Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout211-128 •
ConocoPhillips }
Alaska CM i 2 11 2016
P.O. BOX 100360 AGC
ANCHORAGE,ALASKA 99510-0360
October 25, 2016
Commissioner Cathy Foerster
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100 ,
Anchorage, AK 99501 -'NED 1.110 .
Commissioner Cathy Foerster:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of
these wells was found to have a void in the conductor. These voids were filled with cement and
corrosion inhibitor, engineered to prevent water from entering the annular space. As per
previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the
treatments took place and meets the requirements of form 10-404,Report of Sundry Operations.
No cement was pumped. The corrosion inhibitor/sealant was pumped October 24, 2016. The
attached spread sheet presents the well name,top of cement depth prior to filling and volumes
used on each conductor.
Please call Roger Winter at 659-7506, if you have any questions.
Sin rely,
Roger Winter
ConocoPhillips Well Integrity Field Supervisor
• •
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off
Report of Sundry Operations(10-404)
Kuparuk Field
Date 10/25/2016 1 H-09,1L-28&3H-34
Corrosion
Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/
Well Name API# PTD# cement pumped cement date inhibitor sealant date
ft bbls ft gal
1 H-09 50029223450000 1930290 11.5" NA 11.5" NA 5.10 10/24/2016
1 L-28 50029229510000 1990980 14.5 NA 14.5 NA 5.50 10/24/2016
3H-34 50103206430000 2111280 14" NA 14" NA 6.80 10/24/2016
Image Project Well History File Cover Page
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This page identifies those items that were not scanned during the initial production scanning phase.
They are available in the original file, may be scanned during a special rescan activity or are viewable
by direct inspection of the file.
t - Well History File Identifier
Organizing(done) wo-sided D Rescan Needed
RESC N: OVERSIZED: NOTES:
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2131
WELL LOG TRANSMITTAL
To: State of Alaska January 20, 2012
Alaska Oil and Gas Conservation Commission
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage,Alaska 99501-3539
RE: LWD Formation Evaluation Logs: 3H-34 AK-MW-0008472254
3H-34 50-103-20643-00
2"x 5" MD TRIPLE COMBO Logs: 1 Color Log
2"x 5"TVD TRIPLE COMBO Logs: 1 Color Log
Digital Log Images&LWDG-formatted LIS Data w/verification listing; 1 CD Rom
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Sperry Drilling
Attn: Buster Bryant/Ben Schulze
6900 Arctic Blvd.
Anchorage,Alaska 99518
Office: 907-273-3539/907-273-3536
Fax: 907-273-3535
Buster.Bryant@halliburton.com
Benjamin.Schulze@halliburton.com
Date: l6/� g
2. Signed:1
211-\2'
2t (
WELL LOG TRANSMITTAL
To: Alaska Oil and Gas Conservation Comm. January 3, 2012
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Cement Bond Log: 3H-34
Run Date: 12/28/2011
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage,AK 99518
3H-34
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-103-20643-00
Cement Bond Log 1 Color Log
50-103-20643-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline& Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage,Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
klinton.wood@halliburton.com
Date: Signed: 1 &
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended 0 • lb.Well Class:
20AAC 25.105 20AAC 25.110 Development 0 - Exploratory ❑
GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: Service ❑ Stratigraphic Test El,
2.Operator Name: 5.Date Comp.,Susp., f•24. /r ii)2.Permit to Drill Number:
ConocoPhillips Alaska,Inc. or Aband.: November 25,2011 211-128/ - .
3.Address: 6.Date Spudded: i(.,5- /( iv13.API Number:
-
P.O.Box 100360,Anchorage,AK 99510-0360 Novem 11 Pr/ � 50-103-20643-00 -
4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: O
) Lr
Surface: 932'FNL,282'FWL,Sec.12,T12N,R8E, UM November 19,2011 • - 3H-34( 5-67y41.1
Top of Productive Horizon: 8.KB(ft above MSL): 64'RKB 15.Field/Pool(s):
1891'FSL,2064'FWL,Sec.1,T12N,R8E,UM GL(ft above MSL): 36'AMSL Kuparuk River Field 1-4--
Total Depth: 9.Plug Back Depth(MD+TVD): "3 11,
2065'FSL, 2156'FWL,Sec. 1,T12N,R8E,UM Kuparuk River Oil Pool •
4b.Location of Well(State Base Plane Coordinates,NAD 2 : 10.Total Depth(MD+
16.Property Designation:
� P TVD): P KY 9
Surface: x-498655 • y- 6000725 . Zone-4 7300'MD/6206'TVD ` ADL 25531 ,
TPI: x-500436 y- 6003548 Zone-4 11,SSSV Depth(MD+TVD): 17.Land Use Permit:
Total Depth: x-500528.5 y- 6003722 Zone-4 SSSV @ 1899'MD/1844'TVD 2657
18.Directional Survey: Yes 0 No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD:
(Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1675'MD/1617'TVD
21.Logs Obtained(List all logs here and submit electronic and printed information per 20 MC 25.071): 22.Re-drill/Lateral Top Window MD/TVD
GR/Res not applicable
23. CASING,LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT
CEMENTING RECORD
CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED
16" 62.5# H-40 28' 114' 28' 114' 24" 170 sx cement
10.75" 45.5# L-80 28' 3977' 28' 3518' 13.5" 1578 sx LiteCRETE,380 sx DeepCRETE
7.625" 29.7# L-80 25' 6891' 2S 59,47%,..., 9.875" 532 sx Class G
4.5" 12.6# L-80 6583' 7300' �1 � (...........><5;301 6.75" 28 bbls Class G •
24.Open to production or injection? Yes ❑ No 0 If Yes,list each 25. TUBING RECORD
Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD)
4.5 x 3.5 6639' 6583'MD/5771'TVD
none
26. ACID,FRACTURE,CEMENT SQUEEZE,ETC.
.tr LK--1 .rJ.f,i, DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED
• tY.,
,
It s.. t
27. PRODUCTION TEST
Date First Production Method of Operation(Flowing,gas lift,etc.)
not applicable shut-in
Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
Test Period-->
Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr)
Press. psi 24-Hour Rate->
28. CORE DATA Conventional Core(s)Acquired? Yes No d , Sidewall Cores Acquired? Yes ❑ No ri -
!i If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water
(Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 MC 25.071.
NONE
RECEIVED
BDM011S DEC 1D )EC Z01
F
Aleasa Oil &Gas Cons.Coma issior
Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Mom* Submit original only i�
76- 72sf �
28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS
NAME MD TVD Well tested? ❑ Yes Q No If yes,list intervals and formations tested,
Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if
Permafrost-Bottom 1675' 1617' needed,and submit detailed test information per 20 AAC 25.071.
Top Kuparuk A 7043' 6040'
N/A
Formation at total depth: Kuparuk A
30. LIST OF ATTACHMENTS
Summary of Daily Operations,schematic,final directional survey
31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Hai Bin Guo
Printed Name G.L.Alvord Title: Alaska Drilling Manager ,
Signature � Phone 265-6120 Date (2'l 1 ilLt,L(
Sharon Allsup-Drake
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases 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.
Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for
Injection,Observation,or Other.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 4b: TPI(Top of Producing Interval).
Item 8: The Kelly Bushing and Ground level 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 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00).
Item 20:Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 28.
Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing
tool.
Item 23: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 26: Method of Operation: Flowing,Gas Lift, Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other
(explain).
Item 27:Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed
description and analytical laboratory information required by 20 AAC 25.071.
Item 29:Provide a list of intervals tested and the corresponding formation,and a brief summary of this box.Submit detailed test and
analytical laboratory information required by 20 AAC 25.071.
Form 10-407 Revised 12/2009
KUP 3H-34
Conoco Phillips o Well Attributes Max Angle&MD TD
Alaska.Int; Wellbore API/UWI Field Name Well Status 'noir) MD(ftKB) Act Btm(ftKB)
CniomFttimps 501032064300 KUPARUK RIVER UNIT PROD
Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
SSSV:TRDP Last WO. 11/25/2011
Well Gaulle:-3H-34,12/1/2011 5'31:36 AM
Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date
Rev Reason:NEW WELL ninam 12/1/2011
i Casing Strings
HANGER,23 -- Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd'' CONDUCTOR 16 15.062 28.0 107.0 107.0 62.60 H-40 WELDED
SURFACE 1n 0... 9.950 ID Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd
_ Casing Description String String ID...
SII28.7 3,977.4 3,545.6 45.50 L-80 BTC
IIIII---- Casing INTERMEDIATE String 0... StringID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd
25.3 6,890.9 5,974.7 29.70 L-80 BTCM
Casing Description String 0... String ID...Top(ftKB) Set Depth it..Set Depth(TVD)...String Wt...String... String Top Thrd
LINER 41/2 3.958 6,582.5 7,300.0 6,233.2 12.60 L-80 IBT-mod
Liner Details
Top Depth
IIIr
11111
(TVD) Top Incl Nomi...
Top(ftKB)B) (ftKB) 1°) hem Description Comment ID(in)
4.960
6,582.5 5,771.0 44.34 PACKER BAKER HRD ZXP LINER TOP PACKER
6,601.5 5,784.7 45.01 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870
4.900
6,606.4' 5,788.2 45.18 HANGER BAKER DOUBLE GRIP FLEX-LOCK LINER HANGER
6,616.3 5,795.1 45.53 XO Reducing CROSSOVER,5-1/2"x 5" 4.490
4.000
6,617.3. 5,795.8 45.56 SBE BAKER 80-40 SEAL BORE EXTENSION
coNDUCT000 6,6358 5,808.6 46.22 XO Reducing CROSSOVER 5"x 4-1/2' 3.970
' Tubing Strings
Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd
TUBING 4.5x3.5 31/2 2.992 23.1 6,639.3 5,811.0 9.30 L-80 EUE8RDMOD
=
SAFETY CLV, Completion Details
1,899 1 �"-1 Top Depth
(TVD) Top Incl Nomi...
Top(ftKB) (ftKB) (°) hem Description Comment ID(in)
23.1 23.1 -0.02 HANGER FMC TUBING HANGER 4.500
88.4 88.4 0.25 XO Reducing CROSSOVER,4%"IBT-m box x 3-1/2'EUE pin 3.500
GAS LIFT,
273a 1,898.8 1,843.8 33.39 SAFETY VLV CAMCO TRMAXX-CMT-SSR SAFETY VLV w/2.812'X PROFILE 2.812
1 ^ 6,572.8 5,763.9' 43.99 NIPPLE HES X NIPPLE 2.813
6,620.3 5,798.0 45.67 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 3.000
6,621.2 5,7985 4570 SEAL ASSY BAKER SEAL ASSEMBLY w/10'STROKE&1/2 MULE SHOE 2.990
• 6,639.2 5,810.9 46.34 MULE MULE SHOE 2.990
SURFACE,97.
29-37
n
GAS LIFT, _G
4,206 T
l- OL
„
1
GAS LIFT. j 1�
,11 j l
e4
GAS LIFT. } I
5,982 f
GAS LIFT.
6.514 1
MI
EMI 2 0'5`
NIPPLE,8,573 I; �`
t c
i IV
!3
1
SV
LOCATOR,
6,620
SEAL ASSY, -,
6.621
Mandrel Details
MULE,6,639 I Top Depth Top Port
(TVD) cValve Latch Size TRO Run
Stn Top(ftKB) (ftKB) C)Inl Make Model IiODN Sery Type Type lint (psi) Run Date Com...
1 2,738.4 2,531.7 37.30 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/23/2011
2 4,206.2 3,732.6 33.56 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/23/2011
3 5,170.6 4,573.2 27.34 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/23/2011
TERM206 891 �t 4 5,981.6 5,282.3 26.33 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/23/2011
5 6,514.3 5,721.5 42.08 CAMCO MMG 1 1/2 GAS LIFT SOV REK 0.000 0.0 11/23/2011
I
LINER,
6.1•5513;77:3320°N
,TD,7,58.377,303000 .
ConocoPhillips(Alaska) Inc.
Kuparuk River Unit
Kuparuk 3H Pad
3H-34
501032064300
Sperry Drilling
Definitive Survey Report
01 December, 2011
law
HALLIBURTON
mom
Sperry Drilling
ConocoPhillips (Alaska) Inc.
Definitive Survey Report
Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-34
Project: Kuparuk River Unit TVD Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Site: Kuparuk 3H Pad MD Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Well: 3H-34 North Reference: True
Wellbore: 3H-34 Survey Calculation Method: Minimum Curvature
Design: 3H-34 Database: CPAI EDM Production
Project Kuparuk River Unit
Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Well 3H-34
Well Position +N/-S 0.00 ft Northing: 6,000,725.46 ft Latitude: 70.4132160
+E/-W 0.00 ft Easting: 498,655.48 ft Longitude: -150.0109495
Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 36.40ft
Wellbore 3H-34
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(°) (°) (nT)
BGGM2011 11/5/2011 20.75 80.95 57,637
Design 3H-34
Audit Notes:
Version: 1.0 Phase: ACTUAL Tie On Depth: 27.51
Vertical Section: Depth From(TVD) +N/-S +E/-W Direction
(ft) (ft) (ft) r)
27.51 0.00 0.00 31.94
Survey Program Date
From To
(ft) (ft) Survey(Wellbore) Tool Name Description Survey Date
109.00 632.00 3H-34 Gyro(3H-34) CB-GYRO-SS Camera based gyro single shot 11/5/2011 12:C
684.06 3,944.95 3H-34 MWD R200(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/5/2011 12:C
4,019.06 6,856.36 3H-34 MWD R400(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/12/2011 12,
6,923.04 7,258.46 3H-34 MWD R500(3H-34) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/18/2011 12,
Survey
Map Map Vertical
MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section
(ft) (°) (0) (ft) (ft) (ft) (ft) (ft) (ft) (0/100') (ft) Survey Tool Name
27.51 0.00 0.00 27.51 -36.40 0.00 0.00 6,000,725.46 498,655.48 0.00 0.00 UNDEFINED
109.00 0.34 195.65 109.00 45.09 -0.23 -0.07 6,000,725.23 498,655.41 0.42 -0.23 CB-GYRO-SS(1)
171.00 0.22 129.53 171.00 107.09 -0.49 -0.02 6,000,724.97 498,655.46 0.52 -0.42 CB-GYRO-SS(1)
262.00 1.90 70.68 261.98 198.07 -0.10 1.54 6,000,725.36 498,657.01 1.97 0.73 CB-GYRO-SS(1)
354.00 5.39 59.49 353.78 289.87 2.60 6.70 6,000,728.06 498,662.18 3.85 5.75 CB-GYRO-SS(1)
447.00 7.57 52.35 446.18 382.27 8.56 15.31 6,000,734.02 498,670.79 2.49 15.37 CB-GYRO-SS(1)
539.00 8.99 51.92 537.22 473.31 16.70 25.77 6,000,742.15 498,681.25 1.54 27.80 CB-GYRO-SS(1)
632.00 11.89 52.79 628.67 564.76 26.97 39.12 6,000,752.42 498,694.60 3.12 43.59 CB-GYRO-SS(1)
684.06 13.60 53.99 679.45 615.54 33.82 48.35 6,000,759.26 498,703.83 3.32 54.27 MWD+IFR-AK-CAZ-SC(2)
775.50 12.90 54.34 768.45 704.54 46.09 65.34 6,000,771.53 498,720.82 0.77 73.67 MWD+IFR-AK-CAZ-SC(2)
867.38 13.06 51.02 857.99 794.08 58.60 81.74 6,000,784.04 498,737.22 0.83 92.97 MWD+IFR-AK-CAZ-SC(2)
12/1/2011 10:12:11AM Page 2 COMPASS 2003.16 Build 69
ConocoPhillips (Alaska) Inc.
Definitive Survey Report
Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-34
Project: Kuparuk River Unit TVD Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Site: Kuparuk 3H Pad MD Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Well: 3H-34 North Reference: True
Wellbore: 3H-34 Survey Calculation Method: Minimum Curvature
Design: 3H-34 Database: CPAI EDM Production
Survey
Map Map Vertical
MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section
(ft) (1 (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/700') (ft) Survey Tool Name
958.11 11.62 52.62 946.62 882.71 70.59 96.97 6,000,796.03 498,752.45 1.63 111.20 MWD+IFR-AK-CAZ-SC(2)
1,052.00 12.48 46.62 1,038.44 974.53 83.30 111.86 6,000,808.73 498,767.34 1.62 129.86 MWD+IFR-AK-CAZ-SC(2)
1,145.70 19.61 41.01 1,128.44 1,064.53 102.15 129.56 6,000,827.57 498,785.04 7.78 155.22 MWD+IFR-AK-CAZ-SC(2)
1,177.78 21.08 40.46 1,158.52 1,094.61 110.60 136.83 6,000,836.02 498,792.32 4.62 166.24 MWD+IFR-AK-CAZ-SC(2)
1,237.97 22.82 40.80 1,214.34 1,150.43 127.67 151.49 6,000,853.09 498,806.97 2.90 188.48 MWD+IFR-AK-CAZ-SC(2)
1,330.82 23.24 41.60 1,299.79 1,235.88 155.00 175.41 6,000,880.41 498,830.90 0.56 224.33 MWD+IFR-AK-CAZ-SC(2)
1,423.68 23.15 41.51 1,385.15 1,321.24 182.37 199.67 6,000,907.77 498,855.17 0.10 a, 260.39 MWD+IFR-AK-CAZ-SC(2)
1,516.39 21.36 42.99 1,470.95 1,407.04 208.37 223.27 6,000,933.77 498,878.76 2.02 294.93 MWD+IFR-AK-CAZ-SC(2)
1,609.57 23.48 42.74 1,557.08 1,493.17 234.42 247.44 6,000,959.81 498,902.94 2.28 329.83 MWD+IFR-AK-CAZ-SC(2)
1,703.17 23.43 42.09 1,642.95 1,579.04 261.92 272.57 6,000,987.31 498,928.07 0.28 366.46 MWD+IFR-AK-CAZ-SC(2)
1,793.79 25.89 41.57 1,725.29 1,661.38 290.10 297.77 6,001,015.47 498,953.28 2.73 403.71 MWD+IFR-AK-CAZ-SC(2)
1,879.65 32.14 42.57 1,800.34 1,736.43 320.97 325.69 6,001,046.34 498,981.20 7.30 444.67 MWD+IFR-AK-CAZ-SC(2)
1,977.71 34.54 41.81 1,882.26 1,818.35 360.91 361.87 6,001,086.27 499,017.38 2.48 497.70 MWD+IFR-AK-CAZ-SC(2)
2,071.20 35.90 35.39 1,958.66 1,894.75 403.02 395.43 6,001,128.37 499,050.94 4.22 551.20 MWD+IFR-AK-CAZ-SC(2)
2,164.75 36.29 31.20 2,034.26 1,970.35 449.07 425.66 6,001,174.41 499,081.18 2.67 606.27 MWD+IFR-AK-CAZ-SC(2)
2,259.29 36.24 29.54 2,110.49 2,046.58 497.32 453.93 6,001,222.64 499,109.46 1.04 662.16 MWD+IFR-AK-CAZ-SC(2)
2,352.08 34.91 30.31 2,185.96 2,122.05 544.10 480.86 6,001,269.42 499,136.39 1.51 716.11 MWD+IFR-AK-CAZ-SC(2)
2,442.49 34.44 30.36 2,260.31 2,196.40 588.50 506.83 6,001,313.81 499,162.37 0.52 767.52 MWD+IFR-AK-CAZ-SC(2)
2,535.64 35.47 28.61 2,336.66 2,272.75 634.95 533.09 6,001,360.25 499,188.63 1.54 820.84 MWD+IFR-AK-CAZ-SC(2)
2,627.67 35.28 29.33 2,411.70 2,347.79 681.57 558.89 6,001,406.86 499,214.44 0.50 874.04 MWD+IFR-AK-CAZ-SC(2)
2,722.37 34.11 30.81 2,489.56 2,425.65 728.22 585.89 6,001,453.50 499,241.44 1.52 927.92 MWD+IFR-AK-CAZ-SC(2)
2,815.01 36.51 26.36 2,565.17 2,501.26 775.23 611.44 6,001,500.50 499,267.00 3.80 981.33 MWD+IFR-AK-CAZ-SC(2)
2,907.58 35.55 25.97 2,640.03 2,576.12 824.10 635.45 6,001,549.36 499,291.02 1.07 1,035.50 MWD+IFR-AK-CAZ-SC(2)
2,995.89 34.07 26.05 2,712.53 2,648.62 869.41 657.56 6,001,594.66 499,313.13 1.68 1,085.65 MWD+IFR-AK-CAZ-SC(2)
3,090.95 34.25 30.94 2,791.21 2,727.30 916.28 683.01 6,001,641.53 499,338.59 2.89 1,138.89 MWD+IFR-AK-CAZ-SC(2)
3,184.57 35.13 31.43 2,868.19 2,804.28 961.86 710.60 6,001,687.10 499,366.18 0.99 1,192.17 MWD+IFR-AK-CAZ-SC(2)
3,277.93 34.46 31.76 2,944.85 2,880.94 1,007.24 738.51 6,001,732.47 499,394.10 0.75 1,245.44 MWD+IFR-AK-CAZ-SC(2)
3,370.20 37.22 30.58 3,019.64 2,955.73 1,053.47 766.46 6,001,778.69 499,422.05 3.08 1,299.45 MWD+IFR-AK-CAZ-SC(2)
3,460.85 37.31 30.88 3,091.79 3,027.88 1,100.65 794.50 6,001,825.86 499,450.10 0.22 1,354.33 MWD+IFR-AK-CAZ-SC(2)
3,553.40 33.19 30.44 3,167.35 3,103.44 1,146.59 821.74 6,001,871.78 499,477.35 4.46 1,407.72 MWD+IFR-AK-CAZ-SC(2)
3,647.07 33.47 29.61 3,245.62 3,181.71 1,191.15 847.50 6,001,916.33 499,503.11 0.57 1,459.16 MWD+IFR-AK-CAZ-SC(2)
3,741.70 33.29 30.67 3,324.64 3,260.73 1,236.17 873.64 6,001,961.35 499,529.25 0.64 1,511.19 MWD+IFR-AK-CAZ-SC(2)
3,832.39 35.23 29.66 3,399.59 3,335.68 1,280.31 899.28 6,002,005.48 499,554.90 2.23 1,562.22 MWD+IFR-AK-CAZ-SC(2)
3,924.25 35.22 29.84 3,474.63 3,410.72 1,326.31 925.57 6,002,051.47 499,581.20 0.11 1,615.16 MWD+IFR-AK-CAZ-SC(2)
3,944.95 35.21 30.10 3,491.54 3,427.63 1,336.65 931.53 6,002,061.81 499,587.16 0.73 1,627.09 MWD+IFR-AK-CAZ-SC(2)
4,019.06 35.66 30.33 3,551.92 3,488.01 1,373.78 953.16 6,002,098.93 499,608.79 0.63 1,670.04 MWD+IFR-AK-CAZ-SC(3)
4,113.61 35.51 29.68 3,628.82 3,564.91 1,421.43 980.67 6,002,146.57 499,636.31 0.43 1,725.03 MWD+IFR-AK-CAZ-SC(3)
4,207.44 33.53 26.13 3,706.13 3,642.22 1,468.38 1,005.58 6,002,193.51 499,661.23 3.01 1,778.05 MWD+IFR-AK-CAZ-SC(3)
4,297.19 31.02 27.14 3,782.01 3,718.10 1,511.22 1,027.05 6,002,236.34 499,682.70 2.86 1,825.76 MWD+IFR-AK-CAZ-SC(3)
4,395.34 28.95 30.00 3,867.02 3,803.11 1,554.31 1,050.47 6,002,279.42 499,706.12 2.56 1,874.71 MWD+IFR-AK-CAZ-SC(3)
12/1/2011 10:12:11AM Page 3 COMPASS 2003.16 Build 69
ConocoPhillips (Alaska) Inc.
Definitive Survey Report
Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3H-34
Project: Kuparuk River Unit ND Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Site: Kuparuk 3H Pad MD Reference: D141 @ 63.91ft(D141 (36.4+27.51))
Well: 3H-34 North Reference: True
Wellbore: 3H-34 Survey Calculation Method: Minimum Curvature
Design: 3H-34 Database: CPAI EDM Production
Survey
Map Map Vertical
MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section
(ft) (1 (1 (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name
4,485.19 29.29 30.72 3,945.51 3,881.60 1,592.03 1,072.57 6,002,317.14 499,728.23 0.54 1,918.42 MWD+IFR-AK-CAZ-SC(3)
4,577.69 28.43 26.05 4,026.53 3,962.62 1,631.27 1,093.80 6,002,356.37 499,749.47 2.61 1,962.95 MWD+IFR-AK-CAZ-SC(3)
4,670.66 29.51 25.16 4,107.87 4,043.96 1,671.88 1,113.26 6,002,396.97 499,768.93 1.25 2,007.71 MWD+IFR-AK-CAZ-SC(3)
4,761.67 28.92 26.52 4,187.30 4,123.39 1,711.86 1,132.61 6,002,436.94 499,788.29 0.98 2,051.87 MWD+IFR-AK-CAZ-SC(3)
4,850.33 30.21 26.64 4,264.42 4,200.51 1,750.98 1,152.19 6,002,476.06 499,807.87 1.46 2,095.43 MWD+IFR-AK-CAZ-SC(3)
4,946.59 29.21 29.68 4,348.03 4,284.12 1,793.04 1,174.68 6,002,518.11 499,830.36 1.88 2,143.01 MWD+IFR-AK-CAZ-SC(3)
5,036.13 28.08 30.45 4,426.61 4,362.70 1,830.19 1,196.18 6,002,555.25 499,851.87 1.33 2,185.91 MWD+IFR-AK-CAZ-SC(3)
5,130.52 27.57 31.12 4,510.08 4,446.17 1,868.04 1,218.72 6,002,593.09 499,874.42 0.63 2,229.96 MWD+IFR-AK-CAZ-SC(3)
5,218.37 27.06 31.59 4,588.14 4,524.23 1,902.46 1,239.70 6,002,627.51 499,895.40 0.63 2,270.27 MWD+IFR-AK-CAZ-SC(3)
5,314.51 27.67 31.42 4,673.52 4,609.61 1,940.14 1,262.79 6,002,665.18 499,918.49 0.64 2,314.46 MWD+IFR-AK-CAZ-SC(3)
5,407.98 28.95 31.97 4,755.81 4,691.90 1,977.85 1,286.08 6,002,702.88 499,941.79 1.40 2,358.79 MWD+IFR-AK-CAZ-SC(3)
5,502.78 29.95 32.42 4,838.36 4,774.45 2,017.30 1,310.92 6,002,742.32 499,966.63 1.08 2,405.40 MWD+IFR-AK-CAZ-SC(3)
5,595.62 29.01 29.74 4,919.18 4,855.27 2,056.41 1,334.51 6,002,781.42 499,990.23 1.74 2,451.07 MWD+IFR-AK-CAZ-SC(3)
5,687.60 29.74 30.18 4,999.33 4,935.42 2,095.50 1,357.05 6,002,820.50 500,012.77 0.83 2,496.16 MWD+IFR-AK-CAZ-SC(3)
5,777.90 28.91 28.14 5,078.06 5,014.15 2,134.11 1,378.60 6,002,859.10 500,034.33 1.44 2,540.33 MWD+IFR-AK-CAZ-SC(3)
5,873.10 29.73 27.73 5,161.07 5,097.16 2,175.29 1,400.44 6,002,900.28 500,056.17 0.89 2,586.83 MWD+IFR-AK-CAZ-SC(3)
5,958.98 28.06 30.25 5,236.26 5,172.35 2,211.59 1,420.52 6,002,936.58 500,076.26 2.41 2,628.26 MWD+IFR-AK-CAZ-SC(3)
6,058.67 28.83 31.05 5,323.91 5,260.00 2,252.44 1,444.73 6,002,977.41 500,100.47 0.86 2,675.73 MWD+IFR-AK-CAZ-SC(3)
6,149.40 31.77 30.76 5,402.24 5,338.33 2,291.72 1,468.24 6,003,016.68 500,123.98 3.24 2,721.50 MWD+IFR-AK-CAZ-SC(3)
6,241.50 33.80 31.01 5,479.66 5,415.75 2,334.51 1,493.84 6,003,059.47 500,149.59 2.21 2,771.36 MWD+IFR-AK-CAZ-SC(3)
6,333.41 36.81 30.21 5,554.66 5,490.75 2,380.23 1,520.87 6,003,105.17 500,176.63 3.31 2,824.45 MWD+IFR-AK-CAZ-SC(3)
6,422.65 39.69 29.55 5,624.74 5,560.83 2,428.13 1,548.38 6,003,153.07 500,204.14 3.26 2,879.66 MWD+IFR-AK-CAZ-SC(3)
6,521.02 42.26 29.16 5,699.90 5,635.09 2,484.35 1,580.00 6,003,209.28 500,235.76 2.63 2,944.09 MWD+IFR-AK-CAZ-SC(3)
6,614.66 45.47 30.49 5,766.50 5,702.59 2,540.62 1,612.28 6,003,265.54 500,268.06 3.57 3,008.93 MWD+IFR-AK-CAZ-SC(3)
6,704.57 48.64 30.45 5,827.75 5,763.84 2,597.34 1,645.65 6,003,322.25 500,301.43 3.53 3,074.71 MWD+IFR-AK-CAZ-SC(3)
6,798.54 50.20 31.09 5,888.88 5,824.97 2,658.66 1,682.17 6,003,383.55 500,337.96 1.74 3,146.06 MWD+IFR-AK-CAZ-SC(3)
6,856.36 51.33 30.99 5,925.45' 5,861.54 2,697.03 1,705.26 6,003,421.91 500,361.05 1.96 3,190.84 MWD+IFR-AK-CAZ-SC(3)
6,923.04 52.75 31.58 5,966.46 5,902.55 2,741.96 1,732.56 6,003,466.83 500,388.36 2.24 3,243.41 MWD+IFR-AK-CAZ-SC(4)
7,018.38 51.51 30.19 6,024.99 5,961.08 2,806.54 1,771.20 6,003,531.40 500,427.00 1.74 3,318.65 MWD+IFR-AK-CAZ-SC(4)
7,112.61 50.56 28.29 6,084.25 6,020.34 2,870.46 1,806.99 6,003,595.31 500,462.80 1.86 3,391.83 MWD+IFR-AK-CAZ-SC(4)
7,208.42 49.12 26.91 6,146.04 6,082.13 2,935.34 1,840.92 6,003,660.18 500,496.74 1.86 3,464.84 MWD+IFR-AK-CAZ-SC(4)
7,258.46 49.42 27.27 6,178.69 6,114.78 2,969.10 1,858.19 6,003,693.93 500,514.02 0.81 3,502.63 MWD+IFR-AK-CAZ-SC(4)
7,300.00 49.42 27.27 (6,205.71 6,141.80 2,997.14 1,872.64 6,003,721.97 500,528.47 0.00 3,534.07 PROJECTED to TD
12/1/2011 10.12:11AM Page 4 COMPASS 2003.16 Build 69
ConocoPhillips
Time Log & Summary
Wenview Web Reporting Report
Well Name: 3H-34 Rig Name: DOYON 141
Job Type: DRILLING ORIGINAL Rig Accept: 11/3/2011 6:00:00 AM
Rig Release: 11/25/2011 12:00:00 PM
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
11/02/2011 24 hr Summary
Rig rel;eased from 2A-11 @ 2359 HRS, 11-1-11.Move rig power pack modules from 2A-3H.Return to 2A
and mover rig sub base. Lay matting boards and pit liner.Spot sub base, and pipe sheds.Spot all power
pack complexes.Attach interconnects, and electrical.
00:00 12:00 12.00 MIRU MOVE MOB P Load Rockwasher. Load out power
pack complexes. Move same to
3H-34.Move matting boards. Load
out and move pipe shed modules.
Pull Sub base off of well.Crew
Change
12:00 00:00 12.00 MIRU MOVE MOB P Move sub base to 3H-34. Lay
matting boards. Rig up diverter line.
Spot sub base over conductor. Lay
matting boards for pipe sheds and
power pack.Spot all modules. Spot
rockwasher.Attach interconnects,
steam,water,electrical and air. Prep
rig camp for move. Crew change
11/03/2011
Continue attach interconnects,and rig acceptance checklist. Rig accepted at 0600 HRS. PJSM with crane
dp
operator. Pick and set MWD shack,and centrifuge.Test all gas alarms. Perform Diverter Function test. L,,
AOGCC witness-Matt Herrera. Intial 200 PSI in 40 seconds, an full 3000 PSI in 170 seconds. 5 Nitrogen paEa-f
bottles with 2100 PSI avg PSI.Annular closed in 60 seconds, and Knife valve opened in 9 seconds. Rig on (44"
Hi-Line power at 1600 HRS. Pull drilling equipment to rig floor. Load pipe shed with 5"DP.Change out saver
sub on Top Drive&grabber dies. Pick up 5"DP racking back in derrick.
00:00 06:00 6.00 MIRU MOVE MOB P Continue attach all interconnects.
Work on rig acceptance checklist.
Rig up all stairs and handrails. Install
pit liner, and berms. Rig accepted at
0600 HRS.
06:00 10:30 4.50 MIRU DRILL RURD P Take on 600 BBLS of Spud Mud.
Install diverter line. Install 22' Riser.
Install 4"ball valves on 4"nipples on
conductor.
10:30 12:00 1.50 MIRU DRILL RURD P Held PJSM with ASRC crane
operator. Discuss safety&hazard
recognition issues. Discuss planned
lifts. Lift centrifuge and set same in
place. Crew Change
12:00 13:00 1.00 MIRU DRILL RURD P Held PJSM with new crew.Continue
installation of centrifuge, power box.
13:00 13:30 0.50 MIRU DRILL RURD P Pick and set MWD shack on roof.
13:30 14:00 0.50 MIRU WHDBO NUND P Test all qas alarms, and trip tank
alarms.test flow line alarms with
AOGCC rep-Matt Herrera,witness
of test.
Page 1 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
14:00 14:45 0.75 MIRU WHDBO NUND P Rig on Hi-line power at 1600 HRS.
Continue torque up diverter system
bolts. Length of diverter buoy line=
107.5'. Nearest ignition source=89'.
14:45 16:30 1.75 MIRU WHDBO BOPE P Make up 5" DP joint.Test run in
hole. Perform Diverter test with knife
valve opening in 9 seconds,and
annular closed in 40 seconds.
Accumulator test-obtained first 200
PSI in 40 seconds, and full 3000 PSI
in 170 Seconds.Observed 5 nitrogen
bottles with 2100 PSI avg PSI.
AOGCC rep-Matt Herrera,witness
of test.
16:30 17:45 1.25 MIRU DRILL RURD P Lay down 5"jnt. Pull saver sub to rig
floor. Pick up 4"slips,and 4"test
joint.
17:45 19:30 1.75 MIRU DRILL RURD P Held PJSM.Change out saver sub
on Top Drive,bell guide and grabber
dies.
19:30 22:00 2.50 MIRU DRILL RURD P Load 5"drill pipe in shed. Strap
same for single joint tally.
22:00 00:00 2.00 MIRU DRILL PULD P Held PJSM,discuss safety&hazard
recognition issues. Discuss
procedure to pick up and rack back
5"DP. Begin picking up and racking
back 5"DP stands. Strap Satnds.
Crew Change
11/04/2011
Continue pick up and rack back 5"DP stands. Spot Halliburton GYRO unit. Load, rack back 5"HWDP. Flood
Conductor. pressure test Surface equipment to 3400 PSI. Check&set Pop offs.Calibrate Block Heights with
MWD. Make up bit,drill out to 215'with BHA#1. POOH. RU HES GYRO with sheaves.Calibrate Block
height, and replace transducers. Make up BHA#2.
00:00 07:00 7.00 0 0 MIRU MOVE PULD P Continue pick up and rack back a
total of 50 stands of 5"drill pipe.
Observed pipe full of snow.
07:00 08:45 1.75 0 0 MIRU DRILL RURD P 'Pull tools to rig floor. RU HES GYRO
equipment.
08:45 11:00 2.25 0 0 MIRU DRILL PULD P Load pipe shed with 5"HWDP. Pick
up and rack back 5 stands.
11:00 11:30 0.50 0 0 SURFA( DRILL SFTY P Clean&clear rig floor. Held PJSM
with crew&Sperry Sun reps.
Discuss safety&hazard recognition
issues. Discuss making up BHA.
11:30 12:00 0.50 0 0 SURFA( DRILL RURD P Flood conductor&lines with water.
Check for leaks. Pressure test mud
pumps and lines,surface equipment
to 3400 PSI. Set pop-offs to 3800
PSI.Attempt to tag at 91', no tag.
Crew Change
12:00 12:45 0.75 0 0 SURFA( DRILL RURD P Calibrate block height per MWD.Set
Totco depths.
12:45 13:00 0.25 0 0 SURFA( DRILL SFTY P Held PJSM with crew&Sperry Sun
reps. Discuss safety&hazard
recognition issues. Discuss making
up BHA.
Page 2 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
13:00 15:30 2.50 0 0 SURFA( DRILL PULD P Make up 13 1/2"Bit&drilling
assembly. Set motor bend to 1.5
Deg.Test Mud Motor.
15:30 18:30 3.00 0 215 SURFA( DRILL DDRL P RIH tag and clean out conductor to
90'. Swap to spud mud,continue drill
out at 420 GPM's-500 PSI.WOB=
5K. Drill down to 215'. Back ream the
li stand.
18:30 19:15 0.75 215 215 SURFA( DRILL TRIP P Blow down lines&top drive. rack
back second stand of HWDP.
19:15 19:45 0.50 215 215 SURFA( DRILL PULD P Clean&clear rig floor.
19:45 20:15 0.50 215 215 SURFA( DRILL SRVY P Pick up tools,and rig up HES Gyro
equipment.
20:15 21:00 0.75 215 215 SURFA( DRILL PULD P Make up Float sub on motor.
21:00 23:00 2.00 215 215 SURFA( DRILL RURD T Re-calibrate block height as per
MWD.Trouble shoot encoder and
replace same. Re-calibrate.
23:00 00:00 1.00 215 215 SURFA( DRILL PULD P Continue make up BHA#2 as per
DD&MWD. Crew Change
11/05/2011
Continue make up BHA#2,and upload MWD. orient. Directional drill 13 1/2"hole with GYRO surveys from
215'-1469'MD.TVD=1426'.ADT= 12.91 HRS,AST=8.42 HRS. Utilize GYRO surveys untill not needed
at 1200'MD.Total Jar=12.91. Bit HRS= 13.78
00:00 00:45 0.75 215 215 SURFA( DRILL PULD P Continue make up 13 1/2" BHA#2.
00:45 02:00 1.25 215 215 SURFA( DRILL PULD P Upload MWD.Orient UBHO sub.
02:00 03:45 1.75 215 215 SURFA( DRILL PULD P Continue make up BHA#2 to 204'. p (�
Run GYRO survey at 204'. .3I
03:45 04:00 0.25 215 215 SURFA( DRILL RURD P Calibrate MWD encoder sensor. (,,41
04:00 12:00 8.00 215 690 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from 215'
-690'MD.TVD=685'.ADT=4.44
HRS.AST=3.05 HRS,ART= 1.39
HRS. Utilize GYRO surveys. UP WT
=70K,SOWT=70K, ROTWT=
70K. Pumps at 400 GPM's-1250
PSI.WOB= 10-15K.TQ=2.5K.Jar
HRS=5.31 HRS. BIT=5.31 HRS.
Crew Change
12:00 00:00 12.00 690 1,469 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
690'-1469'MD.TVD=1426'.ADT
=8.47 HRS.AST=5.37 HRS,ART
=3.10 HRS. Utilize GYRO surveys
until released at 1200'MD. UP WT
=93K,SO WT=74K, ROTWT=
82K. Pumps at 513 GPM's-1550
PSI.WOB= 15-20K.TQ=7K.Jar
HRS=12.91 HRS. BIT= 13.78
HRS. Work through tight spot at
1347'-1370'until cleaned up.Crew
Change
11/06/2011
Continue directional drill 13 1/2"hole from 1469'-3100'.TVD=2801'.ADT= 17.03 HRS.AST=6.27 HRS.
Total Jar HRS=28.51.Total Bit Hrs=29.38. Mud wt=9.2 PPG.AVG ROP=68'/HR
Page 3 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
00:00 06:00 6.00 1,469 2,070 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
1469'-2070'MD.TVD= 1958'.ADT
=4.73 HRS.AST=3.67 HRS,ART
= 1.06 HRS. UP WT= 103K,SO WT
=77K, ROT WT=87K. Pumps at
525 GPM's-1600 PSI.WOB=
20-25K.TQ=6K.Jar HRS= 17.64
HRS. BIT=18.51 HRS.
06:00 09:30 3.50 2,070 2,302 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
2070'-2302'MD.TVD=2145'.ADT
= 1.79 HRS.AST=.33 HRS,ART=
1.46 HRS. UP WT= 104K,SO WT=
79K, ROT WT=81K. Pumps at 525
GPM's-1600 PSI.WOB=15-20K.
TQ=5K.Jar HRS=19.43 HRS. BIT
=20.30 HRS.
09:30 10:45 1.25 2,302 2,302 SURFA( RIGMN7 RGRP T Repair charge pump line. (Leaking)
Reciprocate drill string.
10:45 12:00 1.25 2,302 2,395 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
2302'-2395'MD.TVD=2220'.ADT
=2.54 HRS.AST=.33 HRS,ART=
2.21 HRS. UP WT= 108K, SO WT=
85K, ROT WT=96K. Pumps at 530
GPM's-1600 PSI.WOB=15-20K.
TQ=6K.Jar HRS=20.18 HRS. BIT
=22.84 HRS.Crew Change
12:00 18:00 6.00 2,395 2,766 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
2395'-2766'MD.TVD=2525'.ADT
=4.21 HRS.AST=.85 HRS,ART=
3.36 HRS. UP WT= 118K,SO WT=
87K, ROT WT=99K. Pumps at 578
GPM's-1950 PSI.WOB=15-20K.
TQ=6K.Jar HRS=24.39 HRS. BIT
=25.26 HRS.
18:00 00:00 6.00 2,766 3,100 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
2766'-3100'MD.TVD=2801'.ADT
=4.82 HRS.AST=1.09 HRS,ART
=3.73 HRS. UP WT= 122K,SO WT
=92K, ROT WT= 105K. Pumps at
575 GPM's-2000 PSI.WOB=
20-25K.TQ=8K.Jar HRS=28.51
HRS. BIT=29.38 HRS.Crew
Change
11/07/2011
Continue directional drill 13 1/2"hole from 3100'-3990'.TVD=3528'.ADT= 19.6 HRS.AST=4.45 HRS.
Total Jar HRS=48.81.Total Bit Hrs=49.68. Mud wt=9.2 PPG.AVG ROP=45'/HR This section TD'd at
midnight per GEO.
00:00 06:00 6.00 3,100 3,450 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
3100'-3450'MD.TVD=3083'.ADT
=4.60 HRS.AST=.93 HRS,ART=
3.67 HRS. UP WT= 127K, SO WT=
96K, ROT WT= 110K. Pumps at
575 GPM's-2000 PSI.WOB=
20-25K.TQ=9K.Jar HRS=33.81
HRS. BIT= 33.98 HRS.
Page 4 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
06:00 12:00 6.00 3,450 3,638 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
3450'-3638'MD.TVD=3237'.ADT
=4.54 HRS.AST= 1.81 HRS,ART
=2.73 HRS. UP WT= 131K,SO WT
=99K, ROT WT=111K. Pumps at
575 GPM's-2000 PSI.WOB=20K.
TQ=8K.Jar HRS=38.35 HRS. BIT
=38.52 HRS.Crew Change
12:00 18:00 6.00 3,638 3,810 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
3638'-3810'MD.TVD=3381'.ADT
=5.39 HRS.AST=1.71 HRS,ART
=3.68 HRS. UP WT=147K,SO WT
=95K, ROT WT= 115K. Pumps at
600 GPM's-2000 PSI.WOB= 15K.
TQ=9K.Jar HRS=43.74 HRS. BIT
=44.61 HRS.
18:00 00:00 6.00 3,810 3,990 SURFA( DRILL DDRL P Directional drill 13 1/2"hole from
3810'-3990'MD.TVD=3528'.ADT
=5.07 HRS.AST=0 HRS,ART=
5.07 HRS. UP WT= 150K,SO WT=
101K, ROT WT=120K. Pumps at
600 GPM's-2000 PSI.WOB=30K.
TQ= 10K.Jar HRS=48.81 HRS.
BIT=49.68 HRS.This section TD's
at midnight.Crew Change
11/08/2011
Section TD'd at midnight at 3990'MD. Circulate bottoms up x 2.Short trip back to HWDP. POOH on
elevators to 2400'. Pump out of hole to 637'.Trip back to bottom. Circulate bottoms x 2. Monitor well. POOH
to HWDP. No hole issues observed on TOH. Download MWD, Breakout&lay down BHA. Observed proper
displacement. Clean floor area. Rig up to run caisng.
00:00 02:00 2.00 3,990 3,990 SURFA( DRILL CIRC P Circulate bottoms up x 2 with pumps
at 600 GPM's-1700 PSI.
Reciprocate&rotate drill string.
Observed clean shakers.
02:00 02:15 0.25 3,990 3,990 SURFA( DRILL OWFF P Monitor well-static.
02:15 03:15 1.00 3,990 2,369 SURFA( DRILL TRIP P Pull out of hole on elevators to 2369'
MD.Observed displacement off,
swabbing.
03:15 05:00 1.75 2,369 1,935 SURFA( DRILL REAM P Pump out from 2369'.with pumps @
4 BPM-400 PSI.Observed clean
hole conditions to 1935'MD. Pulled
25K over.Work through tight spot.
05:00 08:30 3.50 1,935 637 SURFA( DRILL REAM P BROOH from 1935'to 1842'.Work
through tight spots at 1842'and at
1749', until cleaned up.Continue
Pump out of hole to 637'.Observed
fair hole conditions.
08:30 08:45 0.25 637 637 SURFA( DRILL OWFF P Monitor well-static. Clean floor area.
08:45 12:00 3.25 637 3,047 SURFA( DRILL TRIP P Trip back in hole form 637'to 3047'.
Work through tight spot at 3047'.
Crew Change.
12:00 12:30 0.50 3,047 3,990 SURFA( DRILL TRIP P Continue trip in hole from 3047'-
3970'. Pick up single and wash to
bottom at 3990.Good hole
conditions.
Page 5 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
12:30 14:00 1.50 3,990 3,990 SURFA( DRILL CIRC P Circulate,staging pumps up to 16.5
BPM-2300 PSI. Reciprocate&
rotate drill string.Circulate bottoms
up x 2. Shakers cleaned up.
14:00 14:30 0.50 3,990 3,990 SURFA( DRILL OWFF P Lay down single. Prep for TOH.
Monitor well-static.
14:30 17:15 2.75 3,990 637 SURFA( DRILL TRIP P POOH on elevators form 3990'-
HWDP at 637'. Monitor well-static.
Observed proper displacement.
17:15 18:45 1.50 637 100 SURFA( DRILL PULD P Breakout and lay down Jars and drill
collars.
18:45 19:15 0.50 100 100 SURFA( DRILL PULD P Plug in and download MWD. Held
PJSM with crew, and Sperry reps.
Discuis safety&hazard recognition
issues. Discuss procedure to
breakout&lay down BHA.
19:15 21:30 2.25 100 0 SURFA( DRILL PULD P Breakout&lay down BHA. Inspect
and grade bit to 2/4M/T/A/E/I/CT/TD.
21:30 22:30 1.00 0 0 SURFA( DRILL RURD P Clean&clear rig floor. Send tools
out.
22:30 00:00 1.50 0 0 SURFA( CASING RURD P Held PJSM. Change out short bales
on Top drive to long bales. Pull
casing equipment to rig floor. Crew
Change
11/09/2011
Continue Rig up to run 10 3/4"casing. Held PJSM.Make up Shoe track assembly, and check floats.
Continue RIH with 10 3/4"casing. Break Circulation every 500'. Make up landing joint&hanger. Land casing
on depth. Rig up cement head&equipment.Circulate&condition mud for pre cement properties. Held
PJSM. Batch up cement. Begin cemnt job,pumping Cw100&Mud push, and 450 BBLS of lead before end of
tour.
00:00 01:45 1.75 0 0 SURFA( CASING RURD P Continue rig up to run 10 3/4"casing.
Install franks fill up tool. Hang power
tongs,and scaffold. Double check
order,and pipe shed.
01:45 02:15 0.50 0 0 SURFA( CASING SFTY P Held PJSM with crew and casing
running reps. Discuss safety&
hazard recognition issues. Discuss
procedure to make up and run 10
3/4"casing.
02:15 08:15 6.00 0 0 SURFA( CASING RNCS P Make up shoe track assembly_with
baffle collar in to of float collar joint
as planned. Baker Lok first 4
connections. Make up TQ-8-12K
ft/lbs. Fill pipe check floats pump
thick mud through shoe track at 3
BPM-200 PSI. Continue run in hole
with 10 3/4"casing filling each joint,
and breaking circulaton every 10 jnts.
Obtain T&D parameters.
08:15 09:45 1.50 0 SURFA( CASING RNCS P AT 1945', lost 25k Down weight.
Break circulation and pump down 2
joints to 2058'. UP WT-130K,SO
WT-93K.
09:45 11:30 1.75 SURFA( CASING RNCS P Continue RIH with 10 3/4"casing to
2873'. Observed pushing mud away.
11:30 12:30 1.00 SURFA( CASING CIRC P Break Circualtion ,circulate a casing
volume at 4 BPM-400 PSI.
Reciprocate casing string.
Page 6 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
12:30 15:45 3.25 SURFA( CASING RNCS P Continue run 10 3/4"casing. Slower
running speeds as we were pushing
mud away. Ran to 3975'
15:45 16:30 0.75 SURFA( CASING RNCS P Make up landing joint and hanger
assembly. Break circulation,
reciprocate casing string while rig
down spiders and power tongs.
16:30 17:30 1.00 SURFA( CASING RURD P Rig Down Franks Fill Up Tool. Blow
down Top Drive. Make up Cement
head with one plug loaded.
17:30 20:45 3.25 SURFA( CASING CIRC P Circulate&condition mud for
pre-cement properties. Mud WT=
9.2 PPG. PV= 11,YP= 18, 10 sec
-22, 10 Min-60. Reciprocate casing
string entire time.
20:45 21:15 0.50 SURFA( CEMENT SFTY P Held PJSM with crew, MI,
Schlumberger, and ASRC reps.
Discuss safety&hazard recognition
issues. Discuss procedure to mix&
pump cement job as planned.
Designate spill champions.
21:15 22:15 1.00 SURFA( CEMENT CIRC P Continue circulating,and
reciprocating casing string„while
batching up. UP WT 201K,SO WT-
155K.
22:15 00:00 1.75 SURFA( CEMENT CMNT P Turn over to Schlumberger. Pump 5 G
BBLS fresh water. Pressure test
lines in stages to 3500 PSI. Good pO-i
test.Complete batching up. Pump
43 BBLS of 8.6 PPG CW100,50
BBLS of 10.45 PPG Mud Push with
red dye.Continue pump 450 BBLS of
11.09 PPG ALC cement,to crew
change.
11/10/2011
Continue pump remaing lead cement for a total of 532 BBLS pumped. Pump 109 BBLS of Tail cement. Drop
Plug Displace cement with 9.2 PPG Mud,observing approx-205 BBLS of 11 PPG cement to surface.
Casing hanger hung up 15"from bowl while reciprocating casing string. Bump plug with CIP at 02:07 HRS.
Floats held. Held After job Safety Mtg with all hands. Rig down cement head and equipment. Drop Davis
-Lynch Cancellation plug to DV tool. Nipple down Diverter system.Set emergency slips. Nipple up casing&
tubing spools.Confirm wellhead orientation with Pad operator. Nipple up BOP's
00:00 01:00 1.00 SURFA( CEMENT CMNT P Change hoses on cement line on rig,
as we observed a washout.Continue
pump Lead cement for a total of 532
BBLS,continue with 109 BBLS of 12
PPG Lite Crete cement at 5 BPM-
600 PSI. Pump 10 BBLS of water to
clear lines. Drop Davis Lynch 1st
stage plug. Full reciprocation during
cement pumping.
Page 7 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
01:00 02:00 1.00 SURFA( CEMEN'DISP P Turn over to rig. Displace cement at
6 BPM-observing good lift
pressures to 970 PSI before slowing
pumps to 3 BPM-620 PSI. Bump
plug with 371 BBLS pumped,and
increase pressure to 1200 PSI. Hold
5 minutes. Bleed pressure and
check floats.Held. We stopped
reciprocationg xcasing when the
casing became tight and hung up 15"
off of the hanger.Approximately 100
BBLS into displacement.CIP @
02:07 HRS.
02:00 02:30 0.50 SURFA(CEMEN'SFTY P Held after action review mtg with
crew, and all vendors and cementers.
Discuss job and obtain many
lessons learned from all hands.
02:30 03:15 0.75 SURFA( CEMEN'NUND P Flush diverter system and lines with
black water.
03:15 03:30 0.25 SURFA(WHDBO SFTY P Held PJSM with crew. Discuss
Nipple down diverter system.
03:30 07:30 4.00 SURFA( CASING NUND P Back out landing joint. Nipple down
diverter suystem, riser,and lines.
07:30 09:30 2.00 SURFA( CASING PULD P Make up Landing joint on casing
stump. Drop GREEN Davis-Lynch
cancellation dart.to the DV Tool
978'. Pressure to 2000 PSI,2500
PSI, observing pressure drop
indicating shift. Pressure to 2100
PSI-hold 5 minutes. Bled pressures
and rig down equipment.
09:30 12:00 2.50 SURFA(WHDBO NUND P Continue niopple down diverter,and
surface stack equipment.Crew
Change
12:00 15:00 3.00 SURFA(WHDBO NUND P Continue nidpple down diverter, and
surface stack equipment.
15:00 17:30 2.50 SURFA(WHDBO NUND P Clean cellar box.Clean&inspect
hanger threads. Observed hanger 7"
form landing. Install emergency slip
as per FMC rep. Make up landing
joint. Heat connection on hanger.
Weld gussets to hanger flutes&
conductor to prevent over torquing
casing stump.
17:30 18:45 1.25 SURFA(WHDBO NUND P Heat connection on landing joint to
hanger. Use tongs to put 14K ft/lbs
of torque on landing joint to break out
of hanger. Pull and lay down landing
joint.
18:45 19:00 0.25 SURFA(WHDBO SFTY P Held PJSM with crew. Discuss
Nipple up.
19:00 21:00 2.00 SURFA(WHDBO NUND P Nipple up casing&tubing spools as
per FMC rep.Confirm orientation of
wellhead with pad operator.
SIMOPS:Cleaning pits.
Page 8 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
21:00 00:00 3.00 SURFA(WHDBO NUND P Nipple up 11"x 13"Adapter spool.
Nipple up BOP stack.Test seal on
casing hanger to 1000 PSI-10
minutes. Crew change.
11/11/2011
Continue NU BOP's. Open doors, inspect rams.2 7/8"x 5"VBR's. RU&test BOP's.Witness of test waived
by AOGCC rep Chuck Sheve.All test 250/3500 PSI. Recorded on chart.Tested with 5",and 4"test joints.
Perfom Koomey test. Initial 200 PSI in 29 sec, and full 3000 PSI in 203 secs. 5 Nitrogen bottles with 2100
PSI avg. RD test equipment. Make up BHA#3,TIH to 2450'MD.
00:00 05:00 5.00 SURFA(WHDBO NUND P Continue nipple up BOP stack,
choke&kill lines.Open ram doors.
Install 2 7/8"x 5"VBR's in top&
bottom set of rams. .
05:00 08:00 3.00 SURFA(WHDBO BOPE P Rig up test equipment. Install test
plug and 5"test joint. Fill stack,
choke manifold and lines with water.
08:00 14:30 6.50 SURFA(WHDBO BOPE P Test BOP stack, rams and annular. p ,F
Test Choke&kill HCR's and manual P j
valves.Test choke manifold and allilt
valves.All tests to 250/3500 PSI,
recorded on chart.Annular test to
250/2500 PSI.Test all floor valves.
test with 5"and 4"test joints.
Perform Koomey test with initial 200
PSI in 29 Secs, and full 3000 PSI
obtained in 203 seconds. Observed 5
Nitrogen bottles with 2100 PSI avg.
Witness of test waived by AOGCC
rep Chuck Sheve.
14:30 16:15 1.75 SURFA(WHDBO BOPE P Pull test plug&rig down all test
equipment. Blow down all lines. Line
up choke manifold. Install wear
bushing. RILDS. Clean&clear rig
floor area.
16:15 16:30 0.25 SURFA( DRILL SFTY P Held PJSM with crew, DD&MWD
reps. Discuss safety&hazard
recognitionissues. Discuss
procedure to make up BHA#3.
16:30 18:45 2.25 SURFA( DRILL PULD P Make up BHA#3 with 9 7/8"Reed
Hycalog bit,and 7"Sperry Lobe 7/8-
6.0 STG motor assembly. Make up
MWD assembly. Plug in and upload
MWD assembly.
18:45 20:30 1.75 637 SURFA( DRILL PULD P Continue make up 5"HWDP and
Jars. Perform Shallow pulse test @
700 GPM-1950 PSI. Good test.
Total BHA length=637.41'.
20:30 21:45 1.25 637 974 SURFA( DRILL TRIP P Trip in hole with BHA to tag DV collar
&dart at 974'MD. Drill out Dart with
500 GPM's-1250 PSI,30 RPM's
and WOB-2K.Aluminum dart drilled
out in 10 minutes,and work drill
string through DV collar assembly to
verify cleaned up.
21:45 00:00 2.25 974 2,675 SURFA( DRILL TRIP P Continue TIH with BHA#3 to 2675'.
Crew Change
Page 9 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
11/12/2011 24 hr Summary
Continue TIH with BHA#3,to tag firm cement at 3841'MD. Rack back a stand. Rig up to perform casing test.
Observed upper rams leaking, and pump problem with 4"Demco isolation valve.Troubleshoot problem. POOH
lay down BHA. Repair pump valve. Change out upper rams to 3 1/2"x 6"VBR's.Test same. Service rig. Make
up BHA#4.TIH 3783'. Rig up and test casing to 2500 PSI-30 min. Drill baffle plug and shoe trac cement to
3978'.Clean out open hole to 3990',and drill 20'of new hole to 4010'MD.
00:00 01:00 1.00 2,675 3,841 SURFA( DRILL TRIP P Continue trip in hole with BHA#3 to
tag cement stringers,and firm
cement at 3841' DPM. Rack back a
stand.
01:00 01:45 0.75 3,841 3,841 SURFA( DRILL PRTS P Rig up test equipment. Pump down
drill string and annulus to attempt
casing test. Observed upper rams
leaking. Repeat. Close annular.
Pressure to 100 PSi observing
isolation valve failed in pump room.
01:45 03:30 1.75 3,841 3,841 SURFA(WHDBO PRTS T Troubleshoot isolation valve problem.
Blow down lines. Decision to POOH,
as we essentially had no pump to
proceed.
03:30 06:15 2.75 3,841 200 SURFA(WHDBO TRIP T Held PJSM. POOH racking back DP.
Rack back HWDP.
06:15 06:30 0.25 200 100 SURFA(WHDBO PULD T Plug in and download MWD
assembly.
06:30 07:15 0.75 100 0 SURFA(WHDBO PULD T Breakout&lay down BHA. Inspect
bit-1/1
07:15 07:30 0.25 0 0 SURFA(WHDBO PULD T Clean&clear rig floor area.
07:30 10:00 2.50 0 0 SURFA(WHDBO BOPE T Held PJSM.Set Test plug. Open
upper ram doors on BOP stack.
Inspect 2 7/8"x 5"VBR's. remove
same&install 3 1/2"x 6"VBR's.
SIMOPS: Repair isolation valve in
pump room.
10:00 11:15 1.25 0 0 SURFA(WHDBO BOPE T Rig up test equipment.Test 3 1/2"x
6"VBR's to 250/3500 PSI with 4"and
5"test joints. Record test on chart.
Rig down test equipment. Install
wear bushing. RILDS. SIMOPS:
Repair isolation valve in pump room.
11:15 12:00 0.75 0 0 SURFA( RIGMNT SVRG P Service rig Top drive,drawworks.
SIMOPS: Repair isolation valve in
pump room.Crew Change
12:00 12:30 0.50 0 0 SURFA( RIGMNT SVRG T Continue to service rig Top drive,
drawworks.SIMOPS: Repair
isolation valve in pump room.
12:30 13:30 1.00 0 100 SURFA(WHDBO PULD T Held PJSM. Make up BHA#4,same
as BHA#3.
13:30 14:30 1.00 100 100 SURFA(WHDBO PULD T Plug in and upload MWD assembly.
SIMOPS: Rig up and test rebuilt
isoltaion valve to 3500 PSI.Good
test.
14:30 15:15 0.75 100 630 SURFA(WHDBO PULD T Continue make up BHA with NM
DC"s and HWDP&Jars. Perform
shallow pulse test with pumps at 17
BPM-1950 PSI. Blow down Top
drive&lines.
Page 10 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
15:15 17:00 1.75 630 3,783 SURFA(WHDBO TRIP T Trip in hole with BHA#4 to 3783'
MD.
17:00 18:30 1.50 3,783 3,783 SURFA( DRILL PRTS P Fill drill string. Rig up test
equipment. Close upper rams.
Pressure down DP&annulus to
2500 PSI for a casing test. Hold for
30 minutes. Record on chart. Bleed
pressure. RD test equipment. Blow
down lines.
18:30 19:15 0.75 3,783 3,783 SURFA( DRILL OTHR P Calibrate block heights for MWD&
Canrig. No success with Totco
because encoder failed.
19:15 23:00 3.75 3,783 3,990 SURFA( CEMENT DRLG P Obtain parameters. Drill hard cement
and shoe track from 3841'-3987'.
Conitnune drill cement out in old hole
from 3987'-3990'. UP WT= 140K,
SO WT=95K, ROT WT= 115K.
WOB-2-5K, RPM's 30-50.
23:00 23:30 0.50 3,990 4,010 SURFA( DRILL DDRL P Directional drill 9 7/8"hole from
3990'-4010'MD.TVD=3544'.ADT
=.31 HRS.AST=0 HRS,ART=.31
HRS. UP WT=140K, SO WT=
95K, ROT WT= 115K. Pumps at
650 GPM's-2150 PSI.WOB=
5-10K.TQ=6K.Jar HRS=.31
HRS. BIT=.31 HRS.
23:30 00:00 0.50 4,010 4,010 SURFA( DRILL CIRC P Displace wel pumping a 15 BBLS
Hi-Visc spacer and 360 BBLS of 9.6
LSND mud. Pumps at 650 GPM-
2100 PSI. Reciprocate&rotate drill
string.Crew change
11/13/2011
Complete mud swap to 9.6 PPG LSND. Perform LOT to 15.8 PPG. Establish baseline PWD parameters.
Directional drill 9 7/8"Intermediate hole from 4010'-5580'MD.ADT=13.58 HRS.AST=5.02 HRS.Total Bit
Hrs=13.89.Total Jar Hrs= 13.89
00:00 00:30 0.50 4,010 4,010 SURFA( DRILL CIRC P Complete mud swap to 9.6 PPG
LSND. Monitor well. rack back one
stand of DP.
00:30 01:30 1.00 4,010 4,010 SURFA( DRILL FIT P RU test equipment. Perform FIT test
to 15.8 PPG EMW. Rig down test
equipment.
01:30 01:45 0.25 4,010 4,010 INTRM1 DRILL CIRC P Establish baseline PWD parameters.
Clean hole ECD calculated at 9.89
PPG.
01:45 06:00 4.25 4,010 4,339 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 4010'
-4339'MD.TVD=3817'.ADT=3.26
HRS.AST= 1.46 HRS,ART= 1.80
HRS. UP WT= 136K,SO WT=
105K, ROT WT= 121K. Pumps at
650 GPM's-1900 PSI.WOB=
5-10K.TQ=8K.Jar HRS=3.57
HRS. BIT=3.57 HRS. Obtained
SPR's.
Page 11 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
06:00 12:00 6.00 4,339 4,712 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 4339'
-4712'MD.ND=4142'.ADT=3.28
HRS.AST=.62 HRS,ART=2.66
HRS. UPWT=143K,SOWT=
110K, ROT WT=126K. Pumps at
700 GPM's-2100 PSI.WOB=
5-10K.TQ=9K.Jar HRS=6.85
HRS. BIT=6.85 HRS.Obtained
SPR's.Crew Change
12:00 18:00 6.00 4,712 5,080 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 4712'
-5080'MD.ND=4466'.ADT=3.46
HRS.AST=.80 HRS,ART=2.66
HRS. UP WT= 155K,SO WT=
112K, ROT WT= 134K. Pumps at
700 GPM's-2400 PSI.WOB=
5-10K.TQ=10K.Jar HRS=10.31
HRS. BIT=10.31 HRS. ECD=
10.16 PPG Obtained SPR's
18:00 00:00 6.00 5,080 5,580 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 5080'
-5580'MD.ND=4921'.ADT=3.58
HRS.AST=.68 HRS,ART=2.90
HRS. UP WT=175K,SO WT=
119K, ROT WT= 142K. Pumps at
700 GPM's-2500 PSI.WOB=
5-10K.TQ=12K.Jar HRS= 13.89
HRS. BIT= 13.89 HRS. ECD=
10.36 PPG Obtained SPR's.Crew
Change
11/14/2011
Continue directional drill 9 7/8"Intermediate hole from 5580'-6840'MD ND=5912'.ADT-11.96 HRS.AST
=3.05 HRS.Total Jar Hrs=25.85,Total Bit Hrs=25.85.Changed out failed swab on mud pump, and
changed out failed hydraulic fitting on Top Drive.
00:00 03:30 3.50 5,580 5,922 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 5580'
-5922'MD.ND=5203'.ADT=2.24
HRS.AST= .64 HRS,ART=1.60
HRS. UP WT= 185K,SO WT=
120K, ROT WT=147K. Pumps at
700 GPM's-2600 PSI.WOB=
5-10K.TQ=15K.Jar HRS= 16.13
HRS. BIT=16.13 HRS. ECD=
10.54 PPG. Obtained SPR's.
03:30 07:30 4.00 5,922 5,922 INTRM1 RIGMN1 RGRP T Observed failed Hydraulic fitting on
Top Drive while makling a
connection.Shut down. Breakout a
stand of DP,and lay down same.
Lower top drive to rig floor. Maintain
circulation at 5 BPM-400 PSI,
reciprocate DP when we could.
Observed no hole issues. Change
out fitting and test same.
Page 12 of 29
Time Logs
Date From To Dur S. Death E. Depth Phase Code Subcode T Comment
07:30 12:00 4.50 5,922 6,192 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 5922'
-6192'MD.TVD=5440'.ADT=2.03
HRS.AST= 1.3 HRS,ART=.73
HRS. UP WT=185K,SO WT=
124K, ROT WT= 152K. Pumps at
700 GPM's-2750 PSI.WOB=
5-10K.TQ= 13K.Jar HRS=18.16
HRS. BIT= 18.16 HRS. ECD=
10.58 PPG. Obtained SPR's. Crew
Change
12:00 18:00 6.00 6,192 6,562 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 6192'
-6562'MD.TVD=5729'.ADT=3.94
HRS.AST=.45 HRS,ART=3.49
HRS. UP WT=180K,SO WT=
130K, ROT WT= 152K. Pumps at
700 GPM's-2825 PSI.WOB=
5-10K.TQ= 14K.Jar HRS=22.10
HRS. BIT=22.10 HRS. ECD=
10.77 PPG.Obtained SPR's.
18:00 22:00 4.00 6,562 6,777 INTRM1 DRILL DDRL P Continue directional drill from 6562'-
6777'MD.
22:00 22:30 0.50 6,777 6,777 INTRM1 RIGMNT RGRP P Observed swab on mud pump failed.
Change out swab. Reciprocate&
rotae drill string.
22:30 00:00 1.50 6,777 6,840 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 6777'
-6840' MD.TVD=5912'.ADT=
3.75 HRS.AST= .66 HRS,ART=
3.09 HRS. UP WT=183K,SO WT=
130K, ROT WT= 155K. Pumps at
700 GPM's-3025 PSI.WOB=
5-10K.TQ= 14K.Jar HRS=25.85
HRS. BIT=25.85 HRS. ECD=
11.13 PPG. Obtained SPR's.Crew
Change
11/15/2011
Con't direct'l drill 9 7/8" hole to TD at 6902'MD.TVD=5953'. Circ BU x 4,short trip to 5083', RIH to TD,circ
hi vis nut plug sweep--BU x 2, monitor well-static, POOH on elevators, L/D BHA,clear floor,change top rams
to 7-5/8",test rams to 250/3500,test annular 250/2500, RU casing equipment for 7-5/8"29.7 ppf L-80
BTC-mod casing.
00:00 01:00 1.00 6,840 6,902 INTRM1 DRILL DDRL P Directional drill 9 7/8"hole from 6840'
-6902' MD.TVD=5953'.ADT=
.82 HRS.AST=0 HRS,ART=.82
HRS. UP WT= 185K,SO WT=
130K, ROT WT=155K. Pumps at
700 GPM's-3025 PSI.WOB=
5-10K.TQ= 14K.Jar HRS=26.67
HRS. BIT=26.67 HRS. ECD=
11.09 PPG.Obtained SPR's.
01:00 03:30 2.50 6,902 6,657 INTRM1 DRILL CIRC P Circulate 4 bottoms up at full rates,
while reciprocating and rotating drill
string.700GPM, 100 RPM, Rack
back 4 stands.
03:30 03:45 0.25 6,657 6,902 INTRM1 DRILL WPRT P RIH from 6657'to 6902'. Hole in good
condition. No fill.
03:45 04:00 0.25 6,902 6,902 INTRM1 DRILL OWFF P Monitor well, Static, Blow down top
drive.
Page 13 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
04:00 06:45 2.75 6,902 5,083 INTRM1 DRILL WPRT P POOH on elevators from 6902'to
5862'MD. Started to pull tight,30K
over. Decision made to pump out of
the hole. Pumped out from 5862'to
5547'.700 GPM,2700 PSI. Shut
down pumps,pulled on elevators
from 5547'to 5083'. No Problems.
Decision made to run back to
bottom.
06:45 08:00 1.25 5,083 6,902 INTRM1 DRILL WPRT P RIH from 5083'to 6843'.Wash down
last 40 feet. No hole fill.
08:00 09:15 1.25 6,902 6,902 INTRM1 DRILL CIRC P Circ 40 bbl High Vis Nut Plug Sweep
(2.5 ppb flozan,5 ppb medium nut
plug).2 x's bottoms up. 50%
increase in cuttings.700 GPM, 100
RPM,2900 PSI.TQ=11-15k.
09:15 09:30 0.25 6,902 6,902 INTRM1 DRILL OWFF P Monitor well-static.
09:30 11:30 2.00 6,902 3,879 INTRM1 DRILL TRIP P Pull out of the hole on elevators f/
6902'to 3879'.
11:30 11:45 0.25 3,879 3,879 INTRM1 DRILL OWFF P Monitor well-static.
11:45 12:00 0.25 3,879 3,786 INTRM1 DRILL TRIP P Continue to pull out of the hole on
elevators f/3879'to 3786'.
12:00 12:15 0.25 3,786 3,786 INTRM1 DRILL SFTY P Crew change, PJSM, monitor
well-static.
12:15 14:15 2.00 3,786 637 INTRM1 DRILL TRIP P Continue to pull out of the hole on
elevators f/37869'to HWDP @ 637'.
14:15 14:30 0.25 637 637 INTRM1 DRILL OWFF P Monitor well-static.
14:30 16:00 1.50 637 84 INTRM1 DRILL PULD P Stand back 4 stands of 5"HWDP f/
637'to 265', Lay down BHA to MWD
@ 84'.Torque lift sub,flush tools w/
water. Break off bit.
16:00 16:30 0.50 84 84 INTRM1 DRILL PULD P Download Sperry Sun MWD.
16:30 17:00 0.50 84 0 INTRM1 DRILL PULD P Lay down BHA.
17:00 17:30 0.50 0 0 INTRM1 DRILL OTHR P Clear and clean rig floor.
17:30 18:30 1.00 0 0 INTRM1 DRILL PULD P Lay down subs and bit. Pull FMC
wear bushing.
18:30 18:45 0.25 0 0 INTRM1 CASING PULD P Bring casing tools to the rig floor.
18:45 19:00 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting.
19:00 20:45 1.75 0 0 INTRM1 WHDBO BOPE P With blind rams closed, change
upper pipe rams f/3-1/2"x 6"to
7-5/8".
20:45 21:30 0.75 0 0 INTRM1 WHDBO BOPE P Rig up testing equipment.
21:30 22:30 1.00 0 0 INTRM1 WHDBO BOPE P Test 7-5/8"rams to 250 psi low and /
3500 psi high.Test annular to 250 6
psi low and 2500 psi high. Chart
tests. Held each test f/5 minutes.
22:30 23:00 0.50 0 0 INTRM1 WHDBO BOPE P Rig down test equipment.
23:00 00:00 1.00 0 0 INTRM1 CASING RURD P Rig up casing equipment.
Page 14 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
11/16/2011 24 hr Summary
RU to run 7-5/8"csg, PJSM, Run casing per detail to 3946',CBU, run to 5413', CBU, run casing to 6891',MU
hanger and landing jt, RIH, land @ 6890.9'. RU Dowell cement head,circ and cond mud, cement per plan,
bump plug,check floats-good, R/D landing joint&casing tools, install FMC packoff,test to 5000 psi-OK,
Change top pipe rams to 3-1/2"x 6", perform injectivity test on annulus to 17.1 ppg EMW,flush annulus w/
total of 175 bbls of seawater, RU Little Red to pump freeze protection diesel.
00:00 00:30 0.50 0 0 INTRM1 CASING RURD P Continue to rig up to run 7-5/8"29.7
ppf L-80 BTC-mod casing.
00:30 01:00 0.50 0 0 INTRM1 CASING SFTY P Pre job safety meeting on running
casing.
01:00 02:00 1.00 0 170 INTRM1 CASING RNCS P Pick up shoe joint,baker lock jt#2,
baker lock FC joint, bakerlock and
make up 4th joint to 170'. Hydroform
centralizers run on each joint.
02:00 02:15 0.25 170 170 INTRM1 CASING CIRC P Circ 46 bbls w/Frank's fillup tool,
filling pipe, check floats-OK. Obtain
rates and pressures 4 bpm w/160
psi,5 bpm w/240 psi,6 bpm w/320
psi,7 bpm w/410 psi, and final 8
bpm w/595 psi.
02:15 06:45 4.50 170 3,946 INTRM1 CASING RNCS P Continue to run 7-5/8"29.7 ppf L-80
BTC-mod casing.Apply Hydroform 3
rib centralizers(7.63"x 9.38")on
every joint up to and including jt#43.
Use Jet lube Run-N-Seal dope.
Average make up torque 9000 ft lbs.
Continue running casing to joint#95
(depth 3946'). Fill each joint,top off
every 10th joint. Obtain PU&SO
wt's every 20 joints.
06:45 07:15 0.50 3,946 3,946 INTRM1 CASING CIRC P Circulate and condition mud @
3946'.Circulate a bottom's up
minimum. Pumping 6 bpm w/550 psi
initial,final 6 bpm w/480 psi. PU wt
128k, SO wt 103k.
07:15 09:15 2.00 3,946 5,413 INTRM1 CASING RNCS P Continue to run 7-5/8"29.7 ppf L-80
BTC-mod casing. Use Jet lube
Run-N-Seal dope.Average make up
torque 9000 ft lbs. Continue running
casing from jt#95(depth 3946')to
joint#130(depth 5413'). Fill each
joint,top off every 10th joint.Obtain
PU&SO wt's every 10 joints.
09:15 10:00 0.75 5,413 5,413 INTRM1 CASING CIRC P Circulate and condition mud @
5413'. Reciprocate pipe 18'stroke.
Circulate a bottom's up minimum.
Pumping 5 bpm w/620 psi initial,
final 6 bpm w/570 psi-40%Totco
flow out. PU wt 163k,SO wt 113k.
10:00 12:00 2.00 5,413 6,862 INTRM1 CASING RNCS P Continue to run 7-5/8"29.7 ppf L-80
BTC-mod casing f/joint#130(depth
5413')to jt#164(depth 6862').. Fill
each joint,top off every 10th joint.
Obtain PU&SO wt's every 10 joints.
Calculated displacement 73.1 bbls,
actual 70.3 bbls.
Page 15 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
12:00 12:15 0.25 6,862 6,902 INTRM1 CASING RNCS P Make up FMC hanger with landing
joint. Run in the hole f/6862'to land
on hanger @ 6902'. PU wt 228k, SO
146k.
12:15 12:30 0.25 6,902 6,902 INTRM1 CEMEN-RURD P Rig down Frank's fillup tool. Rig up
Dowell cement head and 2"hose.
12:30 14:15 1.75 6,902 6,902 INTRM1 CEMEN"CIRC P Break circulation @ initial rate of 2
bpm w/315 psi-32%Totco flow out.
Reciprocate pipe f/6902'to 6890'.
(12'stroke). 3.7 bpm w/420 psi-38%
Totco flow out. Stage up to 7 bpm w/
800 psi.Circulate and condition mud
f/cement job. Final MW 10.6 ppg,
PV/YP= 12/20.
14:15 15:00 0.75 6,902 6,902 INTRM1 CEMEN"CIRC P Pre job safety meeting on cement
job.Continue to circulate while
Dowell batches up and primes up f/
job.
15:00 15:15 0.25 6,902 6,902 INTRM1 CEMEN'PRTS P Dowell pump 10 bbls CW100,then
pressure test to 4000 psi-good.
15:15 16:00 0.75 6,902 6,902 INTRM1 CEMEN"CMNT P Dowell continue to pump 28.57 more
bbls of CW100(8.6 ppg)(Total of
38.57 bbls)@ 4.9 bpm w/475 psi, I'1
follow w/42.62 bbls of MudPush II
(11.5 ppg)@ 4bpm w/485 psi,drop
bottom plug,follow w/109.26 bbls of
15.8 ppg class"G"cement(yield
1.16 cu ft/sx, 5.092 gal/sx water,
total of 532 sx)@ 5.7 bpm w/935
psi,drop top plug.
16:00 17:00 1.00 6,902 6,902 INTRM1 CEMEN"DISP P Dowell kick out plug w/10 bbls of
water,the rig displace w/302.4bbls
of 10.6 ppg mud. Rig pumping @ 7
bpm, slowed to 5 bpm w/400 to 980
psi for the last 50 bbls,then slowed
to 3 bpm for final 10 bbls w/863 psi
prior to bumping plug, increased
pressure to 1450 psi, held f/5
minutes. Bleed off pressure,checked
floats-good.CIP 1655 hrs
11/17/2011.
17:00 18:30 1.50 6,902 6,902 INTRM1 CEMEN"RURD P Rig down Dowell cement head,
casing equipment, backout and lay
down landing joint,change bales to
drilling shorter bales.
18:30 19:15 0.75 0 0 INTRM1 WHDBO OTHR P Using a stand of 5"HWDP, install
FMC 7-5/8"packoff. Run in lock
down screws,torque to 450 ft lbs.
19:15 19:30 0.25 0 0 INTRM1 WHDBO PRTS P Test 7-5/8"FMC packoff to 5000 psi
f/10 minutes-good.Witness by rig
supervisor.
Packoff assembly 12-150-017C, HN
-F3006, SN: 1711800204.
Page 16 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
19:30 20:45 1.25 0 0 INTRM1 WHDBO PULD P Lay down crossover subs, lay down
lower test plug and wear bushing,
Pick up upper test plug and wear
bushing.Sim Ops: rigging up in the
cellar for LOT and freeze protection,
loading 225 joints of 4"drill pipe in
the pipe shed.
20:45 21:00 0.25 0 0 INTRM1 WHDBO SFTY P Pre job safety meeting on rigging up
to test and changing upper pipe
rams.
21:00 21:45 0.75 0 0 INTRM1 WHDBO NUND P Make up test plug to the 4"test joint,
install test plug. Change upper pipe
rams f/7-5/8"to 3-12"x 6"VBR's in
the top pipe rams.
21:45 22:00 0.25 0 0 INTRM1 DRILL LOT P Perform LOT on the 10-3/4"x 7-5/8"
annulus with rig pump(approx 5 hrs
after cement in place). Using 8.5 ppg
seawater. LOT 17.1 ppg w/10.43
MWE in annulus and broke over w/ '/
1220 psi=17.1 EMW at the casing L K-,
shoe. Pumped a total of 7.47 bbls, Of
r
3.84 bbls after breaking over. Final
pressure after 10 minutes was 640
psi. Plot annular injectivity report.
SIM Ops:changing rams, loading
pipe in the pipe shed.
22:00 23:15 1.25 0 0 INTRM1 DRILL FRZP P Rig pumping seawater @ 3 bpm,
final pressure 1050 psi.Sim Ops:
Loading pipe in the shed.
23:15 00:00 0.75 0 0 INTRM1 DRILL FRZP P Shut in OA,bleed off presure,blow
down cement line. Rig up Little Red
to pump 160 bbls of diesel,enough
to fill the 10-3/4"x 7-5/8"annulus to
the 10-3/4"shoe @ 3977.4'(3990'
TVD).
11/17/2011
Freeze protect OA W/160 BBLS diesel. Slip and cut drill line. C/O Upper Rams to 3-1/2"x 6",Test upper
pipe w/4"and test upper, lower and annular w/4-1/2".Change saver sub on top drive to XT-39,change bell
guide, LID 5"Drill pipe, PU/MU/RIH w/10 stands of 4"and 2 stands of 4"HWDP, POOH, PJSM, PU/MU/RIH
w/BHA to 79', upload Sperry Sun MWD.
00:00 00:30 0.50 0 0 INTRM1 DRILL FRZP P R/U to freeze protect OA with Hot
Oil.Test Lines to 2500 PSI, Good.
00:30 02:00 1.50 0 0 INTRM1 DRILL FRZP P Little Red freeze protected with 160
barrels of diesel down the OA. Final
circulating pressure=1400 PSI @
2bpm. (Charted.)SIMOPS slip and
cut drilling line.Strap 4"drill pipe.
02:00 02:30 0.50 0 0 INTRM1 DRILL SLPC P Rig down Hot Oil. Finish up slip and
cut drilling line.
02:30 04:00 1.50 0 0 INTRM1 DRILL BOPE P PJSM, R/U BOP test equipment,
Test 31/2"x 6"variable top rams with
4"test joint to 250 PSI low 3500 PSI
high, change out to 4'/2'test joint,
test annular preventer to 250 PSI low
2500 PSI high,and the top and
bottom variable rams to 250 PSI low
3500 PSI high. (Charted).
Page 17 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
04:00 04:30 0.50 0 0 INTRM1 DRILL BOPE P Rig down test equipment, install
FMC 7"ID wear ring.
04:30 07:30 3.00 0 0 INTRM1 DRILL RURD P PJSM,Change out saver sub from
4%"IF to 4"XT39, change bell guide
&grabbers.
07:30 07:45 0.25 0 0 INTRM1 DRILL RURD P Mobilize thread protectors, mouse
hole to rig floor.
07:45 12:00 4.25 0 0 INTRM1 DRILL PULD P PJSM, lay down 4 stands of 5"
HWDP,75 stands of 5"DP using the
mouse hole.
12:00 15:00 3.00 0 0 INTRM1 DRILL PULD P PJSM,lay down 5"DP using the
mouse hole.
15:00 16:15 1.25 0 0 INTRM1 DRILL RURD P Clear rig floor, rig down 5"handling
equipment, pick up 4"handling
equipment and subs for BHA.
16:15 16:30 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on picking up
4"drill pipe.
16:30 18:00 1.50 0 1,125 INTRM1 DRILL PULD P Pick up/make up/run in the hole w/
30 joints of 4"drill pipe and 5 joints
of 4"HWDP, PU/MU jars.
18:00 18:30 0.50 1,125 0 INTRM1 DRILL TRIP P Trip out/stand back 2 stands of 4"
HWDP and 10 stands of 4"drill pipe
18:30 19:30 1.00 0 0 INTRM1 DRILL OTHR P Clear and clean floor. Dress dog
collar clamp f/4-3/4"tools.
19:30 19:45 0.25 0 0 INTRM1 DRILL SFTY P Pre job safety meeting on picking up
BHA.
19:45 22:45 3.00 0 79 INTRM1 DRILL PULD P Change out elevators f/4"to 3.5".
Make up BHA, change elevators
back to 4". Pickup a single and
make a top drive connection(148'
made up, 79'in the hole).
22:45 00:00 1.25 79 79 INTRM1 DRILL PULD P Upload Sperry Sun MWD @ 79'.
11/18/2011
Upload Sperry Sun MWD, pulse test-ok, PJSM, load nuke sources, continue to MU BHA,single in the hole
w/BHA on 4"drill pipe to 6497', RIH to 6780', CBU,test casing,tag cement,drill shoe track+20'new to
6922',circ, perform FIT to 18 ppg,drill 6-3/4"hole to 7065'(6037'TVD).
00:00 00:15 0.25 79 79 INTRM1 DRILL PULD P Upload Sperry Sun MWD @ 79'.
00:15 00:30 0.25 79 79 INTRM1 DRILL DHEQ P Pulse test MWD-ok. Pumping 225
gpm w/1150 psi.
00:30 01:30 1.00 79 95 INTRM1 DRILL PULD P Lay down a single of 4"dp, blow
down the top drive.Work BHA f/79'
to 95'(picked up a 4-3/4"flex collar.
Positon for installation of nuke
sources.
01:30 01:45 0.25 95 95 INTRM1 DRILL SFTY P Pre job safety meeting on loading
nuke sources.
01:45 02:00 0.25 95 392 INTRM1 DRILL PULD P Load sources, continue to work BHA
f/95'to 392'.
02:00 07:15 5.25 392 6,495 INTRM1 DRILL PULD P Single in the hole w/4"XT-39 drill
pipe f/392'to 6495'. Rabbit pipe as
picked up. Fill pipe every 20 stands.
07:15 07:30 0.25 6,495 6,685 INTRM1 DRILL TRIP P Run 4 stands f/derrick f/6495'to
6780'.
Page 18 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
07:30 08:30 1.00 6,685 6,780 INTRM1 DRILL CIRC P Make a top drive connection.Wash
down f/6685'to 6780'.Circulate and
recip f/6780'to 6685'. Pumping 148
gpm w/1025 psi. Rotate 50 rpm w/
7,000 ft lbs of torque.
08:30 08:45 0.25 6,780 6,780 INTRM1 DRILL RURD P Blow down the top drive. Rig up to
test casing to 3000 psi f/30 minutes.
08:45 09:45 1.00 6,780 6,780 INTRM1 DRILL PRTS P Test casing to 3000 psi f/30
minutes.Chart test.
09:45 10:00 0.25 6,780 6,780 INTRM1 DRILL RURD P Rig down testing equipment.
10:00 12:00 2.00 6,902 6,902 INTRM1 DRILL DRLG P Make a connection,wash down f/
6780'to tag cement @ 6795'. Drill
cement,wiper plugs,float collar @
6803',and cement to 6902'. Displace
well to 11.5 PPG from 10.5 PPG
12:00 12:30 0.50 6,902 6,902 INTRM1 DRILL DRLG P Continue to drill out shoe.
12:30 13:00 0.50 6,902 6,922 INTRM1 DRILL DDRL P Drill 20 feet of new hole from 6902'
MD to 6922'MD. 5.5 BPM, 55 SPM,
1950 PSI, 50 RPM.7k TQ
13:00 13:45 0.75 6,922 6,922 INTRM1 DRILL CIRC P CBU @ 65 SPM,2275 PSI, Rotate
@ 50 RPM
13:45 14:00 0.25 6,922 6,922 INTRM1 DRILL LOT P Rack back one stand, blow down top
drive. Rig up to perform FIT.
14:00 14:30 0.50 6,922 6,922 INTRM1 DRILL LOT P Prejob on LOT
14:30 15:30 1.00 6,922 6,922 INTRM1 DRILL LOT P Perform FIT @ 6922'MD.(5947'
TVD).W/11.5 PPG MW. Pressure
up to 1997 PSI.Pump 2.2 BBLS
away.Achievel8 PPG EMW. No leak
off.Shut in&record 30 sec
pressures. Bleed back 1.5 BBLS in
10 mins.
15:30 21:00 5.50 6,922 7,038 PROD1 DRILL DDRL P Established drilling parameters,275
GPM, 90 RPM, 5k WOB,2250 PSI,
P/U 143k, S/O 94K, Rot 112K,TQ
on BTM,6K,TQ off BTM 4K. Drill
from 6922'to 7038'. Bit hrs 1.96-
actual rotating hrs 1.08,actual
sliding hrs.88 hrs.Jar hours 1.96.
Drill 10 feet into Kuparuk'A'Sand.
Flow check. Static.
21:00 21:45 0.75 7,038 7,038 PROD1 DRILL CIRC P Circulate bottoms up to confirm sand
in cuttings samples.Verify sand.
21:45 00:00 2.25 7,038 7,065 PROD1 DRILL DDRL P Directional drill 6-3/4"hole f/7038'to
7065'(6037'TVD). Bit hours 2.38-
Actual rotating hrs.86,actual sliding
hrs 1.52. Pumping 273 gpm w/2375
psi, rotating 90 rpm w/6-7k ft lbs of
torque on bottom,6k off bottom.
WOB 5k. PU wt 146k, SO wt 93k,
Rot wt 113k.
Total hrs on bit 4.34,Total jar hours
4.34.
Note: Max total gas of 1282 units f/
6930'.
Page 19 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
11/19/2011 24 hr Summary
Drilled from 7065'MD to 7300'MD. CBU 3 x's,Weight up mud system from 11.5 PPG to 11.7 PPG. Short trip.
Weight up from 11.7 PPG to 12.0 PPG.Well static.TOOH. L/D BHA.
00:00 01:30 1.50 7,065 7,153 PROD1 DRILL DDRL P PJSM, DRLG, From 7065 MD to
7153'MD. (6100'TVD). 90 RPM,275
GPM,2400 PSI,7K WOB.
01:30 02:30 1.00 7,153 7,153 PROD1 DRILL CIRC P Precautionary. CBU in Kuparuk
basal sand Al.260 GPM,50 RPM,
2200 PSI off btm, 35%flow. Max gas
329 units.Well static with 11.5 PPG
mud.
02:30 06:00 3.50 7,153 7,240 PROD1 DRILL DDRL P DRLG from 7153'to 7240'MD. (6165'
TVD),W/263 GPM,90 RPM,7K,
WOB.ART=2.16,AST=1.65,
ADT=3.81,Total Jar Hrs.=9.41, Bit
Hrs=9.41, P/U WT=150K, S/O
WT=94K, ROT WT=119K,TQ
On=7K,OFF=7K, ECD=12.33 PPG,
06:00 07:45 1.75 7,240 7,300 PROD1 DRILL DDRL P DRLG From 7240'MD to 7300'MD. ✓
(6205 TVD),W/265 GPM,90 RPM,
7K WOB,ART=1.15,AST=0,
ADT=1.15,Total Jar HRS=10.56, Bit
HRS=10.56, P/U WT=150K,S/O
WT=94K, ROT WT=119K.
ECD=12.26 PPG, Max Gas=680
07:45 10:00 2.25 7,300 7,300 PROD1 DRILL CIRC P CBU 3x's, Rack back a stand every
BU.65 SPM,275 GPM,60 RPM,
2450 PSI,WT up the mud system
from 11.5 PPG to 11.7 PPG.Trip
Margin.
10:00 10:15 0.25 7,300 7,300 PROD1 DRILL OWFF P Monitor well,Static.
10:15 10:45 0.50 7,300 7,300 PROD1 DRILL TRIP P Short trip 6 stands.Trip back to
bottom.Wash and ream the last 50
feet.Act Fill=4.8 BBLS,Calc.
Fill=3.1 BBLS.
10:45 12:00 1.25 7,300 7,300 PROD1 DRILL CIRC P CBU.Saw 892 units. Decision made
to weight up to 12.0 PPG from 11.7
PPG.Gas migration seen after the
short trip.
12:00 12:45 0.75 7,300 7,300 PROD1 DRILL CIRC P Continue to weight up. Crew change.
SPR's#1 @ 20 SPM=490 PSI,30
SPM=780 PSI.#2 @ 20 SPM=500
PSI, 30 SPM=780 PSI.7300'MD,
6205'TVD.
12:45 13:45 1.00 7,300 7,300 PROD1 DRILL CIRC P Reduced pump rate to 250 GPM, =
2150 PSI. ECD=12.62 PPG.
Continue to bring 12.0 PPG surface
to surface.
13:45 15:15 1.50 7,300 6,873 PROD1 DRILL CIRC P Monitor well. Static. Pump out to
6873'MD.200 GPM, 1600 PSI.
15:15 15:45 0.50 6,873 6,873 PROD1 DRILL OWFF P Pull inside casing one stand. Blow
down top drive. Monitor well. Static.
15:45 16:45 1.00 6,873 6,400 PROD1 DRILL CIRC P P/U one stand to shoe. Drop 2.20"
hollow rabbit w/100'wire-69 stands
of 4"drill pipe. Pump out to 6400'
MD.W/200 GPM.
Page 20 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
16:45 17:00 0.25 6,400 6,400 PROD1 DRILL OWFF P Monitor well. Static. Pump dry job.
20 BBL. One LB.over.
17:00 20:30 3.50 6,400 392 PROD1 DRILL TRIP P Blow down the top drive. Line up on
the trip tank.. Pull out of the hole f/
6400'to BHA @ 392'.
20:30 21:30 1.00 392 148 PROD1 DRILL PULD P Lay down BHA f/392'to 148'.
21:30 21:45 0.25 148 148 PROD1 DRILL SFTY P Pre job safety meeting on sources.
21:45 22:15 0.50 148 148 PROD1 DRILL PULD P Remove nuke sources.
22:15 23:30 1.25 148 69 PROD1 DRILL PULD P Lay down BHA to 69'. Download
_MWD tools.
23:30 00:00 0.50 69 30 PROD1 DRILL PULD P Continue to lay down BHA.
11/20/2011
UD BHA. M/U and run 4%"Liner RIH on DP. Cement liner @ 7300',set Baker double grip Flex-lock 7-5/8"
liner hanger,set 7-5/8"ZXP packer, circ BU x2, rig down cementing head and lines.
00:00 00:30 0.50 30 0 PROD1 DRILL PULD P Continue to lay down BHA.
00:30 01:00 0.50 0 0 PROD1 DRILL RURD P Clean and clear rig floor.
01:00 02:00 1.00 0 0 COMPZ CASING RUNL P Begin 4'/2"Liner JOB.M/U pups to
Baker cement head.M/U 4"XT-39 x
4'/z"IBT floor valve.
02:00 02:30 0.50 0 0 COMPZ CASING RUNL P R/U to run 4%"12.6 ppf L-80 IBT-m
Liner.
02:30 04:00 1.50 0 128 COMPZ CASING RUNL P PJSM, Pick up/MU 4 joints-shoe
track. Baker locked connections to
pin of 4th joint-collar of 4th joint is
the last baker lock.Rig up to test
float equipment,test with rig pump.
Circulate 20 bbls:2 bpm w/65 psi,3
bpm w/100 psi,4 bpm w/165 psi.
Rig down equipment.
04:00 05:00 1.00 128 728 COMPZ CASING RUNL P Trip in hole, make up 4'/z'IBT-M
12.6#L-80 liner as per Baker Rep.
Volant 4-1/2"x 6-1/8"centralizers
installed on jt's#1 thru#15,except
jt#3.Average MU torque
05:00 06:45 1.75 728 728 COMPZ CASING RUNL P Make up Baker ZXP packer. Mix up
the Pal-Mix(ground up carnuba
beans), Pour mixture into top of the
Packer.Secure dust cap. Let set f/
30 minutes.
06:45 12:00 5.25 728 4,956 COMPZ CASING RUNL P Trip in the hole W/the Liner on 4"
DP. From 728'MD to 4956'MD.
Filling DP on the fly and topping off
every 5 stands.Actual
displacement=26.75 BBLS.
Calculated displacement=27.5 BBLS
12:00 14:15 2.25 4,956 6,878 COMPZ CASING RUNL P Continue to trip in the hole with the
liner on drill pipe.
Page 21 of 29
Time Logs
Date From To Dur S. Death E. Death Phase Code Subcode T Comment
14:15 16:15 2.00 6,878 6,878 COMPZ CASING CIRC P Kelly up on stand#66.Trip in hole to
6878'MD. Start to CBU @ 135
GPM. Stage up to 4.5 BPM.680
PSI. 38% Flow. P/U WT=133k. S/O
WT=88K.The gas in the mud
increased to 2460 Units. From a
back ground of 120 Units. Reduced
pump rate to 3.5 BPM.480 PSI.
Continue to circulate. Run degasser
until gas decreased to 575 Units.
Shut down. Monitor well.Static.
Perform.
SPR's. @ 6891'MD(5947'TVD).
MW=12.0 PPG.#1 @ 20 SPM=320
PSI. 30 SPM=440 PSI.#2 @ 20
SPM=330 PSI.30 SPM=450 PSI.
16:15 18:00 1.75 6,878 7,300 COMPZ CASING RUNL P Continue to Trip in the hole.4 stands
to bottom.Wash down the last
single.Tag on depth. Establish
parameters 3 BPM=500PSI. Stage
up the pump to 6 BPM=1000 PSI.
Circulate, reciprocate,condition
mud.Circulated 434 bbls.
18:00 18:30 0.50 7,300 7,300 COMPZ CEMEN-CIRC P Shut down pumps. Blow down top
drive. Rig up Baker cement head.
Pump 3 BPM=500 PSI,Tag @
7300'MD. Set down 10k, P/U 5"and
tag on bottom again.Confirm bottom.
Pick up 2 feet off bottom to
determine setting position.
18:30 20:00 1.50 7,300 7,300 COMPZ CEMEN'CIRC P Continue to circulate and reciprocate
while waitng for crew change of
Dowell and ASRC crews. Stage
pumps f/3 bpm to 5.5 bpm w/1050
psi.
20:00 20:30 0.50 7,300 7,300 COMPZ CEMEN'SFTY P Pre job meeting for the cement job,
while continuing to circulate and
recip pipe. Pumping 5.3 bpm w/1050
psi.
20:30 21:15 0.75 7,300 7,300 COMPZ CEMEN'CIRC P Continue to circulate @ 5.3 bpm w/
1050 psi and reciprocate(7-8'stroke)
while Dowell batching up cement.
Shut down.
21:15 22:00 0.75 7,300 7,300 COMPZ CEMEN-CMNT P Dowell pump 5 bbls of MudPush
(14.5 ppg)@ 2bpm w/350-400 psi,
shut down,test lines to 4500 psi-ok,
follow w/15 more bbls of MudPush
for a total of 20.4 bbls,follow w/28 7,
bbls class"G"cement( 15 96 ppg) .
w/additives(yield 1.17 cuft/sx) d"
(water 5.208 gal/sx)pumping 3.5
bpm w/350 to 200 psi,shut down,
flush lines of cement at the rig floor.
Reciprocating pipe 7-8'stroke. PU wt
137k, SO wt 88k.
Page 22 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
22:00 22:15 0.25 7,300 7,300 COMPZ CEMEN'DISP P Kick wiper plug out of Baker cement
head,then displace w/12 ppg mud,
pumping @ 5 bpm w/109 to 846 psi.
After pumping 65 bbls,slowed down
to 3 bpm w/558 psi, continued
displacement @ 3 bpm with 780 psi
prior to bumping plug with 80.5 bbls
pumped.
Note: Noticed picking up wiper plug
at the top of liner w/70.6 bbls
pumped w/increase of pressure to
1660 psi. CIP @ 2214 hrs
11/20/2011.
22:15 22:45 0.50 7,300 7,300 COMPZ CEMEN-PACK P Dowell increase pressure to 2600 psi
, slack off to 50k, PU, increase
pressure to 2800 psi,slack off again
w/shoe 1-1/2'off bottom of hole.
Dowell increase pressure to 4000 psi
to release HRD running tool,then
bled down to 0 psi,check floats-ok.
Pick up 4'to get dogs out of top of
liner,pick up another 5', rotate 20
rpm w/5k ft lbs of torque.Slack off
while rotating to apply weight to top
of packer. Set down 50k twice to set
ZXP packer. Picked up to 125k on
weight indicator.Applied 1000 psi,
then continued to pull up hole w/
tools, once pressure fell off,
increased pumps to 8.5 bpm while
continuing to pull tools to the top of
the liner.
22:45 23:30 0.75 7,300 7,300 COMPZ CEMEN-CIRC P Continue to circulate @ 8.5 bpm w/
1600 psi initial-1390 psi final,to
clear MudPush(14.5 ppg)and
excess cement(15.8 ppg)from the
hole.
Note: No clear indications of cement
in the mud returns while pumping @
8.5 bpm. Some indications of Mud
push(PH increase f/10.5 to 11.4)
while circulating bottom's up placed
the mud push @ 5392'in the hole.
Calculated would have been 5724'
using 30%excess open hole
volume(332'or 10.1 bbls early).
Another indication of change @ 1850
strokes pumped,which is 7.1 bbls
early f/calculated top of cement.
23:30 00:00 0.50 7,300 7,300 COMPZ DRILL RURD P Shut down. Pick up a single. Rig
down Baker cement head and lines.
11/21/2011
Set and test Packer to 1000 PSI. POOH W/running tool. M/U negative test Baker Packer. RIH. Set Packer
@ 6578'MD. Pump 75 BBLS 8.6 PPG sea water.Set Packer, open tubing. No returns. Good test. CBU.
POOH W/Packer.Test Upper VBR's w/3Y2'test joint,and annular w/same. R/U and run 3%"completion
string to 3226'.
00:00 00:15 0.25 7,300 7,300 COMPZ DRILL PACK P PJSM, Rig up to test Baker HRD
"ZXP"Packer.
Page 23 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
00:15 00:30 0.25 7,300 6,582 COMPZ DRILL PRTS P Test Packer to 1000 PSI.Charted
00:30 00:45 0.25 6,582 6,582 COMPZ DRILL RURD P Rig down test equipment. Pick up
instring single.
00:45 03:15 2.50 6,582 0 COMPZ DRILL TRIP P PJSM,Trip out of the hole with
packer running tool.Actual fill=39.25
BBLS,Calculated fill=37.8 BBLS
03:15 03:30 0.25 0 0 COMPZ DRILL RURD P Clean and clear rig floor
03:30 04:00 0.50 0 0 COMPZ RIGMNT SVRG P Service the rig.
04:00 04:30 0.50 0 15 COMPZ DRILL PULD P PJSM on running negative pressure
test Packer. Make up Packer.
04:30 08:45 4.25 15 6,587 COMPZ DRILL TRIP P Trip to setting depth of 6578'MD with
Packer.Tagged top of liner.Actual
displacement=38.25 BBLS,
Calculated displacement=37.8 BBLS
08:45 09:30 0.75 6,587 6,587 COMPZ DRILL CIRC P Make up TIW valve to top of DP.
Pump 75 BBLS of 8.6 PPG brine,
ICP @ 20 SPM=375 PSI, FCP @
20 SPM=1120 PSI.
09:30 10:00 0.50 6,587 6,587 COMPZ DRILL PRTS P Close in TIW,set 25k down weight
on Packer, set,test by opening TIW
valve. No returns.good test.
10:00 11:00 1.00 6,587 6,587 COMPZ DRILL PRTS P Rig up to allow U tube. Unseat
Packer. Begin U tubing, keep
annulus full with trip tank.
11:00 12:00 1.00 6,587 6,587 COMPZ DRILL CIRC P Pump dry job. Hole out of balance.
CBU @ 4 BPM.
12:00 12:45 0.75 6,587 6,587 COMPZ DRILL CIRC P Continue to CBU @ 4 BPM
12:45 13:15 0.50 6,587 6,587 COMPZ DRILL CIRC P Pump 15 BBL dry job. 13.5 PPG.
Blow down top drive, line up on trip
tank.
13:15 15:00 1.75 6,587 0 COMPZ DRILL TRIP P Trip out of the hole from 6587'to
surface. Lay down retreive-a-matic,
Baker Packer.
15:00 15:15 0.25 0 0 COMPZ DRILL PULD P Clean and clear rig floor.
15:15 15:45 0.50 0 0 COMPZ WHDBO BOPE P Drain stack,pull wear bushing.
15:45 16:15 0.50 0 0 COMPZ WHDBO BOPE P Rig up to test upper VBR's and
annular with 3'W'test joint.
16:15 17:00 0.75 0 0 COMPZ WHDBO BOPE P Test BOP equipment.250 PSI low,
3500 PSI high for pipe ram.250 PSI
low,2500 PSI high for annular
preventer.Charted.
17:00 17:30 0.50 0 0 COMPZ WHDBO RURD P Rig down test equipment.
17:30 18:30 1.00 0 0 COMPZ RPCOM PULD P Pick up casing tools and rig up
casing equipment
18:30 18:45 0.25 0 0 COMPZ RPCOM RCST P Pre Job safety meeting. Hazard
discussion on running tubing.
18:45 20:00 1.25 0 80 COMPZ RPCOM RCST P Pick up Baker Seal Assembly. Run
in the hole with 1st joint.Attempt to
make up X nipple,appeared galled.
Backed out and replaced 1st joint
with joint#218 from talley. Switched
out the pup joint below the X nipple.
Tally stayed the same. Drifted all
tools with 2.88"drift.
Page 24 of 29
r Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
11/21/2011 24 hr Summary
Set and test Packer to 1000 PSI. POOH W/running tool. M/U negative test Baker Packer. RIH. Set Packer
@ 6578'MD. Pump 75 BBLS 8.6 PPG sea water. Set Packer,open tubing. No returns.Good test.CBU.
POOH W/Packer.Test Upper VBR's w/3%"test joint,and annular w/same. R/U and run 3%"completion
string to 3226'.
20:00 00:00 4.00 80 3,226 COMPZ RPCOM RCST P Continue to run in the hole with 3%"
tubing string to 3226'.#1 GLM/DCK2
SOV after Jt.#2,#2 GLM,after Jt.
#18,#3 GLM after Jt.#43,#4 GLM
after Jt.#73. 98 joints in the hole at
crew change.
11/22/2011
Trip in with the 3%/z'EUE 8R tubing and GLM's. SSSV failed on surface.TIH W/O SSSV to space out.Tag up
with mule shoe, 17'from fully located. Unable to land. Circ BU. POOH.Stand back tubing. Inspect Baker seal
assembly and collar of pup jt on the seal assembly. Remove pup jt on seal assembly, install a joint on top of
seal assembly,change collar on the joint to a special clearance 4.19"OD, install pup on top of single. Run
tubing in the hole, installing GLM's per plan to 1633'.
00:00 01:00 1.00 3,226 4,726 COMPZ RPCOM RCST P Continue to run 3'/z'EUE 8R From
3226'to 4726'.(Jt.#145).Actual
displacement=21.5 BBLS.
Calculated displacement=21.7
BBLS. Prepare to pick up
SLB/Camco SSSV.
01:00 01:30 0.50 4,726 4,726 COMPZ RPCOM RCST P Mobilize 4'/i'handling tools.Control
equipment for Camco from beaver
slide.
01:30 02:45 1.25 4,726 4,726 COMPZ RPCOM RCST P Rig up control line and
TRMAXX-C MT-5-S R-SCSSV.
02:45 03:00 0.25 4,726 4,726 COMPZ RPCOM RCST P Test control line(for SCSSV),
plugged up with ice.
03:00 03:30 0.50 4,726 4,726 COMPZ RPCOM RCST P Thaw out control line with steam.
03:30 07:15 3.75 4,726 4,726 COMPZ RPCOM RCST T Decision made to purge control line
with aviation oil to insure line is clear.
Wait on aviation oil.The wellbore
began to flow out the tubing
indicating the mud was out of
balance, and that the SCSSV was
not holding. Decision made to
change out for an operating down
hole valve.Ordered a new tool from
Deadhorse. Prepared to TIH with the
remaining tubing to space out.
07:15 08:30 1.25 4,726 6,598 COMPZ RPCOM RCST T Trip in to joint#202. Pick up
203/204/205/206 to space out.
08:30 11:30 3.00 6,598 6,623 COMPZ RPCOM RCST T Space out process. Pump 1 BBL,
300 PSI, 11%Flow,tag up @
6623.62'.Observed pressure
increase.Shut down pump and
worked the string, %4 turns to try and
get further down. Put a full round in
and tried to go down. No Go. Set
down 5K, 10k, 15k,20k several
times. No go. Set 20k down,
pressure up to 1000 PSI, bleed off,
No go. P/U=88k,5/0=65k.
11:30 12:00 0.50 6,623 6,623 COMPZ RPCOM CIRC T Circulate @ 2 BPM.400 PSI.Wait
on orders.
Page 25 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
12:00 12:30 0.50 6,623 6,623 COMPZ RPCOM CIRC T Circulate @ 6 BPM. 1086 PSI. One
full BU with the higher rate.
12:30 12:45 0.25 6,623 6,623 COMPZ RPCOM TRIP T PJSM rack back tubing in the
derrick.
12:45 20:45 8.00 6,623 0 COMPZ RPCOM TRIP T UD 2 singles in pipe shed.Jts.206,
205. Pump dry job. Begin trip.
Replace all seals from broken
connections. Lay down GLM's.Verify
running order. Flagged GLM position
in tubing string for all downhole
equipment.
20:45 21:30 0.75 0 0 COMPZ RPCOM TRIP T Switch position of joint#1 and 1st
pup joint in talley. Put'special
clearance coupling'(4.19"OD)on
joint#1. Place pup on top.Saw
beveling wear on leading edge of pup
collar(bottom of collar).Verify the
reason for not being able to land
out.Take pictures of seals, pup
collar, inspect the seals,all looked
good. Prepare to head back in the
hole.
21:30 22:00 0.50 0 80 COMPZ RPCOM RCST T Lower Baker GBH-22 seal assembly
in the hole and removed 6.12'pup jt.
P/U#1 Jt.w/special clearance
coupling', made that up to seal
assembly, P/U pup Jt.,to X nipple,
Jt.#2,GLM#1, and Jt.#3.
22:00 00:00 2.00 80 1,633 COMPZ RPCOM RCST T Trip in the hole coming out of the
derrick with the 3%"9.3#EUE-M
L-80. MU GLM's per plan,con't
running 3-1/2"9.3 ppf L-80 EUE-m
tubing to 1633'@ midnight.
11/23/2011
TIH W/3%'tubing. Land. Space out. POOH to Pick up SCSSV and control line.TIH.Change out fluid
systems from kill weight mud to 8.6 PPG brine. Land hanger.Test tubing to 3500 PSI,test annulus to 3500
PSI. Shear out DCK2 valve. Install 2 way check. ND BOP.Terminate control line.
00:00 02:15 2.25 1,633 6,623 COMPZ RPCOM RCST T Continue to RIH from derrick. From
1633'to 6623'. Pick up 2 joints from
pipeshed.Actual
displacement=21.25 BBLS,
_calculated displacement=22.4 BBLS
02:15 03:15 1.00 6,623 6,623 COMPZ RPCOM PRTS P Sting into top of liner to verify space
out.Test Seals to 1000 PSI. Good.
03:15 05:45 2.50 6,623 4,723 COMPZ RPCOM PULD P Lay down 5 jts. of tubing. POOH 19
stands to place the SCSSV in string.
_Act.fill=7 BBLS,Calc.fill=6.4 BBLS
05:45 06:15 0.50 4,723 4,723 COMPZ RPCOM PULD P Clean and clear rig floor.
06:15 07:00 0.75 4,723 4,723 COMPZ RPCOM PULD P Rig up Camco control line. Pick up
TRMAXX-CMT-5-S R-SCSSV.
07:00 09:45 2.75 4,723 6,623 COMPZ RPCOM TRIP P Trip in the hole out of the derrick to
land. P/U 63 S.S. bands.Act.
displ=5.5 BBLS, Calc. displ=6.4
BBLS.
Page 26 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
09:45 10:45 1.00 6,623 6,623 COMPZ RPCOM PULD P Lay down joint#202 and pick up joint
#206, and an 8.19'pup for space
out.XO,2-4'% 12.6#L-80 IBT-M
joints,to the tubing hanger with 2.27'
pup.
10:45 11:30 0.75 6,623 6,623 COMPZ RPCOM PULD P Change out short bails to long bails,
SIMOPS flush both pumps.
11:30 12:00 0.50 6,623 6,623 COMPZ RPCOM RURD P Rig up to displace well over to 8.6
PPG inhibited brine from 12 PPG kill
weight mud.
12:00 12:15 0.25 6,623 6,623 COMPZ RPCOM SFTY P Crew change. PJSM.Mud
displacement.
12:15 15:00 2.75 6,623 6,623 COMPZ RPCOM CIRC P Displace well with pump#1. Stage
pump up to 5 BPM=1250 PSI.
Increased to 1500 PSI W/brine at
the shoe, FCP=500 PSI. Pump
schedule: 30 BBLS Safe surf W/
290 BBLS Clean brine/252 BBLS
8.6 PPG inhibited brine/58 BBLS
Clean 8.6 PPG brine. Pumped 630
barrels,630 barrels returned to the
pits.
15:00 17:30 2.50 6,623 6,623 COMPZ RPCOM RCST P Make up feed through for SCSSV
control line. Sting back into SBE,
land tubing hanger with landing joint.
Run in lock down screws.
17:30 20:30 3.00 6,623 6,623 COMPZ RPCOM RCST P Pressure up the tubing to 3500 PSI
30 mins. Charted. Bleed down to
2200 PSI. Pressure test IA to 3500
PSI for 30 mins.Gharted. Bleed down
tubing to zero,shear out DCK2 valve.
Saw positive dump. Bleed both sides
to zero. Pull and lay down the tubing
landing joint. Install 2 way check.
Test 2 way check from below to 3750
PSI(11.5 PPG EMW). Charted for 5
mins.good
20:30 00:00 3.50 6,623 6,623 COMPZ WHDBO NUND P PJSM. Nipple down BOPE. Remove
riser.Terminate the CAMCO control
line,to lift the stack. Set stack on
stump.Connect control line through
the tubing spool.
11/24/2011
Nipple down BOPE, Nipple up production tree,test hanger seals 500 PSI low 5000 PSI high.Test tree to 250
PSI low 5000 PSI high. Pull 2 way check. SIMOPS. Lay down DP,clean pits,freeze protect with 92 barrels
diesel. Let fluids U tube. Run BPV with lubricator.Secure well head.Connect all lines. Record
pressures:Tubing=0/OA=100/IA=0. Continue to lay down all the drill pipe and clean and prepare the rig for
move.While waiting on 3G-22 wellsite prep work to be completed:Work on top drive-maintenance.
00:00 00:45 0.75 0 0 COMPZ WHDBO SSSV P PJSM,Continue to hook up control
line to tubing spool.SIMOPS clear
CAMCO and Casing tools off the rig
floor.Test SCSSV control line to
5500 PSI. Good.
00:45 01:30 0.75 0 0 COMPZ WHDBO NUND P Nipple up tree adapter and install as
per FMC Rep.
Page 27 of 29
Time Logs
Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment
01:30 02:30 1.00 0 0 COMPZ WHDBO NUND P Nipple up production tree.Verify
orientation w/DSO Nate.SIMOPS:
Change out long bails back to short
bails and 4"elevators, Rig up to
freeze protect.
02:30 03:00 0.50 0 0 COMPZ WHDBO PRTS P Test hanger neck seals 500 PSI low
/5000 PSI high. 10 min test each.
Good.
03:00 03:30 0.50 0 0 COMPZ WHDBO RURD P Rig up to test production tree.
03:30 04:15 0.75 0 0 COMPZ WHDBO PRTS P Test WKM-5000 lb-4 1/16"
production tree.250 PSI low f/5
minutes/5000 PSI high f/10
minutes. Good. Charted for 10 mins.
04:15 04:30 0.25 0 0 COMPZ WHDBO PRTS P Rig down testing equipment
04:30 05:00 0.50 0 0 COMPZ DRILL PULL P Pull 2 way check valve. Dry rod.Well
static.
05:00 06:30 1.50 0 0 COMPZ DRILL RURD P Clear and clean rig floor of tools and
equipment from tubing run/control
line operation/thread protectors/
P/U and install mouse hole in
preparation to lay down DP.
06:30 11:00 4.50 0 0 COMPZ DRILL FRZP P SIMOPS:2 PJSM held.One team in
the cellar. Freeze protect the well
with Little Red. Second team on the
rig floor. Lay down 4"DP. Began to
lay down DP, layed down 52 stands
(52 were 4"dp, 1 stand of 4"HWDP.
In the cellar: Pressure test lines to
2500 PSI, reverse circulate-pumping
through SOV @ 6514'w/1 BPM,
ICP=200 PSI, FCP=300 PSI.
Displace out the tubing into the rock
washer. 92 barrels of 100 degree
diesel in, 92 barrels clean brine out
(56.67 bbls-non inhibited,35.33 bbls
inhibited). Barrel for barrel. Hook up
to allow fluids to U tube.
11:00 12:00 1.00 0 0 COMPZ DRILL RURD P Pick up lubricator. Make up
lubricator.
12:00 12:15 0.25 0 0 COMPZ DRILL MPSP P Set 4"CIW Type"H"BPV in f
production tree with FMC hand.
12:15 13:45 1.50 0 0 COMPZ DRILL RURD P Rig down lines used for freeze
protection. Install blind flanges and
all gauges on tree. Record
pressures. 100 PSI OA/0 PSI IA/0
PSI tubing.
13:45 14:15 0.50 0 0 COMPZ DRILL PULD P Clean cellar out with Super Sucker.
14:15 14:30 0.25 0 0 COMPZ DRILL SFTY P Prejob safety meeting on laying
down drill pipe.
14:30 15:45 1.25 0 0 COMPZ DRILL PULD P Lay down 23 stand of 4"drill pipe
using the mouse hole.
15:45 17:00 1.25 0 0 COMPZ DRILL PULD P Lay down the mouse hole. Clean and
clear rig floor.
17:00 18:00 1.00 0 0 COMPZ RIGMNT RGRP P While waiting on pad prep @ 3G-22:
work on the top drive:Torque tube
stabilizer.
Page 28 of 29
Time Logs
Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment
18:00 19:15 1.25 0 0 COMPZ RIGMNT RGRP P While waiting on pad prep @
3G-22:Trouble shoot top drive.
Decision was made to change out
rotating link adapter which is
attatched to the top drive.
19:15 19:30 0.25 0 0 COMPZ RIGMNT RGRP P While waiting on pad prep @ 3G-22:
Pre job safety meeting on working on
the top drive.
19:30 00:00 4.50 0 0 COMPZ RIGMN1 RGRP P While waiting on pad prep @ 3G-22:
Begin work on top drive. Remove
bales,link tilt, link tilt rams,
hydraulic lines.
11/25/2011
12 hour day. Rig Released at noon 11/25/2011. Rig down and move off of 3H. Move to 3G-22
00:00 12:00 12.00 0 0 COMPZ DRILL RURD P Move the rig camp from 3H to 3G.
Start @ 0900 and arrive by 1300 hrs.
The crew continued to prepare the rig
for the 10 mile move. Rig release
11/25/2011 @ 12:00 hrs
Page 29 of 29
Z.tl- 121
WELL LOG TRANSMITTAL 2•tot4
To: Alaska Oil and Gas Conservation Comm. January 12, 2012
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: Whipstock Setting Record: 3H-34
Run Date: 1/8/2012
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Klinton Wood, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
3H-34
Digital Data in LAS format, Digital Log Image file 1 CD Rom
50-103-20643-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline&Perforating
Attn: Klinton Wood
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-273-3527
Fax: 907-273-3535
klinton.wood@halliburton.com
Date: \ IV7/11. Signed: AtidA.C1 #6/ie%
STATE OF ALASKA
f' ALASK L AND GAS CONSERVATION COMMIS V
REPORT OF SUNDRY WELL OPERATIONS
1.Operations Performed: Abandon r Repair w ell r Rug Ferforations r Stimulate r Other rj' C iarnge,inetatus
Alter Casing r Pull Tubing r Perforate New Pool r Waiver r Time Extension r O
Change Approved Rogram r Operat.Shutdown r Perforate r Re-enter Suspended Well r
2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development 17 Exploratory r 211-128-0 '
3.Address: 6.API Number: •
Stratigraphic r Service r
P. O. Box 100360,Anchorage,Alaska 99510 50-103-20643-00"'00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 25531 • • -3H-34 '
9.Field/Pool(s):
Kuparuk River Field/Kuparuk River Oil Pool •
10. Present Well Condition Summary:
Total Depth measured 7300 • feet Plugs(measured) None
true vertical 6206 .
feet Junk(measured) None
Effective Depth measured 7300' feet Packer(measured) 6583
true vertical 6206' feet (true vertucal) 5744
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 79 16 114 114
SURFACE 3949 10.75 3977 3518
INTERMEDIATE 6866 7.625 6891 5947
LINER 717 4.5 7300 6206
RECEIVED
Perforation depth: Measured depth: none
True Vertical Depth: none FEB 2 7 2012
Tubing(size,grade,MD,and TVD) 4.5x3.5, L-80,6639 MD,5784 TVD 1 Alaska Oil & Gas Cons. Commission
I Anchorage
Packers&SSSV(type,MD,and TVD) PACKER-BAKER HRD ZXP LINER TOP PACKER @ 65183'12111T,-5744'TVD
SSSV-CAMCO TRMAXX-CMT-5-SR @ 1899'MD, 1816'TVD
11.Stimulation or cement squeeze summary: �+ ,���� LS
- �Jr 01 q h ij R� r
Intervals treated(measured): not applicable [••lam ( /�,S
Treatment descriptions including volumes used and final pressure:
/ /„,vf,j_- XPi 417
12. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation shut-in
Subsequent to operation shut-in
13.Attachments 14.Well Class after work:
Copies of Logs and Surveys run Exploratory r Development 1;7 Service r Stratigraphic r
15.Well Status after work: Oil Gas r WDSPL r
Daily Report of Well Operations
GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r
16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
none
Contact Jill Long 263-4093
Printed Name Jill Long Title Senior CTD Engineer
Signature 7---) — Phone:263-4093 Date 02723 )i i
RBDMS FEB 2�7 ZO2012
p
Form 10-404 Revised 10/2010 J(lIl11/ /1,-,LILO
Submit Orlglnal Only ,
KUP 3H-34
ConocoPhillips • s e'- ell Attributes ax Angle&MD TD
Alaska Inc Wellbore APIIUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB)
501032064300 KUPARUK RIVER UNIT PROD 7,300.0
Comment H2S(ppm) Date Annotation End Date KB-Grd(fl) Rig Release Date
••• Well Confg:-3H-34,215/2012 4:39.28 PM SSSV:TRDP Last WO: 11/25/2011
Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date
Last Tag:RKB 7,223.0 12/27/2011 Rev Reason:ADD SIDETRACKS ninam 2/5/2012
_Casing Strings
HANGER,23 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd
CONDUCTOR 16 15.062 28.0 107.0 107.0 62.60 H-40 WELDED
--- - - V' , 7 Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd
RIM SURFACE 10 3/4 9.950 28.7 3,977.4 3,518.1 45.50 L-80 BTC
Casing Description String 0... String ID...Top(ftKB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd
INTERMEDIATE 75/8 6.875 25.3 6,890.9 5,947.2 29.70 L-80 BTCM
Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...'String...String Top Thrd
LINER 41/2 3.958 6,582.5 7,300.0 12.60 L-80 IBT-mod
Liner Details
Top Depth
(TVD) Top Incl Nomi...
Top(ftKB) (ftKB) (°) Item Description Comment ID(in)
6,582.5 5,743.5 44.34 PACKER BAKER HRD ZXP LINER TOP PACKER 4.960
= 6,601.5 5,757.2 45.01 NIPPLE BAKER RS PACKOFF SEAL NIPPLE 4.870
CONDUCTOR,
I
6,606.4 5,760.7 45.18 HANGER BAKER DOUBLE GRIP FLEX-LOCK LINER HANGER 4.900
26-107 6,616.3 5,767.6 45.53 XO Reducing CROSSOVER,5-1/2"x 5" 4.490
6,617.3 5,768.3 45.56 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000
= 6,635.8 5,781.1 46.22 XO Reducing CROSSOVER 5"x 4-1/2' 3.970
SAFETY VLV.
i"I Tubing Strings
Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd
TUBING 4.5x3.5 3 1/2 2.992 23.1 6,639.3 5,783.5 9.30 L-80 EUE8RDMOD
Completion Details
GAS LIFT, Top Depth
2,738 (TVD) Top Mel Nomi...
Top(ftKB) (ftKB) (°I Item Description Comment ID(In)
23.1 23.1 -0.02 HANGER FMC TUBING HANGER 4.500
I 88.4 88.4 0.25 XO Reducing CROSSOVER,4W IBT-m box x 3-1/2'EUE pin 3.500
1,898.8 1,816.4 33.39 SAFETY VLV CAMCO TRMA)0-CMT-5-SR SAFETY VLV w/2.812'X PROFILE 2.812
SURFACE, 6,572.8 5,736.4 43.99 NIPPLE HES X NIPPLE 2.813
29-3,977 ..., 6,620.3 5,770.5 45.67 LOCATOR BAKER 80-40 GBH-22 LOCATOR SUB 3.000
GAS LIFT, 1 6,621.2 5,771.0 45.70 SEAL ASSY BAKER SEAL ASSEMBLY w/10'STROKE&1/2 MULE SHOE 2.990
4'206 6,639.2 5,783.4 46.34 MULE MULE SHOE 2.990
■ i ole Wireline retrievable plugs,valves,pumps,fish,etc.)
Top Depth
(TVD) Top Incl
GAS LIFT, Top(10KB) MB) PI Description Comment Run Date ID(in)
5.171 - 7,060 6,051.4 51.35 WHIPSTOCK BAKER WHIPSTOCK 1/8/2012 2.625
-
GAS LIFT.
5,982
-
NI
NI
GAS LIFT.
6,514
IIIII
IIII
NIPPLE,6,573 l 5-:
_.
■
i
1 I
LOCATOR,_
6,620
SEAL ASSY, gi
8,821MULE,6,839 _
NTERMEDIATE, e
25-6,891
WHIPSTOCK.
7,060
II Mandrel Details
Top Depth Top Port
(TVD) Incl OD Valve Latch Size TRO Run
Stn Top(ftKB) (ftKB) El Make Model lin) Sery Type Type On/ (psi) Run Date Corn...
SLOTS, 1 2,738.4 2,504.2 37.30 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/23/2011
7.osa7.st6\ 2 4,206.2 3,705.1 33.56 CAMCO MMG '1(7
12 GAS LIFT DMY RK 0.000 0.0 11/23/2011
LINER, \
6•Se3-7.3°° 3 5,170.6 4,545.7 27.34 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/23/2011
TD(3H-34),
7.300 4 5,981.6 5,254.8 26.33 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 11/23/2011
sums,
7,2761,473 5 6,514.3 5,694.0 42.08 CAMCO MMG 1 12 GAS LIFT SPG RK 0.000 0.0 12/19/2011
SLOTS,
7,517-0,938
SLOTS,
7,4749,219
LINER L1-02,
LINER Lt-0
LINER
L19361.
7.28&9.219
ConocoPhillips
TRANSMITTAL ,_/,141 ; f
CONFIDENTIAL DATA 41a 201?
6118 Co
FROM: Sandra D. Lemke,AT01808 TO: Makana Bender r•'-lofiago
ConocoPhillips Alaska, Inc. AOGCC
`�saiore
P.O. Box 100360 333 W. 7th Ave. Suite 100
Anchorage AK 99510-0360 Anchorage, Alaska 99501-3539
RE: 3H-34
AOGCC permit: 211-128-0
DATE: 01/05/2011
Transmitted:
Kuparuk River Unit, North Slope, Alaska
3H-34
CD and hardcopy report
Final Well report, Mud logging report, CANRIG;well 3H-34(501032064300); November 21, 2011
Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports, formation logs color prints;
Formation log(MD) CV
Formation log(ND)
Gas ratio (MD) lr
Gas ratio (TVD) •
LWD Combo (MD)"
LWD Combo (TVD) `7
Drilling dynamics (MD)
Drilling dy nics (TVD) `-
CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files
/ N.). 1-(
Sign, scan and return electronically to Sandra.D.Lemke0Conocophi/lips.com
CC: 3H-34 transmittal folder, production well files, eSearch
Receipt: LI(Lc) Date: 4 --
Y1GIS-Technical Data Management C n oPhilli Anchorage, Alaska Ph: 907.265.6947
9 I oa' Psl 9 .
2LFi/
Page 1 of 2
Schwartz, Guy L (DOA)
From: Long, Jill W[Jill.W.Long@conocophillips.com]
Sent: Tuesday, November 29, 2011 5:18 PM
To: Schwartz, Guy L (DOA) 1,-i A all-_(Z
Subject: RE: 3H-34 Naming Convention Question
Guy-
Based on the phone conversation we had following the email below, we have decided to proceed with
considering the parent 3H-34 wellbore as "suspended". This, as I recall, will not require any additional
paperwork(i.e. no Sundry application). The CTD laterals will then be called 3H-34L1, 3H-34L1-01, and
3H-34L1-02. In conclusion, the only paperwork that we will plan to submit to the State will be 3 PTD
4 applications, one for each of the CTD laterals.
This is how we plan to proceed with the permitting. If any additional paperwork is required beyond the 3
PTDs please let me know.
Thanks,
Jill Long
ConocoPhillips Alaska
Drilling and Wells
Office: 907-263-4093
Cell: 907-230-7550
Fax: 918-662-6330
From: Long,Jill W
Sent: Tuesday, November 29, 2011 3:58 PM
To: 'Schwartz, Guy L(DOA)'
Subject: RE: 3H-34 Naming Convention Question
Thank you for clarifying Guy. We will proceed with naming the laterals 3H-34A, 3H-34AL1, and 3H-
34AL2.
Jill Long
ConocoPhillips Alaska
Drilling and Wells
Office: 907-263-4093
Cell: 907-230-7550
Fax: 918-662-6330
From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov]
Sent: Tuesday, November 29, 2011 3:29 PM
To: Long, Jill W
Subject: [EXTERNAL]RE: 3H-34 Naming Convention Question
11/30/2011
Page 2 of 2
Jill,
We have flip flopped some on these CTD setup wells. Your suggestion is valid that you propose and would
be fine. 3H-34 would have to be officially abandoned when you set the whipstock to sidetrack.
Guy Schwartz
Senior Petroleum Engineer
AOGCC
793-1226 (office)
444-3433 (cell)
From: Long, Jill W [mailto:Jill.W.Long@conocophillips.com]
Sent: Tuesday, November 29, 2011 3:08 PM
To: Schwartz, Guy L (DOA)
Subject: 3H-34 Naming Convention Question
Guy-
The recently drilled rotary, grassroots Kuparuk well, 3H-34, is planned for CTD drilling in January 2012. The
rotary well was a CTD setup well with no plans for production out of the parent. Because of that, will you please
confirm the naming conventions that should be used for the CTD laterals? I've attached a general diagram to
help describe the situation. I think the names should be 3H-34A, 3H-34AL1, and 3H-34AL2, for Lateral 1, 2,
and 3 respectively. Is this correct?
Thank you in advance for clarification.
Jill Long
ConocoPhillips Alaska
Drilling and Wells
Office: 907-263-4093
Cell: 907-230-7550
Fax: 918-662-6330
11/30/2011
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Page 1 of 1
Schwartz, Guy L (DOA)
From: Schwartz, Guy L (DOA)
Sent: Monday, October 24, 2011 9:50 AM
To: 'Greener, Mike R.'
Subject: RE: 3H-34 ( PTD 211-128)
Mike,
You have approval to change the conductor from the permitted standard non-insulated to 30" OD
insulated conductor. (increasing hole Dia from 24"to 42")
Guy Schwartz
Senior Petroleum Engineer
AOGCC
793-1226 (office)
444-3433 (cell)
From: Greener, Mike R. [mailto:Mike.R.Greener@conocophillips.com]
Sent: Monday, October 24, 2011 9:11 AM
To: Schwartz, Guy L(DOA)
Subject:
ConocoPhillips proceeded to install the conductor for the 3H-34 over the
October weekend of the 22nd and 23rd. We anticipated that we would
hit water during the dry drilling of the 24" hole as the last three
conductors on the 3H pad did. We dry drilled to a depth of 80 feet and
did not hit any water.
Therefore, to protect the surface from thawing out during the life of the
well we would like to install an insulated conductor which is 30" in
diameter. This will require us to enlarge the hole from 24" to 42". The
AOGCC field representative requested that we get Anchorage office
approval before we proceed.
This email requests approval for enlarging the 80' deep 24" hole to 42"
so we can install an insulated conductor.
Thank you.
Mike Greener
10/24/2011
sifosI irr , [LAsEgt\\
SEAN PARNELL,GOVERNOR
ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100
CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539
PHONE (907)279-1433
FAX (907)276-7542
G. L. Alvord
Drilling Manager
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Kuparuk River Oil Pool, 3H-34
ConocoPhillips Alaska, Inc.
Permit No: 211-128
Surface Location: 936' FNL, 281' FWL, SEC. 12, T12N, R8E, UM
Bottomhole Location: 2296' FSL, 2297' FWL, SEC. 01, T12N, R8E, UM
Dear Mr. Alvord:
Enclosed is the approved application for permit to drill the above referenced
development well.
This permit to drill does not exempt you from obtaining additional permits or
an approval required by law from other governmental agencies and does not
authorize conducting drilling operations until all other required permits and
approvals have been issued. In addition, the Commission 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 Commission
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 a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit.
Sincerely,
Daniel T. Seamount, Jr.
Chair
DATED this day of September, 2011.
cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail)
Department of Environmental Conservation w/o encl. (via e-mail)
STATE OF ALASKA RECEIVED'
ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 1 2011
PERMIT TO DRILL
20 AAC 25.005 Alaska Oil& Gas Cons.Commission
la.Type of Work: 1 b.Proposed Well Class: Development-Oil 0 • Service-Winj ❑ Single Zone 0 • 1c.Specify if w ••• - for:
It 1
Drill 0 • Re-drill❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas d ydrates❑
Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑
2.Operator Name: 5. Bond: U Blanket U Single Well 11.Well Name and Number:
ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 3H-34 •
3.Address: 6.Proposed Depth: 12. Field/Pool(s):
P.O. Box 100360 Anchorage,AK 99510-0360 MD:7397' , TVD: 6149'• Kuparuk River Field
4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number):
Surface:936'FNL,281'FWL,Sec. 12,T12N, R8E, UM ' ADL 25531 • Kuparuk River Oil Pool •
Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date:
2140'FSL,2206'FWL,Sec. 1,T12N,R8E,UM 2657 11/16/2011
Total Depth: 9.Acres in Property: 14.Distance to
2296'FSL,2297'FWL,Sec. 1,T12N,R8E,UM ' 2560 Nearest Property: 4823'
4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: . 66.6 feet 15.Distance to Nearest Well Open
Surface:x- 498656 • y- 6000721 • Zone- 4 GL Elevation above MSL: . 38.6 feet to Same Pool: 3H-12,1169
16.Deviated wells: Kickoff depth: 300 . ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035)
Maximum Hole Angle: 51* deg Downhole:4136 psig • Surface:3477 psig
18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks
Hole Casing Weight Grade Coupling Length MD • TVD MD - TVD (including stage data)
24" 16" 62.5# H-40 Welded 80' Surf Surf 80' 80' Driven
13.5" 10.75" 45.5# L-80 BTC 4061' Surf Surf 4061' 3592 ' 1472 sx Arctic LiteCRETE,364 sx DeepCRETE
9.875" 7.625" 29.7# L-80 BTCM 7102' Surf Surf 7102' ' 5960' 575 sx Class G •
6.75" 4.5" 12.6# L-80 IBTM 587' 6800' 5767' 7397' 6149' 117 sx Class G
19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured)
Casing Length Size Cement Volume MD TVD
Conductor/Structural
Surface
Intermediate
Production
Liner
Perforation Depth MD(ft): Perforation Depth TVD(ft):
20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0
21.Verbal Approval: Commission Representative: Date:
22. I hereby ceLi�6Actree foregoing is true and correct. Contact Hai Bin Guo 61
Printed Name fd- G. L. Alvord Title Drilling Manager Volohi
Signature i Phon 265-6120 Date
Commission Use Only
Permit to Drill 7
2API Number: Permit Approv I See cover letter
Number: . / / I /-0 50-/&3-200/3--a)-ED Date: q Qq\1\ for other requirements
Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed me ane,gas hydrates,or gas contained in shales: R
.A3500 P sZ, $O7I ' Samples req'd: Yes ❑ No [ Mud log req'd: Yes ❑ No []/
Other: ,, A i„,J.,. ,1 H2S measures: Yes [, 'No ❑ Directional svy req'd: Yes [( No El
/ � APPROVED BY THE COMMISSION
' /26. // DATE: �__�� •_ a COMMISSIONER
sss ow
Form 10-401 (Revised 7/2009) This permit is valid o,2 o tliao . -:datisto approval(20 AAC 25.005(8)) er Submit in Duplicate
COnPost Office Box 100360 oc ''f'
Anchorage,Alaska 99510-0360
Chip Alvord
Phone(907)265-6120
Email: Chip.Alvord@conocophillips.com
September 19th,20111
Alaska Oil and Gas Conservation Commission ` `+�• ��
333 West 7thAvenue, Suite 100
�1�
SEP
Anchorage,Alaska 99501 2 ��»
Alaeka Oil&Gas
RE: Application for Permit to Drill 3H-34 COn$. Commj$$jod
Anchorage
Dear Commissioners,
ConocoPhillips Alaska,Inc hereby applies for a Permit to Drill for the onshore grassroot well 3H-34. The
well will be drilled and completed using Doyon Rig 141. This well will be a production well in Kuparuk
A-sand.The planned spud date for 3H-34 is November 16th,2011.
Please find attached for the review of the Commission forms 10-401 and the information required by 20
ACC 25.005 for this well bore.
If you have any questions or require further information,please contact Haibin Guo at 907-265-1487.
II' Sincerely,
t uc nh4'3 TUY=
Chip
DL wSDrillingng Manager C 74.
it z3.`(
lication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
Permit It — Kuparuk Well 3H-34
Application for Permit to Drill Document
Ma ell
cul p x i m i x
Well Vplue
Table of Contents
1. Well Name 2
Requirements of 20 AAC 25.005( 2
2. Location Summary 2
Requirements of 20 AAC 25.005(c)(2) 2
Requirements of 20 AAC 25.050(b) 2
3. Blowout Prevention Equipment Information 3
Requirements of Al AAC 25.005(c)(3) 3
4. Drilling Hazards Information 3
Requirements of 20 AAC 25.005(c)(4) 3
5. Procedure for Conducting Formation Integrity Tests 3
Requirements of 20 AAC 25.005(c)(5) 3
6. Casing and Cementing Program 4
Requirements of 20 AAC 25.005(c)(6) 4
7. Diverter System Information 4
Requirements of 20 AAC 25.005(c)(7) 4
8. Drilling Fluid Program 4
Requirements of 20 AAC 25.005(c)(8) 4
9. Abnormally Pressured Formation Information 5
Requirements of 20 AAC 25.005(c)(9) 5
10. Seismic Analysis 5
Requirements of 20 AAC 25.005 (c)(10) 5
11. Seabed Condition Analysis 5
Requirements of 20 AAC 25.005(c)(11) 5
12. Evidence of Bonding 5
Requirements of 20 AAC 25.005 (c)(12) 5
13. Proposed Drilling Program 5
Requirements of 20 AAC 25.005(c)(13) 5
3H-34 APD
Page 1 of 7
Printed: 19-Sep-11
lication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
14. Discussion of Mud and Cuttings Disposal and Annular Disposal 6
Requirements of 20 AAC 25.005(c)(14) 6
15. Attachments 6
Attachment 1 Directional Plan 6
Attachment 2 Drilling Hazards Summary 6
Attachment 3 Well Schematic 6
Attachment 4 Cement Summary 6
1. Well Name
Requirements of 20 AAC 25.005(1)
Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC
25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix
to the name designated for the well by the operator and to the number assigned to the well by the commission.
The well for which this application is submitted will be designated as 3H-34.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(2)a plat identdying the property and the property's owners and showing
(A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to
governmental section lines.
(B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained
by the National Geodetic Survey in the National Oceanic and Atmospheric Administration:
(C)the proposed depth of the well at the top of each objective formation and at total depth:
Location at Surface 936'FNL, 281'FWL, Sec 12-T12N-R08E
NAD 1927 RKB Elevation 66.60'AMSL
Northings: 6,000,721 Eastings: 498,656 . Pad Elevation 38.60'AMSL
Location at Top of Productive Interval 2,140' FSL,2,206'FWL,Sec 1-T12N-R08E
(A sand)
NAD 1927 Measured Depth, RKB: 7,161'
Northings: 6,003,797 Eastings:500,578 Total Vertical Depth, RKB: 5,998'
Total Vertical Depth, SS: 5,931'
Location at Total Depth 2,296' FSL, 2,296' FWL, Sec 1-T12N-R08E
NAD 1927 Measured Depth, RKB: 7397'
Northings: 6,003,953 Eastings: 500,669 Total Vertical Depth, RKB: 6,149'
Total Vertical Depth, SS: 6,083'
and
(D)other information required by 20 AAC 25.050(b);
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must
(1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any
portion of the proposed well:
Please see Attachment 1: Directional Plan
and
(2)for all wells within 200 feet of the proposed wellbore
(A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that
each named operator has been furnished a copy of the application by certified mail:or
(B)state that the applicant is the only affected owner.
3H-34 APD
Page 2 of 7
Printed: 19-Sep-11
ication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
The Applicant is the only affected owner.
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c,)(3)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(3)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037,
as applicable;
Please reference BOP schematics on file for Doyon 141. •
4. Drilling Hazards Information
Requirements of 20 AAC 25.005(c)(4)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(4)information on drilling hazards,including
(A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on
a methane gradient:
The offset well 3H-17 data shows the maximum BHP of 4,229 psi at the Top of the A sand at 6,110 ft TVD.
Equivalent Mud Weight @ TD=4,229/(6,110'*.052)= 13.31 ppg
The maximum potential surface pressure(MPSP)while drilling 3H-34 is calculated using the predicted 4,229 psi
reservoir pressure,a 0.11 psi/ft gas gradient,and A5 sand top TVD of 5,994 ft.
MPSP =(5,994 ft TVD)*(0.69-0.11 psi/ft)
=3,477 psi
(B)data on potential gas zones;
The well bore is not expected to penetrate any gas zones.
and
(C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a
propensity for differential sticking;
Please see Attachment 2-Drilling Hazards Summary
5. Procedure for Conducting Formation Integrity Tests
Requirements of 20 MC 25.005(c)(5)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.0300:
Drill out surface casing shoe and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that •
ConocoPhillips Alaska has on file with the Commission.
3H-34 APD
Page 3 of 7
Printed: 19-Sep-11
% L..
'ication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated
liner,or screen to be installed;
Casing and Cementing Program
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD MD/TVD
OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program
16 62.5 H-40 Welded 80' Surf 80'/80' Driven in
Cemented to Surface with 1.4T
10-3/4 13-1/2 45.5 L-80 BTC 4,061' Surf 4,061'/3,592' 1472 sx Arctic LiteCRETE Lead 10.85 ppg, t,G 2-
364
364 sx Tail Slurry DeepCRETE 12.0 ppg
Cement Top planned @ 5,100'MD/4,453'
7-5/8 9-7/8 29.7 L-80 BTCM 7,102' Surf 7,102'/5,960' ND. Cemented w/ i./G
575 sx Class"G"15.8 ppg
Cement Top planned @ 6,800'MD/5,767
4-1/2 6-3/4 12.6 L-80 IBTM 587' 6,800' 7,397'/6,149' ND. Cemented w/ . t.
117 sx Class"G"15.8 ppg
ji ell s .7
7. Diverter System Information
Requirements of 20 AAC 25.005(c)(7)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under
20 AAC 25.035(h)(2);
Please reference diverter schematic on file for Doyon 141.
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(8)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(8)a drillingfluid program,including a diagram and description of the drillingfluid system,as required by 20 AAC 25.033;
Drilling will be done using mud systems having the following properties:
Surface 80'—4,061'
Mud Type Fresh Water Spud Mud
Density(ppg) 8.7—9.6
Funnel Viscosity(seconds) >300 sec.
Yield Point(cP) 60-80
API Fluid Loss(ml/30min) NC—< 10
Chlorides(mg/1) <1000
pH 9.0—9.5
Intermediate 4,061'—7,102'
Mud Type LSND
Density(ppg) 9.5—10.0
Low Shear Rate Yield Point(LSYP) 5- 10
(!b/100 ft^2)
API Fluid Loss(m1.30min) <6
pH 9.5—10.0
Drill Solids(% V/V) <7
Production 7,102'—7,39P
Mud Type LSND
3H-34 APD
Page 4 of 7
Printed: 19-Sep-11
ORIGINAL
ication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
Density(ppg) 10.5— 13.5
Low Shear Rate Yield Point 5-6
(LSYP) (lb/100ft^2)
API Fluid Loss(mL/30min) <6
pH 9.5—10.0
Drill Solids(% V/V) <6
Diagram of Doyon 141 Mud System on file.
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005(c)(9)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by
20 AAC 25.033(1);
N/A-Application is not for an exploratory or stratigraphic test well.
10. Seismic Analysis
Requirements of 20 AAC 25.005(c)(10)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a);
N/A-Application is not for an exploratory or stratigraphic test well.
11. Seabed Condition Analysis
Requirements of 20 AAC 25.005(c)(11)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed
conditions as required by 20 AAC 25.061(b);
N/A-Application is not for an offshore well.
12. Evidence of Bonding
Requirements of 20 AAC 25.005(c)(12)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(12)evidence showing that the requirements of 20 AAC 25.025{Bonding}have been met;
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)
An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic.
1. MIRU Doyon 141 on 3H-34 Conductor. •
2. NU and function test diverter system and prepare spud mud. •
3. Place warning signs on location indicating the rig has diverter equipment rigged up.
4. Spud and directionally drill 13-1/2"hole to the 10-3/4" surface casing point(4,061'MD/3,592' TVD) .
according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional
monitoring and formation data gathering. •
3H-34 APD
Page 5 of 7
Printed: 19-Sep-11
ORIGINAL
ication for Permit to Drill,Well 3H-34
Saved: 19-Sep-11
5. Run and cement 10-3/4"45.5#L-80 BTC casing to surface. Adequate excess cement will be pumped to ensure
cement reaches the surface during the cement job. Displace cement with mud. Perform top job if required to
bring cement to surface.
6. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Record
results.
7. Shut in BOP's and pressure test casing to 3000 psi per AOGCC regulations. Record results. •
8. Drill out cement and 20'minimum to 50' maximum of new hole.Perform LOT. '
9. Directionally drill 9-7/8"hole to 7,102'MD/5,960' TVD. Run MWD/LWD logging tools in drill string as
required for directional monitoring and formatipn da a athering
o C tar'
10. POOH with DP and rack back.Run 7-5/8"29.7#L-80 BTCM casing to 7,102' MD/5,960' TVD and cement.
11. LD 5"DP and PU 4"DP with 6-3/4"hole BHA.
12. Test BOPE to 3,500psi.Record the results.
13. Shut in BOP's and pressure test casing to 3,000 psi per AOGCC regulations. Record results.
14. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT.
15. Directionally drill 6-3/4"hole to 7,397' MD/6,149' TVD. Run MWD/LWD logging tools in drill string as
required for directional monitoring and formation data gathering.
16. POOH with DP and rack back. Run 4-1/2" 12.6#L-80 IBTM casing to 7,397'MD/6,149' TVD and cement.
8
y ,( ;. 274.. s., 4,
17. Run 3-1/2"completion tubing and set at+/-6,800'MD. 1•Z.3-if
18. LD DP and associated equipment.
19. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal C_7-6 eyerJ o*j-
Requirements of 20 AAC 25.005(c)(14)
An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission
and identified in the application:
(14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to
request authorisation under 20 AAC 25.080 for an annular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II
disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary
storage and eventual processing for injection down an approved disposal well,or stored,tested for hazardous
substances,and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska.
ConocoPhillips Alaska does intend to request authorization for the use of this well for annular disposal operations at
a later date provided the well meets the regulatory requirements.
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
Attachment 4 Cement Summary
3H-34 APD
Page 6 of 7
0RIGINAL
Printed: 19-Sep-11
3H-34 Drilling Hazards Summary
13-1/2" Hole/ 10-3/4" Casing Interval
Event Risk Level Mitigation Strategy
Broach of Conductor Low Monitor cellar continuously during interval.
Gas Hydrates Moderate If observed-control drill,reduce pump rates,reduce
drilling fluid temperatures,Additions of Lecithin.
Anti-collision Moderate Run Gyro as needed.Drill with great care at the depth
where Clearance Factor close to 1.5.
Gravel/Sand Sloughing Moderate Increase mud weight/viscosity,High viscosity sweeps.
Monitor fill on connections
Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill(use of
Trips trip sheets),Pumping out of hole as needed.
Lost Circulation Low Prevent by keeping hole clean. If losses occur-reduce
pump rates and mud rheology,use LCM
9-7/8" Hole/7-5/8" Casing Interval
Event Risk Level Mitigation Strategy
Shale stability Moderate Control with higher MW and proper drilling practices.
High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD
higher MW's required tool while drilling across pay interval. Pump and rotate
out on trips as a last resort.
Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced
pump rates,Mud rheology, LCM. Use GKA LC decision
tree.
Hole cleaning Low Use PWD and TAD to monitor hole cleaning. Control the
ROP and use the best hole cleaning practice.
6-3/4" Hole/4-1/2" Casing Interval
Event Risk Level Mitigation Strategy
High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with PWD
higher MW's required tool while drilling across pay interval. Pump and rotate
out on trips as a last resort.
Abnormal Reservoir Pressure Moderate Follow mud weight schedule and do not fall behind.
Stripping Drills,Shut-in Drills,PWD Tools,Increased
mud weight as needed. Ensure adequate kick tolerance
prior to drilling pay interval.
Lost Circulation Low Use PWD and TAD to monitor hole cleaning. Reduced
pump rates,Mud rheology, LCM. Use GKA LC decision
tree.
Att02_3H-34 Hazards.doc
Prepared by Haibin Guo
ORIGINAL
Page 1 of 1
3H-34 Wellbore Design Co coP illips
_. , .•, •:
:•: ,•., :
:: : ; :., .: 30" x 16616#
(4) 80'MD
14-%' Stage Collar Via; 950' Mi)
•
I
5 :•
�,) 10.3;4"45.51'L-80 BTC
•: 4,061'MD I 3,592'TVD
3-1I2" 9.2#L-80 EUE tubing
TOC (4)5,100 MD
Baker liner top .;., r . •
with /.Xi' packer
t-; 6,84(1' MI)/5,7671 L V[) 5 % r. + `: ,
t�
_ ;w.. �, 7-5/829.7# I.-Bc� Iir�rCrr1
,'''. ! : : f : . 7,142' M1)/5,960'TVI)
C.-TD Ta S:aee-te -
j..., Mfrt.i:4. Zo 1 Z
Production Liner
4-1/2" 12,6# L-80At.
11-3-FM R2
.. 0 1 I IV I)
3H-34 Schlumberger
CemCADE Preliminary Job Design
10-3/4" Surface Casino V2 (w•-04)
Preliminary Job Design based on limited input data.For estimate purposes only.
Rig: Doyon 141 Volume Calculations and Cement Systems
Location: Kuparuk Volumes are based on 250% excess in the permafrost and 50% excess below the
Client:CPAI
Revision Date: 09/07/2011 permafrost. The top of the tail slurry is designed to be at 3061' MD.
Prepared by:Mike Martin
Location:Anchorage,AK Lead Slurry Minimum pump time: -260 min. (pump time plus 120 min.)
Phone: (907)263-4207 Arctic LiteCRETE @ 10.85 ppg-1.97 ft3/sk
Mobile: (907)748-6900
email: martin13@slb.com 0.6381 ft3/ft x(80')x 1.00 (no excess) = 51 ft3
0.3637 ft3/ft x(1761 -80')x 3.50 (250% excess) = 2140 ft3
< TOC at Surface 0.3637 ft3/ft x(3061 -1761)x 1.50 (50% excess) = 709 ft3
51 ft3+2140 ft3+709 ft3= 2900 ft3
2900 ft3/1.97 ft3/sk= 1472 sks
Round up to 1290 sks
Have ASI on location for Top Out stage,if necessary.
Previous Csg.
Tail Slurry Minimum pump time: -280 min. (pump time plus120 min.)
< 16",62.6#casing 12.0 ppg DeepCRETE + additives- 1.62 ft3/sk
at 80'MD
0.3637 ft3/ft x(4061 -3061)x 1.50 (50% excess) = 546 ft3
0.53997 ft3/ft x 80' (Shoe Joint) = 43 ft3
546 ft3+43 ft3= 589 ft3
589 ft3/1.62 ft3/sk= 364 sks
Round up to 370 sks
BHST= 92°F, Estimated BHCT = 85°F.
< Base of Permafrost at (BHST calculated using a gradient of 2.0°F/100 ft. from surface)
1,761 MD(1,676'TVD) PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage Volume Time
_ (bpm) (bbl) (min) (min)
CW100 5.0 50.0 10.0 10.0
MUDPUSH II 5.0 50.0 10.0 20.0
< Top of Tail at
Drop top plug 0.0 0.0 5.0 25.0
3,061 MD
Arctic LiteCRETE 6.0 516.7 86.1 111.1
DeepCRETE 6.0 104.9 17.5 128.6
Pause 0.0 0.0 5.0 133.6
Sea Water 5.0 10.0 2.0 135.6
Pause 0.0 0.0 5.0 140.6
Mud 8.0 366.9 45.9 186.5
Mud 3.0 6.0 2.0 188.5
< 10-3/4",45.5#casing
in 13-1/2"OH MUD REMOVAL
Expected Mud Properties:9.6 ppg, Pv<25, Ty< 20
TD at 4,061 MD
(3,592'TVD) Spacer Properties: 10.5 ppg MudPUSH* II, Pv m 20-25, Ty'& 30-35
Centralizers: As per CPAI program.
*Mark of Schlumberger
ORIGINAL
3H-34 Schlumberger
CemCADE Preliminary Job Design
7-5/8" Intermediate V2 (wp04)
Preliminary Job Design based on limited input data.For estimate purposes only.
Rig: Doyon 141
Location: Kuparuk
Client:CPAI
Revision Date: 09/12/2011 Volume Calculations and Cement Systems
Prepared by: Mike Martin Volumes are based on 50% excess. The top of the tail slurry is designed to be
Location:Anchorage,AK
Phone: (907)263-4207 -5100' MD.
Mobile:(907)748-6900
email: martin13@slb.com
Tail Slurry Minimum pump time: -195 min. (pump time plus 120 min.)
15.8 ppg Class G +0.3%D65+ 0.4% D167+ 0.02 gps D177 + 0.2% D46- 1.16 ft3/sk
0.2148 ft3/ft x (7102-5100')x 1.50 (50% excess) = 645 ft3
0.2578 ft3/ft x 80' (Shoe Joint) = 21 ft3
645 ft3+21 ft3= 666 ft3
666 ft3/1.16 ft3/sk= 575 sks
Previous Csg. Round up to 580 sks
< 10-3/4",45.5.#casing
at 4,061'MD
BHST= 145°F, Estimated BHCT= 114°F.
(BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Cumulative
Stage Time
Stage Volume Time
(bpm) (bbl) (min) (min)
CW100 5.0 40.0 8.0 8.0
MUDPUSH II 5.0 40.0 8.0 16.0
Drop bottom plug 0.0 0.0 5.0 21.0
Tail Slurry 6.0 118.5 19.8 40.8
Drop top plug 0.0 0.0 5.0 45.8
Water 5.0 10.0 2.0 47.8
Switch to rig 0.0 0.0 3.0 50.8
Mud 8.0 240.0 30.0 80.8
< Top of Cement at
Slow ECD 5.0 66.4 13.3 94.1
5,100'MD Slow&bump plug 3.0 6.0 2.0 96.1
MUD REMOVAL
< 7-5/8",29.7#casing Expected MUD Properties: 10.0 ppg, Pv<25, TY< 20.
in 9-7/8"OH
Spacer Properties: 11.5 ppg MudPUSH* II, Pv=20-25, Ty= 35-40
TD at 7,102'MD Centralizers: As per COP program
(5,960 TVD)
Mark of Schlumberger
ORIGINAL
3H-34 Schlumberger
CemCADE Preliminary Job Design
4-1/2" Production Liner (V1, WP-04)
Preliminary Job Design based on limited input data.For estimate purposes only.
Rig: Doyon 141 Volume Calculations and Cement Systems
Location: Kuparuk
Client:CPAi
Revision Date: 09/12/2011 Volumes are based on 30% excess. Displacement is calculated with a 4.0"-15.7#drill
Prepared by: Mike Martin pipe using mud.
Location:Anchorage,AK
Phone: (907)263-4207 Tail Slurry Minimum thickening time: -150 min. (pump time plus 120 min.)
Mobile: (907)748-6900 15.8 ppg Class G +2.0 gps D600G, 0.4%D65, 0.15% D153, 0.4 gps D47- 1.17 ft3/sk
email:martin13@slb.com
Annular Volume:
0.1381 ft3/ft x(7380'-7102')x 1.30 (30% excess) = 50 ft3
Lap Volume:
0.1473 ft3/ft x(7102'-6800')x 1.00 (no excess) = 45 ft3
Top of Slurry at
end of pumping Cap Volume:
< 6,600'MD 0.1705 ft3/ft x(6800'-6600')x 1.00 (no excess) = 34 ft3
Shoe Volume:
< Liner Top at 0.0854 ft3/ft x 80'x 1.00 (no excess) = 7 ft3
-6,800' MD
Totals:
50 ft3+45 ft3+ 34 ft3 +7 ft3= 136 ft3
136 ft3/1.17 ft3/sk= 117 sks (-r120 on site)
7-5/8",29.7#casing
at 7,102'MD BHST = 149 °F, Estimated BHCT= 115 °F.
(BHST calculated using a gradient of 2.1 °F/100 ft. from surface)
PUMP SCHEDULE
4-1/2",12.6#liner
in 6 3/4" hole Pump Rate Stage Stage Time Cumulative
Stage Volume Time
(bpm) (bbl) (min) (min)
CW100 5.0 20.0 4.0 4.0
MUDPUSH II 5.0 20.0 4.0 8.0
Slurry 5.0 24.1 4.8 12.8
Drop liner dart 0.0 0.0 3.0 15.8
Water 5.0 10.0 2.0 17.8
Switch to rig 0.0 0.0 3.0 20.8
Mud 5.0 55.0 11.0 31.8
Slow,pick up plug and 3.0 12.0 4.0 35.8
bump
A5 at-7,145'MD
MUD REMOVAL
Recommended Mud Properties: 14.0 ppg, Pv<20, Ty< 15. As thin and light as
possible to aid in mud removal during cementing.
TD at-7397'MD Spacer Properties: 14.5 ppg MudPUSH* II, Pv rz 25- 30, Ty 35-40
(6,149'TVD)
Centralizers: As per CPAi program
Mark of Schlumberger
ORIG ( NAL
ConocoPhillips (Alaska) Inc. -Kup2
Kuparuk River Unit
Kuparuk 3H Pad
Plan: 3H-34
3H-34
}
Plan: 3H-34 (wp04)
Standard Proposal Report
11 August, 2011
L
HALLIBURTON
Sperry Drilling Services
ORGINAL
is
HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: PIan:3H-34 NAD 1927(NADCONCONUS) Alaska Zone 04
Sperry Drilling Services Site: Kuparuk 3H Pad Ground Level: 38.60
Well: Plan: 3H-34 +N/-S+E/-w Northing Easting Latittude Longitude Slot
Wellbore: 3H-34 0.00 0.00 6000720.67 498655.55 70°24'47.531 N 150°0'39.416 W
Plan: 3H-34(wp04)
REFERENCE INFORMATION
0_ Co-ordinate(N/E)Reference:Well Plan:3H-34,True North
SHL:936'FNL,281'FWL-Sec12-T12N-R08E Vertical(TVD)Reference:Planned D141 @66.600(0141(38.6+28))
Measured Depth Reference:Planned D141 @ 66.606(D141(38.6028))
- Calculation Method Minimum Curvature
0°
400- FORMATION TOP DETAILS
5° CASING DETAILS
TVDPath TVDssPath MDPath Formation
10° MD TVD TVDSS Name Size Hole Size 1112.60 1046.00 1138.49 T3
4060.99 3592.26 3525.66 10 3/4" 10-3/4 13-1/2 1236.60 1170.00 1275.15 K15
800- 15° 7101.79 5960.00 5893.40 7 5/8" 7-5/8 9-7/8 1675.60 1609.00 1761.91 Base Pfrost
7396.99 6149.17 6082.57 4 1/2" 4-1/2 6-3/4 2100.60 2034.00 2261.10 Ugnu C
10CP 2243.60 2177.00 2433.65 Ugnu B
2315.60 2249.00 2520.53 Ugnu A
_ 2y 2385.60 2319.00 2605.00 N Sand
1200- 2547.60 2481.00 2800.47 West Sak D
2606.60 2540.00 2871.66 West Sak B
26 2629.60 2563.00 2899.41 West Sak A
2975.60 2909.00 3316.91 Base West Sak
3267.60 3201.00 3669.25 Tabasco Sand
1600- 3542.60 3476.00 4001.07 Base Tabasco
-BaseP/rost- -- 4488.60 4422.00 5142.55 c35
5563.60 5497.00 6486.28 Top HRZ
1.53 5743.60 5677.00 6764.08 Base HRZ/Upper Kalubik
5864.60 5798.00 6950.82 Lower Kalubik/K-Mkr
2000- 5949.60 5883.00 7085.20 Top Kuparuk D
-Ugnu C 5953.60 5887.00 7091.58 C4/C1
5959.60 5893.00 7101.16 B
-Ugnu ti 5993.60 5927.00 7154.96 a5
Ugnu A 5997.60 5931.00 7161.19 a3
2400 6019.60 5953.00 7195.42 a2
- N Sand 6051.60 5985.00 7245.20 a 1
West Sak D- - 6110.60 6044.00 7336.99 Miluveach
- West Sak B113
2800- West Sak A
-Base West Sak- - - -
o
0 3200-
oo - -Tabasco Sand--
_c
art - - --
a - OQO
- Base Tabasco '" Casing @ 4061'MD,3592'TVD:475'FSL,1248'FWL-Sec1-T12N-R08E
0 3600-
T 10 3/4'r
U_ -
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0)
4000-
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4400- Casing @ 7102'MD,5960'TVD:2100'FSL,2183'FWL-Sec1-712N-R08E
_ I
4800- Formation @ 7161'MD,5998'TVD:2140'FSL,2206'FWL-Sec1-T12N-ROBE
- � r
r �
- I �
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r
60 r r
- r r
- I r
I r
5600- Top HRZ- - - • /
C3
-Base HRZ/Upper Kalubik- DO
r
Lower Kalubik/K-Mkr -7 5/8- --
6000 _ • o,�
v r -.--,--..,Top Kuparuk D- 3H-34(wp04)C4/C1 3H-34(wp04)A3 `
•
Ns` S B
`. 4 1/2"
6400 `s s 's ;a5 ✓
- %,a 1 a2a3
- Miluveach
TD @ 7397'MD,6149'TVD:2296'FSL,2296'FWL-Sec1-T12N-R38E
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Vertical Section at 31.94° (800 Win)
ConocoPhillips
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ORIGINAL
Halliburton -Sperry
HALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Site: Kuparuk 3H Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Wellbore: 3H-34
Design: 3H-34(wp04)
Project Kuparuk River Unit,North Slope Alaska,United States
Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level
Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point
Map Zone: Alaska Zone 04 Using geodetic scale factor
Site Kuparuk 3H Pad
Site Position: Northing: 6,000,110.73 ft Latitude: 70°24'41.531 N
From: Map Easting: 498,655.44ft Longitude: 150°0'39.416 W
Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.01 °
Well Plan:3H-34
Well Position +N/-S 0.00 ft Northing: 6,000,720.67 ft Latitude: 70°24'47.531 N
+E/-W 0.00 ft Easting: 498,655.55 ft . Longitude: 150°0'39.416 W
Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 38.60 ft
Wellbore 3H-34
Magnetics Model Name Sample Date Declination Dip Angle Field Strength
(°) (°) (nT)
BGGM2009 8/10/2010 21.49 80.87 57,667
Design 3H-34(wp04)
Audit Notes:
Version: Phase: PLAN Tie On Depth: 28.00
Vertical Section: Depth From(TVD) +N/-S +El-W Direction
(ft) (ft) (ft) (°)
28.00 0.00 0.00 31.94
Plan Sections
Measured Vertical TVD Dogleg Build Turn
Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face
(ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/1O0ft) (°)
28.00 0.00 0.00 28.00 -38.60 0.00 0.00 0.00 0.00 0.00 0.00
228.00 0.00 0.00 228.00 161.40 0.00 0.00 0.00 0.00 0.00 0.00
428.00 5.00 55.00 427.75 361.15 5.00 7.14 2.50 2.50 0.00 55.00
628.00 11.00 55.00 625.71 559.11 20.96 29.93 3.00 3.00 0.00 0.00
1,228.00 25.57 42.59 1,194.07 1,127.47 149.85 165.22 2.50 2.43 -2.07 -21.00
1,728.00 25.57 42.59 1,645.11 1,578.51 308.72 311.25 0.00 0.00 0.00 0.00
2,078.00 34.03 29.94 1,948.85 1,882.25 449.58 411.53 3.00 2.42 -3.61 -42.25
6,068.00 34.03 29.94 5,255.57 5,188.97 2,384.43 1,526.01 0.00 0.00 0.00 0.00
6,457.58 49.61 29.94 5,545.00 5,478.40 2,608.84 1,655.27 4.00 4.00 0.00 0.00
6,959.15 49.61 29.94 5,870.00 5,803.40 2,939.89 1,845.95 0.00 0.00 0.00 0.00
7,015.39 51.19 28.93 5,905.85 5,839.25 2,977.63 1,867.24 3.13 2.80 -1.81 -26.74
7,114.87 51.19 28.93 5,968.19 5,901.59 3,045.47 1,904.73 0.00 0.00 0.00 0.00
7,161.19 50.00 30.00 5,997.60 5,931.00 3,076.64 1,922.34 3.13 -2.57 2.32 145.42
7,336.99 50.00 30.00 6,110.60 6,044.00 3,193.26 1,989.67 0.00 0.00 0.00 0.00
7,396.99 50.00 30.00 6,149.17 6,082.57 3,233.07 2,012.65 0.00 0.00 0.00 0.00
9/6/2011 1:27.53PM Page 2 COMPASS 2003.16 Build 69
Halliburton -Sperry
HALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Site: Kuparuk 3H Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Wellbore: 3H-34
Design: 3H-34(wp04)
Planned Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section
(ft) (a) () (ft) ft (ft) (ft) (ft) (ft) -38.60
28.00 0.00 0.00 28.00 -38.60 0.00 0.00 6,000,720.67 498,655.55 0.00 0.00
SHL:936'FNL,281'FWL-Sec12-T12N-R08E
100.00 0.00 0.00 100.00 33.40 0.00 0.00 6,000,720.67 498,655.55 0.00 0.00
200.00 0.00 0.00 200.00 133.40 0.00 0.00 6,000,720.67 498,655.55 0.00 0.00
228.00 0.00 0.00 228.00 161.40 0.00 0.00 6,000,720.67 498,655.55 0.00 0.00
300.00 1.80 55.00 299.99 233.39 0.65 0.93 6,000,721.32 498,656.48 2.50 1.04
400.00 4.30 55.00 399.84 333.24 3.70 5.28 6,000,724.37 498,660.83 2.50 5.94
428.00 5.00 55.00 427.75 361.15 5.00 7.14 6,000,725.67 498,662.69 2.50 8.02
500.00 7.16 55.00 499.34 432.74 9.38 13.39 6,000,730.04 498,668.94 3.00 15.04
600.00 10.16 55.00 598.19 531.59 18.01 25.72 6,000,738.68 498,681.27 3.00 28.89
628.00 11.00 55.00 625.71 559.11 20.96 29.93 6,000,741.62 498,685.49 3.00 33.62
700.00 12.70 52.06 696.17 629.57 29.77 41.80 6,000,750.42 498,697.35 2.50 47.37
800.00 15.09 49.08 793.24 726.64 45.05 60.31 6,000,765.71 498,715.86 2.50 70.14
900.00 17.52 46.90 889.21 822.61 63.87 81.14 6,000,784.52 498,736.69 2.50 97.12
1,000.00 19.96 45.23 983.91 917.31 86.17 104.25 6,000,806.82 498,759.80 2.50 128.27
1,100.00 22.41 43.92 1,077.14 1,010.54 111.93 129.59 6,000,832.56 498,785.15 2.50 163.54
1,138.49 23.36 43.48 1,112.60 1,046.00 122.75 139.93 6,000,843.38 498,795.49 2.50 178.19
T3
1,200.00 24.88 42.85 1,168.74 1,102.14 141.09 157.12 6,000,861.71 498,812.68 2.50 202.85
1,228.00 25.57 42.59 1,194.07 1,127.47 149.85 165.22 6,000,870.48 498,820.78 2.50 214.57
1,275.15 25.57 42.59 1,236.60 1,170.00 164.83 178.99 6,000,885.45 498,834.55 0.00 234.56
K15
1,300.00 25.57 42.59 1,259.02 1,192.42 172.73 186.25 6,000,893.35 498,841.81 0.00 245.11
1,400.00 25.57 42.59 1,349.23 1,282.63 204.50 215.45 6,000,925.11 498,871.02 0.00 287.52
1,500.00 25.57 42.59 1,439.43 1,372.83 236.28 244.66 6,000,956.88 498,900.23 0.00 329.93
1,600.00 25.57 42.59 1,529.64 1,463.04 268.05 273.87 6,000,988.64 498,929.44 0.00 372.35
1,700.00 25.57 42.59 1,619.85 1,553.25 299.82 303.08 6,001,020.41 498,958.65 0.00 414.76
1,728.00 25.57 42.59 1,645.11 1,578.51 308.72 311.25 6,001,029.30 498,966.83 0.00 426.64
1,761.91 26.33 41.05 1,675.60 1,609.00 319.78 321.14 6,001,040.36 498,976.72 3.00 441.26
Base Pfrost
1,800.00 27.20 39.41 1,709.61 1,643.01 332.88 332.22 6,001,053.45 498,987.80 3.00 458.23
1,900.00 29.58 35.55 1,797.58 1,730.98 370.63 361.09 6,001,091.19 499,016.67 3.00 505.53
2,000.00 32.05 32.23 1,883.47 1,816.87 413.16 389.59 6,001,133.72 499,045.18 3.00 556.71
2,078.00 34.03 29.94 1,948.85 1,882.25 449.58 411.53 6,001,170.13 499,067.12 3.00 599.22
2,100.00 34.03 29.94 1,967.08 1,900.48 460.25 417.67 6,001,180.80 499,073.26 0.00 611.53
2,200.00 34.03 29.94 2,049.96 1,983.36 508.74 445.60 6,001,229.28 499,101.20 0.00 667.45
2,261.10 34.03 29.94 2,100.60 2,034.00 538.37 462.67 6,001,258.91 499,118.27 0.00 701.63
Ugnu C
2,300.00 34.03 29.94 2,132.83 2,066.23 557.24 473.54 6,001,277.76 499,129.14 0.00 723.38
2,400.00 34.03 29.94 2,215.71 2,149.11 605.73 501.47 6,001,326.25 499,157.08 0.00 779.31
2,433.65 34.03 29.94 2,243.60 2,177.00 622.05 510.87 6,001,342.56 499,166.48 0.00 798.13
Ugnu B
2,500.00 34.03 29.94 2,298.58 2,231.98 654.22 529.40 6,001,374.73 499,185.01 0.00 835.24
2,520.53 34.03 29.94 2,315.60 2,249.00 664.18 535.13 6,001,384.68 499,190.75 0.00 846.72
Ugnu A
9/6/2011 1:27:53PM Page 3 COMPASS 2003.16 Build 69
ORiGINAL
Halliburton -Sperry
I-IALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Site: Kuparuk 311 Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Wellbore: 3H-34
Design: 3H-34(wp04)
Planned Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Veil Section
(ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 2,314.86
2,600.00 34.03 29.94 2,381.46 2,314.86 702.71 557.33 6,001,423.21 499,212.95 0.00 891.16
2,605.00 34.03 29.94 2,385.60 2,319.00 705.14 558.73 6,001,425.63 499,214.35 0.00 893.96
N Sand
2,700.00 34.03 29.94 2,464.34 2,397.74 751.21 585.26 6,001,471.69 499,240.89 0.00 947.09
2,800.00 34.03 29.94 2,547.21 2,480.61 799.70 613.20 6,001,520.18 499,268.83 0.00 1,003.02
2,800.47 34.03 29.94 2,547.60 2,481.00 799.93 613.33 6,001,520.41 499,268.96 0.00 1,003.28
West Sak D
2,871.66 34.03 29.94 2,606.60 2,540.00 834.45 633.21 6,001,554.92 499,288.85 0.00 1,043.10
West Sak B
2,899.41 34.03 29.94 2,629.60 2,563.00 847.91 640.96 6,001,568.38 499,296.60 0.00 1,058.62
West Sak A
2,900.00 34.03 29.94 2,630.09 2,563.49 848.19 641.13 6,001,568.66 499,296.77 0.00 1,058.95
3,000.00 34.03 29.94 2,712.96 2,646.36 896.68 669.06 6,001,617.14 499,324.70 0.00 1,114.88
3,100.00 34.03 29.94 2,795.84 2,729.24 945.18 696.99 6,001,665.63 499,352.64 0.00 1,170.80
3,200.00 34.03 29.94 2,878.71 2,812.11 993.67 724.92 6,001,714.11 499,380.58 0.00 1,226.73
3,300.00 34.03 29.94 2,961.59 2,894.99 1,042.16 752.85 6,001,762.59 499,408.52 0.00 1,282.66
3,316.91 34.03 29.94 2,975.60 2,909.00 1,050.36 757.58 6,001,770.79 499,413.24 0.00 1,292.12
Base West Sak
3,400.00 34.03 29.94 3,044.46 2,977.86 1,090.65 780.79 6,001,811.07 499,436.45 0.00 1,338.59
3,500.00 34.03 29.94 3,127.34 3,060.74 1,139.15 808.72 6,001,859.56 499,464.39 0.00 1,394.51
3,600.00 34.03 29.94 3,210.21 3,143.61 1,187.64 836.65 6,001,908.04 499,492.33 0.00 1,450.44
3,669.25 34.03 29.94 3,267.60 3,201.00 1,221.22 855.99 6,001,941.61 499,511.68 0.00 1,489.17
Tabasco Sand
3,700.00 34.03 29.94 3,293.09 3,226.49 1,236.13 864.58 6,001,956.52 499,520.27 0.00 1,506.37
3,800.00 34.03 29.94 3,375.96 3,309.36 1,284.62 892.51 6,002,005.00 499,548.21 0.00 1,562.30
3,900.00 34.03 29.94 3,458.84 3,392.24 1,333.12 920.45 6,002,053.49 499,576.14 0.00 1,618.23
4,000.00 34.03 29.94 3,541.71 3,475.11 1,381.61 948.38 6,002,101.97 499,604.08 0.00 1,674.15
4,001.07 34.03 29.94 3,542.60 3,476.00 1,382.13 948.68 6,002,102.49 499,604.38 0.00 1,674.75
Base Tabasco
4,060.99 34.03 29.94 3,592.26 3,525.66 1,411.18 965.41 6,002,131.54 499,621.12 0.00 1,708.27
10 3/4"
4,061.00 34.03 29.94 3,592.27 3,525.67 1,411.19 965.42 6,002,131.54 499,621.12 0.00 1,708.27
Casing @ 4061'MD,3592'TVD:475'FSL,1248'FWL-Sec1-T12N-RO8E
4,100.00 34.03 29.94 3,624.59 3,557.99 1,430.10 976.31 6,002,150.45 499,632.02 0.00 1,730.08
4,200.00 34.03 29.94 3,707.46 3,640.86 1,478.59 1,004.24 6,002,198.93 499,659.96 0.00 1,786.01
4,300.00 34.03 29.94 3,790.34 3,723.74 1,527.09 1,032.17 6,002,247.42 499,687.90 0.00 1,841.94
4,400.00 34.03 29.94 3,873.21 3,806.61 1,575.58 1,060.11 6,002,295.90 499,715.83 0.00 1,897.87
4,500.00 34.03 29.94 3,956.09 3,889.49 1,624.07 1,088.04 6,002,344.38 499,743.77 0.00 1,953.79
4,600.00 34.03 29.94 4,038.96 3,972.36 1,672.56 1,115.97 6,002,392.87 499,771.71 0.00 2,009.72
4,700.00 34.03 29.94 4,121.84 4,055.24 1,721.06 1,143.90 6,002,441.35 499,799.65 0.00 2,065.65
4,800.00 34.03 29.94 4,204.71 4,138.11 1,769.55 1,171.83 6,002,489.83 499,827.58 0.00 2,121.58
4,900.00 34.03 29.94 4,287.59 4,220.99 1,818.04 1,199.76 6,002,538.31 499,855.52 0.00 2,177.50
5,000.00 34.03 29.94 4,370.46 4,303.86 1,866.53 1,227.70 6,002,586.80 499,883.46 0.00 2,233.43
5,100.00 34.03 29.94 4,453.34 4,386.74 1,915.03 1,255.63 6,002,635.28 499,911.40 0.00 2,289.36
9/6/2011 1:27:53PM Page 4 COMPASS 2003.16 Build 69
ORIGINAL
Halliburton -Sperry
HALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Slte: Kuparuk 3H Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Wellbore: 3H-34
Design: 3H-34(wp04)
Planned Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Fasting DLS Vert Section
(ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 4,422.00
5,142.55 34.03 29.94 4,488.60 4,422.00 1,935.66 1,267.51 6,002,655.91 499,923.28 0.00 2,313.16
c35
5,200.00 34.03 29.94 4,536.21 4,469.61 1,963.52 1,283.56 6,002,683.76 499,939.34 0.00 2,345.29
5,300.00 34.03 29.94 4,619.09 4,552.49 2,012.01 1,311.49 6,002,732.24 499,967.27 0.00 2,401.22
5,400.00 34.03 29.94 4,701.96 4,635.36 2,060.50 1,339.42 6,002,780.73 499,995.21 0.00 2,457.14
5,500.00 34.03 29.94 4,784.84 4,718.24 2,109.00 1,367.36 6,002,829.21 500,023.15 0.00 2,513.07
5,600.00 34.03 29.94 4,867.71 4,801.11 2,157.49 1,395.29 6,002,877.69 500,051.09 0.00 2,569.00
5,700.00 34.03 29.94 4,950.59 4,883.99 2,205.98 1,423.22 6,002,926.17 500,079.02 0.00 2,624.93
5,800.00 34.03 29.94 5,033.46 4,966.86 2,254.47 1,451.15 6,002,974.66 500,106.96 0.00 2,680.85
5,900.00 34.03 29.94 5,116.34 5,049.74 2,302.97 1,479.08 6,003,023.14 500,134.90 0.00 2,736.78
6,000.00 34.03 29.94 5,199.21 5,132.61 2,351.46 1,507.02 6,003,071.62 500,162.84 0.00 2,792.71
6,068.00 34.03 29.94 5,255.57 5,188.97 2,384.43 1,526.01 6,003,104.59 500,181.84 0.00 2,830.74
6,100.00 35.31 29.94 5,281.89 5,215.29 2,400.21 1,535.09 6,003,120.36 500,190.92 4.00 2,848.93
6,200.00 39.31 29.94 5,361.41 5,294.81 2,452.72 1,565.34 6,003,172.86 500,221.18 4.00 2,909.50
6,300.00 43.31 29.94 5,436.51 5,369.91 2,509.91 1,598.28 6,003,230.04 500,254.12 4.00 2,975.45
6,400.00 47.31 29.94 5,506.82 5,440.22 2,571.50 1,633.76 6,003,291.62 500,289.61 4.00 3,046.49
6,457.58 49.61 29.94 5,545.00 5,478.40 2,608.84 1,655.27 6,003,328.95 500,311.12 4.00 3,089.55
6,486.28 49.61 29.94 5,563.60 5,497.00 2,627.79 1,666.18 6,003,347.89 500,322.04 0.00 3,111.41
Top HRZ
6,500.00 49.61 29.94 5,572.49 5,505.89 2,636.84 1,671.40 6,003,356.95 500,327.25 0.00 3,121.85
6,600.00 49.61 29.94 5,637.28 5,570.68 2,702.84 1,709.41 6,003,422.93 500,365.28 0.00 3,197.97
6,700.00 49.61 29.94 5,702.08 5,635.48 2,768.84 1,747.43 6,003,488.92 500,403.30 0.00 3,274.09
6,764.08 49.61 29.94 5,743.60 5,677.00 2,811.14 1,771.79 6,003,531.21 500,427.67 0.00 3,322.87
Base HRZ/Upper Kalubik
6,800.00 49.61 29.94 5,766.88 5,700.28 2,834.85 1,785.45 6,003,554.91 500,441.33 0.00 3,350.21
6,900.00 49.61 29.94 5,831.67 5,765.07 2,900.85 1,823.47 6,003,620.90 500,479.35 0.00 3,426.34
6,950.82 49.61 29.94 5,864.60 5,798.00 2,934.39 1,842.79 6,003,654.43 500,498.68 0.00 3,465.02
Lower Kalubik/K-Mkr
6,959.15 49.61 29.94 5,870.00 5,803.40 2,939.89 1,845.95 6,003,659.93 500,501.85 0.00 3,471.36
7,000.00 50.76 29.20 5,896.15 5,829.55 2,967.18 1,861.44 6,003,687.22 500,517.33 3.13 3,502.71
7,015.39 51.19 28.93 5,905.85 5,839.25 2,977.63 1,867.24 6,003,697.67 500,523.14 3.13 3,514.65
7,085.20 51.19 28.93 5,949.60 5,883.00 3,025.24 1,893.55 6,003,745.27 500,549.46 0.00 3,568.97
Top Kuparuk D
7,091.58 51.19 28.93 5,953.60 5,887.00 3,029.59 1,895.96 6,003,749.62 500,551.86 0.00 3,573.94
C4/C1
7,100.00 51.19 28.93 5,958.88 5,892.28 3,035.33 1,899.13 6,003,755.36 500,555.04 0.00 3,580.49
7,101.16 51.19 28.93 5,959.60 5,893.00 3,036.12 1,899.57 6,003,756.15 500,555.47 0.00 3,581.39
B
7,101.79 51.19 28.93 5,960.00 5,893.40 3,036.56 1,899.81 6,003,756.58 500,555.71 0.00 3,581.89
Casing @ 7102'MD,5960'TVD:2100'FSL,2183'FWL-Sec1-T12N-RO8E-7 5/8"
7,114.87 51.19 28.93 5,968.19 5,901.59 3,045.47 1,904.73 6,003,765.49 500,560.64 0.00 3,592.06
7,154.96 50.16 29.85 5,993.60 5,927.00 3,072.49 1,919.95 6,003,792.51 500,575.86 3.13 3,623.04
a5
7,161.19 50.00 30.00 5,997.60 5,931.00 3,076.64 1,922.34 6,003,796.65 500,578.25 3.13 3,627.82
Formation @ 7161'MD,5998'TVD:2140'FSL,2206'FWL-Sec1-T12N-R08E-a3-3H-34(wp04)A3
9/6/2011 1:27:53PM Page 5 COMPASS 2003.16 Build 69
RV A _
Halliburton -Sperry
HALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhiilips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Site: Kuparuk 3H Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Wellbore: 3H-34
Design: 3H-34(wp04)
Planned Survey
Measured Vertical Map Map
Depth Inclination Azimuth Depth TVDss +N/-S +El-W Northing Easting DLS Vert Section
(ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,953.00
7,195.42 50.00 30.00 6,019.60 5,953.00 3,099.34 1,935.45 6,003,819.35 500,591.36 0.00 3,654.02
a2
7,200.00 50.00 30.00 6,022.55 5,955.95 3,102.38 1,937.20 6,003,822.39 500,593.12 0.00 3,657.53
7,245.20 50.00 30.00 6,051.60 5,985.00 3,132.37 1,954.51 6,003,852.37 500,610.43 0.00 3,692.13
al
7,300.00 50.00 30.00 6,086.82 6,020.22 3,168.72 1,975.50 6,003,888.72 500,631.43 0.00 3,734.09
7,336.99 50.00 30.00 6,110.60 6,044.00 3,193.26 1,989.67 6,003,913.25 500,645.60 0.00 3,762.41
Miluveach
7,396.99 50.00 30.00 6,149.17 6,082.57 3,233.07 2,012.65 6,003,953.05 500,668.58 0.00 3,808.34
Targets
Target Name
-hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting
-Shape (°) (°) (ft) (ft) (ft) (ft) (ft)
3H-34(wp04)A3 0.00 0.00 5,997.60 3,076.64 1,922.34 6,003,796.65 500,578.25
-plan hits target center
-Circle(radius 250.00)
Casing Points
Measured Vertical Casing Hole
Depth Depth Diameter Diameter
(ft) (ft) Name (') (")
4,060.99 3,592.26 10 3/4" 10-3/4 13-1/2
7,396.99 6,149.17 4 1/2" 4-1/2 6-3/4
7,101.79 5,960.00 7 5/8" 7-5/8 9-7/8
9/6/2011 1:27:53PM Page 6 COMPASS 2003.16 Build 69
Halliburton -Sperry
I-IALLIBURTON Standard Proposal Report
Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well Plan:3H-34
Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Project: Kuparuk River Unit MD Reference: Planned D141 @ 66.60ft(D141(38.6+28))
Site: Kuparuk 3H Pad North Reference: True
Well: Plan:3H-34 Survey Calculation Method: Minimum Curvature
Weilbore: 3H-34
Design: 3H-34(wp04)
Formations
Measured Vertical Vertical Dip
Depth Depth Depth SS Dip Direction
(ft) (ft) ft Name Lithology (°) r)
1,275.15 1,236.60 K15 0.00
6,486.28 5,563.60 Top HRZ 0.00
7,336.99 6,110.60 Miluveach 0.00
1,138.49 1,112.60 T3 0.00
7,245.20 6,051.60 al 0.00
7,091.58 5,953.60 C4/C1 0.00
2,433.65 2,243.60 Ugnu B 0.00
7,101.16 5,959.60 B 0.00
6,764.08 5,743.60 Base HRZ/Upper Kalubik 0.00
6,950.82 5,864.60 Lower Kalubik/K-Mkr 0.00
2,871.66 2,606.60 West Sak B 0.00
4,001.07 3,542.60 Base Tabasco 0.00
2,800.47 2,547.60 West Sak D 0.00
3,669.25 3,267.60 Tabasco Sand 0.00
7,085.20 5,949.60 Top Kuparuk D 0.00
2,605.00 2,385.60 N Sand 0.00
1,761.91 1,675.60 Base Pfrost 0.00
7,195.42 6,019.60 a2 0.00
7,161.19 5,997.60 a3 0.00
3,316.91 2,975.60 Base West Sak 0.00
2,899.41 2,629.60 West Sak A 0.00
2,520.53 2,315.60 Ugnu A 0.00
2,261.10 2,100.60 Ugnu C 0.00
5,142.55 4,488.60 c35 0.00
7,154.96 5,993.60 a5 0.00
Plan Annotations
Measured Vertical Local Coordinates
Depth Depth +NI-S +EI•W
(ft) (ft) (ft) (ft) Comment
28.00 28.00 0.00 0.00 SHL:936'FNL,281'FWL-Sec12-T12N-R08E
4,061.00 3,592.27 1,411.19 965.42 Casing @ 4061'MD,3592'TVD:475'FSL,1248'FWL-Sec1-712N-R08E
7,101.79 5,960.00 3,036.55 1,899.81 Casing @ 7102'MD,5960'TVD:2100'FSL,2183'FWL-Sec1-T12N-R08E
7,161.19 5,997.60 3,076.64 1,922.34 Formation @ 7161'MD,5998'TVD:2140'FSL,2206'FWL-Sec1-T12N-R08E
7,396.99 6,149.17 3,233.07 2,012.65 TD @ 7397'MD,6149'TVD:2296'FSL,2296'FWL-Sec1-T12N-R08E
9/6/2011 1:27:53PM Page 7 COMPASS 2003.16 Build 69
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Page 1 of 1
Schwartz, Guy L (DOA)
From: Guo, Hai Bin [HaiBin.Guo@conocophillips.com]
Sent: Sunday, September 25, 2011 11:02 AM
To: Schwartz, Guy L(DOA)
Cc: Venhaus, Dan E; Galiunas, Elizabeth C
Subject: RE: 3H-34 Work Scope Fri) 2 i, 128
Guy,
As Liz said, 3H-34 will be a rotary set-up for CTD (coil tubing drilling) sidetrack. 3H-34 is expected to spud
in mid November of 2011 using Doyon 141 drilling rig. The subsequent CTD sidetrack in A sand is
planned in mid 2012 with Nabors CDR2 rig.
The rotary set-up work scope include: Drill and set 10-3/4" surface casing at+1-4,061' MD/3,592' TVD.
Drill and set 7-5/8" intermediate casing at +/-7,102' MD/5,960' TVD. Drill and set 4-1/2" production
casing at+/- 7,397' MD, 6,149' TVD. Run 3-1/2" tubing with GLM as the upper completion. Then 3H-34
will be suspended until the coil tubing drilling rig CDR2 moves on the well to drill laterals in mid 2012.
If any question, please let know.
Haibin Guo
Drilling Engineer
ConocoPhillips Alaska
Office: 907.265.1487
Cell: 907.943.0219
From: Galiunas,Elizabeth C
Sent: Friday,September 23,2011 2:25 PM
To: Guo,Hai Bin
Cc: Guy Schwartz(guy.schwartz@alaska.gov);Venhaus,Dan E
Subject: 3Hr34 Work Scope
Haibin,
Guy, with the AOGCC, requested an email with the work scope of 3H-34. I copied Guy, so you would
have his email.
Items to include information in your note to Guy on 3H-34:
1. 3H-34 is a being drilled for a coil tubing drilling sidetrack
2. CDR2 will move onto 3H-34 mid 2012
3. 3H-34 will be suspended until the coil tubing drilling rig moves on the well to drill laterals in the A sand.
Danny, Am I missing something?
Liz Galiunas
Supervising Drilling Engineer
ConocoPhillips Alaska
Office: 907.265.6247
Cell: 907.903.1200
9/26/2011
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TRANSMITTAL LETTER CHECKLIST
WELL NAME et/e. _3f(--37- (/
PTD# 7-i / f 2 �
/Development Service Exploratory Strati ra hic Test
Non-Conventional Well
FIELD: POOL: 4,y-;("< it.L �( � ,T,
Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS
WHAT (OPTIONS) TEXT FOR APPROVAL LETTER
APPLIES
MULTI LATERAL The permit is for a new wellbore segment of existing
well
(If last two digits in Permit No. ,API No. 50- - -
API number are
between 60-69) Production should continue to be reported as a function of the
original API number stated above.
PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name ( PH) and API number
(50- - - ) from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
assumes the liability of
any protest to the spacing exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the Commission must be in
SAMPLE no greater than 30' sample intervals from below the permafrost or
from where samples are first caught and 10' sample intervals
through target zones.
Non-Conventional Please note the following special condition of this permit:
Well production or production testing of coal bed methane is not allowed
for (name of well) until after (Company Name) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. (Company Name) must contact the
Commission to obtain advance approval of such water well testing
program.
Rev: 1/11/2008
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113
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Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplffy finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
FINAL WELL REPORT
MUDLOGGING DATA
3H-34
Approved by: Mike Werner Compiled by: Joshua Dubowski
James Foradas
Distribution: December 6, 2011 Date: November 21, 2011
3H-34
2
TABLE OF CONTENTS
1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 3
1.1 Equipment Summary ...................................................................................................................... 3
1.2 Crew................................................................................................................................................ 4
2 WELL DATA ........................................................................................................................................... 5
2.1 Well Summary................................................................................................................................. 5
2.2 Hole Data ........................................................................................................................................ 5
2.3 Well Synopsis ................................................................................................................................. 5
3 GEOLOGICAL DATA ............................................................................................................................. 6
3.1 Formation Tops: .............................................................................................................................. 6
3.2 Lithologic Descriptions/Stratigraphy ............................................................................................... 7
3.3 Connection Gas Summary: ........................................................................................................... 13
3.4 Trip/Wiper Gas Summary ............................................................................................................. 13
3.5 Sampling Program / Sample Dispatch .......................................................................................... 14
4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 15
4.1 Pore Pressure Gradient Evaluation .............................................................................................. 15
4.2 Quantitative Methods .................................................................................................................... 16
5 DRILLING DATA .................................................................................................................................. 17
5.1 Daily Activity.................................................................................................................................. 17
5.2 Survey Data .................................................................................................................................. 19
5.3 Bit Record ..................................................................................................................................... 22
5.4 Mud Record: ................................................................................................................................. 23
5.4.1 Intermediate Hole-LSND ....................................................................................................... 23
5.4.2 Production Hole MiSwaco LSND .......................................................................................... 24
6 DAILY REPORTS ................................................................................................................................ 25
Enclosures:
2”/100’ Formation Log (MD and TVD)
2”/100’ LWD Combo Log (MD and TVD)
2”/100’ Drilling Dynamics Log (MD and TVD)
2”/100’ Gas Ratio Log (MD and TVD)
Final Well Data on CD ROM
3H-34
3
1 MUDLOGGING EQUIPMENT & CREW
1.1 Equipment Summary
Parameter Equipment Type / Position Total
Downtime Comments
Ditch gas
QGM agitator and gas trap
Flame ionization total gas
and chromatography.
30 seconds
Circuit breaker would
occasionally pop in
the shaker room.
Hook Load, Weight on bit TOTCO WITS Feed 14 days WOB not accurate
Mud Flow In Derived from Pump Stroke
Rates* and Pump Output 0
Mud Flow Out TOTCO WITS Feed* 0
Mudlogging Unit computer
systems
HP Compaq Pentium 4
(x2: DML & RigWatch) 0
Mudlogging Unit Acromeg
box
In-unit data
collection/distribution center 0
Pit Volumes, Pit Gain/Loss TOTCO WITS Feed* 0
Pump Pressure TOTCO WITS Feed* 0
Pump Strokes TOTCO WITS Feed* 0
TOTCO Well Monitoring
Components
TOTCO computer networked
in mud logging unit* 0
Rate of Penetration
Derived from TOTCO depth
tracking components (block
height*)
10 days
Block height either
sporadic with readings
or non-existent
RPM TOTCO WITS Feed* 0
Torque TOTCO WITS Feed* 0
3H-34
4
1.2 Crew
Unit Number: ML056
Unit Type: Custom/Arctic/Steel
Mudloggers
Years of
Experien
ce
Days at
3H-34 Sample Catchers
Years of
Experie
nce
Days at
3H-34 Technician Days at
2L-306
Joshua Dubowski 4 16 Dickey Hudgins 1 15 Howard Lamp 2
James Foradas 5 16 Steve Franzen 4 15
3H-34
5
2 WELL DATA
2.1 Well Summary
Well: 3H-34 API Index #: 50-103-20643-00-00
Field: Kuparuk River Unit Surface Co-Ordinates: 1828945.304N
499471.889E
Borough: North Slope Primary Targets: Bottom of A1 sand
State: Alaska Primary Target Depth: 7397’MD/-6149’SSTVD
Rig Name / Type: Doyon 141/Arctic Triple Primary Actual Depth 7300’MD/6209’TVD
Spud Date: November 5, 2011 TD Depth: 7300’MD/6205’’SSTVD
TD Date: November 19, 2011 Ground Elevation: 36.4’
Days Drilling: 15 KB Elevation: 63.91’
Completion Status: Completed TD Formation: A1 Sand
Classification: Conventional Grassroots
Producer Days Evaluating: None
2.2 Hole Data
Hole
Section
Maximum Depth TD
Formation
Mud
Weight
(ppg)
Dev.
(oinc)
Casing/
Liner
Shoe Depth LOT
(ppg) MD
(ft)
TVD
(ft)
MD
(ft)
TVD
(ft)
Conductor Permafrost 0 16” 108 108
13-1/2” 3990’ 3528’ Base of
permafrost 9.4 35.41 10-3/4” 3948’ 3495’
9-7/8” 6902’ 5954’ Just above
Kuparuk 10.5 30.99 7-5/8” 6890’ 5947’ 16
6-3/4” 7300’ Base A1
sand 11.8 4-1/2” 7300’ 6204’ 18
2.3 Well Synopsis
KRU 3H-34 was drilled as a conventional grassroots producer targeting the Kuparuk a1, a2, and a3 sands.
The directional well was designed to explore and define reservoir presence and parameters. The well
encountered XXX’ feet of gross reservoir thickness at a depth of 7300’ TVDSS.
3H-34
6
3 GEOLOGICAL DATA
3.1 Formation Tops:
Zone or Horizon Prognosed Depth (ft) Actual Depth (ft)
MD TVD SS MD TVD SS
Tabasco Sand
(Base) 4001 3542 3475 4001 3537.30
C-52 4450 3914.99
C-51 4520 3976.33
C-50 4665 4103.50
C-40 4808 4228.03
C-35 5142 5055 4443.48
C-31 5900 5184.95
C-30 6248 5485.37
C-20 6582 5743.27
BASE HRZ 6764 6640 5784.19
KALUBIK 6764 6640 5784.19
K-1 MARKER 6950 6832 5910.32
KUPARUK RIVER 6970 6970 5961.91 5898.00
UNIT D 7085 6970 5961.91
UNIT C 7091 6978 5964.91 5901.00
C-4 INTERVAL 6978 5964.91
TD 6990’ 6007.74
7-5/8” Casing Shoe 7101 6891’ 6008.35
4-1/2” Production
Borehole
LOWER
CRETACEOUS
UNCONFORM
UNIT B 7101 5970.91 5907.00
UNIT A
A-5 INTERVAL 7154 6001.91 5938.00
A-3 INTERVAL 7164 6006.91 5943.00
A-2 INTERVAL 7195 6027.91 5964.00
A-1 INTERVAL 7245 6057.91 5994.00
MILUVEACH 7334 6113.91 6050.00
TD 7304
Note: Horizons and Depths provided by wellsite geologist.
3H-34
7
3.2 Lithologic Descriptions/Stratigraphy
TABASCO SAND TO TOP OF C52: (3990' MD / -2365’ TVDSS to 4450’ MD / -3533’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
291 0 134.8 59 0 23.6
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
4389’ 59 6675 486 9 0 0 0 0
Gas is generally low in this section with no notable drilled gas peaks.
This interval which includes portions of the Tabasco Sand lying in the Intermediate Section of the well bore. It
is composed of sandstone and siltstone, fining down to claystone.
The sandstones in this interval are characterized by medium to dark gray color; clear translucent and white
quartz grain frameworks; and very fine to medium grain size. They are moderately sorted with subangular to
subrounded angularity; and low to moderate sphericity. Some impact features and polish are evident on grain
surfaces. Most cuttings indicate the sandstones are matrix supported with silty to clayey matrix; and
unconsolidated to easily friable. Some greenstone grains were also observed in the sandstone framework.
Siltstones in the Tabasco are medium to dark gray; lumpy to gelatinous and mushy in consistency; pulverulent
to maleable tenacity; irregular to blocky fracture; amorphous massive to tabular cuttings habit; dull to earthy
luster becoming microsparkling in some more indurated specimens at high magnification. Most cuttings
indicate smooth to gritty texture; thin structure; with some very fine and fine sand grains observed in the
framework. The siltstone is typically interbedded and intergrading with sandstone
Claystone is typically medium gray to light gray in color with occasional greenish hues. It exhibits pulverulent
to crumbly tencity; slightly clumpy consistency; earthy to irregular fracture; has no discernable cuttings habit;
dull to earthy luster; and clayey to silty texture. Sample appears to be cut from massive claystone beds with
alternating laminae of silty sand. Loose sediment associated with this claystone is predominantly clear to
translucent quartz; lower to slightly upper very fine; well rounded; well sorted; and has good sphericity. A
minor amount of black carbonaceous shale, dark lithics and sandstone fragments are also typically detected in
the claystone samples.
3H-34
8
C52 TO TOP OF C51: (4450’ MD / -’ TVDSS to 4520’ MD / -3920’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
145 21 112.2 29 0 19.9
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
4454’ 29 3373 234 7
Gas is generally low in this section with no notable peaks.
This interval consists of the C-52 and is composed of claystone intergrading with some siltstone and sand.
The claystone is light medium gray to medium gray in color, and occasionally brownish gray. It is poorly
indurated; clumpy to mushy; has moderate to good cohesion; moderate adhesion; is pulverulent to crumbly;
and xhibits earthy to irregular fracture. Commonly there is no discernable cuttings habit but rare curved
cuttings were observed. The claystone has dull to earthy luster and clayey to slightly silty texture. Clear to
translucent quartz grain content increased through the interval. The sand associated with the claystones was
predominantly made up of lower very fine to ultra fine clear to translucent quartz grains. Clasts and flakes of
carbonaceous shale are also common but not abundant. Overall these samples appear to be representative
of massive beds of claystone, interbedded with very thin layers of sand and siltstone.
C51 TO C50: (4520’ MD / 3920’ TVDSS’ to 4665’ MD / -4162’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
163 38 118.1 62 0 21.5
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
4664’ 62 7069 414 35 0 0 0 0
Gas is generally low in this section with no notable peaks.
This interval consists of the C-51 and is composed of claystone intergrading with some siltstone and sand.
Calystone in this interval is colored medium gray to dark medium gray with brownish hues. Cuttings were
characterized by poor induration; clumpy to mushy consistency; pulverulent to somewhat crumbly tenacity;
earthy to irregular fracture; rare curved but generally amorphous cuttings habit; dull to earthy luster; clayey
to slightly silty texture. Overall the sample appears to represent massive claystone beds with alternating
laminae of siltstone and sand. Loose sediment in samples is predominantly clear to translucent quartz
thatg is lower to slightly upper very fine grained; well rounded; well sorted; and has good sphericity. Minor
amounts of black carbonaceous shale, dark lithics and sandstone fragments were also observed in
samples.
3H-34
9
C50 TO TOP C35: (4665’ MD / 4162’ TVDSS to 5055’ MD / -5005’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
193 24 109.7 150 2 50.6
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
5035’ 150 26845 1732 104 0 0 0 0
Gas is generally low in this section with no notable peaks.
This interval traverses the C50 and C-40 and is comprised of claystone and siltstone with minor sandstone.
The claystone in this section is dark medium gray to medium gray with occasional blackish hues;
unconsolidated to poorly consolidated; pulverulent; has earthy to irregular fracture; no discernable cuttings
habit; dull to earthy luster; and clayey to silty texture. Carbonaceous shale is abundant at the beginning of the
interval. It is flexible to brittle in tenacity. Trace amounts of calcite and poorly consolidated sandstone
consisting of clear to translucent quartz, dark lithics and carbonaceous shale is also present in the claystone
samples.
The siltstone in this section is colored dark medium gray to dark gray with blackish hues. The rocks are friable
to easily friable to rarely unconsolidated; exhibit moderate to poor induration; dense to crumbly and brittle to
occasionally pulverulent tenacity; planar to occasionally earthy to rarely blocky fracture; platy to tabular to
occasional elongated cuttings habit; and earthy to dull to occasionally resinous luster. Induration increases
through the interval as well as the variety of sediments associated with the siltstone cuttings. Coarse to fine
grained calcite is abundant in the sample (and may be in part an additive). Pyrite, carbonaceous shale and
sandstone clasts are also common.
Sandstone clasts are very fine grained and are firmly friable. They are commonly made up of translucent to
smokey gray quartz and trace amounts of dark lithics and carbonaceous shale. The quartz in sandstones is
sub angular to angular and has poor sphericity. Overall, the samples are slightly calcareous.
C35 TO BASE HRZ (TOP KALUBIK): (5055’ MD / 4162’ TVDSS to 6640’ MD / -5005’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
253 4 153.7 373 0 88.0
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
6507’ 373 1201 468 154 147 301 99 75
Gas increased twofold in this section, but with no notable peaks.
This interval includes C-35, C3, C-30 and C-20 and extends to the top of the HRX (the top of the Kalubik).
Rocks in this interval are predominantly claystone and siltstone in the upper part of the section and shale in
the lower part.
The claystone and siltstone in this section intergrade and are described as one rock. They appear medium
gray to dark gray with some darker hues in color. Cuttings exhibit soft to clumpy consistency; pulverulent to
3H-34
10
malleable tenacity; irregular to blocky fracture; amorphous to blocky cuttings habit; and earthy luster becoming
somewhat microsparkling at high magnification. Common dark lithics and dark fines are present in the matrix
and these mudrocks are calcareous. Overall, the claystone/siltstone samples represent massive beds of
claystone with very thin layers of siltstone, and thin laminar interbeds of coal. Shale as described below, and
occasional thin beds of dark gray very fine to fine grained thinly bedded sandstone are also associated with
the claystone and siltstone
Shale of dark brownish gray to black color is common especially in the lower part of the section. The shale is
stiff to mushy in consistency; brittle to crumbly in tenacity; has blocky to splintery fracture and thin wedge-like
platy to flaky cuttings habit. Resinous to waxy luster is common as is silty to very fine gritty texture. Th shale
is laminated with very fissile structure and interbedded with thin veins of yellowish white calcite; and thin
stringers of very fine to fine grained quartz sandstone containing traces of greenstone, and darker lithic
fragments. The shale is carbonaceous and calcareous in part, liberating trace amounts of oil when treated with
hydrochloric acid.
BASE HRZ (TOP KALUBIK) TO TOP OF KUPARUK RIVER UNIT B: (6640’ MD / 4162’ TVDSS to 6995’ MD
/ -5005’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
143 8 75.2 1282 9 99.7
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
6930’ 1282 135302 6963 1694 1080 997 422 0
Gas increased slightly on the average in this section, and there were notable peaks.
This interval extends from the HRZ through the Kalubik to the top of the Kuparuk River Unit B and is
comprised of shale and siltstone above the reservoir.
The shale is typically dark brownish gray to olive black in color. It exhibits stiff to mushy consistency;
pulverulent to mushy tenacity; blocky to planar fracture; medium to fine blocky cuttings habit; resinous to waxy
luster; and smooth to very fine gritty texture. It is commonly laminated with weak fissile structure evident in
some cuttings. Shale tends to crush rather than parting along laminae when probed. The shales are
carbonaceous in part and calcareous, liberating trace amounts of oil when treated with hydrochloric acid.
The section also contains some fine cuttings of a gray to light gray, very fine grain sandstone composed of
subangular moderately spheroidal quartz grains in a grain supported framework that is very soft to easily
friable.
Calcite is also common in the 6840 and 6870' MD samples. It is light yellowish white in color with reddish
brown hues; consistency is stiff; dense to crunchy tenacity; fine blocky fracture; wedge like to platy cuttings
habit; greasy to waxy luster; smooth texture; thin structure; and appears to occur as very thin lenses or veins
in the shale in this interval.
Siltstone is brownish gray with white hues; dense; has blocky fracture; tabular cuttings habit; earthy luster;
sucrosic to granular texture; and massive structure. It is non-calcareous and interbedded with more common
shale, mainly below the K-1 marker.
The samples below the K-1 to the TD of the intermediate section consisted of 90% mud additives making
detailed description difficult.
3H-34
11
TOP TO BASE OF RESERVOIR: (6995’ MD / -5005’ TVDSS – 7218’MD / -5103’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
196 9 57.4 490 80 118.2
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 Nc5
7101 308 19201 1190 439 98 136 83 69
7202 490 76928 5343 2659 363 772 106 99
Gasses in the reservoir zone were managed by increasing mudweight. They were slightly lower than further
upsection in the Kuparuk formation.
The reservoir zone is predominantly composed of sandstone associated with the Kuparuk River Units a5, a3,
a2, and a1.
The sandstone in the reservoir section is gray to brownish gray with light gray and yellowish hues. A quartz
framework composed of very fine to medium sized; fair to well sorted; subangular to rounded grains with
moderate to high sphericity is typical. Polish is a common surface feature on grains. In general the
sandstone is firm to unconsolidated; grain supported with common silty matrix and more rarely cement, both of
which are only slightly calcareous. The rocks are predominantly clear and gray quartz in composition but also
contain dark lithics; traces of glauconite and pyrite. Oil indicators include some oil staining and mild oil odor
when wet. The odor is stronger when cuttings air dry on a sample tray and some sandstone cuttings change
color to an oily black on once air dry. Mud additives including calcarb and a black additive are common in
samples, but the black color of the additive and that of black of the sandstone cuttings are distinguishable.
BASE OF RESERVOIR TO TD: (7218’ MD / 5103’ TVDSS – 7300’ MD / -5163’ TVDSS)
Drill Rate (ft/hr) Total Gas (units)
Maximum Minimum Average Maximum Minimum Average
76 22 40.6 186 66 103.7
Gas Peaks
Depth(MD) TG C1 C2 C3 iC4 nC4 iC5 nC5
7252’ 186 27992 1770 997 130 391 35 64
Gas decreased slightly on the average in this section due to the increase in mudweight. There were no
notable peaks, however connection gases and flowing gas was present even when the pumps were off.
At the base of the reservoir, siltstone and sandstone of the Miluveach member were encountered.
The sandstone is medium gray to light medium gray to brownish gray in color. It is upper fine to lower
medium grained with common lower fine to upper very fine grains. Moderate to high sphericity;
subrounded to subangular angularity; and well to moderate sorting are typical. The rocks are
predominantly unconsolidated; and grain supported with a silty matrix. The sand is quartz dominate with
most quartz grains being clear to translucent to occasionally smokey gray. Trace amounts of dark gray
lithics, carbonaceous shale and pyrite are also present in samples.
3H-34
12
Siltstone content increases through the interval. The siltstone has the same colors as the sandstone, is
commonly firmly friable; shows good induration; elongated to tabular cuttings habit; tough and dense to
somewhat crumbly tenacity; and resinous luster. Moderate to strong hydrocarbon odor is present and free
oil occurs in the samples especially if treated with HCl..
3H-34
13
3.3 Connection Gas Summary:
1 Unit = 200 ppm =0.05% Methane Equivalent
Depth (ft)
MD/TVD
Units
Above Background
7202’/6142’ 398u
7251’/6174’ 706u
3.4 Trip/Wiper Gas Summary
1 Unit = 200 ppm = 0.05% Methane Equivalent
Depth (ft)
MD/TVD
Trip to (ft)
MD/TVD
Max. Gas
(Units) Comments
SURFACE 7300’(TD) 2529
Tripping in with tubing. Background gas
was 140u. Constant high gas readings
whenever pumps where turned on with 12.0
ppg Mud
3H-34
14
3.5 Sampling Program / Sample Dispatch
Set Type/Purpose Frequency Interval Dispatched To
A Washed, screened and dried.
Set Owner: CPAI
50 ft
10 ft
3990’ to 6902’ MD
6902’ to 7300’ MD
CPAI, ABV 100
Bayview Warehouse
619 E. Ship Creek Ave.
Anchorage, AK 99501
Attn: D. Przywojski/M. McCracken
(907) 263-4859
B Washed, screened and dried.
Set Owner: CPAI/AOGCC
50 ft
10 ft
3990’ to 6902’ MD
6902’ to 7300’ MD
CPAI, ABV 100
Bayview Warehouse
619 E. Ship Creek Ave.
Anchorage, AK 99501
Attn: D. Przywojski/M. McCracken
(907) 263-4859
3H
-
3
4
15
4
P
R
E
S
S
U
R
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/
F
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M
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1
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(%
)
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)
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p
s
P
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P
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(
E
M
W
)
Trend Indicators
MD
(f
t
)
TV
D
(f
t
)
TV
D
S
S
(f
t
)
Mi
n
(p
p
g
)
Ma
x
(p
p
g
)
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e
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d
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5
0
C
L
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4
0
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T
S
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0
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1
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3
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9
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6
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%
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T
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48
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5
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T
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,
SH
2
0
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62
4
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3
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6
9
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5
9
9
5
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10
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3
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5
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7
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6
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Ab
b
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=
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a
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l
a
b
l
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BG
=
B
a
c
k
g
r
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d
G
a
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C
G
=
C
o
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=
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w
n
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m
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G
a
s
MW
=
M
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d
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e
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g
h
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3H-34
16
4.2 Quantitative Methods
The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective
circulating density (ECD), including increases in background gas (BG), appearance and trends of connection
gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic
data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered.
As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then
modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD,
and BG as measured by total ditch gas:
PPG = ECD – (0.6-((.001*TLGSU) + (0.05*DX)))
The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD,
and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is
dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when
estimating trends, as with DXC data, with data points in shale intervals.
3H-34
17
5 DRILLING DATA
5.1 Daily Activity
November 11, 2011
Mudlogging Unit rigged up and operational; gas sampling system calibrated and tested. Completed 10.75”
casing run; R/U cementers; Cement job successful; Nipple up BOP
November 12, 2011
Nippling up completed; Tested BOP’s; M/U BHA per DD; P/U BHA; Singled in with 5” DP to 976’; drill out DV
collar; continue singling into hole with 5” DP.
November 13, 2011
RIH to 3841’; tag cement; R/B one stand; casing test; top rams failed; decision to POOH; POOH; Rack Back
DP, HWDP and collars; L/D BHA; C/O rams & 4” valve; Service Rig; P/U BHA; RIH; Clean out to 3851’; Test
Casing to 2500psi 15:30 to 18:00 hrs; test successful; Drill out shoetrack/clean out rathole to 3990’; Drill out
20’ new hole; 4010’ MD reached at 23:25 hrs. Swapped out mud; FIT started
November 14, 2011
FIT completed; Drilled ahead per DD; currently at 5640’MD drilling ahead (some drilling data not available to
mudlogger, see failures below).
November 15, 2011
FIT completed; Drilled ahead per DD; currently at 6841’MD drilling ahead (some drilling data not available
to mudlogger, see failures below).
November 16, 2011
Drilled ahead per DD reaching TD at 0044 hrs at depth of 6902’/5954’ (some drilling data not available to
mudlogger, see failures below); Monitored Well; CBU 4 times (max BU Gas 794u); R/B 4 stands to 6657’;
RIH to TD; Monitored well; POOH with tight spots to 5083’; RIH to TD washing down 6843-6902’; CC &
CBU x 2; POOH; R/B 4 HWDP; L/D BHA; P/U and R/U Csg. Eqpmt. C/O, test Top rams
November 17, 2011
Finished R/U of 7.625” casing eqpmt.; Ran casing to 3946; CC& CBU (37u gas); Ran casing to 5413’;
CC& CBU (227u gas); completed casing run, landing at 6891’;CC& CBU (348u gas); R/D casing tools;
R/U cementing tools; cement; check floats; L/D cement head and landing jt.; Install packoff and test;
change upper rams To VBR and test; pump flush; shut in OA & bleed off; blow down cement line
November 18, 2011
Finished freeze protecting and testing lines; slip and cut drill line; R/U testing equipment; tested BOP’s;
R/D test equipment; Installed 7” wear ring; changed saver sub, bell guide and grabbers to 4”; L/D 5”
HWDP and DP and freeze protect; P/U and stand back 10 stands 4” DP; P/U BHA;begin TIH (part of BHA
in hole).
November 19, 2011
TIH continued, singling in to 100’ above float collar; tagged cement; CBU; tested casing to 3000psi; drilled
out shoe track, weighing up to MW 11.5; Drilled out shoe and 20’ new formation to 6922’; CBU; LOT to
minimum 16ppg EMW; Drilling ahead since 1550 hrs, midnight depth at 7067’MD.
November 20, 2011
Drilled ahead from 7067’MD, reaching TD at 7300’MD/6205’TVD at 7:47 hrs; POOH to 6873’; Wash and
Ream to 7300’; C/C and weigh up mud to 11.9 due to gas migration (CBU 892u); weighed up mud to 12.0;
3H-34
18
POOH from 7300-6870’; monitored well (static); POOH on pumps 5 stds. to 6400’; monitored well (static);
POOH on elevators R/B DP/HWDP; currently L/D BHA
November 21, 2011
L/D BHA; R/U to Run 4.5” liner; RIH with 4.5” liner and 4” DP; Trip gas from 728 to 6878’ MD ranged from
56 to 289u; CBU at 6878’MD (2529u max gas); RIH to 7300’; CBU (2117u max gas); C&C mud (337u max
gas); Stage pumps and R/U cementers; cemented per plan (28bbls of 15.8ppg cement); set packer; pulled
out top of liner; 2xCBU (135u max gas); shut down pumps and R/D cement line.
November 22, 2011
R/D cementers; POOH; Rigdown.
3H-34
19
5.2 Survey Data
Measured
Depth
(feet)
Inclination
(degrees))
Azimuth
(degrees)
Verticle
Section
(feet)
True
Vertical
Depth
(feet)
Latitude
N(+)/S(-)
(feet)
Departure
E(+)/W(-)
(feet)
Dogleg
Rate
(o/100ft)
27.51 0.00 0.00 0.00 27.51 0.00 0.00 0.00
109.00 0.34 195.65 -0.23 109.00 -0.23 -0.07 0.42
171.00 0.22 129.53 -0.42 171.00 -0.49 -0.02 0.52
262.00 1.90 70.68 0.73 261.98 -0.10 1.54 1.97
354.00 5.39 59.49 5.75 353.78 2.60 6.70 3.85
447.00 7.57 52.35 15.37 446.18 8.56 15.31 2.49
539.00 8.99 51.92 27.80 537.22 16.70 25.77 1.54
632.00 11.89 52.79 43.59 628.67 26.97 39.12 3.12
684.06 13.60 53.99 54.27 679.45 33.82 48.35 3.32
775.50 12.90 54.34 73.67 768.45 46.09 65.34 0.77
867.38 13.06 51.02 92.97 857.99 58.60 81.74 0.83
958.11 11.62 52.62 111.20 946.62 70.59 96.97 1.63
1052.00 12.48 46.62 129.86 1038.44 83.30 111.86 1.62
1145.70 19.61 41.01 155.22 1128.44 102.15 129.56 7.78
1177.78 21.08 40.46 166.24 1158.52 110.60 136.83 4.62
1237.97 22.82 40.80 188.48 1214.34 127.67 151.49 2.90
1330.82 23.24 41.60 224.33 1299.79 155.00 175.41 0.56
1423.68 23.15 41.51 260.39 1385.15 182.37 199.67 0.10
1516.39 21.36 42.99 294.93 1470.95 208.37 223.27 2.02
1609.57 23.48 42.74 329.83 1557.08 234.42 247.44 2.28
1703.17 23.43 42.09 366.46 1642.95 261.92 272.57 0.28
1793.79 25.89 41.57 403.71 1725.29 290.10 297.77 2.73
1879.65 32.14 42.57 444.67 1800.34 320.97 325.69 7.30
1977.71 34.54 41.81 497.70 1882.26 360.91 361.87 2.48
2071.20 35.90 35.39 551.20 1958.66 403.02 395.43 4.22
2164.75 36.29 31.20 606.27 2034.26 449.07 425.66 2.67
2259.29 36.24 29.54 662.16 2110.49 497.32 453.93 1.04
2352.08 34.91 30.31 716.11 2185.96 544.10 480.86 1.51
2442.49 34.44 30.36 767.52 2260.31 588.50 506.83 0.52
2535.64 35.47 28.61 820.84 2336.66 634.95 533.09 1.54
2627.67 35.28 29.33 874.04 2411.70 681.57 558.89 0.50
2722.37 34.11 30.81 927.92 2489.56 728.22 585.89 1.52
2815.01 36.51 26.36 981.33 2565.17 775.23 611.44 3.80
2907.58 35.55 25.97 1035.50 2640.03 824.10 635.45 1.07
2995.89 34.07 26.05 1085.65 2712.53 869.41 657.56 1.68
3090.95 34.25 30.94 1138.89 2791.21 916.28 683.01 2.89
3184.57 35.13 31.43 1192.17 2868.19 961.86 710.60 0.99
3277.93 34.46 31.76 1245.44 2944.85 1007.24 738.51 0.75
3370.20 37.22 30.58 1299.45 3019.64 1053.47 766.46 3.08
3460.85 37.31 30.88 1354.33 3091.79 1100.65 794.50 0.22
3553.40 33.19 30.44 1407.72 3167.35 1146.59 821.74 4.46
3H-34
20
Measured
Depth
(feet)
Inclination
(degrees))
Azimuth
(degrees)
Verticle
Section
(feet)
True
Vertical
Depth
(feet)
Latitude
N(+)/S(-)
(feet)
Departure
E(+)/W(-)
(feet)
Dogleg
Rate
(o/100ft)
3647.07 33.47 29.61 1459.16 3245.62 1191.15 847.50 0.57
3741.70 33.29 30.67 1511.19 3324.64 1236.17 873.64 0.64
3832.39 35.23 29.66 1562.22 3399.59 1280.31 899.28 2.23
3924.25 35.22 29.84 1615.16 3474.63 1326.31 925.57 0.11
3944.95 35.21 30.10 1627.09 3491.54 1336.65 931.53 0.73
3977.40 35.41 30.20 1645.84 3518.02 1352.87 940.95 0.63
4019.06 35.66 30.33 1670.04 3551.92 1373.78 953.16 0.63
4113.61 35.51 29.68 1725.03 3628.82 1421.43 980.67 0.43
4207.44 33.53 26.13 1778.05 3706.13 1468.38 1005.58 3.01
4297.19 31.02 27.14 1825.76 3782.01 1511.22 1027.05 2.86
4395.34 28.95 30.00 1874.71 3867.02 1554.31 1050.47 2.56
4485.19 29.29 30.72 1918.42 3945.51 1592.03 1072.57 0.54
4577.69 28.43 26.05 1962.95 4026.53 1631.27 1093.80 2.61
4670.66 29.51 25.16 2007.71 4107.87 1671.88 1113.26 1.25
4761.67 28.92 26.52 2051.87 4187.30 1711.86 1132.61 0.98
4850.33 30.21 26.64 2095.43 4264.42 1750.98 1152.19 1.46
4946.59 29.21 29.68 2143.01 4348.03 1793.04 1174.68 1.88
5036.13 28.08 30.45 2185.91 4426.61 1830.19 1196.18 1.33
5130.52 27.57 31.12 2229.96 4510.08 1868.04 1218.72 0.63
5218.37 27.06 31.59 2270.27 4588.14 1902.46 1239.70 0.63
5314.51 27.67 31.42 2314.46 4673.52 1940.14 1262.79 0.64
5407.98 28.95 31.97 2358.79 4755.81 1977.85 1286.08 1.40
5502.78 29.95 32.42 2405.40 4838.36 2017.30 1310.92 1.08
5595.62 29.01 29.74 2451.07 4919.18 2056.41 1334.51 1.74
5687.60 29.74 30.18 2496.16 4999.33 2095.50 1357.05 0.83
5777.90 28.91 28.14 2540.33 5078.06 2134.11 1378.60 1.44
5873.10 29.73 27.73 2586.83 5161.07 2175.29 1400.44 0.89
5958.98 28.06 30.25 2628.26 5236.26 2211.59 1420.52 2.41
6058.67 28.83 31.05 2675.73 5323.91 2252.44 1444.73 0.86
6149.40 31.77 30.76 2721.50 5402.24 2291.72 1468.24 3.24
6241.50 33.80 31.01 2771.36 5479.66 2334.51 1493.84 2.21
6333.41 36.81 30.21 2824.45 5554.66 2380.23 1520.87 3.31
6422.65 39.69 29.55 2879.66 5624.74 2428.13 1548.38 3.26
6521.02 42.26 29.16 2944.09 5699.00 2484.35 1580.00 2.63
6614.66 45.47 30.49 3008.93 5766.50 2540.62 1612.28 3.57
6704.57 48.64 30.45 3074.71 5827.75 2597.34 1645.65 3.53
6798.54 50.20 31.09 3146.06 5888.88 2658.66 1682.17 1.74
6831.00 50.83 31.03 3171.11 5909.52 2680.12 1695.09 1.96
6856.36 51.33 30.99 3190.84 5925.45 2697.03 1705.26 1.96
6880.55 51.33 30.99 3209.75 5940.57 2713.22 1714.98 0.00
6902.00 51.33 30.99 3217.94 5953.97 2727.58 1723.60 0.00
6923.04 52.75 31.58 3243.41 5966.46 2741.96 1732.56 2.24
6971.34 52.12 30.88 3281.69 5995.91 2774.69 1752.41 1.74
6974.59 52.08 30.83 3284.26 5997.91 2776.90 1753.73 1.74
3H-34
21
Measured
Depth
(feet)
Inclination
(degrees))
Azimuth
(degrees)
Verticle
Section
(feet)
True
Vertical
Depth
(feet)
Latitude
N(+)/S(-)
(feet)
Departure
E(+)/W(-)
(feet)
Dogleg
Rate
(o/100ft)
6985.96 51.93 30.67 3293.22 6004.91 2784.60 1758.31 1.74
7018.38 51.51 30.19 3318.65 6024.99 2806.54 1771.20 1.74
7035.89 51.33 29.84 3332.33 6035.91 2818.39 1778.04 1.86
7043.88 51.25 29.68 3338.57 6040.91 2823.81 1781.14 1.86
7075.73 50.93 29.04 3363.32 6060.91 2845.40 1793.29 1.86
7112.61 50.56 28.29 3391.83 6084.25 2870.46 1806.99 1.86
7124.64 50.38 28.12 3401.10 6091.91 2878.64 1811.38 1.86
7208.42 49.12 26.91 3464.84 6146.04 2935.34 1840.92 1.86
7211.28 49.14 26.93 3466.99 6147.91 2937.27 1841.90 0.81
7230.10 49.25 27.07 3481.19 6160.21 2949.97 1848.37 0.81
7258.46 49.42 27.27 3502.63 6178.69 2969.10 1858.19 0.81
7300.00 49.42 27.27 3534.07 6205.71 2997.14 1872.64 0.00
3H
-
3
4
22
5.
3
B
i
t
R
e
c
o
r
d
NB
=
N
e
w
B
i
t
BN
=
B
i
t
N
u
m
b
e
r
RR
=
R
e
-
R
u
n
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3H-34
25
6 DAILY REPORTS
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/11/11 Time: 00:01 Current Depth (MD): 3990
Current Depth
(TVD): 3528.37
Current
Operations: Nippling up
24 hr Footage (MD): 0
Drilling Parameters
ROP: Current: Max: Torque: Current: Max:
WOB: Current Max: RPM: Current: Max:
PP: Current: Max:
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 3990’MD/3528’TVD
MW: 9.2 FV: 78 PV: 19 YP: 28 FL: NC
Gels: 66/117/146 Sol: 7 pH: 11.0 Cl -: 300 Ca ++: 20
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: Max: Depth (MD/TVD):
Avg BG :
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
None
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
Lithologies: Current: Tabasco sand (logging to commence after drill out from surface casing)
Last 24 hrs: Tabasco sand
Operational Summary:
Mudlogging Unit rigged up and operational; gas sampling system calibrated and
tested. Completed 10.75” casing run; R/U cementers; Cement job successful;
Nipple up BOP
Calibrations: Chromatograph, THA.
Failures: None
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/12/11 Time: 00:01 Current Depth (MD): 3990
Current Depth
(TVD): 3528.37
Current
Operations: TIH
24 hr Footage (MD): 0
Drilling Parameters
ROP: Current: NA Max: NA Torque: Current: 0 Max: 3653
WOB: Current 29.9 Max: 29.9 RPM: Current: 0 Max: 23
PP: Current: 428 Max: 2023
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 3990’MD/3528’TVD 11/10/11 21:00 hrs
MW: 9.2 FV: 433 PV: 11 YP: 4 FL: NC
Gels: 1/3/3 Sol: - pH: 9.6 Cl -: 500 Ca ++: 60
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 0 Max: Depth (MD/TVD):
Avg BG :
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
None
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
Lithologies: Current: Tabasco sand (logging to commence after drill out from surface casing)
Last 24 hrs: Tabasco sand
Operational Summary: Nippling up completed; Tested BOP’s; M/U BHA per DD; P/U BHA; Singled in with
5” DP to 976’; drill out DV collar; continue singling into hole with 5” DP.
Calibrations: Chromatograph, THA.
Failures: None
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/13/11 Time: 00:01 Current Depth (MD): 4010’
Current Depth
(TVD): 3544’
Current
Operations: FIT started
24 hr Footage (MD): 20’
Drilling Parameters
ROP: Current: Max: Torque: Current: Max:
WOB: Current Max: RPM: Current: Max:
PP: Current: Max:
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 4010’MD – Full Midnight Mud Report not available
MW: 9.1 FV: 38 PV: YP: FL:
Gels: Sol: pH: Cl -: Ca ++:
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: Max: Depth (MD/TVD):
Avg BG : 0 21 4010’/3544’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
None
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
Lithologies: Current: Spot sample at 4010’: fine to medium grained quartz sand with minor siltstone.
Last 24 hrs: Tabasco sand
Operational Summary:
RIH to 3841’; tag cement; R/B one stand; casing test; top rams failed; decision to
POOH; POOH; Rack Back DP, HWDP and collars; L/D BHA; C/O rams & 4” valve;
Service Rig; P/U BHA; RIH; Clean out to 3851’; Test Casing to 2500psi 15:30 to
18:00 hrs; test successful; Drill out shoetrack/clean out rathole to 3990’; Drill out
20’ new hole; 4010’ MD reached at 23:25 hrs. Swapped out mud; FIT started.
Calibrations:
Failures: Totco Blockheight encoder failure affected Canrig RW/DML ops. Lag manually determined .
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/14/11 Time: 00:01 Current Depth (MD): 5640’
Current Depth
(TVD): 4958’
Current
Operations: Driling ahead
24 hr Footage (MD): 1630’
Drilling Parameters
ROP: Current: indet Max: indet Torque: Current: 9543 Max: 9317
WOB: Current indet Max: indet RPM: Current: 44 Max: 92
PP: Current: 2369 Max: 2618
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 5540’MD – Full Midnight Mud Report not available
MW: 9.6 FV: 43 PV: YP: FL:
Gels: Sol: pH: Cl -: Ca ++:
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 56 Max: Depth (MD/TVD):
Avg BG : 47 149 5100’/4483’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
NA
Connection
Gases minor C1 C2 C3 C4I C4N C5I C5N
None
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
5640’MD 63 5039 435 126
Lithologies: Current: Claystone, siltstone, and shale.
Last 24 hrs: Claystone and siltstone with minor sandstones and shale
Operational Summary: FIT completed; Drilled ahead per DD; currently at 5640’MD drilling ahead (some
drilling data not available to mudlogger, see failures below).
Calibrations:
Failures: Totco Blockheight encoder failure affected Canrig RW/DML ops. Lag manually determined to
catch cuttings samples and sample ditch gas using data provided by rig floor, DD and MWD.
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/15/11 Time: 00:01 Current Depth (MD): 6841’
Current Depth
(TVD): 5916’
Current
Operations: Drilling ahead
24 hr Footage (MD): 1201’
Drilling Parameters
ROP: Current: indet Max: indet Torque: Current: 10743 Max: 12160
WOB: Current indet Max: indet RPM: Current: 70 Max: 92
PP: Current: 3089 Max: 3089
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 5540’MD – Full Midnight Mud Report not available
MW: 9.6 FV: 43 PV: YP: FL:
Gels: Sol: pH: Cl -: Ca ++:
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 100 Max: Depth (MD/TVD):
Avg BG : 166 350 6513’/5766’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
NA
Connection
Gases minor C1 C2 C3 C4I C4N C5I C5N
None
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
6512’/5765’ 346 21711 1095 428 143 135 91 69
Lithologies: Current: Shale.
Last 24 hrs: Claystone and siltstone, transitioning to shale at 6460’ MD.
Operational Summary: FIT completed; Drilled ahead per DD; currently at 6841’MD drilling ahead (some
drilling data not available to mudlogger, see failures below).
Calibrations:
Failures:
Totco Blockheight encoder failure, and power surges causing frequent interrupts to gas trap
plug breaker affected Canrig RW/DML ops much of day. Lag manually determined to obtain
samples, using data provided by rig floor, DD and MWD.
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/16/11 Time: 00:01 Current Depth (MD): 6902’
Current Depth
(TVD): 5954’
Current
Operations: R/U Casing Equipment
24 hr Footage (MD): 61’
Drilling Parameters
ROP: Current: NA Max: indet Torque: Current: 0 Max: 11866
WOB: Current NAt Max: indet RPM: Current: 0 Max: 92
PP: Current: 7 Max: 3056
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 6902’MD – Full Midnight Mud Report not available
MW: 10.5 FV: 47 PV: YP: FL:
Gels: Sol: pH: Cl -: Ca ++:
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 0 Max: Depth (MD/TVD):
Avg BG : 101 119 6902’/5954’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
2 indet
Connection
Gases minor C1 C2 C3 C4I C4N C5I C5N
B/U Gas: 794u 6902’/5954’
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
6512’/5765’ 346 21711 1095 428 143 135 91 69
Lithologies: Current: NA
Last 24 hrs: Shale.
Operational Summary:
Drilled ahead per DD reaching TD at 0044 hrs at depth of 6902’/5954’ (some
drilling data not available to mudlogger, see failures below); Monitored Well; CBU
4 times (max BU Gas 794u); R/B 4 stands to 6657’; RIH to TD; Monitored well;
POOH with tight spots to 5083’; RIH to TD washing down 6843-6902’; CC & CBU x
2; POOH; R/B 4 HWDP; L/D BHA; P/U and R/U Csg. Eqpmt. C/O, test Top rams.
Calibrations: Gas Trap rerouted by rig electrician – trap and gas sampling system functioning normally
Failures: Totco Blockheight encoder failure affecting Canrig RW/DML ops. Hand plotting some data.
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Scott Heim
Date: 11/17/11 Time: 00:01 Current Depth (MD): 6902’
Current Depth
(TVD): 5954’
Current
Operations:
Freeze protection in
progress
24 hr Footage (MD): 0’
Drilling Parameters
ROP: Current: NA Max: Torque: Current: 0 Max:
WOB: Current NA Max: RPM: Current: 0 Max:
PP: Current: Max:
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 6902’MD – Full Midnight Mud Report not available
MW: FV: PV: YP: FL:
Gels: Sol: pH: Cl -: Ca ++:
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 0 Max: Depth (MD/TVD):
Avg BG :
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
33u
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
B/U Gas: 348u 6902’/5954’
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
Lithologies: Current: NA
Last 24 hrs: Shale.
Operational Summary:
Finished R/U of 7.625” casing eqpmt.; Ran casing to 3946; CC& CBU (37u gas);
Ran casing to 5413’; CC& CBU (227u gas); completed casing run, landing at
6891’;CC& CBU (348u gas); R/D casing tools; R/U cementing tools; cement; check
floats; L/D cement head and landing jt.; Install packoff and test; change upper
rams To VBR and test; pump flush; shut in OA & bleed off; blow down cement line
Calibrations:
Failures:
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Larry Hill
Date: 11/18/11 Time: 00:01 Current Depth (MD): 6902’
Current Depth
(TVD): 5954’
Current
Operations: TIH
24 hr Footage (MD): 0’
Drilling Parameters
ROP: Current: NA Max: Torque: Current: 0 Max: 19817
WOB: Current NA Max: RPM: Current: 0 Max: 23
PP: Current: 0 Max: 0
Lag: Strokes: Time: Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 6902’/5954’ (21:00hrs 11/16/2011)
MW: 10.7 FV: 50 PV: 11 YP: 22 FL: 4.2
Gels: 6/8/10 Sol: 12 pH: 8.8 Cl -: 450 Ca ++: 40
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 0 Max: Depth (MD/TVD):
Avg BG :
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
Lithologies: Current: NA
Last 24 hrs: Shale.
Operational Summary:
Finished freeze protecting and testing lines; slip and cut drill line; R/U testing
equipment; tested BOP’s; R/D test equipment; Installed 7” wear ring; changed
saver sub, bell guide and grabbers to 4”; L/D 5” HW DP and DP and freeze protect;
P/U and stand back 10 stands 4” DP; P/U BHA;begin TIH (part of BHA in hole).
Calibrations: Chromatograph, THA.
Failures: Power failure in DML unit caused by 480W Power Generator needing service (13:20-1400hrs)
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Larry Hill
Date: 11/19/11 Time: 00:01 Current Depth (MD): 7067’
Current Depth
(TVD): 6055’
Current
Operations: Slide drilling ahead
24 hr Footage (MD): 165’
Drilling Parameters
ROP: Current: 0 Max: 70 Torque: Current: 0 Max: 5959
WOB: Current 8.3 Max: 25.2 RPM: Current: 0 Max: 95
PP: Current: 2192 Max: 3082
Lag: Strokes: 2049 Time: 32.5 Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 7059’/6049’ (21:00hrs 11/18/2011)
MW: 11.45 FV: 48 PV: 14 YP: 26 FL: 3.8
Gels: 7/10/13 Sol: 16 pH: 10.3 Cl -: 350 Ca ++: 40
MW Change: Depth: 6902’MD From: 10.5 To: 11.5 Reason: Drill plan
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 10 Max: Depth (MD/TVD):
Avg BG : 31 1282 6930’/
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
0
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
26u 6967/ 3636 64
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
6930’/ 1282 135302 6963 1694 1080 997 422 0
7004’/ 66 12703 667 284 0 0 0 0
7031’/ 64 10386 512 214 0 0 0 0
Lithologies: Current: Sandstone with minor siltstone and shale (Kuparuk a3 sand)
Last 24 hrs: Siltstone and sandstone (drilled through Kuparuk D, C4/C1, B, and a5)
Operational Summary:
TIH continued, singling in to 100’ above float collar; tagged cement; CBU; tested
casing to 3000psi; drilled out shoe track, weighing up to MW 11.5; Drilled out shoe
and 20’ new formation to 6922’; CBU; LOT to minimum 16ppg EMW; Drilling
ahead since 1550 hrs, midnight depth at 7067’MD.
Calibrations: Chromatograph, THA.
Failures:
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Larry Hill
Date: 11/20/11 Time: 00:01 Current Depth (MD): 7300’
Current Depth
(TVD): 6205’
Current
Operations: L/D BHA
24 hr Footage (MD): 233’
Drilling Parameters
ROP: Current: 0 Max: 72 Torque: Current: 0 Max: 6467
WOB: Current 0 Max: 14.1 RPM: Current: 0 Max: 97
PP: Current: 0 Max: 2412
Lag: Strokes: 2116 Time: 33.5 Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 7300’/6205’ (21:00hrs 11/19/2011)
MW: 12.0 FV: 57 PV: 15 YP: 27 FL: 4.0
Gels: 9/14/18 Sol: 17 pH: 10.5 Cl -: 400 Ca ++: 40
MW Change: Depth: 7300’MD From: 11.8 To: 12.0 Reason: Gas
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 0 Max: Depth (MD/TVD):
Avg BG : 138 490 7202’/6142’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
Connection
Gases 7253’/6175’ C1 C2 C3 C4I C4N C5I C5N
706u
Gas Samples
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
7101’/6078’ 308 50144 3118 1471 193 402 0 0
7202’/6142’ 490 76928 5343 2659 364 772 106 99
Lithologies: Current: Sandstone and siltstone (Miluveach)
Last 24 hrs: Siltstone and sandstone (drilled through Kuparuk a3,a2,a1 into Miluveach)
Operational Summary:
Drilled ahead from 7067’MD, reaching TD at 7300’MD/6205’TVD at 7:47 hrs;
POOH to 6873’; Wash and Ream to 7300’; C/C and weigh up mud to 11.9 due to
gas migration (CBU 892u); weighed up mud to 12.0; POOH from 7300-6870’;
monitored well (static); POOH on pumps 5 stds. to 6400’; monitored well (static);
POOH on elevators R/B DP/HWDP; currently L/D BHA
Calibrations: Chromatograph, THA.
Failures:
Daily Cost: $2,970.00
ConocoPhillips Alaska Inc.
KRU 3H-34
Daily Report
Report for: Larry Hill
Date: 11/21/11 Time: 00:01 Current Depth (MD): 7300’
Current Depth
(TVD): 6205’
Current
Operations: R/D cementers
24 hr Footage (MD): 0’
Drilling Parameters
ROP: Current: NA Max: Torque: Current: 0 Max: 4751
WOB: Current 0 Max: 26.8 RPM: Current: 0 Max: 24
PP: Current: 0 Max:
Lag: Strokes: 1999 Time: 23.8 Surf-Surf: Strokes: Time:
ECD: Current: Max:
Mud Properties @ 7300’/6205’ (21:00hrs 11/19/2011)
MW: 12.0 FV: 47 PV: 16 YP: 26 FL: 3.8
Gels: 7/11/12 Sol: 17 pH: 10.5 Cl -: 300 Ca ++: 40
MW Change: Depth: From: To: Reason:
Mud Loss event: Depth: Volume:
Gas Data
Ditch Gas: Current: 67 Max: Depth (MD/TVD):
Avg BG : 130 2529 6885’/5947’
Gas Events
Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N
Trip Gas
130U avg. 7300’/6205’
Connection
Gases C1 C2 C3 C4I C4N C5I C5N
Gas Samples (#1 and 2 CBU during RIH with 4.5” liner and 4” DP; #3 CBU after cementing and setting packer)
No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N
1 6885’/5947’ 2529
2 7300’/6205’ 2117
3 7298’/6204’ 135
Lithologies: Current: TD in sandstone and siltstone (Miluveach)
Last 24 hrs: Drilling completed
Operational Summary:
L/D BHA; R/U to Run 4.5” liner; RIH with 4.5” liner and 4” DP; Trip gas from 728 to
6878’ MD ranged from 56 to 289u; CBU at 6878’MD (2529u max gas); RIH to
7300’; CBU (2117u max gas); C&C mud (337u max gas); Stage pumps and R/U
cementers; cemented per plan (28bbls of 15.8ppg cement); set packer; pulled out
top of liner; 2xCBU (135u max gas); shut down pumps and R/D cement line.
Calibrations: Chromatograph, THA.
Failures:
Daily Cost: $2,870.00
• 24-1:2A-
2.1 Z6 I
4"12--ztZ6I
Sperry-Sun Drilling Services
LIS Scan Utility
$Revision: 3 $
LisLib $Revision: 4 $
Thu Jan 19 14:31:05 2012 REC E%V ED
Reel Header JAN 2 3 2012
Service name LISTPE
Date 12/01/19 /�OG'`C,C
Origin STS /"�
Reel Name UNKNOWN
Continuation Number 01
Previous Reel Name UNKNOWN
Comments STS LIS Writing Library. Scientific Technical Services
Tape Header
Service name LISTPE
Date 12/01/19
Origin STS
Tape Name UNKNOWN
Continuation Number 01
Previous Tape Name UNKNOWN
Comments STS LIS Writing Library. Scientific Technical Services
Physical EOF
Comment Record '?i,',1, ,
TAPE HEADER
Kuparuk Kuparuk
MWD/MAD LOGS
WELL NAME: 3H-34
API NUMBER: 501032064300
OPERATOR: ConocoPhillips (Alaska) , Inc
LOGGING COMPANY: Sperry Drilling
TAPE CREATION DATE: 19-JAN-12
JOB DATA
MWD RUN 2 MWD RUN 4 MWD RUN 5
JOB NUMBER: -MW-0008472254 -MW-0008472254 -MW-0008472254
LOGGING ENGINEER: ALEX BERGERO BRETT HARVEY JOSEPH LYMAN
OPERATOR WITNESS: GUY WHITLOCK GUY WHITLOCK GRANVI RIZEK
SURFACE LOCATION
SECTION: 12
TOWNSHIP: 12N
RANGE: 8E
FNL: 936
FSL:
FEL:
FWL: 281
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR: 63.91
GROUND LEVEL: 36.40
WELL CASING RECORD
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING 13.500 30.000 106.0
2ND STRING 9.875 10.750 3977.0
3RD STRING 6.750 7.625 6890.0
PRODUCTION STRING
411
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED. THESE
DEPTHS ARE BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) .
3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED.
4. MWD RUNS 2, 4, 5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY
(DGR) UTIL-
IZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC
WAVE RESIS-
TIVITY-PHASE 4 (EWR-P4) , DRILLSTRING DYNAMICS SENSOR
(DDSr) , AND
PRESSURE WHILE DRILLING (PWD) . MWD RUN 5 ALSO
INCLUDED COMPENSATED
THERMAL NEUTRON POROSITY (CTN) AND AZIMUTHAL
LITHO-DENSITY (ALD) .
NO PROGRESS WAS MADE ON MWD RUN 3.
5. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER
PHONE CONVERSATION
BETWEEN MIKE WERNER (CPAI) AND BUSTER BRYANT (SD) ON
18 JANUARY 2012.
6. MWD RUNS 1-5 REPRESENT WELL 3H-34 WITH API#
50-103-20643-00. THIS
WELL REACHED A TOTALDEPTH (TD) OF 7300'MD/6205'TVD.
MNEMONICS CURVE DESCRIPTION
ROPA AVERAGE RATE OF PENETRATION
DGRC DGR COMBINED GAMMA RAY
R09P 9 INCH PHASE RESISTIVITY
R15P 15 INCH PHASE RESISTIVITY
R27P 27 INCH PHASE RESISTIVITY
R39P 39 INCH PHASE RESISTIVITY
EWXT EWR FORMATION EXPOSURE TIME
TNPS CTN POROSITY - SANDSTONE
TNFA CTN FAR AVERAGE COUNT RATE
TNNA CTN NEAR AVERAGE COUNT RATE
ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY
ADCL/ALDCLC ALD LCRB DENSITY CORRECTION
APEL/ALPELC ALD LCRB Pe FACTOR
AHSI/ALHSI ALD HOLE SIZE INDICATOR
ALRP/ALRPM ALD RPM (TO HIGHLIGHT SLIDE INTERVALS)
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: FIXED AT 6.75 INCHES
MUD WEIGHT: 11.0 - 11.55 PPG
WHOLE MUD CHLORIDES: 300 - 400 PPM CL
FORMATION WATER SALINITY: 14,545 PPM CL
FLUID DENSITY: 1.0 G/CC
MATRIX DENSITY: 2. 65 G/CC
LITHOLOGY: SANDSTONE
ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A
WINDOW OF
0.6 FT, EXCEPT FOR SROP AND SGRC. THESE CURVES ARE
SMOOTHED WITH A
1.1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES.
File Header
Service name STSLIB.001
Service Sub Level Name
Version Number 1 0 0
Date of Generation. . • • •
12/09 4111
Maximum Physical Record. .65O535
File Type• • • • • • • " STSLIB.000
Previous File Name. . . . . .
Comment Record
FILE HEADER 1
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and c1ed curves; all bit runs merged.
DEPTH INCREMENT: 5000
FILE SUMMARY TOP DEPTH
PBU TOOL CODE START DEPTH STOP
RPS 156.0 .0
7245.0
RPS 156.0 7245.0
RPX 156.0 7245.0
RPD 156.0 7238.0
GR 163.5 7245.0
FET 215.5
ROP 216.5 7300.0730.0
NPHI 6880.0 100
DRHO 6880.0 7225.5
NCNT 6880.0 7210.07225.5
CALN 6880.0 725,5
FCNT 6880.0 7225.500
PEF 6880.0 7225.5
RHOB 6880.0
$
BASELINE CURVE FOR SHIFTS: ----
CURVE SHIFT DATA (MEASURED-DEPT )
EQUIVALENT UNSHIFTED DEPTH -----
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO MERGE TOP MERGE
0,BAS
E
156.0
MWD 4 3990.0 6902.0
3990
MWD 5 6902.0 7300.0
MWD
$
# MERGED MAIN PASS.
REMARKS: $
#
Data Format Specification Record
Data Record Type• • • • • • • • " ' •
Data Specification Block Type. . . . .Down
Logging Direction. . . . . • • • : : : : ,Down
Optical log depth units. •
t
Point. . . . .
Data Reference • • " ' . . . .Undefined60 .lIN
Frame Spacing. . . . . . . . • • • • • • ' • ,Undefined
Max frames per record. . • • • • • :- 999
Absent value. . . . . . . . . . . . . . . •
Depth Units. . • • • • • • • • ' • " „0
Datum Specification Block sub-type•
Code Offset Channel
Name Service Order Units Size Nsam RR68 0
DEPT FT 4 G/CC 4 1 68 4 2
DRHRHOB MWD 4 8
G/CC 1 68 12 4
CALN MWD IN 4 1 68 162 5
PEFMWD B/E 4 1 68 26 5
GR
MWD API 4 1 68 240 7
FET MWD HR 4 1 68 8
MWD 4 28
OHMM 1 68 32 8
RPX MWD OHMM 4 1 68
RPS MWD
RPM MWD
OHMM 1 1 68 36 10 •
RPD MWD OHMM 4 1 68 40 11
ROP MWD FPH 4 1 68 44 12
FCNT MWD CP30 4 1 68 48 13
NCNT MWD CP30 4 1 68 52 14
NPHI MWD PU 4 1 68 56 15
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 156 7300 3728 14289 156 7300
RHOB MWD G/CC 1.92 3.094 2.41422 692 6880 7225.5
DRHO MWD G/CC -0.828 0.358 0.0779985 692 6880 7225.5
CALN MWD IN 5. 63 7.75 6.74433 427 6880 7225.5
PEF MWD B/E 2.07 15.41 6.51555 692 6880 7225.5
GR MWD API 17.91 461.63 91.1505 14150 163.5 7238
FET MWD HR 0.25 121.8 1.94119 13936 215.5 7245
RPX MWD OHMM 1.02 847.36 9.4906 14055 156 7245
RPS MWD OHMM 0.37 2000 24.4762 14055 156 7245
RPM MWD OHMM 1.06 2000 63.8055 14055 156 7245
RPD MWD OHMM 1.11 2000 92.4393 14055 156 7245
ROP MWD FPH 0.58 763.73 123.9 14168 216.5 7300
FCNT MWD CP30 114.67 674 .29 309.58 661 6880 7210
NCNT MWD CP30 14808.8 31999.8 21199.9 661 6880 7210
NPHI MWD PU 21.67 53.84 33.7897 661 6880 7210
First Reading For Entire File 156
Last Reading For Entire File 7300
File Trailer
Service name STSLIB.001
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Next File Name STSLIB.002
Physical EOF
File Header
Service name STSLIB.002
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Previous File Name STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
R27P 156.0 3930.5
R39P 156.0 3930.5
R15P 156.0 3930.5
RO9P 156.0 3930.5
•
DGRC 163.• 3938.5 •
EWXT 215.5 3930.5
ROPA 216.5 3990.0
LOG HEADER DATA
DATE LOGGED: 08-NOV-11
SOFTWARE
SURFACE SOFTWARE VERSION: INSITE
DOWNHOLE SOFTWARE VERSION: 88.47
DATA TYPE (MEMORY OR REAL-TIME) : Memory
TD DRILLER (FT) : 3990.0
TOP LOG INTERVAL (FT) : 215.0
BOTTOM LOG INTERVAL (FT) : 3990.0
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE: .2
MAXIMUM ANGLE: 34.2
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN) : 13.500
DRILLER'S CASING DEPTH (FT) : 106.0
BOREHOLE CONDITIONS
MUD TYPE: spud
MUD DENSITY (LB/G) : 8.80
MUD VISCOSITY (S) : 200.0
MUD PH: 11.1
MUD CHLORIDES (PPM) : 250
FLUID LOSS (C3) : 100.0
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT) : 2.500 65.0
MUD AT MAX CIRCULATING TERMPERATURE: 1.630 103.4
MUD FILTRATE AT MT: 1.850 65.0
MUD CAKE AT MT: 2.700 65.0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
Data Format Specification Record
Data Record Type 0
Data Specification Block Type 0
Logging Direction Down
Optical log depth units Feet
Data Reference Point Undefined
Frame Spacing 60 .1IN
Max frames per record Undefined
Absent value -999
Depth Units
Datum Specification Block sub-type. . .0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD020 API 4 1 68 4 2
FET MWD020 HR 4 1 68 8 3
RPX MWD020 OHMM 4 1 68 12 4
RPS MWD020 OHMM 4 1 68 16 5
RPM MWD020 OHMM 4 1 68 20 6
RPD MWD020 OHMM 4 1 68 24 7
ROP MWD020 FPH 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 156 3990 2073 7669 156 3990
GR MWD020 API 17. 91 136. 64 72.5858 7551 163.5 3938.5
FET MWD020 HR 0.26 3.26 1.08361 7431 215.5 3930.5
RPX MWD020 OHMM 1.44 208 14.5827 7550 156 3930.5
RPS MWD020 OHMM 1.58 2000 42.2845 7550 156 3930.5
RPM MWD020 OHMM 1. 65 2000 112.454 7550 156 3930.5
RPD MWD020 OHMM 1.77 2000 163.794 7550 156 3930.5
ROP MWD020 FPH 0.58 763.73 126. 654 7548 216.5 3990
First Reading For Entire File 156
Last Reading For Entire File 3990
File Trailer
Service name STSLIB.002
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Next File Name STSLIB.003
Physical EOF
File Header
Service name STSLIB.003
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Previous File Name STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 4
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
DGRC 3939.0 6854.0
R15P 3960.0 6846.5
R27P 3960.0 6846.5
R09P 3960.0 6846.5
EWXT 3960.0 6846.5
R39P 3960.0 6846.5
ROPA 3990.5 6902.0
$
LOG HEADER DATA
DATE LOGGED: 15-NOV-11
•
SOFTWARE •
SURFACE SOFTWARE VERSION: INSITE
DOWNHOLE SOFTWARE VERSION: 88.47
DATA TYPE (MEMORY OR REAL-TIME) : Memory
TD DRILLER (FT) : 6902.0
TOP LOG INTERVAL (FT) : 3990.0
BOTTOM LOG INTERVAL (FT) : 6902.0
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE: 35.5
MAXIMUM ANGLE: 51.3
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN) : 9.875
DRILLER'S CASING DEPTH (FT) : 3977.0
BOREHOLE CONDITIONS
MUD TYPE: polymer
MUD DENSITY (LB/G) : 10.00
MUD VISCOSITY (S) : 44 .0
MUD PH: 10.0
MUD CHLORIDES (PPM) : 300
FLUID LOSS (C3) : 6.0
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT) : 2.900 60.0
MUD AT MAX CIRCULATING TERMPERATURE: 1.400 132.0
MUD FILTRATE AT MT: 2.200 60.0
MUD CAKE AT MT: 1.800 60.0
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
Data Format Specification Record
Data Record Type 0
Data Specification Block Type 0
Logging Direction Down
Optical log depth units Feet
Data Reference Point Undefined
Frame Spacing 60 .1IN
Max frames per record Undefined
•
Absent value -999
Depth Units
Datum Specification Block sub-type. . .0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD040 API 4 1 68 4 2
FET MWD040 HR 4 1 68 8 3
RPX MWD040 OHMM 4 1 68 12 4
RPS MWD040 OHMM 4 1 68 16 5
RPM MWD040 OHMM 4 1 68 20 6
RPD MWD040 OHMM 4 1 68 24 7
ROP MWD040 FPH 4 1 68 28 8
•
• 4
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 3939 6902 5420.5 5927 3939 6902
GR MWD040 API 41.21 461.63 115.674 5831 3939 6854
FET MWD040 HR 0.25 121.8 2.27848 5774 3960 6846.5
RPX MWD040 OHMM 1.02 14 .53 3.03699 5774 3960 6846.5
RPS MWD040 OHMM 0.37 12.9 3.10404 5774 3960 6846.5
RPM MWD040 OHMM 1.06 28.01 3.16462 5774 3960 6846.5
RPD MWD040 OHMM 1.11 2000 6.5736 5774 3960 6846.5
ROP MWD040 FPH 4.04 291.44 130.364 5824 3990.5 6902
First Reading For Entire File 3939
Last Reading For Entire File 6902
File Trailer
Service name STSLIB.003
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Next File Name STSLIB.004
Physical EOF
File Header
Service name STSLIB.004
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Previous File Name STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 5
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
DGRC 6854.5 7238.0
TNPS 6880.0 7210.0
R27P 6880.0 7245.0
EWXT 6880.0 7245.0
R15P 6880.0 7245.0
R39P 6880.0 7245.0
RO9P 6880.0 7245.0
APEL 6880.0 7225.5
ADCL 6880.0 7225.5
AHSI 6880.0 7225.5
TNFA 6880.0 7210.0
ACDL 6880.0 7225.5
TNNA 6880.0 7210.0
ROPA 6902.5 7300.0
$
LOG HEADER DATA
DATE LOGGED: 19-NOV-11
INSITE
111
SOFTWARE 88 47
III
SURFACE SOFTWARE VERSION: Memory
DOWNHOLE SOFTWARE VERSION: 7.4
DATA TYPE (MEMORY OR REAL-TIME) : 6902.0
300.0
TD DRILLER N ( 7300.092
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) : 49.4
HOLE INCLINATION (DEG 52 8
MINIMUM ANGLE:
MAXIMUM ANGLE:
# TOOL NUMBER
TOOL STRING (TOTO BOOL TYPE
VENNCDOR TOOL CODE DUAL GAMMA RAY
EWRDGR ELECTROMAG. RESIS. 4
CTN COMP THERMAL NEUTRON
ALD Azimuthal Litho-Dens
$
# 6,750
BOREHOLE AND CASING DATA 6890.0
OPEN HOLE BIT SIZE (IN) :
DRILLER'S CASING DEPTH (FT) :
# ploymer
BOREHOLE CONDITIONS 11.40
MUD TYPE:ENS48.0
MUD DENSITY (LB/G) : 9 6
MUD VISCOSITY (S) : 400.
MUD PH: 3,0
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) : AT TEMPERATURE (DEGF) 1 .0 70.0
RESISTIVITY TY (SURE990 141.4
MUD AT MEXSCRRCULA TEMPERATURE (MT) :
1 990 70.014
MUD MAX 1.980. 0 70.0
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN) :
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS: $
#
Data Format Specification Record 0
Data Record Type. . . . . . . . . . . . . . . . . .
Data Specification Block Type... .Down
0
Logging Direction. . . . . • • Feet
Optical log depth units. . . . . . . .. . .Feetfined
Data Reference Point. 60 Undefined
Frame Spacing. . . . . . . . . . . . . . . . . . . . .
. . . . .Undefined
Max frames per record. • : -999
Absent value. . . . . . . . . . .
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type• • .0
Units Size Nsam Rep Code Offset Channel
Name Service Order FT 4 1 68 4 2
DEPT G/CC 4 1 68 8 3
RHOB MWD050 G/CC 4 1 68 12 4
CAL
DRHO MWD050 IN 4 1 68 16 5
PEF MWD050 B/E 4 1 68 26 6
GEF MWD050 API 4 1 68 240 6
FET MWD050 HR 4 1 68
MWD050
IIIIII
RPX MWD050 OHMM 4 1 68 28 8
RPS MWD050 OHMM 4 1 68 32 9
RPM MWD050 OHMM 4 1 68 36 10
RPD MWD050 OHMM 4 1 68 40 11
ROP MWD050 FPH 4 1 68 44 12
FCNT MWD050 CP30 4 1 68 48 13
NCNT MWD050 CP30 4 1 68 52 14
NPHI MWD050 PU 4 1 68 56 15
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 6854 .5 7300 7077.25 892 6854.5 7300
RHOB MWD050 G/CC 1.92 3.094 2.41422 692 6880 7225.5
DRHO MWD050 G/CC -0.828 0.358 0.0779985 692 6880 7225.5
CALN MWD050 IN 5. 63 7.75 6.74433 427 6880 7225.5
PEF MWD050 B/E 2.07 15.41 6.51555 692 6880 7225.5
GR MWD050 API 37.37 145.86 87.4861 768 6854.5 7238
FET MWD050 HR 0. 91 87.95 7. 99481 731 6880 7245
RPX MWD050 OHMM 1.88 847.36 7.87297 731 6880 7245
RPS MWD050 OHMM 2.05 1043.12 9.36044 731 6880 7245
RPM MWD050 OHMM 2.09 2000 40.3318 731 6880 7245
RPD MWD050 OHMM 2.1 1943.69 33.6965 731 6880 7245
ROP MWD050 FPH 1.49 198.86 50.5014 796 6902.5 7300
FONT MWD050 CP30 114.67 674.29 309.58 661 6880 7210
NCNT MWD050 CP30 14808.8 31999.8 21199. 9 661 6880 7210
NPHI MWD050 PU 21. 67 53.84 33.7897 661 6880 7210
First Reading For Entire File 6854 .5
Last Reading For Entire File 7300
File Trailer
Service name STSLIB.004
Service Sub Level Name
Version Number 1 0 0
Date of Generation 12/01/19
Maximum Physical Record65535
File Type LO
Next File Name STSLIB.005
Physical EOF
Tape Trailer
Service name LISTPE
Date 12/01/19
Origin STS
Tape Name UNKNOWN
Continuation Number 01
Next Tape Name UNKNOWN
Comments STS LIS Writing Library. Scientific Technical Services
Reel Trailer
Service name LISTPE
Date 12/01/19
Origin STS
Reel Name UNKNOWN
Continuation Number 01
Next Reel Name UNKNOWN
Comments STS LIS Writing Library. Scientific Technical Services
Physical EOF
r
♦ • 410
Physical EOF
End Of LIS File
