C -sand perforations will be squeezed with cement and
the 3-1/2" tubing tail will be cemented in place to provide a means to kick out of the 7" casing.
Following the cement squeeze Nabors CDR3-AC will mill a pilot hole to 7180' MD and set a mechanical
whipstock in the 2.80" pilot hole to kick off at 7150' MD. A window will be milled in the 7" casing at
7150' MD to drill and complete the 1C-04 laterals.
The 1 C -04A sidetrack will exit the cement pilot hole at 7150' MD and TD at 10800' MD, targeting the C4
sand to the northwest. It will be completed with 2-3/8" slotted liner from TD up to 8500'MD with an
aluminum billet for kicking off the 1C-04AL1 lateral.
The 1 C-04AL1 lateral will drill to the northwest to a TD of 10800' MD targeting the C4 sand. It will be
completed with 2-3/8" slotted liner from TD up to 6970' MD with a deployment sleeve inside the 3-1/2"
tubing.
Page 4 of 6 May 23, 2016
PTD Application: 1C -04A & 1C-04AL1
Pre -CTD Work
1. RU Slickline: Obtain SBHP, change our GLV's, and pressure test.
2. RU E -line: Punch 2' of holes in the 3-1/2" tubing tail at 6964' MD.
3. RU Pumping Unit: Perform injectivity test down the tubing.
4. RU Service Coil: Mill out "D" nipple and cement squeeze the C -sand perforations up to the holes in
the tubing tail.
5. RU Slickline: Tag top of cement and pressure test cement.
6. Prep site for Nabors CDR3-AC rig and set BPV.
Rie Work
1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test.
1 C -04A Sidetrack (C4 sand - northwest)
a. Mill 2.80" pilot hole through the cement to 7180' MD.
b. Caliper pilot hole.
c. Set top of whipstock at 7150' MD.
d. Mill 2.80" window at 7150' MD.
e. Drill 3" bi-center lateral to TD, of 10800' MD.
f. Run 2-3/8" slotted liner with an aluminum billet from TD up to 8500' MD.
3. 1 C-04AL 1 Lateral (C4 sand - northwest)
a. Kickoff of the aluminum billet at 8500' MD.
b. Drill 3" bi-center lateral to TD of 10800' MD.
c. Run 2-3/8" slotted liner with a deployment sleeve from TD up to 6970' MD.
4. Obtain SBHP, freeze protect, set BPV, ND BOPE, and RDMO Nabors CDR3-AC rig.
Post -Rig Work
1. Pull BPV.
2. Return to production.
Pressure Deployment of BHA
The planned bottom hole assemblies (BHAs) are too long to simply isolate by closing the double swab valves on
the Christmas tree. MPD operations require the BHA to be lubricated under pressure using a system of double
swab valves on the Christmas tree, double deployment rams, double check valves and double ball valves in the
BHA, and a slick -line lubricator can be used. This pressure control equipment listed ensures there are always two
barriers to reservoir pressure, both internal and external to the BHA, during the deployment process.
During BHA deployment, the following steps are observed.
- Initially the double swab valves on the tree are closed to isolate reservoir pressure. The lubricator is
installed on the BOP riser with the BHA inside the lubricator.
- Pressure is applied to the lubricator to equalize across the swab valves. The swab valves are opened and
the BHA is lowered in place via slickline.
- When the BHA is spaced out properly, the double deployment rams are closed on the BHA to isolate
reservoir pressure via the annulus. A closed set of double ball valves and double check valves isolate
reservoir pressure internal to the BHA. Slips on the double deployment rams prevent the BHA from
moving when differential pressure is applied. The lubricator is removed once pressure is bled off above
the deployment rams.
- The coiled tubing is made up to the BHA with the double ball valves plus the double check valves in the
closed position. Pressure is applied to the coiled tubing to equalize internal pressure and then the
double ball valves are opened. The injector head is made up to the riser, annular pressure is equalized,
and the deployment rams are opened. The BHA and coiled tubing are now ready to run in the hole.
During BHA undeployment, the steps listed above are observed, only in reverse.
Page 5 of 6 May 23, 2016
PTD ADDlication: 1C -04A & 1C-04AL1
Liner Running
- The 1 C-04 laterals will be displaced to an overbalancing fluid prior to running liner. See "Drilling Fluids"
section for more details.
- While running 2-3/8" slotted liner, a joint of 2-3/8" non -slotted tubing will be standing by for emergency
deployment. A floor valve is made up onto this joint ahead of time, and the rig crew conducts a
deployment drill with this emergency joint on every slotted liner run. The 2-3/8" rams will provide
secondary well control while running 2-3/8" liner.
14. Disposal of Drilling Mud and Cuttings
(Requirements of 20 AAC 25.005(c)(14))
• No annular injection on this well.
• All solid waste will be transported to the grind and inject facility at DS -4 Prudhoe Bay for disposal.
• Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1 R-18
or 1 B disposal facilities) or Prudhoe DS -4 if a Kuparuk facility is unavailable.
• All wastes and waste fluids hauled from the pad must be properly documented and manifested.
• Contact Kuparuk Environmental Coordinator for questions regarding waste classification. (670-4200).
15. Directional Plans for Intentionally Deviated Wells
(Requirements of 20 AAC 25.050(b))
- The Applicant is the only affected owner.
- Please see Attachment 1: Directional Plans
- Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
- MWD directional, resistivity, and gamma ray will be run over the entire open hole section.
- Distance to Nearest Property Line (measured to KPA boundary at closest point)
Lateral Name
Distance
1C -04A
9000'
1 C-04AL1
9800'
Distance to Nearest Well within Pool
Laral Name Distance Well
1 C-0te4A 303' 1 C -03A
1 C-04AL1 303' IC -0_0 C -03A
16. Attachments
Attachment 1: Directional Plans for 1C -04A & 1C-04AL1laterals
Attachment 2: Current Well Schematic for IC -04
Attachment 3: Proposed Well Schematic for 1C -04A & 1C-04AL1 laterals
Page 6 of 6 May 23, 2016
ConocoPhillips
1C-04
Project: Kuparuk River Unit
Kuparuk 1C Patlg.w
.
Alin NlesSite:
WELLBORE DETAILS: 1C -04A
REFERENCE INFORWTIOx
Parent Wellbore: 1C-04a4n,.I
Relelerce: WdIIco4,TMNoonWell:
1C-04
so -e lm
iN
Te on MD: 7100.00
vemca(ND) 144werx: Ic.a4 a 94.00wit(1COqWellbore:
lC-04A
tA
Seeaen lvsl Rale.. Slot -(OWN, ME)
Plan: 1C.04Avi(1C4,111Ca14A)
D.
Meew It1:047
Mi1"4@9�N
Morm
11 ilnc.li` IC -15"W-111
I. ....
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_uu....
HUEROFagc
GHES
ConocoPhillips
ConocoPhillips (Alaska) Inc. -Kup1
Kuparuk River Unit
Kuparuk 1C Pad
1C-04
1 C-04AL1
Plan: 1 C-04AL1_wp02
Standard Planning Report
22 May, 2017
rias
BAKER
HUGHES
ConocoPhillips ,AP:.
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Site:
Kuparuk 1C Pad
Well:
1C-04
Wellbore:
1 C-04ALl
Design:
lC-04AL1_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1 C-04
Mean Sea Level
1C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
project Kuparuk River Unit, North Slope Alaska, United States
Nap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level
Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point
Nap Zone: Alaska Zone 04 Using geodetic scale factor
Site
Kuparuk 1C Pad
Site Position:
Northing:
5,968,522 46 usft Latitude:
70` 19'28,285 N
From:
Map
Easting:
562,372.05 usft Longitude:
149° 29'39,293 W
Position Uncertainty:
0.00 usft Slot Radius:
0.000 in Gdtl Convergence:
0.48 `
Depth
Inclination
Azimuth
System
Well
1C-04
Rate
Rate
Rate
Well Position
+N/ -S
0.00 usft Northing:
5,968,727.00 usft Latitude:
70° 19'30.322 N
(usft)
+E/ -W
0.00 usft Easting:
562,065.00 usft Longitude:
149° 29'48.207 W
Position Uncertainty
8,500.00
0.00 usft Wellhead Elevation:
usft Ground Level:
0.00 usft
-325.35
-3,578.31
0.00
0.00
0.00
Wellbore
1C-04ALl
81.93
323.38
6,350.36
Magnetics
Model Name
Sample Date
Declination Dip Angle
Field Strength
150.00
8,670.00
84.37
(°) (I
mn
-190.01
BGGM2016 8/1/2017
17.55 80.95 57,541
3.49
9.44
70.00
8,770.00
90.83
Design
1C-04AL1_wp02
-100.46
-3,723.38
10.00
Audit Notes:
7.65
50.00
8,970.00
96.85
Version:
6,349.37
Phase: PLAN
Tie On Depth:
8,500.00
Vertical Section:
9.56
Depth From (TVD)
+N/ -S +E1 -W
Direction
15.49
6,332.49
(usft)
(usft) (usft)
C)
-1.90
9.86
-60.50
Goo 0.00
289.13
Plan Sections
Measured
TVD Below
Dogleg
Build
Turn
Depth
Inclination
Azimuth
System
+N/ -S
+E/ -W
Rate
Rate
Rate
TFO
(usft)
(°)
(°I
(usft)
(usft)
(usft)
(°/100ft)
(°AOOft)
(°/100ft)
(^) Target
8,500.00
90.58
318.35
6,343.83
-325.35
-3,578.31
0.00
0.00
0.00
0.00
8,600.00
81.93
323.38
6,350.36
-248.06
-3,641.23
10.00
-8.65
5.03
150.00
8,670.00
84.37
329.99
6,358.71
-190.01
-3,679.36
10.00
3.49
9.44
70.00
8,770.00
90.83
337.64
6,362.90
-100.46
-3,723.38
10.00
6.46
7.65
50.00
8,970.00
96.85
356.76
6,349.37
93.10
-3,767.49
10.00
3.01
9.56
72.00
9,160.00
93.25
15.49
6,332.49
280.40
-3,747.29
10.00
-1.90
9.86
100.00
9,360.00
93.74
355.46
6,320.18
478.09
-3,728.33
10.00
0.24
-10.02
272.00
9,560.00
90.11
335.78
6,313.39
670.72
-3,777.76
10.00
-1.81
-9.84
260.00
9,800.00
90.92
311.79
6,311.19
862.93
-3,918.52
10.00
0.33
-9.99
272.00
9,975.00
90.88
329.29
6,308.43
997.50
-4,029.29
10.00
-0.02
10.00
90.00
10,250.00
90.78
301.79
6,304.39
1,191.88
4,220.04
10.00
-0.04
-10.00
270.00
10,450.00
80.30
318.90
6,320.04
1,320.14
4,371.36
10.00
-5.24
8.56
122.00
10,575.00
85.15
330.52
6,335.92
1,421.18
4,442.79
10.00
3.88
9.30
68.00
10,775.00
90.50
311.23
6;343.58
1,575.40
4,568.31
10.00
2.68
-9.65
285.00
10,800.00
91.35
308.88
6,343.18
1,591.48
4,587.44
10.00
3.42
-9.40
290.00
5222017 11: 4627AM Page 2 COMPASS 5000.1 Build 74
I
ConocoPhillips .��.
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1C-04
Company:
ConocoPhillips (Alaska) Inc. -Kup1
TVD Reference:
Mean Sea Level
Project:
Kuparuk River Unit
MD Reference:
1C-04 @ 94.00usft (1C-04)
Site:
Kuparuk 1C Pad
North Reference:
True
Well:
1C-04
Survey Calculation Method:
Minimum Curvature
Wellbore:
1 C-04AL1
Depth Inclination
Azimuth
Design:
1C-04AL1_wp02
+E/ -W
Section
Planned Survey
Measured
TVD Below
Vertical
Dogleg
Toolface
Map
Map
Depth Inclination
Azimuth
System
+N/ -S
+E/ -W
Section
Rate
Azimuth
Northing
Easting
(usft)
(_)
(1
(usft)
(usft)
(usft)
(usft)
(-]I00ft)
(')
(usft)
(usft)
8,500.00
90.58
318.35
6,343.83
-325.35
-3,578.31
3,274.01
0.00
0.00
5,968,372.10
558489.84
TIP/KOP
8,600.00
81.93
323.38
6,350.36
-248.06
-3,641.23
3,358.79
10.00
150.00
5,968,448.86
558,426.30
Start 10 dls
8,670.00
84.37
329.99
6,358.71
-190.01
-3,679.36
3,413.84
10.00
70.00
5,968,506.58
558,387.69
3
8,700.00
86.31
332.29
6,361.15
-163.83
-3,693.79
3,436.06
10.00
50.00
5,968,532.65
558,373.04
8,770.00
90.83
337.64
6,362.90
-100.46
-3,723.38
3,484.78
10.00
49.81
5,968,595.76
558,342.93
4
8,800.00
91.76
340.49
6,362.22
-72.45
3,734.10
3,504.09
10.00
72.00
5,968,623.68
558,331.99
8,900.00
94.80
350.03
6,356.49
23.97
-3,759.48
3,559.67
10.00
72.06
5,968,719.88
558,305.81
8,970.00
96.85
356.76
6,349.37
93.10
-3,767.49
3,589.89
10.00
72.61
5,968,788.93
558,297.23
6
9,000.00
96.32
359.73
6,345.93
122.89
-3,768.40
3,600.51
10.00
100.00
5,968,818.71
558,296.08
9,100.00
94.44
9.60
6,336.52
221.99
-3,760.29
3,625.34
10.00
100.34
5,968,917.86
558,303.36
9,160.00
93.25
15.49
6,332.49
280.40
-3,747.29
3,632.20
10.00
101.27
5,968,976.37
558,315.87
6
9,200.00
93.38
11.49
6,330.18
319.22
-3,737.98
3,636.13
10.00
-88.00
5,969,015.26
558,324.86
9,300.00
93.64
1.47
6,324.04
418.27
-3,726.73
3,657.96
10.00
-88.23
5,969,114.39
558,335.30
9,360.00
93.74
355.46
6,320.18
478.09
-3,728.33
3,679.08
10.00
-88.85
5,969,174.20
558,333.20
7
9,400.00
93.04
351.52
6,317.81
517.76
-3,732.86
3,696.36
10.00
-100.00
5,969,213.82
556,328.34
9,500.00
91.22
341.67
6,314.09
614.84
-3,756.00
3,750.04
10.00
-100.23
5,969,310.70
558,304.40
9,560.00
90.11
335.78
6,313.39
670.72
-3,777.76
3,788.92
10.00
-100.60
5,969,366.39
558,282.18
8
9,600.00
90.25
331.78
6,313.26
706.60
-3,795.43
3,817.37
10.00
-88.00
5,969,402.12
558,264.22
9,700.00
90.60
321.79
6,312.52
790.15
-3,850.14
3,896.44
10.00
-88.01
5,969,485.21
558,208.83
9,800.00
90.92
311.79
6,311.19
862.93
-3,918.52
3,964.90
10.00
-88.09
5,969,557.41
558,139.86
9
9,900.00
90.90
321.79
6,309.60
935.72
-3,986.89
4,073.35
10.00
90.00
5,969,629.62
558,070.89
9,975.00
90.88
329.29
6,308.43
997.50
-4,029.29
4,133.66
10.00
90.16
5,969,691.05
558,027.98
10
10,000.00
90.87
326.79
6,308.05
1,016.71
-4,042.52
4,153.11
10.00
-90.00
5,969,712.15
558,014.58
10,100.00
90.85
316.79
6,306.54
1,097.18
.4,104.29
4,237.18
10.00
-90.04
5,969,790.09
557,952.17
10,200.00
90.81
306.79
6,305.08
1,163.73
-4,178.74
4,329.34
10.00
-90.19
5,969,856.02
557,877.17
10,250.00
90.78
301.79
6,304.39
1,191.88
-4,220.04
4,377.58
10.00
-90.34
5,969,883.83
557,835.65
11
10,300.00
88.13
306.03
6,304.87
1,219.77
-4,261.52
4,425.91
10.00
122.00
5,969,911.37
557,793.95
10,400.00
82.87
314.57
6,312.72
1,284.14
-4,337.47
4,518.76
10.00
121.96
5,969,975.10
557,717.47
10,450.00
80.30
318.90
6,320.04
1,320.14
-4,371.36
4,562.58
10.00
121.29
5,970,010.82
557,683.29
12
10,500.00
82.20
323.58
6,327.65
1,358.67
-4,402.29
4,604.43
10.00
68.00
5,970,049.09
557,652.05
10,575.00
85.15
330.52
6,335.92
1,421.18
-4,442.79
4,663.18
10.00
67.29
5,970,111.26
557,611.03
13
10,600.00
85.80
328.10
6,337.89
1,442.61
-4,455.51
4,682.22
10.00
-75.00
5,970,132.58
557,598.14
10,700.00
88.47
318.45
6,342.91
1,522.56
-4,515.16
4,764.78
10.00
-74.81
5,970,212.02
557,537.83
10,775.00
90.50
.311.23
6,343.58
1,575.40
-4,568.31
4,832.31
10.00
-74.33
5,970,264.41
557,484.26
14
10,800.00
91.35
308.88
6,343.18
1,591.48
-4,587.44
4,855.66
10.00
-70.00
5,970,280.34
557,464.99
Planned TD at 10800.00
5222017 11:46:27AM Page 3 COMPASS 5000.1 Build 74
ConocoPhillips 11PAR.
ConocoPhillips Planning Report BAKER
HUGHES
Database:
EDM Alaska NSK Sandbox
Company:
ConocoPhillips (Alaska) Inc. -Kupt
Project:
Kupamk River Unit
Site:
Kupamk lC Pad
Well:
1C-04
Wellbore;
1C-04AL7
Design:
1C-04AL1_wp02
Targets
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Well 1C-04
Mean Sea Level
1C-04 @ 94.00usft (1C-04)
True
Minimum Curvature
Target Name
-hiVmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting
-Shape (1) (1 (usft) (usft) (usft) (usft) (usft)
1C-04AL1 T05 0.00 0.00 6,314.00 -7,758.911,135,256.22 5,970,358.00 1,697,238,00
- plan misses target center by 1138858.79usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
- Point
1C-04AL1_T01 0.00 0.00 6,362.00 -9,738.531,136,388.99 5,968,388.00 1,698,387.00
- plan misses target center by 1140006.17usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
- Point
1C-04 CTD Polygon
0.00 0.00 0.00
-7,842.341,135,065.50
5,970,273.00
1,697,048.00
- plan misses target center by 1138686.30usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
1C-04A_Faultl 0.00 0.00 6,312.00 -8,962.111,136,349.41 5,969,164.00
- Polygon
- plan misses target center by 1139960.44usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
(usft) Name
- Polygon
(in)
Point 6,312.00 0.00 0.00 5,969,164.00
Point 1
0.00
0.00
0.00
5,970,273.00
1,697,048.00
Point
0.00
164.15
349.39
5,970,440.02
1,697,395.99
Point
0.00
-961.81
1,421.28
5,969,323.07
1,698,477.05
Polnt4
0.00
-1,501.16
1,577.87
5,968,785.08
1,698,638.08
Points
0.00
-1,807.94
2,519.47
5,968,486.13
1,699,582.10
Point
0.00
-2,455.27
2,671.17
5,967,840.14
1,699,739.13
Point
0.00
-2,632.12
2,162.65
5,967,659.11
1,699,232.14
Point
0.00
-2,607.34
1,703.79
5,967,680.09
1,698,773.13
Point
0.00
-2,353.45
1,233.82
5,967,930.06
1,698,301.12
Point 10
0.00
-1,862.37
1,110.84
5,968,420.06
1,698,174.10
Point 11
0.00
-1,408.81
1,171.57
5,968,874.06
1,698,231.07
Point 12
0.00
-722.29
632.15
5,969,556.03
1,697,686.04
Point 13
0.00
0.00
0.00
5,970,273.00
1,697,048.00
Latitude Longitude
70° 4' 16.368 N 140° 22 32.580 W
70° 3'55.486 N 140° 22'
70° 4' 15.837 N 140'22'38.367W
1C-04AL1 TO4 0.00 0.00 6,343.00 -8,075.461,135,559.64 5,970,044.00
1,697,544.00 70° 4' 12.849 N 140° 22'25.304 W
- plan misses target center by 1139164.32usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
Hole
- Point
Depth
1C-04A_Faultl 0.00 0.00 6,312.00 -8,962.111,136,349.41 5,969,164.00
1,698,341.00 70° 4'1083 N 140° 22'6.639 W
- plan misses target center by 1139960.44usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
(usft) Name
- Polygon
(in)
Point 6,312.00 0.00 0.00 5,969,164.00
1,698,341.00
Point 6,312.00 1.00 1.00 5,969,165.01
1,698,341.99
1C-04A_Fault7 M 0.00 0.00 0.00 -8,962.111,136,349.41 5,969,164.00
1,698,341.00 70° 4'3,083 N 140° 22'&639 W
- plan misses target center by 1139978.09usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
Hole
- Rectangle (sides W1.00 1-11,000.00 D0.00)
Depth
1C-04AL7_T03 0.00 0.00 6,304.00 -8,427.041,135,865.77 5,969,695.00
1,697,853.00 70" 4'8.987 N 140" 22'18102 W
- plan misses target center by 1139472.Bgusft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
(usft) Name
- Point
(in)
1C-04AL1 T02 0.00 0.00 6,313.00 -8,962.111,136,349.41 5,969,164.00
1,698,341.00 70" 4'3.083 N 140° 22'6.639 W
- plan misses target center by 1139960.44usft at 8500.00usft MD (6343.83 TVD, -325.35 N, -3578.31 E)
3.000
- Point
Casing Points
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
10,800.00
6,343.18 23/8"
2.375
3.000
5222017 11:46:27AM Page 4 COMPASS 5000.1 Build 74
Plan Annotations
ConocoPhillips
FEW
ConocoPhillips
Planning Report
Vertical
BA IM
Depth
Depth
NYGM
Database: EDM Alaska NSK Sandbox
Local Co-ordinate Reference:
Well 1C-04
(usft)
Company: ConocoPhillips (Alaska) Inc. -Kupl
ND Reference:
A1ean Sea Level
8,500.00
Project: Kuparuk River Unit
MD Reference:
1C-04 @ 94.00usft (1C-04)
TIP/KOP
Site: Kuparuk 1C Pad
North Reference:
True
-3,64123
Well: 1C-04
Survey Calculation Method:
Minimum Curvature
-190.01
Wellbore: 1C-04AL1
3
8,770.00
6,362.90
Design: 1 C-04AL1_vvp02
-3,723.38
4
8,970.00
Plan Annotations
Measured
Vertical
Local Coordinates
Depth
Depth
+N/ -S
+E/ -W
(usft)
(usft)
(usft)
(usft)
Comment
8,500.00
6,343.83
-325.35
-3,578.31
TIP/KOP
8,600.00
6,350.36
-248.06
-3,64123
Start 10 ols
8,670.00
6,358.71
-190.01
-3,679.36
3
8,770.00
6,362.90
-100.46
-3,723.38
4
8,970.00
6,349.37
93.10
-3,767.49
5
9,160.00
6,332.49
280.40
-3,747.29
6
9,360.00
6,320.18
478.09
-3,728.33
7
9,560.00
6,313.39
670.72
-3,777.76
8
9,800.00
6,311.19
862.93
-3,918.52
9
9,975.00
6,308.43
997.50
4,029.29
10
10,250.00
6,304.39
1,191.88
-4,220.04
11
10,450.00
6,320.04
1,320.14
-4,371.36
12
10,575.00
6,335.92
1,421.18
-4,442.79
13
10,775.00
6,343.58
1,575.40
-4,568.31
14
10,800.00
6,343.18
1,591.48
-4,587.44
Planned TD at 10800.00
5222017 11:4627AM Page 5 COMPASS 5000.1 Build 74
Baker Hughes INTEQ FEARS
ConocoPhillips Travelling Cylinder Report BAKER
HLIG B
Company:
ConomPhillips(Alaska) Inc.-Kupl
Project:
Kuparuk River Unit
Reference Site:
Kuparuk 1C Pad
Site Error:
0.00 usft
Reference Well:
1C-04
Well Error:
0.00 usft
Reference Weilbom
1C-04AL1
Reference Design:
1C-04AL1_wp02
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1C-04
1C-04 @ 94.00usft (1C-04)
1 C-04 Q 94.00usft (1 C-04)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Reference
1C-04AL7_wp02
Filter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft Error Model: ISCWSA
Depth Range:
8,500.00 to 10,800.O0usft Scan Method: Tray. Cylinder North
Results Limited by:
Maximum center -center distance of 1,276.65 usft Error Surface: Elliptical Conic
Survey Tool Program
Date 5/19/2017
From
To
Reference
Offset
(usft)
(usft) Survey (Wellbore)
Tool Name
Description
100.00
7,100.00 1C-04 (1C-04)
BOSS -GYRO
Sperry -Sun BOSS gyro
mullishol
7,100.00
8,500.00 1C-04A_wp05(I C -04A)
MWD
MWD -Standard
Distance
8.500.00
10,800.00 1C-04AL1_wp02(I C-04AL1)
MWD
MWD -Standard
(usft)
--
—_--
-
(usft)
--
Casing Points
Measured Vertical
Casing
Hole
8,525.00
Depth Depth
0.95
Diameter
Diameter
1 C-05 - 1 C-05 - 1 C-05
(usft) (usft)
Name
10.800.00 6,437.18 2 3/8'
1 C-06 - 1 C-06 - 1 C-06
2-3/8
3
Summary
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kuparuk 1C Pad
1C-04-1C-04A-1C-04A_wp05
8,524.99
8,525.00
0.54
0.95
-0.26
FAIL - Minor 1/10
1 C-05 - 1 C-05 - 1 C-05
Out of range
1 C-06 - 1 C-06 - 1 C-06
Out of range
1C -08 -1C -08-1C-08
10,792.70
7,350.00
1,211.12
247.73
1,077.52
Pass - Major Risk
1C -08 -1C -081_1-1C-081_1
10,792.70
7,350.00
1,211.12
247.73
1,077.52
Pass - Major Risk
1C -08 -1C -0811-01-1C-0811-01
10,792.70
7,350.00
1,211.12
247.73
1,077.52
Pass - Major Risk
1C-08-1C-08LI PBI -1C-081_1 PBI
10,792.70
7,350.00
1,211.12
247.73
1,077.52
Pass - Major Risk
1 C-109 - 1 C-109 - 1 C-109
Out of range
1C-109 - 1C-1091_1 - 1C-1091_1
Out of range
1C-13 - 1C-13 - 1C-13
Out of range
1C-14 -1 C-14 - 1C-14
Out of range
1C-14 - 1C -14A- IC -14A
Out of range
1C-15 - 1C-151_1 - 1C-151_1
Out of range
1 C-150 - 1 C-150 - 1 C-150
Out of range
1 C-154 - 1 C-154 - 1 C-154
Out of range
1 C-154 - 1 C-154 - 1 C-154wp06
Out of range
1 C-155 - 1 C-155 - 1 C-155
Out of range
1 C-16 - 1 C-16 - 1 C-16
Out of range
1 C-170 - 1 C-170 - 1 C-170
Out of range
1 C-170 - 1 C-170PBI - 1 C-170PBI
Out of range
1 C-172 - 1 C-172 - 1 C-172
Out of range
1 C-172 - 1 C -1 72A- 1 C-172AOut
of range
1C-172 - 1C-172ALl - 1C-172ALl
Out of range
1 C-172 - 1 C-172AL2 - 1 C-172AL2
Out of range
1C-172-1C-172AL2PBI - 1C-172AL2PB1
Out of range
1 C-172 - 1 C-172AL2PB2 - 1C-172AL2PB2
Out of range
I C-174 -1 C-174 - 1 C-174
Out of range
1C -174 -Plan: 1C -174a -1C -174a w 01
Out of range
Cu - Min centre to center distance or covergent point, St- - min separation factor, ES - min ellipse separation
5119/2017 1:40:07PM Page 2 COMPASS 5000.1 Build 74
Baker Hughes INTEQ Ffla.
ConocoPhillips Travelling Cylinder Report BAKER
HUGHES
Company:
ConomPhillips (Alaska) Inc. -Kupl
Project:
Kuparuk River Unit
Reference Site:
Kupamk 1C Pad
Site Error:
0.00 usft
Reference Well:
1C-04
Well Error:
0.00 usft
Reference Wellbore
1C-04AL7
Reference Design:
1C-04AL1_wp02
Local Cc -ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well 1C-04
1C-04 @ 94.00usft (1C-04)
1C-04 @ 94.00usft (I0-(4)
True
Minimum Curvature
1.00 sigma
OAKEDMP2
Offset Datum
Summary
KuparuklCPad-
1C-04-1C-D4A-lC-04A_wp05
Reference
Offset
Centre to
No -Go Allowable
100-BOSS�GVRQ
71MMM
Measured
Measured
Centre
Distance Deviation
Warning
Site Name
Depth
Depth
Distance
(usft) from Plan
Onset
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
Kupawk 1C Pad
1 C-174 - Plan: 1 CA 74a L1 (wp01) - 1 C-174aL7 (w
Vertical
Measured
Vertical
Reference
Out of range
I C-178 - 1C-178 - 1 C-178
offset Welltmre Centre
Caeing-
Centre to
No Go
Out of range
1 C-178 - 1 C-1781-1 - 1 CA 7811
Depth
Depth
Depth
Out of range
1 CA 78 - 1 C-1781_1 PBI - 1 C-178LI Pat
Azimuth
N13
♦Ew
Out of range
1 C-178 - 1 C-1781_1 PB2 - 1 C-17811 P132
Distance
Deviation
Out of range
1 C-18 - 1 C-18 - 1 C-18
lush)
(usft)
(usft)
(usft)
Out of range
Plan: 1 C-156 - Plan: 1 CA 56 - 1 CA 56wpO6
turns)
1'9
(usft)
(u m
Out of range
Plan: 1 C-157 - Plan: 1 C-157 - 1 C-157wp05
8,50000
6,437.83
8,50000
Out of range
Plan: 1C-158 - Plan:IC-158 - 1 C-158wp01
0.00
-01.65
-325.35
-3,578.31
Out of range
Plan: 1C-29 - Plan 1C-29 - IC -29 wp04
D.31
-022
FAIL - Minor VIC, CC
Out of range
Plan: 1C -29 -Plan 1C-29PB1-1C-29PB7 wp04
8.525.00
6,437.59
0.15
030
Out of range
Offset Design
KuparuklCPad-
1C-04-1C-D4A-lC-04A_wp05
Offintsite Enor:
000 usft
Survey Program:
100-BOSS�GVRQ
71MMM
Rule
Assigned: Minor 1/10
ORset Well Error.
0.00 usft
Reference
Onset
semi Motor Axis
Measured
Vertical
Measured
Vertical
Reference
Olrsel
Toronto+
offset Welltmre Centre
Caeing-
Centre to
No Go
AIIoWeON
Warning
Depth
Depth
Depth
Depth
Azimuth
N13
♦Ew
hole sin
Centre
Distance
Deviation
(ran)
lush)
lush)
(usft)
(usft)
(usft)
11)
(usft)
turns)
1'9
(usft)
(u m
(.an)
8,50000
6,437.83
8,50000
643783
0.00
0.00
-01.65
-325.35
-3,578.31
2-11116
000
D.31
-022
FAIL - Minor VIC, CC
8,524.99
6438.05
8.525.00
6,437.59
0.15
030
-983
-306.32
-3,594.51
2-11116
0.54
0.95
-0.26
FAIL -Minor 1/10, ES.
SF
8,54981
6,43920
8.550.00
6,437.37
031
05o
-8.57
-286.59
3,809.87
2-11/16
2.14
1.27
1.02
Pass -Minor 1/10
8.57469
6.441.20
8,575.00
8,437.17
0.47
0.94
-7.31
-28821
-3.624.35
2-11/16
4.81
137
3.59
Pass -Minor 1110
0,599.28
6,44626
8,600.00
6.435.99
084
1.28
-6.05
-24522
-3.637.93
2-11116
8.53
1.40
724
Pass -Minor 1/10
8,62428
6447.59
8,6250D
6,435.82
D84
1.70
-3.34
-223.66
-3,85057
2-11116
12.66
1.41
1135
Pass -Minor 1/10
8,64948
6,450.57
0,650.00
5438.66
105
2.11
0.02
-201.57
-3,68227
2-11116
16sO
141
1527
Pass - Minor 1110
8.674.90
6,453.18
8,67500
6.436.49
1.29
2.59
365
-178.99
-3,67299
2-11/16
20.05
1.42
19.18
Pass - Minor 1110
9]00.62
5455.19
8,700.00
6.436.33
1-55
307
7.80
-155.96
-388272
2-11/16
23.20
1.39
22.97
Pets - Minor 1116
8,728.52
6.45646
8.725.00
6,436.17
184
3.66
12.82
-132.53
-3,69143
2-11116
25.95
139
2572
Pass - Minor 1110
8]52.55
6,456.98
8)5000
6,43800
2.15
424
1982
-108,75
-3.699.11
2-11/16
28.38
1,40
28.14
Pass - Minor 1110
877884
6.456.75
8,775.00
6,43585
249
5.02
2526
-84.65
-3,70575
2-11116
30.55
140
30.32
Pass - Minor 1110
8,80475
6,456.07
8,800.00
8,435.69
286
5.80
3231
E028
-3,711.33
2-11116
3]66
1.39
3243
Pass - Minor 1/10
0,83099
6.45501
8.825.00
6,435.53
3.27
8.05
3932
-35.69
-3,71594
2-11116
34.75
133
34.53
Pass - Minor 1/10
8,85796
6,45358
8,850.00
6,435.38
3.71
10.33
46.32
10.93
-3,71928
2-11116
36.86
141
36.84
Pass - Minor 1110
8.803.83
5451.77
8,875.00
8,43520
4.21
11.58
5328
1395
.3,721.63
2-11116
3901
140
30]9
Pau - Minor 1110
8.910.41
6,44959
8.900.00
6.434.97
4.77
12.83
60.19
38.92
-3,72290
2-11/18
41.25
0.46
41.03
Pass -Minor 1110
9,937.09
6.447,03
0,925.00
6,43489
540
13.49
67.04
6391
-3,72308
2-11/16
43.58
0.48
43.36
Pau - Minor 1110
8.983.87
6444.09
8,950.00
8,434.33
6.13
14.15
7394
8889
-3,722.16
2-11/16
46.03
049
45.81
Pass - Minor 1/10
8.990.66
5440.97
8.97500
6,433.93
7.17
1482
80.42
11381
-3,720.17
2-11116
48.63
0.51
49.40
Pass - Minor 1/10
9,017.63
6,43804
9.000.00
643347
9.02
15.10
8635
138.61
-3,717.08
2-11116
51.35
051
51.14
Pass - Minor 1110
904480
6.435.31
9.025.00
0,432.98
1127
15.46
91.66
18325
-3.712.92
2-11116
54.17
0.53
53.94
Pass - Minor 1/10
9,072.17
6,432.91
9,050.00
6,43240
1229
15.82
96.44
187.69
-3,707.69
2-11116
5689
0.53
56.76
Pass - Minor 1/10
9,09973
8,43051
907500
6,431.78
13.03
15.11
100.76
211.88
-3,70140
2-11116
59.77
0.55
59.54
Pass - Minor 1110
9,12]48
6,42952
9,100.00
6,431.12
13.54
16.39
104.69
235]7
-3.69608
2-11/16
6247
0.55
6225
Pass - Minor 1110
9,15547
6,426]5
9,125.00
8,430.43
14.04
lase
108.35
25985
-3,686.73
2-11/16
64.00
0.55
63.77
Pass -Minor 1110
9,178.88
8,425.41
9,150.00
5429.74
14.38
1693
107.49
28384
3,880.41
2-11/16
64.01
D.56
6378
Pan - Minor 1110
9,200.00
6,424.18
9,175.00
6429.06
14.67
17.22
105.95
30827
3,675.21
2-11/16
93gD
056
8388
Pass -Minor 1110
9:223.82
6,422,76
920000
6.428.37
14.99
17.51
101.17
332.92
-3,671.06
2-11116
6387
0.57
63.44
Pass -Minor 1110
9,248.32
6,421.39
9.225.110
6,427.70
1529
17.81
10257
357.71
-3,687.98
2-11116
63.35
0.57
6313
Pau - Minor 1110
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
5179/2017 1:40..'07PM Page 3 COMPASS 5000.1 Build 74
ConocoPhillips
Project: Kuparuk River Unit
---------------
�mr.nrom nu. Norm
ure^eao w�u. n.
WELLBORE DETAILS: 1C-04AL1
REFERENCE INFORNATION
Site: Kuparuk 1C Pad
uwM4o rWa
Parent Wellbore: 1C.04A
C dvele(Nkl R.Meze: WOIC44,T.Nw
Well: 1c.0
Northing
saerem. nui shT
Tie on MD: 8500.00
vuum(m)Rete. Neer Seal
Wellbore: IC-04AL7
0.00 0.00
laa ave; mss
5968727
a lm (VS) Relue ,Sul-(0.aaN,OWE)
Plan: iCA4,npD2(1C-D4/1C-04AL1)
ewe' 1'�i
Sec
taa,urea oepm Rehrzrcz: tC04@940oum ltc44l
Inc
Azi
TVDSS
+NAS +E/ -W
Da�9elbr Aktlp]: 44imm Darvamrt
Mean E
2230
2000
1750
1500
1250
c
1000
a
0 Iso
v,
so0
+
250
0
0
s
j -250
n
-500
.750
-1000
250
ri.l
BAKER
MGM
---------------
WELL
DETAILS:
1C-04
+N/ -S +E/ -W
Northing
Easting
Latitude
Longitude
0.00 0.00
5968727
562065
70° 19'30.322
N 149° 29'48.207 W
Sec
MD
Inc
Azi
TVDSS
+NAS +E/ -W
Dleg
TFace
VSect
Annotation
1
8500.00
90.58
318.35
6343.83
-325.35 -3578.31
0.00
0.00
3274.01
TIP/KOP
2
8600.00
81.93
323.38
6350.36
-248.06 -3641.23
10.00
150.00
3358.79
Start 10 cls
3
8670.00
84.37
329.99
6358.71
-190.01 -3679.36
10.00
70.00
3413.84
3
4
8770.00
90.83
337.64
6362.90
-100.46 3723.38
10.00
50.00
3484.78
4
5
8970.00
96.85
356.76
6349.37
93.10 -3767.49
10.00
72.00
3589.89
5
6
9160.00
93.25
15.49
6332.49
280.40 -3747.29
10.00
100.00
3632.20
6
7
9360.00
93.74
355.46
6320.18
478.09 3728.33
10.00
272.00
3679.08
7
8
9560.00
90.11
335.78
6313.39
670.72 -3777.76
10.00
260.00
3788.92
8
9
9800.00
90.92
311.79
6311.19
862.93 3918.52
10.00
272.00
3984.90
9
10
9975.00
90.88
329.29
6308.43
997.50 4029.29
10.00
90.00
4133.66
10
11
10250.00
90.78
301.79
6304.39
1191.88 -4220.04
10.00
270.00
4377.58
11
12
10450.00
80.30
318.90
6320.04
1320.14 -4371.36
10.00
122.00
4562.58
12
13
10575.00
85.15
330.52
6335.92
1421.18 4442.79
10.00
68.00
4663.18
13
14
10775.00
90.50
311.23
6343.58
1575.40 -4568.31
10.00
285.00
4832.31
14
15
10800.00
91.35
308.88
6343.18
1591.48 -4587.44
10.00
290.00
4855.66
Planned TD at 10800.00
Mean E
2230
2000
1750
1500
1250
c
1000
a
0 Iso
v,
so0
+
250
0
0
s
j -250
n
-500
.750
-1000
250
ri.l
BAKER
MGM
0 8 0 8 0 0 8 A R R o 0 0 0 0 0
West( -)/East(+) (250 usR/in)
5795
---------------
-04/I -04A
I
A4AL
TOS
1
:..._...-....Plan
-' -
TDa 108 00
S8H0
1
0
-0411 -WA
IC -0
A Fa tl
IC -04
LIT
3
C-04
LI
2
IC -041C-04
F
IC -0
ALI TOI
Maio dla
TIPn< OP
C -03/I AIA
6080
U
C-03
I C-03
0 8 0 8 0 0 8 A R R o 0 0 0 0 0
West( -)/East(+) (250 usR/in)
5795
S8H0
5985
F
6080
U
6175
IC4)
/IC.
A
6270
P KOLs
6365
. 710 11
6
12
:`.....
6460
4
5
13
4 PI
ndW
Detl
800.
1
-03/1 4)3A
IC -041C-04
LI
6$55
6650
I -O4 Faultl
6745
ea L_
QQ
.-
Vertical Section at 289.13° (95 usft/in)
KUP PROD 1C-04
ConocoPhilhps
Aeyltl.l(k•.
Well Attributes
MOX Angie&MD TD
WeIINo,e APll LWl Feltl Name WNIEo,e Slalus
596292650]00 KUPARUK RIVER UNIT PROD
n[I (° MDIXKB A[IB-TE aI
Y.98 4,300.60 ].5]59
COmmenlH25 Rpm) Mnoption Eno Dale
SSSV:NONE 40 DN9/1012016 LastWO: 1/24/2015
NBL[E in) Rig Release Oale
39.01 217I1981
Icoa,an5rzoq vm'.52AM
re[x
Annolallon Oapl111flKB) Eno- AnnGnlon
Lasl Tag: SLM ].2460 12l]a016 Rev Reason'.CORRECTED "nipple reducer was
pulled 2/6/2015"
Leal MOE By
pproven
Entl Otle
4/151201]
--
HANGER 2)A-
cCO.GOTOF.E.A. "
N DSOA
GASLIPI'1
SURFACE, 550191077
GAS UFT: 3,92DA
CARE uFT:4REQ .1
GAS LIFT: 557577
GAG LIFT: SNS.]
GAS LIFT: eTrze
LOCATOR; a Teaa
SFU A45R 5nSx
P.R. 6.7751
PACKFA;s,Tsss
Amt E;ApEPL
ONERSHOT;SPoV
SpRWEKTI IE
PROOOCTION:5016,9555-
PA.IESE 9.W5D
NIPRE,UEG5
SOS; B.SSOP
FISN: fi.SpOA
nPE11F1ASo.I
PERF:120BP7,211O0�
UNER:5.812.1.1.545A�
as ng r ngs
Caxmp oexcnpimE OETE man) Top lane) Seloepmlfllee) Sel wvu irv0)... WNLen p._G2ae Top Tfil.
GONDOCTOR Insulated 20 10.940 34.0 WX 800 9400 K40 WELDED
32'
CUN9 oeavlpllon ODPO IDllne) l T.PppSet Depth (RED)anGaMh RVDI'.� WNL9n lI... Ginnie Too TMuo
SURFACE 13318 12.347 33.0 2,910.0 27078 7200 N-40 ETC
GasMp ...'am IOD (in)ID 6a) Top(nKn B) Son None inKe) apeal, UNIP. WNL.,(I Gape Top Terme
PRODUCTION 9518 8.861 30.1 6,9356 6,258.1 4].00480 BTC
easing Desnivin To (in) Io(In) TOp IReB) sal Dopm inKe) SIT Couh TVD)... WNLen I.O[aoe TOP Th,uo
LINER ] 6,2]6 6612.1 ],5450 6.0663 2600 K-55 BTC
Liner Details
Ncminal to
Top PUB) Top (TVO(RIKBE935Z Top ilei i'I IYm Oei Lom
6,61 2.1 5.9358 585 TIEBACK BAKER TIE BACK SLEEVE 6.151
AK
6,610.2 5,9411 560 NIPPLE BER SEAL NIPPLE 6.151
6,621.5 5,945.0 558 HANGER BAKER LINER HANGER 5,151
6,6316 5,955.0 550 1 XO BUSHING BAKER XO CENTRALIZER BUSHING 6.151
Tubing Strings
,ing Dexxnpll On
NBING-WO-2015
-4112X3112@62.6
" Ma,,,loiin
""11"1211"12
31/2
2.992
".)
Top(".)27
2Z8
Sen Dept,(n..Set
6,9100
Dept,(TVO) WI
6,2325
polN)
9.30L-50
Graoe
Top Connection
EUE Ord MOd
COMPteticin Details
Nominal lD
Top TERSE GP(I.uff Ke) T.PnEm PI nem.. cnm (m)
20 278 006 HANGER FMC GEN 3 HANGER WITH LH ACME LIFT THREAD 3.958
62.8 628 0.13 XO Redudng Crossover Pup 4112 RIM x31/2"EUE BN 2.992
6,769.3 60922 4.38 LOCATOR GBH LOCATOR SUB 2.980
6,770.2 60932 4.38 SEAL ASSY 8040 SEAL ASSEMBLY 2.990
6,775.7 60986 4.33 PER BAKER 004D PER (29) 4.000
6,)906 6,121.7 4.14 PACKER BAKER 4752 FHL RETRIEVABLE PACKER 2.960
6,849.3 6,172.0 PAA NIPPLE CAMCO DS NIPPLE 2.813
6.901.] 6,224.3 4,07 OVERSHOT BAKER POOR BOY OVERSHOT 3.590
Tm, n9"'upllon SInn9 Me... ID( in) T*p D1KB Set DeFl,in.,5el 0epl,(TVO) I... W1 Dan, Gr... Tn1Ca E-onn
TUBINGORIGINAL 31/2 2.992 69000 6,986E 6,308.13 9.20 K-55 BTC
Completion Details
Numnal l0
Top(nK8) Top I (IIKB) Top Imp V) Sam Das Com (in)
6,9192 8,2411 408 BEER W/EXT BAKER KB4 SBR 3.000
6,9453 6.267.8 404 ACKER BAKER FK PACKER 3000
6,903.5 6,305.9 402 NIPPLE CAMCOD NIPPLE NOGG(1.81"NIPPLE REDUCER 1.810
BET 911]114 -PULLED 2520151
6,980E 6.306.8 4.02 SOS BAKER SHEAR OUT SUB 2992
Other In HOIe (Wireline retrievable plugs, Valves, pumps, fish, etc.)
Top lnee)
TOP('.) To, ln[I
IFER) I")
Dee
Com Ran Dane ID OnI
6990.0
6,312.3 4.02
FISH
I ILINE SPINNER 2"LDngx 114 Wide 8120/2014
Perforations
8 Slots
Top (ne51
B1m
rov lEU
(x.41
alm(rvo)
In
lnm
Dale
an.,
0
pnIT I
q
Typo
eom
].088.0
148
],1480
6.410.1
6,4]00
,4
Cd, G3, G2,
1C-04
21/1901
4.0
PERT
7,200.0
7,218.0
8,529.9
8.5396
1-1. UNIT B.
1C-04
V711981
4.0
PER
Mandrel Inserts
ED
all
an '4Top (flKB Temni DI MOYe Oo in y,e. "Iva LNC. PASS. TRORun
(I Mooal ( 1 vpa Type On) ea) an. pale Com
1 2,6311 2088.5 CAMCO MMG 112 GASLIFT OV RK 0.250 00 2/6/2017
2 3,920.4 3,5519 CAMCO MMG 112 GAS LIFT GLV RK OA88 1.1990 2/5/2015
3 4,9822 4,39].] CAMCO MMG Ila GAB LIFT OV RK 0.108 00 24/2015
4 5,6780 50189 CAMPO MMG 11/2 GAS LIFT DMY RK 0.000 00 1/31/2015
5 6,3467 5,6]1.6 CAMCO MMG 11/2 GAS LIFT GUY RK 0000 0.0 1/31/2015
6 6112.4 50355 CAMCO AMC 11/2 GAS LIFT DMY RK 0.000 0.0 11112015
Notes: General R Safety
Eld Den,Annotation
1212512012NOTE: WAIVEREDWELC WXOADOMMUMOATION
0/1012010 NOTE: View SC.emaliCWl Alaake'Fmmpu.0
1 NOTE: LEAK AT 5]63;3" SPINNER STILL IN HOLE.
111411.11 NOTE: WORKOVER
IC -04 Proposed CTD Schematic
13-3/8" 72# N-40
shoe @ 2910' MD
195/8.'4 7# L-80 shoe
@ 8938' MD
C -sand perfs
7088'- 7148' MD
C -sand perfs
7208'- 7218' MD
7" 26# K-55 shoe
@ 7545' MD
4-1/2" x 3-1/2" 9.3# L-80 ELIE 8rd to surface
3-1/2" Camco MIG gas lift mandrel @ 2631', 3920', 4982',
56781, 6347'
Baker Tie Back Sleeve @ 6612' RKB
Baker Seal Nipple @ 661 8'RKB
Baker Liner Hanger @ 6622' RKB
3-1/2" Camco MMG gas lift mandrel @ 6712' RKB
Baker 80-40 Seal Assy @ 6770' RKB
Baker PBR@ 6776' RKB
Baker FHL Packer @ 6799' RKB
3-1/2" Camco DS Nipple @ 6849' RKB w/ 2.813' ID
Baker Poor Boy Overshot @ 6902' RKB
Baker 3-1/2" PBR @ 691 9'MD (3.0" ID)
Baker FHL packer @ 6945' MD (3.0" ID)
3-1/2" Camco D landing nipple @ 6984' MD (2.75" min ID, No-
Go; 1.81" nipple reducer) Mill to 2.80" ID
3-1/2" tubing tail @ 6986' MD
1O04AO w W
TD @ 10800' MD
Liner Top ® 6970' MD
1GNAw905
TD 0 10800' MD
Liner Billet 0 8500' MD
TRANSMITTAL LETTER CHECKLIST
WELL NAME«L
: J. IC -ay A L�J
PTD: AI;-- 0- O
Development _ Service _ Exploratory _ Stratigraphic Test _ Non -Conventional
FIELD: �,V�r POOL: I(u�.rt.k �IVEJ KI.JG/t.K �tU�i'/
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 existin
tiwell Permit
LATERAL
No. /}-U�� API No. 50- - �QQ
(If last two digits
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
_) from records, data and logs acquired for well
(name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Comnanv 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 I O' sam le 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 wed until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Comnanv Name) must contact the AOGCC
to obtain advance approval of such water well testing pro
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 _ _ _ _ - Well Name: KUPARUK RIV UNIT 1C_04AL1 Program _DEV _ Well bore seg ❑d I
PTD#: 2170830 Company CONOCOPHILLIPS ALASKA INC__ ___ Initial Class/Type DEV /.PEND __ GeoArea 890, Unit 11160 On/Off Shore On Annular Disposal ❑
Administration
117
Nonconven, gas conforms to A$31.05.030(j.1.A),(j.2.A-uJ
Date
Commissioner:
1
Permit fee attached_ _ _ _
NA
blas
6 JC 17
2
Lease number appropriate. _ _ _
Yes
ADL0025649, entire wellbore.
3
Unique well. name and number _ _ _
Yes
_ _ KRU 1C -04A
4
Well located in.a defined pool
Yes
KUPARUK RIVER,. KUPARUK. RIV OIL - 490100, governed by Conservation Order No, 432D. _
5
Well located proper distance from. drilling unit. boundary
Yes
CO 432D contains no spacing restrictions with. respect to drilling unit boundaries.. _
6
Well located proper distance from other wells. _
Yes
CO 432D has no interwell spacing restrictions.. _
7
Sufficient acreage available in. drilling unit_
Yes
8
If deviated, is wellbore plat. included _
Yes
9
Operator only affected party _
Yes
Wellbore. will be more than 500' from an external property line where ownership or landownership changes.
10
Operator has appropriate bond in force
Yes
Appr Date
11
Permit can be issued without conservation order..
Yes
12
Permit can be issued without administrative approval _ _
Yes
PKB 5/31/2017
13
Can permit be approved before 15 -day wait
Yes
14
Well located within area and strata authorized by Injection Order # (put 0# in. comments). (For
NA
15
All wells within 1/4. mile area of review identified (For service well only)
NA
16
Pre -produced injector; duration of pre production less than 3 months (For service well only)
NA
_
18
Conductor string. provided _
NA
_ Conductor set in KRU 1C-04 _
Engineering
19
Surface casing protects all. known USDWs
NA
Surface casing set in KRU 1C-04
20
CMT vol adequate. to circulate on conductor & surf csg
NA
Surface casing set and fully cemented
21
CMT. vol adequate to tie-in long string to surf csg _ _
NA
22
CMT -will cover all known. productive horizons. _
No
Productive interval will be completed with. uncemented slotted liner
23
Casing designs adequate for C, T. B &. permafrost _
Yes _
24
Adequate tankage. or reserve pit
Yes
Rig has steel tanks; all waste to approved disposal wells.
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed
Yes
Anti -collision analysis complete; no major risk failures
27
If diverter required, does it meet regulations
NA
Date
28
Drilling fluid program schematic & equip list adequate
Yes
Max formation pressure is. 3841 psig(11.4 ppg EMW ); will drill w/ 8.6. & maintain overbal w/ MPD
Appr
VTL 6/5/2017
29
BOPEs, do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
MPSP is 3194 psig; will test BOPS to 4000 psig
31
Choke. manifold complies w/API. RP -53 (May 84).
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of 1-12S gas probable
Yes
H2S measures required.
34
Mechanical condition of wells within AOR verified (For service well only)
NA
35
Permit can be issued w/o hydrogen sulfide measures
No
Wells. on IC -Pad are H2S-bearing. H2S measures required.
Geology
36
Data presented on potential overpressure zones
Yes
Max potential reservoir pressure is. 1.1.4 ppg EMW; will be drilled using 8.6 ppg mud and MPD technique.
Appr Date
37
Seismic analysis of shallow gas zones _
NA
_
PKB 6/5/2017
38
Seabed condition survey (if off -shore) _
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA
Onshore development lateral to be drilled.
Geologic
Date:
Engineering Public
Date
Date
Commissioner:
Com issioner: Commissioner
l � 6- z,7
I,q
blas
6 JC 17
(I('
