Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout204-237C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-11023_23058_KRU_1D-28_MapsProductionProfile_Transmittal.docx
DELIVERABLE DISCRIPTION
Ticket # Field Well # API # Log Description Log Date
23058 KRU 1D-28 50-029-23237-00 MAPS Production Profile 23-Nov-24
DELIVERED TO
Company & Address
DIGITAL FILE
# of Copies
LOG PRINTS
# of Prints
CD’s
# of Copies
1
AOGCC
Attn: Natural Resources Technician
333 W. 7th Ave., Suite 100
Anchorage, Ak. 99501-3539
Delivered By: CPAI Sharefile
______________________________ _____________________________________
Date received Signature
______________________________ ______________________________________
PLEASE RETURN COPY VIA EMAIL TO:
DIANE.WILLIAMS@READCASEDHOLE.COM
READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503
PHONE: (907)245-8951
E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM
204-237
T39850
12/10/2024
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.12.10 08:36:17
-09'00'
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program
Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Offset for Marcit Trtmnt
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 14672'feet None feet
true vertical 6633' feet None feet
Effective Depth measured 14672'feet 10933'feet
true vertical 6633' feet 6568' feet
Perforation depth Measured depth
True Vertical depth
Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10968' MD 6572' TVD
Packers and SSSV (type, measured and true vertical depth) 10933' MD
N/A
6568' TVD
N/A
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13a.
Prior to well operation:
Subsequent to operation:
13b. Pools active after work: Kuparuk River Oil Pool
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Authorized Name and
Digital Signature with Date: Contact Name:
Contact Email:
Authorized Title: Contact Phone:
6581' 4421'
Burst Collapse
11034'
3749'
Casing
6584'
4-1/2"
11065'
14672' 6633'
6547'
153'Conductor
Surface
Intermediate
20"
10-3/4"
118'
measured
TVD
7-5/8"
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
204-237
50-029-23237-00-00
P.O. Box 100360
Anchorage, AK 99510
3. Address:
ConocoPhillips Alaska, Inc.
N/A
5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work:
ADL0025650, ADL0028243
Kuparuk River Field/ Kuparuk River Oil Pool
KRU 1D-28
Plugs
Junk measured
Length
measured
true vertical
Packer
Representative Daily Average Production or Injection Data
Casing Pressure Tubing Pressure
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
~
Gas-Mcf
MD
~
Size
153'
~ ~~
~~
~
Production
N/A
Sr Pet Eng: Sr Pet Geo: Sr Res Eng:
WINJ WAG
Water-BblOil-Bbl
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
N/A
Packer: Baker ZXP Liner Top Packer
SSSV: None
Allen Eschete
allen.eschete@conocophillips.com
(907) 265-6558Interventions Engineer
Slotted Liner: 11162-11873', 12315-13514', 14269-14639'
Slotted Liner: 6592-6625', 6628-6616', 6641-6635'
Offset Injector remains Shut-in
Slotted Liner
Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov
By Grace Christianson at 3:08 pm, May 22, 2023
Digitally signed by Allen Eschete
DN: CN=Allen Eschete, E=Allen.Eschete@
ConocoPhillips.com
Reason: I have reviewed this document
Location:
Date: 2023.05.22 10:31:16-08'00'
Foxit PDF Editor Version: 12.0.1
Allen Eschete
DTTMSTART JOBTYP SUMMARYOPS
3/29/2023 SUPPORT
OTHER
OPERATIONS
PULLED 4.5" SLIP STOP & CHOKE @ 541' RKB; BRUSH n' FLUSHED D-NIPPLE @
11,008' RKB; SET 2.25" CA-2 PLUG @ 11,008' RKB. READY FOR E-LINE IPROF.ttttt
4/1/2023 SUPPORT
OTHER
OPERATIONS
PERFORM INJECTION PROFILE. WELL INJECTING AT 6250 BWPD, 900 PSI.
PERFORM UP/DOWN PASS AND VERIFY ALL INJECTION IS GOING INTO LATERAL 2,
CONFIRMED PLUG IN LATERAL 1 IS HOLDING (NO INJECTION INTO L1).
JOB COMPLETE
4/19/2023 SUPPORT
OTHER
OPERATIONS
Continue rigging up, spotting up equipment. Stage liquid and dry product. Troubleshoot
generator issues. Perform safety / operations pre job walk down. Freeze protect 1D-11 flow
line and 1D-10 tubing. Fill tank farm tanks with seawater from process line. Flood SNF
mixing unit. Calibrate gel mixer, verify skid function. Performed step rate test, start 4000
ppm Marcit non cross linked, SNF skid unable to deliver mixed product at rate to LRS pump.
Troubleshoot issue. 200 bbl polymer injected. No cross linker. - In Progress-
4/20/2023 SUPPORT
OTHER
OPERATIONS
Continue to troubleshoot SNF skid mixing issues. Replace automated mixing tank valve,
adjust marcit mother solution concentration and dilution pump ratios, trial changes on non
cross linked gel, begin to pump stage #1, 4000 ppm Marcit polymer with Chromic Acetate
cross linker @ maximum rate, skid performance limited, of 3 bpm. Totals - 3,199 bbls 4k gel
stage one, WH 1,225 psi. - In Progress-
4/21/2023 SUPPORT
OTHER
OPERATIONS
Pumped 3,650 bbls, 4k ppm Marcit gel in stage #1. Well head climbed from 1,225 to 1,300
psi, total gel pumped in stage one is 6,849 bbls. Main generator powering NSF skid started
shutting down @ 22:00. Trouble shoot and restart multiple times. 1D-28 and 1D-41 floc tests
both negative. - In Progress-
4/22/2023 SUPPORT
OTHER
OPERATIONS
Continue to troubleshoot generator with nights field mechanic with no success. Flush and
FP X-linked Marcit from surface with 120 bbl's diesel. Request replacement generator.
Wrap and heat additional surface lines. Spot replacement generator and stand by for
electricians to disconnect / reconnect. Electricians determined replacement generator not
compatible with bolt up connections. Stand by for days field mechanic. Mechanic restarted
generator, test run for 1 hr, energize NSF skid, test run. On line with 4000 ppm Marcit to
establish injection. Pumped remaining 4000 ppm cross linked stage #1 - 7,639 bbls. Start
pumping stage two, 5000 ppm Marcit 1D-28 and 1D-41 floc tests both negative. Total stage
#2, 2,063 bbls - total vol. treatment 9,701 bbls - In Progress-
4/23/2023 SUPPORT
OTHER
OPERATIONS
Pumped 4,230 bbls, 5k ppm Marcit gel in stage #2. Well head climbed from 1,475 to 1,550
psi. 1D-28 and 1D-41 floc tests both negative. Total stage #2, 6,293 bbls - total vol.
treatment 13,931 bbls - In Progress-
4/24/2023 SUPPORT
OTHER
OPERATIONS
Completed stage two, 7,804 bbls 5000 ppm Marcit. Completed stage three, 798 bbls 6000
ppm Marcit. Started stage four, 8000 ppm Marcit. Total stage #4, 1,293 bbls - total vol.
treatment 17,534 bbls. Well head built from 1,325 psi to 1,450 psi during stage #4. 1D-28
and 1D-41 floc tests both negative. - In Progress-
4/25/2023 SUPPORT
OTHER
OPERATIONS
Completed stage four, 2,108 bbls total of 8,000 ppm Marcit. Started final stage five, 10,000
ppm Marcit. Total stage #5, 1,205 bbls - total vol. treatment 19,553 bbls. Well head built
from 1,500 psi to 1,700 psi during stage #4 & 5. 1D-28 and 1D-41 floc tests both negative. -
In Progress-
1D-11 Marcit Treatment
4/26/2023 SUPPORT
OTHER
OPERATIONS
Pumped stage five, 10,000 ppm Marcit to completion. Flushed Marcit with 147 bbls water
and 35 bbls diesel FP. Contacted PE to flag well 'do not inject'. FP seawater header flow
line on 1D-10 with 10 bbls MetOH. Vac our surface lines, upright tanks and SNF skid. Job
complete. Begin rig down of treating equipment.
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag: CTMD 13,145.0 1D-28 3/4/2020 rogerba
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Replaced OV in kind 1D-28 6/6/2022 zembaej
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Cement bridge plug pushed to bottom 1/15/17, 13,522' MD 1/15/2017 pproven
NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0.1/8/2009 sheskin
NOTE: TREE: CC/WF/5M, 6"" OTIS QUICK CONNECT 1/23/2005 TRIPLWJ
NOTE: MULTI-LATERAL WELL - MAIN LEG COMPLETED 1/22/2005 TRIPLWJ
NOTE: LEFT OPEN HOLE BEHIND SLOTTED LINER, AND MAY PRODUCE 1/22/2005 TRIPLWJ
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
CONDUCTOR 20 19.12 35.0 153.0 153.0 91.50 H-40 WELDED
SURFACE 10 3/4 9.79 34.1 6,580.8 4,421.0 45.50 L-80 BTC
PRODUCTION 7 5/8 6.87 31.7 11,065.4 6,584.5 29.70 L-80 BTC MOD
SLOTTED LINER 4 1/2 3.96 10,922.5 14,672.0 6,632.9 12.60 L-80 IBT-M
WINDOW 4 1/2 3.99 11,168.0 11,173.0 6,592.6
Tubing Strings: string max indicates LONGEST segment of string
Top (ftKB)
34.0
Set Depth
10,968.2
Set Depth
6,572.4
String Ma
3 1/2
Tubing Description
Tubing Completion Upper
Wt (lb/ft)
9.30
Grade
L-80
Top Connection
EUE 8rd
ID (in)
2.99
Completion Details: excludes tubing, pup, space out, thread, RKB...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal
ID (in)
34.0 34.0 0.00 HANGER 11.000 FMC TC-1A-EMS, 11" x 4-1/2" w/ 2
- .25" Ports, 4-1/2 IBT Top and
Bottom
3.870
3,192.7 2,520.3 53.61 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO
W/DMY RK Latch 3,161-MD / 2,500-
TVD SN: 047AH05
Camco MMG 2.915
5,331.5 3,724.5 55.97 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO
W/DMY RK Latch 5,287-MD / 3,700
-TVD SN: 045AH05
Camco MMG 2.915
7,022.7 4,666.4 56.79 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO
W/DMY RK Latch 6,991-MD / 4,650
-TVD SN: 043AH05
Camco MMG 2.915
8,278.1 5,375.7 56.19 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO w/
DMY RK Latch 8,232-MD / 5,350-
TVD SN: 017AH07
Camco MMG 2.915
9,251.0 5,926.9 59.50 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO w/
SOV RKP Latch 9,198-MD / 5,900-
TVD SN: 016AH07
Camco MMG 2.915
9,972.8 6,317.9 59.26 GAS LIFT 5.968 MANDREL,3 1/2X1-
1/2",MMG,EUE8RMOD,CAMCO w/
DMY RK Latch 9,940-MD / 6,300-
TVD SN: 042AH05
Camco MMG 2.867
10,033.5 6,347.1 63.31 NIPPLE 3.500 NIPPLE,LANDING,3
1/2",DS,2.812",EUE8RMOD SN:
3651-21
Camco 2.813
DS
2.813
10,928.1 6,566.8 81.91 XO Enlarging 4.500 3-1/2" EUE Box x 4-1/2" IBT Pin 2.980
10,929.6 6,567.0 81.90 LOCATOR 4.500 GBH-22 Locator Sub Baker GBH-22
192-47
3.870
10,930.0 6,567.1 81.89 SEAL ASSY 4.720 192-47 Seal Assembly Baker 192-47 3.870
Mandrel Inserts : excludes pulled inserts
Top (ftKB)
Top (TVD)
(ftKB)
Top
Incl (°)
St
ati
on
No
/S Serv
Valve
Type
Latch
Type
OD
(in)
TRO Run
(psi)Run Date Com Make Model
Port
Size (in)
3,192.7 2,520.3 53.61 1 GAS LIFT GLV RK 1 1/2 1,233.0 1/10/2017 0.188
5,331.5 3,724.5 55.97 2 GAS LIFT GLV RK 1 1/2 1,225.0 1/10/2017 0.188
7,022.7 4,666.4 56.79 3 GAS LIFT GLV RK 1 1/2 1,224.0 1/10/2017 0.188
8,278.1 5,375.7 56.19 4 GAS LIFT GLV RK 1 1/2 1,219.0 1/10/2017 0.188
9,251.0 5,926.9 59.50 5 GAS LIFT OV RK 1 1/2 0.0 6/6/2022 0.250
9,972.8 6,317.9 59.26 6 GAS LIFT DMY RK 1 1/2 0.0 1/2/2017 0.000
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
10,922.5 6,566.0 81.95 TIE BACK 6.390 BAKER TIE BACK SLEEVE 5.750
10,933.5 6,567.6 81.87 PACKER 6.550 BAKER ZXP LINER TOP
APCKER
4.960
10,941.5 6,568.7 81.91 NIPPLE 6.050 BAKER 'RS' PACKOFF NIPPLE 4.875
11,110.1 6,588.0 86.11 Swell Packer 6.300 Swell Packer 3.958
11,880.9 6,624.5 91.10 Swell Packer 6.300 Swell Packer 3.958
12,287.4 6,627.6 89.07 Swell Packer 6.300 Swell Packer 3.958
13,522.2 6,616.1 87.70 Swell Packer 6.300 Swell Packer 3.958
14,243.0 6,640.3 88.04 Swell Packer 6.300 Swell Packer 3.958
1D-28, 5/16/2023 4:36:08 PM
Vertical schematic (actual)
SLOTTED LINER; 10,922.5-
14,672.0
SLOTS; 14,269.0-14,639.0
SLOTS; 12,315.0-13,514.0
SLOTS; 11,162.0-11,873.0
WINDOW; 11,168.0-11,173.0
PRODUCTION; 31.7-11,065.4
GAS LIFT; 9,972.8
GAS LIFT; 9,251.0
GAS LIFT; 8,278.0
GAS LIFT; 7,022.7
SURFACE; 34.1-6,580.7
GAS LIFT; 5,331.5
GAS LIFT; 3,192.7
CONDUCTOR; 35.0-153.0
HANGER; 34.0
KUP PROD
KB-Grd (ft)
37.46
RR Date
1/26/2005
Other Elev
1D-28
...
TD
Act Btm (ftKB)
14,672.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292323700
Wellbore Status
PROD
Max Angle & MD
Incl (°)
93.27
MD (ftKB)
14,599.15
WELLNAME WELLBORE
Annotation
Last WO:
End Date
1/2/2017
H2S (ppm)
12
Date
1/28/2016
Comment
SSSV: NONE
Perforations & Slots
Top (ftKB)Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB)Linked Zone Date
Shot
Dens
(shots/ft)Type Com
11,162.0 11,873.0 6,591.6 6,624.7 C-4, C-3, 1D-28 1/23/2005 8.0 SLOTS Slotted Liner alternating
w/solid pipe & swell packers
12,315.0 13,514.0 6,627.9 6,615.8 C-4, C-3, UNIT
D, 1D-28
1/23/2005 8.0 SLOTS
14,269.0 14,639.0 6,640.9 6,634.8 C-4, 1D-28 1/23/2005 8.0 SLOTS
1D-28, 5/16/2023 4:36:11 PM
Vertical schematic (actual)
SLOTTED LINER; 10,922.5-
14,672.0
SLOTS; 14,269.0-14,639.0
SLOTS; 12,315.0-13,514.0
SLOTS; 11,162.0-11,873.0
WINDOW; 11,168.0-11,173.0
PRODUCTION; 31.7-11,065.4
GAS LIFT; 9,972.8
GAS LIFT; 9,251.0
GAS LIFT; 8,278.0
GAS LIFT; 7,022.7
SURFACE; 34.1-6,580.7
GAS LIFT; 5,331.5
GAS LIFT; 3,192.7
CONDUCTOR; 35.0-153.0
HANGER; 34.0
KUP PROD 1D-28
...
WELLNAME WELLBORE
Last Tag
Annotation Depth (ftKB)Wellbore End Date Last Mod By
Last Tag:1D-28L1 TRIPLWJ
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: GLV C/O 1D-28L1 12/3/2015 lehallf
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/8/2009 lmosbor
NOTE: MULTI-LATERAL WELL - 1D-28 COMPLETED, 1D28-L1 ABANDONED, LEFT OPEN HOLE 1/23/2005 TRIPLWJ
Casing Strings
Csg Des OD (in)ID (in)Top (ftKB)
Set Depth
(ftKB)
Set Depth
(TVD) (ftKB)Wt/Len (lb/ft)Grade Top Thread
OPEN HOLE -
Abandoned
4 1/2 4.50 11,170.0 11,663.0
Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe...
Top (ftKB)
Top (TVD)
(ftKB)
Top Incl
(°)Item Des
OD
Nominal
(in)Com Make Model
Nominal ID
(in)
11,170.0 6,591.8 86.98 OPEN HOLE 4.500 4.500
1D-28L1, 5/16/2023 4:36:13 PM
Vertical schematic (actual)
OPEN HOLE - Abandoned;
11,170.0-11,663.0
WINDOW; 11,168.0-11,173.0
SLOTTED LINER; 10,922.5-
14,672.0
SLOTS; 11,162.0-11,873.0
PRODUCTION; 31.7-11,065.4
GAS LIFT; 9,972.8
GAS LIFT; 9,251.0
GAS LIFT; 8,278.0
GAS LIFT; 7,022.7
SURFACE; 34.1-6,580.7
GAS LIFT; 5,331.5
GAS LIFT; 3,192.7
CONDUCTOR; 35.0-153.0
HANGER; 34.0
KUP PROD
KB-Grd (ft)
37.46
RR Date
1/26/2005
Other Elev
1D-28L1
...
TD
Act Btm (ftKB)
11,663.0
Well Attributes
Field Name
KUPARUK RIVER UNIT
Wellbore API/UWI
500292323760
Wellbore Status
PROD
Max Angle & MD
Incl (°)
90.25
MD (ftKB)
11,484.02
WELLNAME WELLBORE
Annotation
Last WO:
End DateH2S (ppm)
12
Date
1/28/2016
Comment
SSSV: NIPPLE
RECEIVED
STATE OF ALASKA
ALlit OIL AND GAS CONSERVATION COMMI ION FEB 0 2 2017
REPORT OF SUNDRY WELL OPERATIONS �;
1.Operations Abandon E Plug Perforations r Fracture Stimulate E Pull Tubing F p�'ra ns Shutdown E
Performed: Suspend E Perforate E Other Stimulate Alter Casing fl Change Approved Program I'
Plug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r r
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development F Exploratory fl 204-237
3.Address: 6.API Number:
P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23237-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 25650,ADL 28243 KRU 1D-28
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
N/A Kuparuk River Field/Kuparuk River Oil Pool
11.Present Well Condition Summary:
Total Depth measured 14672 feet Plugs(measured) 13522
true vertical 6633 feet Junk(measured) None
Effective Depth measured 13522 feet Packer(measured) 10933
true vertical 6616 feet (true vertical) 6568
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 118 20 153 153
SURFACE 6547 10 3/4 6581 4421
PRODUCTION 11034 7 5/8 11065 6584
SLOTTED LINER 3750 4 1/2 14672 6633
Op
AR 08Zr
Perforation depth: Measured depth: 11162-11873, 12315- 13514, 14269-14639 �`-
True Vertical Depth: 6592-6625,6628-6616,6641 -6634
Tubing(size,grade,MD,and ND) 3.5, L-80, 10968 MD,6572 TVD
Packers&SSSV(type,MD,and ND) PACKER=BAKER ZXP LINER TOP PACKER @ 10933 MD and 6568 TVD
SSSV: NONE
12.Stimulation or cement squeeze summary:
Intervals treated(measured): N/A
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 200 1390 2220 900 190
Subsequent to operation 330 1900 2250 1230 230
14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations F Exploratory E Development F Service E Stratigraphic E
Copies of Logs and Surveys Run 16.Well Status after work: Oil F Gas E WDSPL
Printed and Electronic Fracture Stimulation Data E GSTOR E WINJ r WAG I— GINJ SUSP -.� SPLUG I-
17.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:
N/A
Contact Sara Heskin @ 265-1027 Email Sara.Heskin@conocophillips.com
Printed Name Sara Heskin Title Assoc. Wells Engineer
Signature �---- Phone:265-1027 Date
K 1-.. �Z—�Q—?_cit
"24
Form 10-404 Revised 5/2015 it 1—c— / / l RBDMS lV F 3 - 3 2017 Submit Original Only
,Af .2-461'7
•
•
Operations Summary (with Timelog Depths)
1D-28
Conoco ill ps
Alaska,
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End.Depth(ftK8)
12/29/2016 12/29/2016 3.00 MIRU MOVE MOB P Pull away motor complex,pipe shed,
00:00 03:00 unplug pits.Pull pump room and pits
away and continue to work on pre-skid
check list.
12/29/2016 12/29/2016 1.00 MIRU MOVE MOB P Skid rig floor to move position.Pick up
03:00 04:00 rear stompers.
12/29/2016 12/29/2016 1.00 MIRU MOVE MOB P Pull sub off of 1D-37.Lower,position
04:00 05:00 and raise.
12/29/2016 12/29/2016 4.50 MIRU MOVE MOB P Spot sub over 1D-28
05:00 09:30
12/29/2016 12/29/2016 2.50 MIRU MOVE MOB P Set down stompers and apply
09:30 12:00 pressure.Skid rig floor to drilling
position.
12/29/2016 12/29/2016 3.00 MIRU MOVE MOB P Spot pit,pump,and MTR complex.
12:00 15:00 Spot pipe shed and rock washer.
12/29/2016 12/29/2016 1.50 MIRU MOVE RURD P Lower beaver slide,install cuttings
15:00 16:30 tank,handi-berm around cellar and
cuttings tank,lower stairways and
prep landing.Plug in electrical
interconnects.
12/29/2016 12/29/2016 4.00 MIRU MOVE RURD P Continue plug in electrical
16:30 20:30 interconnects.Swap PWR from cold
starts to Hi-line.MU service lines
between complexes and on sub.Roll
steam and install traps. Install plugs in
centrifugal pumps,raise skate rail and
test.Hold pre-spud meeting.
12/29/2016 12/29/2016 2.25 MIRU WHDBOP MPSP P RU to test BPV.Test BPV to 1000 psi
20:30 22:45 for 10 charted min.Unload 290 bbls of
seawater to the pits.Rig accepted at
20:30 HRS
12/29/2016 12/30/2016 1.25 MIRU WHDBOP NUND P Bleed hanger void.MT and ND tree.
22:45 00:00
12/30/2016 12/30/2016 1.50 MIRU WHDBOP NUND P Nipple down and remove tree from
00:00 01:30 cellar. Pull adapter spool.Install
blanking plug. Inspect hanger threads.
12/30/2016 12/30/2016 4.00 MIRU WHDBOP SVRG P Install and torque spacer spool
01:30 05:30 assembly.Begin BOP between well
maintenance.
12/30/2016 12/30/2016 2.50 MIRU WHDBOP NUND P NU 13-5/8 5M BOPE stack. Install
05:30 08:00 choke and kill lines,install air boot
system on Annular and install Flow
riser.
12/30/2016 12/30/2016 1.50 MIRU WHDBOP RURD P Grease choke manifold. PU test joint
08:00 09:30 and MU cross over's. MU TIW Valve
and Dart assembly. Fill and stack
with water to purge the air from
system.
12/30/2016 12/30/2016 2.50 MIRU WHDBOP BOPE P Test annular,upper and lower pipe
09:30 12:00 rams with 4.5"test joint.Test rig floor
kill,mezz kill,manual kill and HCR kill.
Floor valves.Test blinds.Upper IBOP.
Perform accumulator test to 250/3500
psi.Test waived by AOGCC
representative,Louis Grimaldi.Notice
given 12/28/16 at 7:18 am.
12/30/2016 12/30/2016 0.25 MIRU WHDBOP BOPE P Test blinds,choke valve 3,4,&6 to
12:00 12:15 250/3500 for 5/5 charted min(good).
Page 1/4 Report Printed: 1/31/2017
• •
Operations Summary (with Timelog Depths)
0,14
1D-28
ConocoPhillips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Our(hr).; Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/30/2016 12/30/2016 1.75 MIRU WHDBOP BOPE P Pull 4-1/2"test jt. Install 3-1/2"test jt.
12:15 14:00 Test annular,HCR choke,lower IBOP.
Witnessed unusual pump up time.
Trouble shoot where the leak is.
12/30/2016 12/30/2016 1.75 MIRU WHDBOP BOPE T Blow down top drive.Pull test jt,
14:00 15:45 ACME XO and inspect threads.
Reinstall and pull test jt,ACME XO
and 4-1/2"NS-CT X ACME blanking
plug.Rebuild blanking plug(replacing
ball).
12/30/2016 12/30/2016 0.25 MIRU WHDBOP BOPE T Reinstall 3-1/2"test jt with XO and
15:45 16:00 blanking plug.
12/30/2016 12/30/2016 2.00 MIRU WHDBOP WAIT T Phase 3.Blow down choke,kill,mud
16:00 18:00 lines and test pump lines.
12/30/2016 12/30/2016 1.50 MIRU WHDBOP BOPE P Phase conditions downgrade to phase
18:00 19:30 2.Fill lines and test annular,upper
and lower 3-1/2"X 6"VBR's, HCR and
manual choke&lower IBOP to
250/3500 psi for 5/5 charted minutes.
12/30/2016 12/30/2016 1.00 MIRU WHDBOP RURD P Pull and rigdown 3-1/2"test't with XO
1
19:30 20:30 and blanking plug.Blow down test
equipment.
12/30/2016 12/30/2016 0.50 MIRU RPCOMP MPSP P PUT bar and pull BPV.
20:30 21:00
12/30/2016 12/30/2016 0.50 COMPZN RPCOMP RURD P PU 4-1/2"landing jt.MU XO and head
21:00 21:30 pin.
12/30/2016 12/31/2016 2.50 COMPZN RPCOMP CIRC P PJSM.Circulate out freeze protect.
21:30 00:00 Pump 180 bbls of heated seawater at
2.5 BPM(49 psi).Increase rate and
pump 100 bbls at 6 BPM(673 psi).
Pump 25 bbls spacer pill at 5 BPM
(268 psi).Chase pill with 350 bbls of
seawater at 6 BPM.ICP=673 psi,
FCP=617 psi.
12/31/2016 12/31/2016 1.50 COMPZN RPCOMP RURD P Blow down lines,pick up handling
00:00 01:30 equipment for POOH.MU landing jt to
hanger and crew into top drive.
12/31/2016 12/31/2016 1.25 COMPZN RPCOMP OWFF P Open IA.Monitor well for flow.
01:30 02:45 Observe diesel and flow.Line up to
flow back tank and allow to bleed off.
Well static.Back out LDS.
12/31/2016 12/31/2016 0.75 COMPZN RPCOMP PULL P Pull up to 273K,work string down to
02:45 03:30 tag hanger in bowl.Work string up to
273K and pull free.Steady UW=
168K.Break out and lay down tubing
hanger.
12/31/2016 12/31/2016 1.25 COMPZN RPCOMP CIRC P Pump btms up.Divert 20 bbls of diesel
03:30 04:45 to rock washer. Pumped 360 bbls of
seawater,400 psi(363 GPM).Blow
down top drive.
12/31/2016 12/31/2016 1.00 COMPZN RPCOMP RURD T Change out power tongs and tong
04:45 05:45 power unit.
12/31/2016 12/31/2016 1.50 COMPZN RPCOMP PULL P Trip out of the hole laying down 4-1/2", 10,972.0 10,253.0
05:45 07:15 12.6#, L-80 IBTM from 10972'to
10253'. UW=160K.
12/31/2016 12/31/2016 0.50 COMPZN RPCOMP RURD T Change out the hydraulic motor on
07:15 07:45 GBR's power tongs
Page 2/4 Report Printed: 1/31/2017
• •
' Operations Summary (with Timelog Depths)
Jut
0
1D-28
ConocoPhillips
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr)" Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
12/31/2016 12/31/2016 4.25 COMPZN RPCOMP PULL P Trip out of the hole laying down 4- 10,253.0 5,932.0
07:45 12:00 1/2", 12.6#,L-80 IBTM from
10253'(UW=150K)to 5932'(UW=
102K/DW=81K)
12/31/2016 12/31/2016 7.50 COMPZN RPCOMP PULL P Finish laying down 4-1/2", 12.6#,L-80 5,932.0 0.0
12:00 19:30 IBTM from 5932'to surface while
monitoring displacement in the trip
tank.Holes were observed in jts#174
¨.Jts 79-88&128, 129, 131,
133, 168, 174&175 were set aside
for corrosion evaluation&pictures
placed in the well file.
12/31/2016 12/31/2016 1.00 COMPZN RPCOMP RURD P RD GBR tubing equipment.Clean and
19:30 20:30 clear rig floor.
12/31/2016 1/1/2017 3.50 COMPZN WELLPR PULD P Install mouse hole.Lay down 32
20:30 00:00 stands of XT-39 4"DP via mouse
hole.
1/1/2017 1/1/2017 4.00 COMPZN WELLPR -PULD P Lay down 4"Drill Pipe Via mouse hole
00:00 04:00 -33 stands/99 joints
1/1/2017 1/1/2017 0.50 COMPZN WELLPR SVRG P Grease Crown and blocks. Service
04:00 04:30 Top Drive
1/1/2017 1/1/2017 1.50 COMPZN RPCOMP RURD P RU for running 3-1/2 Tubing,change
04:30 06:00 over slips,elevators and Tubing
Tongs.
1/1/2017 1/1/2017 13.50 COMPZN RPCOMP PUTB P MU and RIH w/Baker 192-47 Seal 0.0 10,941.0
06:00 19:30 Assembly and Continue to follow as
per run order to 10941'MD.Monitor
displacement via trip tank.UW=
113K,DW=79K.Make up torque=
2240 FT/LB.
1/1/2017 1/1/2017 3.50 COMPZN RPCOMP HOSO P RU to circulate,come on line @ 1 bpm
19:30 23:00 and locate SBE with seals at 10968'.
Seen 210 psi increase,bleed off,with
bleeder open.Continue to RIH and
locate NoGo at 10944'and set down
10k down.PU and Mark 3-ft off No-
Go,pick up the following space out
pups 10.23', 10.24',8.15'. 1 full jt of 3-
1/2 and X-O to 4-1/2 IBT,and MU
TBG hanger w/4-1/2 NS-CT landing
joint.
1/1/2017 1/2/2017 1.00 COMPZN RPCOMP CRIH P Rig up to reverse circulate.PT lines to
23:00 00:00 3000 psi.Begin to reverse circulate
with 470 bbls of CI sea water.
1/2/2017 1/2/2017 2.50 COMPZN RPCOMP CRIH P Continue to reverse circulate 470 bbls
00:00 02:30 of CI sea water taking returns to
double kill tanks due to large volume.
Bring up rate slowly due to fill on the
back side.818 psi at 4.5 bpm.
1/2/2017 1/2/2017 0.50 COMPZN RPCOMP THGR P Stab seals into SBE,drain BOP stack
02:30 03:00 and flush through the IA valve. Land
hanger and RILDS.
1/2/2017 1/2/2017 2.00 COMPZN RPCOMP PRTS P RU and PT TBG to 3,000 psi for 10
03:00 05:00 minutes,bleed to 2,000 psi. PT IA to
2,500 psi for 30 minutes. Dump
pressure on TBG and Shear out SOV
@ 400 psi differential @ 9,936-ft.
Break circulation both directions
through the SOV.
Page 3/4 Report Printed: 1/31/2017
Mo
Operations Summary (with Timelog Depths)
0 •
1 D-28
ConocoPhiiiips
- IxS"rk9
Rig: DOYON 142 Job: RECOMPLETION
Time Log
Start Depth
Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)
1/2/2017 1/2/2017 0.50 COMPZN WHDBOP MPSP P Install BPV and Plug, PT from below
05:00 05:30 to 1,000 psi for 10 minutes.
1/2/2017 1/2/2017 1.00 COMPZN WHDBOP OTHR P Blow down Choke,Kill and Mud lines,
05:30 06:30 Pull Flow riser,bleed down
Accumulator
1/2/2017 1/2/2017 2.50 COMPZN WHDBOP NUND P Remove air boot from top of annular,
06:30 09:00 remove securing Lines. Take off
choke and kill hoses. Break stack
flanges to well head and hoist stack to
mezzanine,remove spacer spools and
rack back for move.
1/2/2017 1/2/2017 2.00 COMPZN WHDBOP NUND P Prep hanger for tree and adapter
09:00 11:00 installation. Install SBM seal,Install
adapter. Set Tree on Adapter spool
and Torque flanges.
Simops-Rig Down Skate ramp from
rig floor. Blow down and Rig down
mud lines in pit and pump room.
1/2/2017 1/2/2017 0.50 COMPZN WHDBOP PRTS P Pressure test Extended Neck seal
11:00 11:30 void @ 250/5,000 psi for 10 minutes.
-Good
1/2/2017 1/2/2017 1.00 COMPZN WHDBOP NUND P Finish Torquing up Tree flanges and
11:30 12:30 installing 1502 Integral to wing valve.
1/2/2017 1/2/2017 0.50 COMPZN WHDBOP PRTS P Fill Tree with Diesel and Pressure test
12:30 13:00 to 250/5,000 psi-Good test.
1/2/2017 1/2/2017 0.50 COMPZN WHDBOP MPSP P Pull test dart 4"H-BPV from well.
13:00 13:30
1/2/2017 1/2/2017 3.25 COMPZN WHDBOP FRZP P RU Little Red Services and PT lines to
13:30 16:45 2,500 psi,Freeze protect well with 100
bbls of diesel @ 2 BPM max rate. ICP
=500 and FCP 650. Allow well to
swap. Balanced Pressure 50 psi-
bleed off in preparation for setting
BPV
1/2/2017 1/2/2017 0.75 COMPZN WHDBOP MPSP P Install BPV and test from Below at
16:45 17:30 1,000 for 5 minutes each. Good Test.
1/2/2017 1/2/2017 0.50 DEMOB MOVE RURD P RD LRS and pump lines in the cellar.
17:30 18:00
1/2/2017 1/2/2017 1.00 DEMOB MOVE RURD P Dress Tree and secure well.
18:00 19:00
TBG PSI=0,IA PSI=0,OA PSI=0
Doyon 142 Rig Released at 19:00 hrs
Page 4/4 Report Printed: 1/31/2017
KUP WD 1D-28
ConocoPhillips 4 Well Attribu Max Angle D TD
Alaska,Inc. Wellbore API/0W' Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB)
CorrocoPhdkpc 500292323700 KUPARUK RIVER UNIT PROD 93.27 14,599.15 14,672.0
r,.. Comment H2S(ppm) Date Annotation End Date KB-Grd(n) Rig Release Date
1D-28,2/1/20176.12.51 AM SSSV:NONE 12 1/28/2016 Last WO: 1/2/2017 37.46 1/26/2005
Vertical sohemasc:(aotba6Annotation Depth(MB) End.
ate Annotation Last Mod By End Date
Last Tag:RKB 1 r117 Rev Reason:RECOMPLETION, • 1/31/2017
a. Mil
f • • NOTES
:
HANGER;34.0 I. Casing Description OD(in) ID(in) Top iftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
CONDUCTOR 20 19 124 35.0 153.0 153.0 91.50 H-40 WELDED
j Lii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
SURFACE 10 3/4 9.794 34.1 6,580.8 4,421.0 45.50 L-80 BIC
Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(I...Grade Top Thread
. ;Inn"'PRODUCTION 7 5/8 6.875 31.7 11,065.4 6,584.5 29.70 L-80 BTC MOD
: IL Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread
It SLOTTED LINER 4 1/2 3.958 10,922.5 14,672.0 6,632 9 12 60 L-80 IBT-M
CONDUCTOR;35.0-153.0 Liner Details
Nominal ID
Top(ftKB) Top(TVD)MB) Top Incl(°) Item Des Com (in)
GAS LIFT,3,192.7 g
10,922.5 6,566.0 81.95 TIE BACK BAKER TIE BACK SLEEVE 5.750
IL.
..iii
10,933.5 6,567.6 81.87 PACKER BAKER ZXP LINER TOP APCKER 4.960
II
10,941.5 6,568.7 81.91 NIPPLE BAKER'RS'PACKOFF NIPPLE 4.875
GAS LIFT;5,331.5 10,944.4 6,569.1 81.93 HANGER BAKER FLEX-LOCK LINER HANGER 4.830
10,954.9 6,570.6 82.01 SBE BAKER 190-47 SEAL BORE EXENSION 4.750
SI
pp 11,110.1 6,588.0 86.11 Swell Packer Swell Packer 3.958
II 11,880.9 6,624.5 91.10 Swell Packer Swell Packer 3.958
12,287.4 6,627.6 89.07 Swell Packer Swell Packer 3.958
SURFACE;341-6,580.7-. l 13,522.2 6,616.1 87.70 Swell Packer Swell Packer 3.958
14,243.0 6,640.3 88.04 Swell Packer Swell Packer 3.958
I Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len ...Grade Top Thread
GAS LIFT,7,022.7 WINDOW1111
I I 41/21 39921 11168.01 11173.01 6592.6 (1 J
Tubing Strings
® Tubing Description String Ma... ID(in) Top(ftKB) 'Set Depth(ft..Set Depth(N0)(...Wt(Ib/ft) Grade Top Connection
GAS LIFT,e,2790 UPPER 3 1/2 2.992 34.0 10,968.2 6,572.4 9.30 L-80 EUE 8rd
COMPLETION
WO/2016
Completion Details
Nominal ID
GAS LIFT;9,251.0 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in)
34.0 34.0 0.00 HANGER FMC TC-1A-EMS,11"x 4-1/2"w/2-.25"Ports,4-112IBT 3.870
Top and Bottom
10,033.5 6,347.1 63.31 NIPPLE NIPPLE,LANDING,31/2",DS,2.812",EUEBRMOD SN: 2.813
GAS LIFT;9,9728 4 3651-21
1 10,928.1 6,566.8 81.91 XO Enlarging 3-1/2"EUE Box x 4-1/2"IBT Pin 2.980
10,929.6 6,567.0 81.90 LOCATOR GBH-22 Locator Sub 3.870
NIPPLE;10,033.5 10,930.0 6,567.1 81.89 SEAL ASSY 192-47 Seal Assembly 3.870
411 Perforations&Slots
Shot
Top(ND) Bfm(TVD) (Dens
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com
{4J�(1) 11,162.0 11,873.0 6,591.6 6,624.7 C-4,C-3,1D- 1/23/2005 8.0 SLOTS Slotted Liner alternating
LOCATOR;10,929.5 ` .1 28 w/solid pipe 8 swell
j,, ,_ packers
1f_ 12,315.0 13,514.0 6,627.9 6,615.8 C-4,C-3, 1/23/2005 8.0 SLOTS
UNIT D,1D-
(' s 1 28
SEAL ASSY,10,930.0 14,269.0 14,639.0 6,640.9 6,634.8 C-4,10-28 1/23/2005 8.0 SLOTS
I i I Mandrel Inserts
at to
6t
ati
N Top(TVD) Valve Latch Port Size TRO Run
Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com
1 3,192.7 2,520.3 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,233.0 1/10/2017
2 5,331.5 3,724.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,225.0 1/10/2017
3 7,0227 4,666.4 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,224.0 1/10/2017
PRODUCTION;31 -11,o6s.4 4 8,278.1 5,375.7 Camco MMG 11/2 GAS LIFT GLV RK 0.188 1,219.0 1/10/2017
5 9,251.0 5,926.9 Camco MMG 1 1/2 GAS LIFT OV RK 0250 0.0 1/9/2017
6 9,972.8 6,317.9 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/2/2017
- Notes:General&Safety
End Date Annotation
1 1/22/2005 NOTE LEFT OPEN HOLE BEHIND SLOTTED LINER,AND MAY PRODUCE
I 1/22/2005 NOTE.MULTI-LATERAL WELL-MAIN LEG COMPLETED
WINDOW,11,168611,173.0 i
SLOTS,11,162.0-11,073.0 .i 1/23/2005 NOTE:TREE:CCANF/5M,6""OTIS QUICK CONNECT
Ur 1/8/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0.
1/15/2017 NOTE Cement bridge plug pushed to bottom 1/15/17,13,522'MD
I
liWr
SLOTS;12,315.613,514.0
Z 1
liliai
SLOTS;14,269.614,63.0
SLOTTED LINER;10,922.5._
• 2-04-2:S7
ReCEIVLu
SEP 14 2016
Schlumberger AOGCC
WIRELINE Transmittal#: 13SEP16-SPO2
DATA LOGGED
Log Product Delivery q i0+4/2o1Co
K.BENDER
Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender
Well No: 1D-28 Date Dispatched: 16-Aug-16
Job#: CYCD-00097 Dispatched By: Stephanie Pacillo
Well/
Product Description Hardcopy Digital Copy E-Delivery Date
Color Log Prints: N/A Contents on CD N/A
Wireline 24 Multi-Finger Caliper x
LAS Digital Data N/A Contents on CD N/A
x
CD 1 Contents on CD N/A
Data: ASCII x
Graphics:pdf x
*Note this is not a revision,just a replacement cd due to the pdf log file not opening/missing in the
previous cd delivered 28JUL16-SPO2
Please sign and email a copy to:
AlaskaPTSPrintCenter(a�slb.com
Attn:Stephanie Pacillo
Received By: / t � _,AKS
SCANNED Nov 0 420j6
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(4, O O O O
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y� yg� ~ CI
d CCD r O >Op N
111 !CO
XHVZE
Image pr:ct Well History File COy! Page
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.
~ 0 Y- - cl3 7 Well History File Identifier
Organizing (done)
o Two-sided III II 111111" 111111
o Rescan Needed 11111111111 II III III
RES CAN
~olor Items:
o Greyscale Items:
DIGITAL DATA
~iskettes, No. d-
O Other, NolType:
OVERSIZED (Scannable)
o Maps:
o Other Items Scannable by
a Large Scanner
o Poor Quality Originals:
o Other:
OVERSIZED (Non-Scannable)
o Logs of various kinds:
NOTES:
BY: ~
Date 3/1!;/07
o Other::
151
·ooP
11I1111111111111111
Project Proofing
BY: ~
mP
+ I ~ = TOTAL PAGES 10 d--
(Count does not include cover sheet)
151
151
Scanning Preparation
BY:
Date:
Production Scanning
III 11111111111 111/1
Stage 1
Page Count from Scanned File:
I 0 3 (Count does include cover sheet)
VYES
NO
151 WI P
NO
BY:
Page Count Matches Number in Scanning Preparation:
~ Date:3//:J/07
Stage 1 If NO in stage 1, page(s) discrepancies were found:
YES
BY:
Maria
Date:
151
11/11111111111111/1
Scanning is complete at this point unless rescanning is required.
ReScanned
III 11111I11 1111111I
BY:
Maria
Date:
151
Comments about this file:
Quality Checked
11111111111I 111111I
10/6/2005 Well History File Cover Page. doc
• •
~:~ .
MICRC}FILMED
03/01 /2008
DC.) NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:1LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc
.
.
~
ConocoPhillips
Alaska
RECEIVED
AUG 2 9 2007
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
Alaska Oil & Gas Cons. Commission
Anchorage
August 23,2007
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501 SCANNED SEP 062007
dvölf..~j7
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(K.RU). Each of
these wells was found to have a void in the conductor. These voids were filled with a 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.
The corrosion inhibitor/sealant was pumped between August 19& 21,2007. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call me at 907-659-7043, if you have any questions.
Sincerely, ~
~~~~
ConocoPhillips Well Integrity Projects Supervisor
.
.
Co no co Phillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Kuparuk Field
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTO# cement pumped cement date inhibitor sealant date
ft bbls ft ç¡al
1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007
1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007
1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007
10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007
10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007
10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007
10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007
. 1C-11 199-172 'SF NA NA NA 0.5 8/21/2007
1C-12 196-177 SF NA NA NA 0.5 8/21/2007
1C-15 198-229 SF NA NA NA 0.5 8/21/2007
1C-16 198-246 22" NA NA NA 8 8/21/2007
1 C-17 198-224 17" NA NA NA 1.7 8/21/2007
1C-18 199-005 SF NA NA NA 0.5 8/21/2007
1C-24 201-248 20" NA NA NA 11 8/21/2007
1 C-26 199-051 3" NA NA NA 0.85 8/21/2007
1C-27 199-043 4" NA NA NA 1.7 8/21/2007
1 C-28 205-104 SF NA NA NA 0.5 8/21/2007
1 C-117 201-121 . 26" NA NA NA 12.3 8/21/2007
Date
8/21/2007
)~ Fe.0
DATA SUBMITTAL COMPLIANCE REPORT
3/7/2007
Permit to Drill 2042370
Well Name/No. KUPARUK RIV UNIT 1D-28
Operator CONOCOPHILlIPS ALASKA INC
fp f.VL ~ J 1W'o...þ ~ aQ 1-
API No. 50-029-23237-00-00
MD 14672"
TVD 6633 /' Completion Date 1/26/2005../
Completion Status 1-01L
Current Status 1-01L
UIC N
__, __ ,._ ._~__. .._.____,__'.__'_ _ ___,___,',.___________ .________' ______"_M__ ___,________',__ ..______
REQUIRED INFORMATION
Directional Survey ~ .
Mud Log No
Samples No
DATA INFORMATION
Types Electric or Other Logs Run: GRlRes, Dens/Neu
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint
Logf Electr -
Data Digital Dataset Log Log Run Interval OH/
Type MedfFrmt Number Name Scale Media No Start CH Received Comments
{/E6 -.,----
D Asc Directional Survey 0 14672 Open 3/29/2005
~D D Asc Directional Survey 0 14672 Open 3/29/2005 MWD
41:D 0 Lis 13089 Induction/Resistivity c..." If,",,, "'~ F:t-L $~ 13"84fC1C/J"-.6553 14615 Open 3/11/2005 GRIEWR4/ABI
VRpt 13089 LIS Verification 6553 14615 Open 3/11/2005 GR/EWR4/ABI
Aog Production
~ C Lis 13698 Induction/Resistivity
~ C Las 14432 Induction/Resistivity
I
Name
Interval
Start Stop
2 Blu 10900 13293 Case 6/20/2005 mem production profile
w/deft & ghost psp
ccl/g r/stp/deftlg host
188 14672 Open 2/22/2006 ROP DGR EWR SLD CTN
plus Graphics
6553 14672 Open 1/29/2007 LIS Veri, GR, FET, ROP,
NCNT, NPHI, RHOB, e
DRHO w/Graphics
Sample
Set
Sent Received Number Comments
Well Cores/Samples Information:
ADDITIONAL INFORMATION
Well Cored? Y Ð
Chips Received? ~
Daily History Received?
~/N
(;)N
Formation Tops
Analysis
Received?
"¥++ ..
Permit to Drill 2042370
MD 14672
Comments:
-------------------------------------
Compliance Reviewed By: _
TVD 6633
DATA SUBMITTAL COMPLIANCE REPORT
3/7/2007
Well Name/No. KUPARUK RIV UNIT 1D-28
Operator CONOCOPHILLlPS ALASKA INC
Completion Date 1/26/2005
Completion Status 1-01L
Current Status 1-01L
UIC N
---- --JL.o-~-~~~ ____c__~~- --- ~-
API No. 50-029-23237-00-00
Date:
~~~~~illm~--~ ~~ - ~.mm __u
n _/ J" t(J/\.. ÀJæJ '7
e
-
.
.
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
November 14, 2006
RE: MWD Formation Evaluation Logs: 1B-15A, 1C-21 L1 L2 L3, 1D-28 L1, 1F-01A,
- - - -
3F-19A, 3H-14B.
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518
1B-15A: ;Jo4./-d5"c:' 11: ¡i.../¿./:!D
Digital Log Images: 1 CD Rom
50-029-23465-01 - ~
gDf)-034 I {) o "E)-I DO , f;JOS -/01 I [)O~ -/D
1C-21_L1_ L2 _L3: IL/L/3<-/ 14435'" /4t..13fo /¿./¿43+
Digital Log Images: 1 CD Rom
50-029-23253-00,60,61,62
1D-28 L1:
Digital Log Images:
50-029-23237-00, 60
96"/ -~3?
/~/43d.
go4 -.93'1í
14./¿/33
1 CD Rom
IF-01A: d05"" -Olf7 11 ¡,-/Ll(7)
Digital Log Images:
50-029-20889-01
3F-19A: {)()t../ -(:>/0 P-¡L¡t.¡ 31
Digital Log Images:
50-029- 22680-01
1 CD Rom
1 CD Rom
3H-14B: 0òG -Odl 1t t4¿'¡&l
Digital Log Images:
50-103-20092-02
1 CD Rom
, I
.
.
WELL LOG TRANSMITTAL
~0.4 ~ c?51
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West ih Ave., Suite 100
Anchorage, Alaska 99501
February 16, 2006
/3Lv%
RE: MWD Formation Evaluation Logs 1D-28,
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500
1 D-28:
LAS Data & Digital Log Images:
50-029-23270-00
1 CD Rom
v~
~19 ~ylc¥.p
PMIT KRU lD-28 01-31-05.xls
.
.
Subject: PMIT KRU 1D-28 01-31-0S.xls
From: NSK Problem Well Supv <n1617@conocophillips.com>
Date: Thu, 17 Mar 200S 12:S6:46 -0900
To: Thomas Maunder <tom_maunder@admin.state.ak.us>
CC: Bob Fleckenstein AOGCC <bob_fleckenstein@admin.state.ak.us>, NSK Problem Well Supv
<n1617@conocophillips.com>
«PM IT KRU 10-28 01-31-05.xls»
Tom,
Here is the MIT data to comply with CO 494 Rule 1, "conduct and document a pressure test... ", for pre
produced injector 1 0-28 PTO 204-237.
Please let me know if you have any questions.
MJ Loveland
ConocoPhillips
Problem Well Supervisor
659-7224
KRU ID-28
Content-Description: PMIT KRU 1D-28 01-31-0S.xls
Content-Type: application/vnd.ms-excel
Content-Encoding: base64
1 of 1
3/17/2005 1 :02 PM
· STATEOFALASKA .
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Kuparuk / KRU / 1 D
01/31/05
Woods
<rf17(. '
(1105
o
P
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
Well
P.T.D.
Notes:
Test Details:
TYPE INJ codes
F = Fresh Water Inj
G = Gas Inj
S = Salt Water Inj
N = Not Injecting
TYPE TEST Codes
M = Annulus Monitoring
P = Standard Pressure Test
R = Internal Radioactive Tracer Survey
A = Temperature Anomaly Survey
D = Differential Temperature Test
INTERVAL Codes
I = Initial Test
4 = Four Year Cycle
V = Required by Variance
Test during Workover
0= other (describe in notes)
MIT Report Form
Revised: 05/19/02
PMIT KRU 1O-2801-31-05.xls
3/17/2005
.
.
24-Feb-05
AOGCC
Helen Warman
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
DEFINITIVE
Re: Distribution of Survey Data for Well 10-28
Dear Dear Sir/Madam:
Enclosed is one disk with the *'pTT and *.PDF files.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
0.00 I MD
0.00' MD
14,672.00' MD
(if applicable)
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Carl Ulrich
6900 Arctic Blvd.
Anchorage, AK 99518
Date ). Çf jV1vv~),D..J1[ Signed
,. .
LOlL)
r
Please call me at 273-3545 if you have any questions or concerns.
Regards,
Carl Ulrich
Survey Manager
Attachment(s)
~rJV(-Å3'ì
.
.
AOGCC
Helen Warman
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well 1 D-28 MWD
Dear Dear Sir/Madam:
Enclosed is one disk with the *.PTT and *.PDF files.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
0.00' MD
0.00' MD
14,672.00' MD
(if applicable)
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Carl Ulrich
6900 Arctic Blvd.
Anchorage, AK 99518 ~ /
Date)q (flmJi',f:,)- Signed W ûlJJ
Please call me at 273-3545 if you have any questions or concerns.
Regards,
Carl Ulrich
Survey Manager
Attachment(s)
24-Feb-05
)í:JV¡-~~7
.
ConocóP'hillips
.
Randy Thomas
Kuparuk Drilling Team Leader
Drilling & Wells
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-265-6830
February 10, 2005
Commissioner
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, Alaska 99501
Subject: Well Completion Reports for 10-28, 1 D-28L 1
Dear Commissioner:
ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the
recent drilling operations of the Kuparuk wells 10-28 and 1 D-28L 1.
If you have any questions regarding this matter, please contact me at 265-6830 or
Scott Lowry at 265-6869.
Sincerely,
~~
R. Thomas
Kuparuk Drilling Team Leader
CPAI Drilling
RT Iskad
. STATE OF ALASKA ...
ALA Oil AND GAS CONSERVATION COM~ON
WELL COMPLETION OR RECOMPLETION REPORTAND,LOG
1 a. Well Status: Oil 0 Gas U Plugged U Abandoned U Suspended U WAG 0 1 b. Well Class:
20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0
GINJ 0 WlNJ 0 WDSPL 0 No. of Completions Other Service 0 Stratigraphic Test 0
2. Operator Name: 5. Date Comp., Susp., I 12. Permit to Drill Number:
ConocoPhillips Alaska, Inc. or Aband.: January 26, 2005 204-237 J
3. Address: 6. Date SPUdd' ., . l2. ZCL» 13. API Number:
P. O. Box 100360, Anchorage, AK 99510-0360 '" 4_,t:..........,...~ ' 7Þ lÇ 50-029-23237-00
D8r;:8F1'1B~1 2B, aS4 2/j~"
4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number:
Surface: 357' FNL, 419' FEL, Sec. 23, T11N, R10E, UM January 23, 2005 / 1 D-28
At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s):
Horizon: 499' FSL, 2381' FWL, Sec. 18, T11N, R11E, UM 34' RKB Kuparuk River Field
Total Depth: 9. Plug Back Depth (MD + 1VD): Kuparuk Oil Pool
113' FSL, 4219' FEL, Sec. 17, T11 N, R11 E, UM 14670' MD 16633' TVD
4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + 1VD): 16. Property Designation:
Surface: x- 560671 , 5959309 , Zone- 4 14672' MD /6633' TVD ,. ADL 25650 & 28243
y-
TPI: x- 568743 y- 5960234 Zone- 4 11. Depth where SSSV set: 17. Land Use Permit:
Total Depth: x- 572375 I y- 5959883 .. Zone- 4 none ALK 468 & 3814
18. Directional Survey: Yes 0 NOU 19. Water Depth, if Offshore: 20. Thickness of
N/A feet MSL Permafrost: 1810' MD
21. Logs Run:
GRlRes, Dens/Neu
22. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD SETTING DEPTH 1VD HOLE AMOUNT
CEMENTING RECORD PULLED
CASING SIZE wr. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE
20" 91.5# H-40 34' 118' 34' 118' 30" 16 cu yds ABI Type 11/
10.75" 45.5# L-80 34' 6581' 34' 4426' 13.5" 837 sx AS Lite, 485 sx LiteCrete
7-5/8" 29.7# L-80 34' 11065' 34' 6587' 9-7/8" 52 bbls Class G
4.5" 12.6# L-80 10922' 14672' 6566' 6633' 6.75" slotted liner
23. Perforations open to Production (MD + 1VD of Top and Bottom 24. TUBING RECORD
Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) I PACKER SET
4.5" 10974' I 10933' ,
slotted liner 11110', 11880', 12287', 13522', 14243'
25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
n/a
26. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
February 7,2005 Oil Producer - shares production with 1 D-28L 1
Date of Test Hours Tested Production for Oll-BBL GAS-MCF WATER-BBl CHOKE SIZE GAS-Oil RATIO
2/9/2005 9.5 hours Test Period --> 771 699 131 100% 1049
Flow Tubing Casing Pressure Calculated Oll-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr)
press. 350 psi 780 24-Hour Rate -> 1810 1899 330 not available
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). fCOMPLETJON
Submit core chips; if none, state "none". ¡ DATE._ .
1-2-(., ,os.
RBDMS BFl FEB 1 7 2005 -~ED .
NONE ~ . -:J v-'
OR\G\~\!AL t -
t)r
Form 10-407 Revised 12/2003
CONTINUED ON REVERSE
28.
29.
GEOLOGIC MARKERS
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested. and
attach detailed supporting data as necessary. If no tests were
conducted. state "None".
1 D-28
Top Kuparuk C
Base Kuparuk C
11010'
14672'
6578'
6633'
N/A
30. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact: Scott Lowry @ 265-6869
Printed N
Title: Greater Kucaruk Area Drillina Team Leader
Phone 2..~.s- 6,"'i , 0
Date
V(olo.$"
Prepared by 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.
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 elevation in feet abour mean low low water. 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: True vertical thickness.
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, Other (explain).
Item 27: If no cores taken, indicate "none".
Item 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003
Halliburton Sperry-Sun
Western North Slope
ConocoPhillips
1 D-28
.
Job No. AKZZ3444739, Surveyed: 23 January, 2005
Survey Report
9 February, 2005
Your Ref: API 500292323700
Surface Coordinates: 5959309.20 N, 560670.72 E (70017' 57. 8051 w N, 149030' 31. 126r W)
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4
Kelly Bushing Elevation: 104. 65ft above Mean Sea Level
.
spe..........\I-sul!
DFUL..LING SERVIC:ES
A Halliburton Company
Survey Ref: svy2092
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
eft) eft) eft) (ft) eft) eft) (ft) (O/100ft)
0.00 0.000 0.000 -104.65 0.00 0.00 N 0.00 E 5959309.20 N 560670.72 E 0.00 CB-GYRO-SS
152.00 0.000 0.000 47.35 152.00 0.00 N 0.00 E 5959309.20 N 560670.72 E 0.000 0.00
169.00 0.300 60.000 64.35 169.00 0.02 N 0.04 E 5959309.22 N 560670.76 E 1.765 0.04
257.00 1.700 58.000 152.33 256.98 0.83 N 1.35 E 5959310.04 N 560672.06 E 1.591 1.41 MWD+IIFR+MS+SAG
288.06 2.360 57.420 183.37 288.02 1.42 N 2.27 E 5959310.64 N 560672.98 E 2.126 2.39 .
379.53 5.140 65.140 274.64 379.29 4.15 N 7.58 E 5959313.42 N 560678.27 E 3.082 7.91
469.53 8.290 68.930 364.01 468.66 8.18 N 17.30 E 5959317.52 N 560687.95 E 3.533 17.93
559.47 10.860 63.010 452.69 557.34 14.36 N 30.90 E 5959323.81 N 560701.50 E 3.056 32.01
648.89 13.770 60.040 540.05 644.70 23.50 N 47.63 E 5959333.08 N 560718.16 E 3.329 49.46
743.63 14.350 59.780 631.95 736.60 35.04 N 67.54 E 5959344.78 N 560737.98 E 0.616 70.28
840.88 16.640 62.790 725.66 830.31 47.48 N 90.34 E 5959357.40 N 560760.68 E 2.495 94.06
932.54 20.070 65.600 812.65 917.30 59.98 N 116.34 E 5959370.11 N 560786.58 E 3.864 121.03
1029.26 24.150 65.910 902.23 1006.88 74.91 N 149.53 E 5959385.32 N 560819.64 E 4.220 155.38
1120.71 24.080 63.690 985.70 1090.35 90.82 N 183.34 E 5959401.50 N 560853.32 E 0.995 190.41
1214.02 26.100 63.070 1070.21 1174.86 108.56 N 218.70 E 5959419.52 N 560888.54 E 2.183 227.16
1307.98 28.080 63.480 1153.85 1258.50 127.79 N 256.92 E 5959439.06 N 560926.60 E 2.117 266.88
1401.76 30.730 63.700 1235.54 1340.19 148.27 N 298.16 E 5959459.87 N 560967.67 E 2.828 309.71
1495.82 35.150 62.840 1314.46 1419.11 171.29 N 343.82 E 5959483.26 N 561013.14 E 4.725 357.17
1590.98 37.460 62.590 1391.15 1495.80 197.12N 393.88 E 5959509.49 N 561063.00 E 2.432 409.25
1684.90 39.750 63.290 1464.54 1569.19 223.76 N 446.07 E 5959536.56 N 561114.97 E 2.482 463.52
1776.59 41.140 63.930 1534.31 1638.96 250.20 N 499.35 E 5959563.42 N 561168.04 E 1.582 518.86
1871.92 41.500 64.330 1605.91 1710.56 277.66 N 555.99 E 5959591.34 N 561224.45 E 0.468 577.63 .
1965.82 47.750 62.860 1672.71 1777.36 307.02 N 615.02 E 5959621.18 N 561283.24 E 6.746 638.95
2058.78 52.480 62.900 1732.30 1836.95 339.53 N 678.49 E 5959654.19 N 561346.44 E 5.088 704.96
2152.84 53.720 62.990 1788.78 1893.43 373.74 N 745.47 E 5959688.94 N 561413.15 E 1.321 774.62
2245.17 53.330 62.750 1843.67 1948.32 407.59 N 811.55 E 5959723.33 N 561478.95 E 0.471 843.34
2340.75 52.920 63.760 1901.02 2005.67 442.00 N 879.82 E 5959758.29 N 561546.95 E 0.948 914.30
2436.25 51.980 63.810 1959.22 2063.87 475.45 N 947.75 E 5959792.28 N 561614.60 E 0.985 984.83
2530.03 50.850 64.300 2017.71 2122.36 507.52 N 1013.67 E 5959824.89 N 561680.25 E 1.272 1053.24
2623.24 52.380 63.450 2075.59 2180.24 539.70 N 1079.26 E 5959857.59 N 561745.59 E 1.790 1121.34
2716.36 54.630 62.700 2130.97 2235.62 573.60 N 1146.00 E 5959892.03 N 561812.05 E 2.501 1190.72
2810.00 54.430 62.810 2185.31 2289.96 608.51 N 1213.80 E 5959927.49 N 561879.56 E 0.234 1261.25
2904.67 52.960 62.820 2241.36 2346.01 643.37 N 1281.66 E 5959962.89 N 561947.14 E 1.553 1331.84
2998.96 51.330 64.460 2299.22 2403.87 676.43 N 1348.36 E 5959996.49 N 562013.57 E 2.208 1401.11
3093.94 53.640 64.490 2357.06 2461.71 708.89 N 1416.34 E 5960029.50 N 562081.29 E 2.432 1471.61
9 February, 2005 - 16:53 Page 2 of 8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
3187.35 53.590 64.190 2412.47 2517.12 741.45 N 1484.12 E 5960062.61 N 562148.80 E 0.264 1541.92
3280.51 53.970 69.540 2467.54 2572.19 770.96 N 1553.19E 5960092.67 N 562217.64 E 4.650 1613.26
3373.29 54.220 72.510 2521.96 2626.61 795.39 N 1624.25 E 5960117.67 N 562288.49 E 2.607 1686.14
3466.76 53.540 74.890 2577.06 2681.71 816.58 N 1696.71 E 5960139.45 N 562360.78 E 2.182 1760.14
3562.61 53.120 76.760 2634.31 2738.96 835.41 N 1771.24 E 5960158.88 N 562435.16 E 1.625 1836.00 .
3655.61 53.750 80.360 2689.72 2794.37 850.21 N 1844.43 E 5960174.28 N 562508.23 E 3.182 1910.19
3748.86 55.780 82.580 2743.52 2848.17 861.49 N 1919.74 E 5960186.16 N 562583.45 E 2.919 1986.19
3842.14 57.240 85.950 2795.00 2899.65 869.24 N 1997.13 E 5960194.54 N 562660.77 E 3.395 2063.96
3934.92 57.820 89.170 2844.82 2949.47 872.57 N 2075.32 E 5960198.49 N 562738.93 E 2.994 2142.15
4023.16 56.940 88.820 2892.39 2997.04 873.87 N 2149.63 E 5960200.40 N 562813.22 E 1.052 2216.30
4117.54 56.170 89.690 2944.40 3049.05 874.90 N 2228.37 E 5960202.06 N 562891.96 E 1.121 2294.84
4210.57 55.440 89.720 2996.69 3101.34 875.29 N 2305.32 E 5960203.08 N 562968.90 E 0.785 2371.54
4306.05 54.660 89.800 3051.38 3156.03 875.62 N 2383.58 E 5960204.04 N 563047.15 E 0.820 2449.54
4399.40 53.910 89.960 3105.88 3210.53 875.78 N 2459.37 E 5960204.81 N 563122.94 E 0.815 2525.07
4493.35 55.040 89.560 3160.47 3265.12 876.10 N 2535.83 E 5960205.75 N 563199.40 E 1.252 2601.28
4588.32 54.470 89.500 3215.27 3319.92 876.74 N 2613.39 E 5960207.01 N 563276.95 E 0.602 2678.61
4681.37 57.270 88.780 3267.47 3372.12 877.90 N 2690.40 E 5960208.79 N 563353.94 E 3.077 2755.44
4774.10 57.910 88.490 3317.17 3421.82 879.77 N 2768.66 E 5960211.29 N 563432.19 E 0.739 2833.58
4867.76 57.600 88.300 3367.15 3471.80 881.98 N 2847.84 E 5960214.15 N 563511.35 E 0.373 2912.66
4961.75 57.270 88.380 3417.74 3522.39 884.28 N 2927.02 E 5960217.08 N 563590.51 E 0.358 2991.75
5055.84 57.330 88.750 3468.57 3573.22 886.26 N 3006.18 E 5960219.70 N 563669.64 E 0.337 3070.78
5151.52 56.940 88.350 3520.49 3625.14 888.30 N 3086.52 E 5960222.39 N 563749.96 E 0.538 3151.00 .
5244.69 56.530 87.880 3571.60 3676.25 890.86 N 3164.38 E 5960225.58 N 563827.80 E 0.610 3228.80
5340.98 55.910 88.640 3625.13 3729.78 893.29 N 3244.37 E 5960228.65 N 563907.77 E 0.919 3308.71
5437.78 55.420 88.880 3679.73 3784.38 895.02 N 3324.29 E 5960231.03 N 563987.67 E 0.546 3388.48
5532.46 55.610 88.140 3733.34 3837.99 897.05 N 3402.30 E 5960233.69 N 564065.67 E 0.675 3466.38
5626.70 56.230 87.530 3786.15 3890.80 900.00 N 3480.30 E 5960237.27 N 564143.64 E 0.849 3544.35
5721.00 56.500 88.490 3838.38 3943.03 902.72 N 3558.76 E 5960240.63 N 564222.08 E 0.895 3622.76
5814.56 56.260 88.800 3890.18 3994.83 904.57 N 3636.65 E 5960243.10 N 564299.95 E 0.377 3700.52
5909.73 56.390 89.660 3942.95 4047.60 905.63 N 3715.84 E 5960244.80 N 564379.13 E 0.764 3779.52
6000.61 56.510 89.540 3993.18 4097.83 906.16 N 3791.58 E 5960245.94 N 564454.86 E 0.172 3855.02
6094.85 56.460 90.290 4045.21 4149.86 906.28 N 3870.15 E 5960246.69 N 564533.43 E 0.666 3933.32
6187.84 56.680 90.030 4096.44 4201.09 906.06 N 3947.76 E 5960247.10 N 564611.03 E 0.332 4010.62
6280.66 55.650 91.440 4148.13 4252.78 905.08 N 4024.85 E 5960246.74 N 564688.13 E 1.680 4087.35
6374.01 55.880 91.040 4200.65 4305.30 903.41 N 4102.00 E 5960245.70 N 564765.30 E 0.432 4164.08
9 February, 2005 - 16:53 Page 30f8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft)
6466.19 56.130 90.520 4252.19 4356.84 902.37 N 4178.42 E 5960245.27 N 564841.72 E 0.541 4240.13
6558.33 55.790 90.570 4303.76 4408.41 901.64 N 4254.77 E 5960245.16 N 564918.07 E 0.372 4316.14
6581.00 55.760 90.580 4316.51 4421.16 901.45 N 4273.51 E 5960245.13 N 564936.82 E 0.137 4334.80
6652.23 55.660 90.650 4356.64 4461.29 900.82 N 4332.36 E 5960244.97 N 564995.67 E 0.162 4393.38
6745.33 55.270 90.840 4409.42 4514.07 899.82 N 4409.05 E 5960244.59 N 565072.36 E 0.451 4469.70 .
6837.96 56.680 88.750 4461.26 4565.91 900.11 N 4485.81 E 5960245.50 N 565149.12 E 2.411 4546.21
6931.87 57.330 87.390 4512.40 4617.05 902.77 N 4564.52 E 5960248.79 N 565227.81 E 1.398 4624.87
7026.00 56.770 87.490 4563.60 4668.25 906.30 N 4643.43 E 5960252.96 N 565306.69 E 0.602 4703.79
7120.32 56.180 90.300 4615.70 4720.35 907.82 N 4722.04 E 5960255.11 N 565385.27 E 2.561 4782.23
7215.18 55.620 91.550 4668.88 4773.53 906.55 N 4800.57 E 5960254.48 N 565463.82 E 1.241 4860.38
7310.04 56.640 91.240 4721.75 4826.40 904.64 N 4879.31 E 5960253.20 N 565542.57 E 1.109 4938.67
7403.48 56.070 92.460 4773.52 4878.17 902.13 N 4957.06 E 5960251.32 N 565620.33 E 1.246 5015.91
7494.98 56.440 93.060 4824.34 4928.99 898.46 N 5033.05 E 5960248.27 N 565696.35 E 0.679 5091.32
7589.07 56.040 91.340 4876.63 4981.28 895.46 N 5111.21 E 5960245.90 N 565774.54 E 1.578 5168.94
7682.93 56.520 90.800 4928.74 5033.39 894.00 N 5189.27 E 5960245.07 N 565852.60 E 0.700 5246.59
7777.52 54.660 90.700 4982.19 5086.84 892.98 N 5267.29 E 5960244.68 N 565930.63 E 1.968 5324.24
7869.10 54.760 90.300 5035.10 5139.75 892.33 N 5342.04 E 5960244.63 N 566005.38 E 0.373 5398.66
7963.42 54.350 90.520 5089.80 5194.45 891.78 N 5418.88 E 5960244.70 N 566082.22 E 0.474 5475.17
8055.06 54.020 90.620 5143.42 5248.07 891.04 N 5493.19 E 5960244.56 N 566156.53 E 0.371 5549.15
8147.12 54.660 91.610 5197.09 5301.74 889.58 N 5567.97 E 5960243.71 N 566231.33 E 1.117 5623.53
8241.95 56.090 91.640 5250.97 5355.62 887.37 N 5645.97 E 5960242.12 N 566309.34 E 1.508 5701.06
8335.33 56.360 89.610 5302.89 5407.54 886.52 N 5723.58 E 5960241.90 N 566386.96 E 1.830 5778.32 .
8430.75 55.790 89.450 5356.14 5460.79 887.17 N 5802.75 E 5960243.19 N 566466.12 E 0.613 5857.26
8524.93 55.240 89.820 5409.47 5514.12 887.67 N 5880.38 E 5960244.31 N 566543.74 E 0.668 5934.64
8618.20 53.910 89.250 5463.53 5568.18 888.28 N 5956.38 E 5960245.54 N 566619.73 E 1.510 6010.42
8711.57 52.380 90.640 5519.53 5624.18 888.36 N 6031.08 E 5960246.23 N 566694.44 E 2.026 6084.86
8806.24 53.130 91.490 5576.83 5681.48 886.96 N 6106.43 E 5960245.43 N 566769.79 E 1.067 6159.81
8899.30 54.780 90.710 5631.59 5736.24 885.52 N 6181.66 E 5960244.60 N 566845.03 E 1.898 6234.64
8992.67 57.050 90.090 5683.91 5788.56 884.99 N 6258.98 E 5960244.69 N 566922.35 E 2.493 6311.64
9087.73 56.520 89.620 5735.98 5840.63 885.19 N 6338.51 E 5960245.53 N 567001.88 E 0.694 6390.89
9181.57 58.440 92.300 5786.43 5891.08 883.84 N 6417.61 E 5960244.83 N 567080.98 E 3.160 6469.59
9277.12 59.900 91.980 5835.40 5940.05 880.78 N 6499.60 E 5960242.43 N 567162.99 E 1.555 6551.02
9368.28 58.640 91.650 5881.98 5986.63 878.29 N 6577.92 E 5960240.57 N 567241.33 E 1.417 6628.84
9465.12 57.380 92.730 5933.28 6037.93 875.16 N 6659.99 E 5960238.10 N 567323.42 E 1.609 6710.35
9560.70 56.900 93.090 5985.15 6089.80 871.09 N 6740.17 E 5960234.68 N 567403.64 E 0.594 6789.89
9 February, 2005·16:53 Page 4 of8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 DDft)
9657.39 55.670 92.990 6038.81 6143.46 866.82 N 6820.48 E 5960231.06 N 567483.98 E 1.275 6869.55
9752.02 56.270 92.850 6091.77 6196.42 862.83 N 6898.81 E 5960227.70 N 567562.33 E 0.646 6947.24
9846.88 56.020 92.210 6144.62 6249.27 859.35 N 6977.50 E 5960224.85 N 567641.06 E 0.619 7025.36
9939.54 57.050 92.860 6195.71 6300.36 855.93 N 7054.73 E 5960222.06 N 567718.31 E 1.256 7102.01
10033.44 63.310 91.380 6242.38 6347.03 852.95 N 7136.09 E 5960219.73 N 567799.70 E 6.805 7182.83 .
10115.94 65.690 88.270 6277.91 6382.56 853.19 N 7210.54 E 5960220.58 N 567874.14 E 4.460 7257.02
10219.57 68.620 89.600 6318.14 6422.79 854.96 N 7306.01 E 5960223.12 N 567969.59 E 3.065 7352.30
10312.56 73.020 91.610 6348.68 6453.33 854.01 N 7393.81 E 5960222.88 N 568057.39 E 5.153 7439.69
10404.25 77.100 90.030 6372.32 6476.97 852.75 N 7482.37 E 5960222.34 N 568145.96 E 4.751 7527.82
10498.11 77.790 90.030 6392.72 6497.37 852.71 N 7573.98 E 5960223.03 N 568237.57 E 0.735 7619.10
10592.03 77.920 90.180 6412.48 6517.13 852.54 N 7665.80 E 5960223.60 N 568329.39 E 0.209 7710.57
10684.08 80.860 90.490 6429.43 6534.08 852.01 N 7756.26 E 5960223.80 N 568419.85 E 3.211 780Q.66
10715.50 82.420 89.400 6433.99 6538.64 852.04 N 7787.35 E 5960224.08 N 568450.94 E 6.036 7831.63
10746.85 82.920 89.310 6437.99 6542.64 852.39 N 7818.44 E 5960224.68 N 568482.02 E 1.620 7862.64
10777.38 82.850 88.470 6441.78 6546.43 852.98 N 7848.73 E 5960225.52 N 568512.31 E 2.740 7892.87
10808.98 82.230 88.450 6445.88 6550.53 853.82 N 7880.05 E 5960226.61 N 568543.62 E 1.963 7924.15
10840.37 82.040 88.930 6450.17 6554.82 854.53 N 7911.14 E 5960227.57 N 568574.70 E 1.631 7955.18
10876.74 82.310 88.660 6455.13 6559.78 855.29 N 7947.16 E 5960228.62 N 568610.72 E 1.045 7991.14
10934.46 81.860 87.870 6463.07 6567.72 857.02 N 8004.30 E 5960230.81 N 568667.84 E 1.564 8048.22
10970.66 82.120 87.730 6468.12 6572.77 858.39 N 8040.12 E 5960232.48 N 568703.65 E 0.814 8084.03
11004.37 82.110 87.250 6472.74 6577.39 859.85 N 8073.48 E 5960234.21 N 568737.00 E 1.411 8117.39
11056.54 84.190 87.320 6478.97 6583.62 862.31 N 8125.22 E 5960237.08 N 568788.71 E 3.989 8169.15 .
11099.62 86.050 87.380 6482.63 6587.28 864.29 N 8168.10 E 5960239.41 N 568831.57 E 4.320 8212.04
11140.00 86.270 87.440 6485.33 6589.98 866.11 N 8208.34 E 5960241.56 N 568871.80 E 0.565 8252.30
11196.01 83.640 89.430 6490.26 6594.91 867.64 N 8264.11 E 5960243.53 N 568927.55 E 5.880 8307.99
11247.31 85.480 90.900 6495.12 6599.77 867.49 N 8315.17 E 5960243.80 N 568978.62 E 4.583 8358.86
11291.31 85.750 94.580 6498.49 6603.14 865.39 N 8358.99 E 5960242.05 N 569022.45 E 8.362 8402.33
11338.86 83.760 97.330 6502.84 6607.49 860.48 N 8406.08 E 5960237.52 N 569069.57 E 7.119 8448.83
11387.33 84.640 99.140 6507.73 6612.38 853.58 N 8453.80 E 5960231.00 N 569117.35 E 4.135 8495.79
11435.75 85.550 100.710 6511.87 6616.52 845.26 N 8501.32 E 5960223.07 N 569164.93 E 3.737 8542.43
11482.91 86.220 101.660 6515.26 6619.91 836.14 N 8547.46 E 5960214.32 N 569211.15 E 2.461 8587.62
11531.28 86.250 104.890 6518.44 6623.09 825.06 N 8594.43 E 5960203.62 N 569258.21 E 6.664 8633.48
11580.27 87.050 105.990 6521.30 6625.95 812.04 N 8641.57 E 5960190.98 N 569305.45 E 2.773 8679.34
11626.61 87.980 105.660 6523.31 6627.96 799.41 N 8686.11 E 5960178.71 N 569350.09 E 2.129 8722.64
11674.48 90.270 106.310 6524.04 6628.69 786.23 N 8732.12 E 5960165.91 N 569396.21 E 4.973 8767.36
9 February, 2005 -16:53 Page 50f8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft)
11722.91 91.030 105.350 6523.49 6628.14 773.02 N 8778.71 E 5960153.07 N 569442.90 E 2.528 8812.65
11770.71 91.870 103.520 6522.28 6626.93 761.11 N 8824.98 E 5960141.53 N 569489.27 E 4.211 8857.74
11819.34 91.030 101.500 6521.05 6625.70 750.58 N 8872.44 E 5960131.39 N 569536.81 E 4.497 8904.13
11866.86 91.140 99.200 6520.15 6624.80 742.04 N 8919.18E 5960123.23 N 569583.62 E 4.845 8949.97
11914.65 91.010 96.720 6519.25 6623.90 735.43 N 8966.49 E 5960117.00 N 569630.98 E 5.196 8996.55 .
11963.12 90.760 94.830 6518.50 6623.15 730.55 N 9014.71 E 5960112.51 N 569679.24 E 3.933 9044.17
11994.76 90.770 94.490 6518.08 6622.73 727.98 N 9046.24 E 5960110.19 N 569710.79 E 1.075 9075.37
12059.21 89.620 94.020 6517.86 6622.51 723.20 N 9110.51 E 5960105.93 N 569775.10 E 1.928 9139.00
12156.12 89.560 93.680 6518.56 6623.21 716.69 N 9207.20 E 5960100.21 N 569871.84 E 0.356 9234.78
12203.21 86.960 94.040 6519.99 6624.64 713.52 N 9254.16 E 5960097.42 N 569918.82 E 5.574 9281.30
12251.12 88.080 93.190 6522.06 6626.71 710.51 N 9301.93 E 5960094.78 N 569966.61 E 2.934 9328.64
12299.32 89.390 92.230 6523.12 6627.77 708.23 N 9350.06 E 5960092.89 N 570014.76 E 3.369 9376.40
12346.75 89.560 90.510 6523.56 6628.21 707.09 N 9397.47 E 5960092.14 N 570062.18 E 3.644 9423.54
12395.20 89.970 91.510 6523.76 6628.41 706.24 N 9445.92 E 5960091.68 N 570110.63 E 2.231 9471.74
12443.41 89.720 91.060 6523.89 6628.54 705.16 N 9494.11 E 5960090.99 N 570158.83 E 1.068 9519.67
12491.75 91.160 92.960 6523.51 6628.16 703.46 N 9542.42 E 5960089.68 N 570207.15 E 4.932 9567.65
12539.40 90.840 96.080 6522.68 6627.33 699.71 N 9589.91 E 5960086.31 N 570254.67 E 6.581 9614.65
12588.13 91.510 98.250 6521.68 6626.33 693.63 N 9638.24 E 5960080.63 N 570303.05 E 4.660 9662.29
12634.75 91.060 98.570 6520.64 6625.29 686.82 N 9684.35 E 5960074.18 N 570349.21 E 1.184 9707.65
12681.53 91.170 96.980 6519.73 6624.38 680.49 N 9730.69 E 5960068.23 N 570395.60 E 3.406 9753.28
12730.63 90.090 96.790 6519.19 6623.84 674.60 N 9779.43 E 5960062.74 N 570444.39 E 2.233 9801.34
12777.03 90.350 96.190 6519.01 6623.66 669.36 N 9825.53 E 5960057.87 N 570490.53 E 1 .409 9846.83 .
12826.68 90.740 95.210 6518.54 6623.19 664.43 N 9874.94 E 5960053.33 N 570539.97 E 2.124 9895.63
12875.17 90.680 94.480 6517.94 6622.59 660.33 N 9923.25 E 5960049.63 N 570588.31 E 1.510 9943.42
12923.06 90.580 93.470 6517.41 6622.06 657.01 N 9971.02 E 5960046.70 N 570636.11 E 2.119 9990.73
12971.86 91.670 93.390 6516.45 6621.10 654.10 N 10019.72 E 5960044.17 N 570684.83 E 2.240 10039.01
13018.59 89.330 93.520 6516.04 6620.69 651.28 N 10066.36 E 5960041.73 N 570731.50 E 5.015 10085.24
13066.95 90.490 94.660 6516.12 6620.77 647.83 N 10114.60 E 5960038.67 N 570779.76 E 3.363 10133.01
13114.78 91.080 95.010 6515.46 6620.11 643.80 N 10162.25 E 5960035.03 N 570827.44 E 1.434 10180.14
13161.75 90.830 94.750 6514.68 6619.33 639.80 N 10209.05 E 5960031.41 N 570874.27 E 0.768 10226.43
13211.16 91.560 94.480 6513.65 6618.30 635.83 N 10258.28 E 5960027.83 N 570923.54 E 1.575 10275.15
13259.39 91.700 95.660 6512.28 6616.93 631.57 N 10306.31 E 5960023.96 N 570971.59 E 2.463 10322.63
13306.68 91.750 96.780 6510.86 6615.51 626.45 N 10353.29 E 5960019.22 N 571018.62 E 2.370 10369.01
13355.13 91.140 98.610 6509.63 6614.28 619.96 N 10401.29 E 5960013.12 N 571066.67 E 3.980 10416.28
13402.83 91.570 97.500 6508.51 6613.16 613.28 N 10448.51 E 5960006.82 N 571113.93 E 2.495 10462.75
9 February, 2005· 16:53 Page 6 of 8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 1D-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Inct. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) ("1100ft)
13452.32 88.610 96.470 6508.43 6613.08 607.26 N 10497.62 E 5960001.20 N 571163.10 E 6.333 10511.18
13499.14 86.690 95.540 6510.35 6615.00 602.37 N 10544.14 E 5959996.68 N 571209.66 E 4.556 10557.11
13547.65 88.820 95.070 6512.25 6616.90 597.89 N 10592.41 E 5959992.59 N 571257.95 E 4.496 10604.82
13594.25 90.580 95.510 6512.49 6617.14 593.59 N 10638.81 E 5959988.67 N 571304.39 E 3.893 10650.68
13644.01 92.170 93.430 6511.30 6615.95 589.71 N 10688.40 E 5959985.19 N 571354.01 E 5.260 10699.76 .
13691.09 91.200 94.840 6509.91 6614.56 586.32 N 10735.33 E 5959982.18 N 571400.97 E 3.634 10746.24
13721.93 91.820 94.840 6509.10 6613.75 583.72 N 10766.05 E 5959979.82 N 571431.71 E 2.010 10776.62
13762.30 89.320 92.850 6508.70 6613.35 581.01 N 10806.32 E 5959977.44 N 571472.00 E 7.915 10816.52
13795.12 88.770 92.910 6509.25 6613.90 579.36 N 10839.10 E 5959976.06 N 571504.78 E 1.686 10849.03
13827.65 88.150 93.390 6510.12 6614.77 577.58 N 10871.56 E 5959974.53 N 571537.27 E 2.410 10881.23
13858.36 87.470 93.040 6511.29 6615.94 575.86 N 10902.20 E 5959973.06 N 571567.92 E 2.490 10911.61
13889.74 85.860 92.800 6513.12 6617.77 574.26 N 10933.49 E 5959971.72 N 571599.22 E 5.187 10942.64
13921.51 85.740 94.270 6515.45 6620.10 572.31 N 10965.11 E 5959970.02 N 571630.85 E 4.630 10973.99
13953.35 86.110 94.990 6517.71 6622.36 569.74 N 10996.77 E 5959967.71 N 571662.53 E 2.537 11005.31
14001.66 85.860 95.060 6521.09 6625.74 565.52 N 11044.77 E 5959963.88 N 571710.57 E 0.537 11052.78
14048.69 86.480 95.010 6524.23 6628.88 561.40 N 11091.52 E 5959960.14 N 571757.34 E 1.323 11099.00
14094.83 85.860 95.870 6527.32 6631.97 557.04 N 11137.35 E 5959956.14 N 571803.21 E 2.294 11144.29
14143.83 86.970 96.400 6530.38 6635.03 551.81 N 11185.97 E 5959951.31 N 571851.87 E 2.509 11192.29
14192.63 86.420 97.180 6533.19 6637.84 546.05 N 11234.35 E 5959945.94 N 571900.29 E 1.954 11240.00
14240.99 87.960 98.190 6535.56 6640.21 539.59 N 11282.21 E 5959939.87 N 571948.21 E 3.807 11287.14
14286.34 89.750 96.810 6536.47 6641.12 533.68 N 11327.16 E 5959934.31 N 571993.20 E 4.983 11331.43
14336.86 91.300 97.690 6536.01 6640.66 527.30 N 11377.27 E 5959928.34 N 572043.37 E 3.528 11380.81 .
14380.66 89.690 97.920 6535.63 6640.28 521.35 N 11420.67 E 5959922.74 N 572086.80 E 3.713 11423.54
14433.38 88.950 99.330 6536.25 6640.90 513.45 N 11472.78 E 5959915.26 N 572138.98 E 3.020 11474.79
14476.54 90.370 98.630 6536.51 6641.16 506.71 N 11515.41 E 5959908.87 N 572181.67 E 3.668 11516.69
14530.06 91.790 97.870 6535.50 6640.15 499.03 N 11568.37 E 5959901.62 N 572234.68 E 3.009 11568.80
14599.14 93.270 97.930 6532.45 6637.10 489.55 N 11636.72 E 5959892.68 N 572303.11 E 2.144 11636.10
_ 14672.00 93.270 97.930 6528.30 6632.95 _ 479.51 N 11708.77 E 5959883.23 N 572375.24 E ~ 0.000 11707.03 Projected Survey
All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US Survey).
Vertical Section is from Well and calculated along an Azimuth of 85.110· (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 14672.00ft.,
9 February, 2005 -16:53 Page 7 of 8 DrillQuest 3.03.06.008
Halliburton Sperry-Sun
Survey Report for 10-28
Your Ref: API 500292323700
Job No. AKZZ3444739, Surveyed: 23 January, 2005
ConocoPhillips
Western North Slope
The Bottom Hole Displacement is 11718.58ft., in the Direction of 87.655° (True).
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
.
14672.00
6632.95
479.51 N
11708.77 E Projected Survey
Survey tool program for 1 D-28
From
Measured Vertical
Depth Depth
(ft) (ft)
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
0.00
257.00
0.00 257.00
256.98 14672.00
256.98 CB-GYRO-SS
6632.95 MWD+IIFR+MS+SAG
.
9 February, 2005 - 16:53
Page 8 of 8
OrillQuest 3.03.06.008
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 0-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
12/18/2004 21 :00 - 00:00 3.00 MOVE DMOB MOVE Secured 1 H-05a well site, prepped and skidded rig floor to center of
module, cleared around rig and pad, pulled rig off well, loaded rig mats
for transport to 1 D pad, moved rock washer away from rig, and held a
PJSM with crew coming on tour.
12/19/2004 00:00 - 01 :00 1.00 MOVE DMOB MOVE PJSM on rig move, load shims in pipe shed, clear pad entrance for rig,
prep beaver slide for moving.
01 :00 - 06:00 5.00 MOVE MOVE MOVE Notify Kuparuk base and move rig from 1 H pad to KCC parking lot, with
snow blower escort to keep drifts down. Turn rig around for intersection
, notify Kuparuk base, move rig from KCC to 1 D pad, with snow blower
escort. 6 mile move.
06:00 - 08:00 2.00 MOVE POSN MOVE Clear snow from well site #28 and around camp with loaders and snow
blower.
08:00 - 10:30 2.50 MOVE POSN MOVE Set rig mats, spot rig over conductor #28, shim level. Skid rig floor over
cellar. Accept rig @ 09:00 hrs on 12/19/2004.
10:30 - 11 :30 1.00 DRILL RIRD RIGUP Hook up steam lines service and mud lines to rig floor.
11 :30 - 18:00 6.50 DRILL RIRD RIGUP N/U diverter, 21 1/4" Hydril and 16" diverter tube. Button up cellar area
I i for high winds, remove snow from conductor and cellar box. Locate drill
pipe on pad, clear snow and load 5" DP in shed. Cut off riser tube to fit,
C/O saver sub on top drive, perform derrick inspection, RIU rig floor for
P/U 5" DP, on-load spud mud.
18:00 - 00:00 6.00 DRILL PULD RIGUP P/U 5" DP drifting same, stnd back in derrick, DP packed with snow,
I thawing with steam in pipeshed, conductor had ice plug and M/U stnds
in mouse-hole, for a total of 32 stnds out of 64 needed.
12/20/2004 00:00 - 06:30 6.50 DRILL PULD SURFAC I Con!. P/U 5" DP and HWDP, stnd back in derrick.
06:30 - 07:30 1.00 DRILL OTHR SURFAC Cut and slip drill line.
07:30 - 09:00 1.50 I DRILL PULD SURFAC P/U and M/U MWD tools, bit, mud mtr, stabs and x-o's.
09:00 - 10:30 1.50 DRILL SFTY SURFAC RIU slick-line unit for gyro, hold pre-spud mtng, function test diverter
system, fill conductor with mud-no leaks, AOGCC witness waived by
John Spalding.
10:30 - 12:00 1.50 DRILL DRLG SURFAC Spud in at 118', drill to 169' and take gyro survey, cont drilling to 219'.
12:00 - 13:00 1.00 DRILL TRIP SURFAC POOH stnd back 2 stnds HWDP.
13:00 - 14:00 1.00 DRILL PULD SURFAC M/U MWD and orient, M/U non-mag flex DC's.
14:00 - 00:00 10.00 DRILL DRLG SURFAC Cont drilling from 219' to 258' and take gyro survey. Cont drilling to 985'
MD/966' TVD with MWD survey's, P/U wt 93K, S/O wt 91 K, ROT wt
93K, torque on bot 5K, torque off bot 2K, 60 RPM, 25K on bit, pump psi
on bot 1,580, pump psi off bot 1,240, ART=3.86 hrs, AST=4.04 hrs,
IADT=7.90 hrs.
I
12/21/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC PTSM, Directional Drill 13-1/2" OH from 985'MD(920'TVD) to
2,385'MD(2,020'TVD). ART= 3.8 hrs, AST= 4.5 hrs, ADT= 8.3 hrs,
ROP= 170' FPH, PUW= 105k, SOW= 92k, ROTW= 100k, TKOFFBTM=
3k, TKONBTM= 6k, PPOFFBTM= 1,700 psi, PPONBTM= 2,020 psi @
,525 GPM.
12:00 - 00:00 12.00 DRILL DRLG SURFAC I PTSM, Directional Drill 13-112" OH from 2,385'MD(2,020'TVD) to
13,615'MD(2,740'TVD). Observed Gas Hydrates from
2,503'MD(2,100'TVD) to 2,896'MD(2,340'TVD), Max 1,600 Units. ART=
2.3 hrs, AST= 6.1 hrs, ADT= 8.35 hrs, ROP= 150' FPH, PUW= 140k,
SOW= 95k, ROTW= 112k, TKOFFBTM= 7k, TKONBTM= 9k,
PPOFFBTM= 1,720 psi, PPONBTM= 1,960 psi @ 525 GPM.
12/22/2004 00:00 - 03:30 3.50 DRILL DRLG SURFAC I PTSM, Directional Drill 13-112" OH from 3,615'MD(2,740'TVD) to
13,986'MD(2,955'TVD). Achieved Directional requirements.
03:30 - 05:30 2.00 DRILL CIRC SURFAC Circulate bottoms up 2X, Rotate and reciprocate drillstring. Hole in good
condition.
05:30 - 08:30 3.00 DRILL TRIP SURFAC Pump out of hole from 3,986' to the BHA.
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 0-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
Stand back HWDP and DC's. Lay Down UBHO sub and break off bit.
M/U new 13-112" Bit, Reset BH on MM to 1.5? Orientate MWD Tool,
RIH with De's and HWDP.
11 :00 - 12:00 1.00 DRILL TRIP SURFAC RIH with BHA #2. Shallow test MWD at 1,700', OK. RIH to 2,768'.
12:00 - 13:00 1.00 DRILL TRIP SURFAC PTSM, RIH to 3,986', Wash down last stand. Hole in good condition.
13:00 - 00:00 11.00 DRILL DRLG SURFAC Directional Drill 13-1/2" OH from 3,986'MD(2,955'TVD) to
5,298'MD(3,680'TVD). ART= 6.95 hrs, AST= 1.02 hrs, ADT= 7.97 hrs,
ROP= 165' FPH, PUW= 155k, SOW= 105k, ROTW= 127k,
TKOFFBTM= 8k, TKONBTM= 10k, PPOFFBTM= 2,120 psi,
PPONBTM= 2,350 psi @ 550 GPM.
12/23/2004 00:00 - 01 :30 1.50 DRILL DRLG SURFAC PTSM, Drill 13-112" OH from 5,298' to 5,391', No signal from MWD Tool
01 :30 - 02:30 1.00 DRILL DEQT SURFAC Attempt to re-establish signal from MWD Tool, NO-GO.
02:30 - 03:30 1.00 DRILL CIRC SURFAC Circulate Bottoms up. Rotate and Reciprocate Drillstring. Hole in good
condition.
I Flow Check, OK, Pump out from 5,391' to 3,700'. Hole in good
03:30 - 05:00 1.50 DRILL TRIP SURFAC
condition.
05:00 - 06:30 1.50 DRILL TRIP SURFAC Flow check, OK, POH on elevators, WET, to HWDP, hole in good
condition.
06:30 - 07:00 0.50 DRILL ITRIP SURFAC Stand back HWDP, Jars, and DC's.
07:00 - 08:00 1.00 DRILL PULD SURFAC Break off bit, Break out and lay down Mud Motor and MWD Tool.
08:00 - 10:30 2.50 DRILL PULD I SURFAC M/U new MWD Tool, Mud Motor, and rerun Bit#2. Orient MWD Tool.
M/U De's, Jars, and HWDP. Shallow Test MWD Tool, OK.
10:30 - 12:00 1.50 DRILL TRIP SURFAC RIH with BHA #3, Fill pipe, Rih to 4,547'
12:00 - 12:30 0.50 DRILL TRIP SURFAC PTSM, RIH from 4,547' to 5,391, Wash last stand to btm. Hole in good
condition.
12:30 - 00:00 11.50 DRILL DRLG SURFAC I Directional Drill 13-1/2" OH from 5,391 'MD(3, 740'TVD) to
6,426'MD(4,391'TVD). ART= 7.77 hrs, AST= 1.41 hrs, ADT= 7.77 hrs,
ROP= 145' FPH, PUW= 175k, SOW= 1115k, ROTW= 140k,
I TKOFFBTM= 11 k, TKONBTM= 12k, PPOFFBTM= 2,350 psi,
PPONBTM= 2,600 psi @ 550 GPM.
12/24/2004 00:00 - 02:30 2.50 DRILL DRLG SURFAC I Directional Drill 13-112" OH from 6,426'MD(4,391 'TVD) to
I 6,591'MD(4,426'TVD). ART= 1.88 hrs, AST= 0 hrs, ADT= 1.88 hrs,
ROP= 88' FPH, PUW= 175k, SOW= 1115k, ROTW= 140k,
ITKOFFBTM= 11k, TKONBTM= 12k, PPOFFBTM= 2,350 psi,
ICIRC PPONBTM= 2,600 psi @ 550 GPM.
02:30 - 05:00 2.50 DRILL SURFAC ,Circulate And Condion Mud - Circulate 2 X Bottoms Up While Rotating
, I And Reciprocating the Drill String - 565 GPM With 2,300 Psi. At 100
IWIPR RPM
05:00 - 06:30 1.50 DRILL SURFAC 'Monitor The Well Bore (Static) - Pump Out Of The Hole From 6,591' To
Above The Last Bit Trip Depth To 5,140' - No Problems On Trip
06:30 - 07:00 0.50 DRILL WIPR SURFAC RIH From 5,140' To 6,591' With No Problems - As Precaution Wash
2.00 I DRILL Last Stand To Bottom
07:00 - 09:00 CIRC SURFAC Circulate And Condion Mud - Circulate 1.5 X Bottoms Up While
Rotating And Reciprocating the Drill String - 565 GPM With 2,300 Psi.
I At 100 RPM - 210 Units Of Gas On Bottoms Up
09:00 - 11 :30 2.50 DRILL REAM SURFAC Monitor The Well Bore (Static) - Pump Out Of The Hole From 6,591' To
I GIRG I SURFAG Above The Ugnu Formation To 4,040' - No Problems On Trip
11 :30 - 13:00 1.50 DRILL Circulate Hole Clean - Monitor The Well Bore (Static) - Pump Dry Job -
Blow Down Surface Equipment
13:00 - 15:30 2.50 DRILL TRIP SURFAC POH With The 13 1/2" Directional Drilling Assembly BHA NO.3 From
1.50 I DRILL 4,040' To 700' With No Problems
15:30 - 17:00 IPULD SURFAC Stand Back The 5" HWDP And Daily Drilling Jars - Lay Down The 8"
Flex Collars, Sperry Sun MWD Tools - Drain Mud Motor And Remove
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 D-28
1 D-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Sta rt:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
12/24/2004 15:30 - 17:00 1.50 DRILL PULD SURFAC Bit - Clear Directional BHA From Rig Floor And Wash Down Same.
17:00 - 17:30 0.50 CASE SFTY SURFAC Hold Pre-Job Safety Meeting With All Crew Members
17:30 - 19:30 2.00 CASE RURD SURFAC RIU casing running equipment.
19:30 - 22:00 2.50 CASE RUNC SURFAC RIH with 10.75" 45# L-80 BTC Casing, installed bow spring centralizers
on the first 13 jts in the hole. Check floats, OK.
22:00 - 23:15 1.25 CASE OTHR SURFAC While running in the hole with 10.75" Casing Driller observed a
decrease in slack off weight. Driller was picking up casing string (+/- 5')
when casing collar snagged riser which in turn separated flow line from
riser. This resulted in the uncontrolled discharge of 2 gals of drilling
mud from the flow line into the well cellar area. Approximately 1/2 gal of
drilling mud spilled out of secondary containment onto the snow and
gravel pad, 3 sq ft area. Material was immediately cleaned up with a
Vac truck and will be properly disposed offsite. All proper notifications
were communicated.
23:15 - 00:00 0.75 CASE RUNC SURFAC RIH with 10.75" 45# L-80 BTC Casing. Special Drift 9.875".
12/25/2004 100:00 - 04:00 4.00 CASE RUNC SURFAC PTSM,RIH with 10?" 45# L-80 BTC Casing. Special Drift 9.875". Total
jts. run, 161.
104:00 - 04:30 0.50 CASE RUNe SURFAC M/U Landing Jt and FMC Mandrel Casing Hgr. Break circ at 30 spm at
430 psi SOW 160k ,Unable to reciprocate casing.
04:30 - 05:00 0.501 CASE RUNC SURFAC I Continue circulating and land 10?" Casing with mandrel hgr. Float Shoe
at 6,581'MD.
05:00 - 06:00 1.00 CASE CIRC SURFAC Circulate casing vol., start at 3.3 bpm 280 psi, slowly ramp pumps up to
7.5 bpm 720 psi.
06:00 - 06:30 0.50 CEMEN J CIRC SURFAC Lay down top drive casing fill up tool. Make up Schlumberger plug
dropping cement head with plugs preloaded.
06:30 - 09:00 2.50 CEMEN I CIRC SURFAC Circulate casing vol. 1.5x @ 75 spm 480 psi. Unable to reciprocate
casing.
09:00 - 09:30 0.50 CEMENi SFTY SURFAC Held PJSM on cement job with Rig crew, Schlumberger Cement crew,
and AES Trucking Support Crew while circulating casing.
09:30 - 14:30 5.00 CEMEN PUMP SURFAC Shut down circulating, Flush out mud pumps with water. Switch to
Schlumberger, pump 5 bbls water, Test surface lines to 2,500 psi.
Pump 50 bbls CW100 followed by 50 bbls mud push. Kick out btm plug.
I Mix and pump 653 bbls ( 825 sx ) lead cement slurry at 10.7 ppg.
followed by 185 bbls (462 sx) tail cement slurry at 12.5 ppg.
I Schlumberger kick out top plug with 20 bbls water. Switch over to rig
pumps, displace cement to float shoe at 6 bpm 980 psi. FICP prior to
I bumping plug 1,980 psi. Bump plug with 2,450 psi. Floats held. CIP at
114:00 hrs. Observed 410 bbls cement returns back to surface. Rig
I down cement lines and plug dropping head.
14:30 - 16:30 2.00 CEMEN1RURD SURFAC Flush out diverter system and all surface equipment. Back out and lay
116:30 - 17:30 down landing joint. Clear rig floor of all casing handling tools.
1.00 CEMEN~ RURD SURFAC I PJSM, Nipple Down flow line, 20" riser, Hydril, and diverter line. Clear
1.50 I WELLS~ NUND celler area.
17:30 - 19:00 SURFAC I M/U FMC Gen 'V' Wellhead System. Test seal to 1,000 psi, OK
19:00 - 23:00 I 4.00 WELCT NUND SURFAC I Nipple up BOPE, C/O choke hose spool.
23:00 - 00:00 1.00 WELCT BOPE SURFAC I M/U test joint and plug, Set test plug. RIU surface equipment to test
BOPE.
12/26/2004 00:00 - 06:30 6.50 WELCT I SURFAC PTSM, Test BOPE 250/3,500 psi. AOGCC PI , Jeff Jones, waived
witnessing test.
106:30 - 07:00 0.50 WELCT BOPE SURFAC Pull test plug, set wear ring.
07:00 - 08:00 ' 1.00 DRILL PULD SURFAC P/U BHA # 4, Strap and caliper BHA equipment.
08:00 - 10:30 2.50 DRILL TRIP SURFAC M/U 9-7/8" HTC PDC Bit, RIH with BHA # 4. Shallow test MWD Tool,
OK.
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 0-28
1 0-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
12/26/2004 10:30 - 11 :30 1.00 DRILL TRIP SURFAC RIH picking up 4" drill pipe from pipe shed.
11 :30 - 12:00 0.50 WAlTON WOW SURFAC Suspend rig operations due to hi-winds and phase 3 driving conditions.
12:00 - 16:30 4.50 WAlTON WOW SURFAC PTSM, Suspend rig operations due to hi-winds and phase 3 driving
conditions.
16:30 - 20:30 4.00 DRILL TRIP SURFAC RIH, Stage in, Break circ every 1,000', RIH to 6,345'
20:30 - 22:00 1.50 RIGMNT RSRV SURFAC PJSM, Slip and cut drilling line. Service top drive, blocks, and
drawworks.
22:00 - 23:00 1.00 DRILL SFTY SURFAC Conduct table top stripping drill with all drilling crew members. Review
CPAI drills and expectations SOP.
23:00 - 00:00 1.00 WAlTON WOW SURFAC Suspend rig operations due to hi-winds and phase 3 driving conditions.
12/27/2004 00:00 - 01 :00 1.00 WAlTON WOW SURFAC PTSM, Suspend rig operations due to hi-winds and phase 3 driving
I conditions. Conduct table top stripping drill with all drilling crew
members. Review CPAI drills and expectations SOP.
101 :00 - 02:00 1.00 CASE CIRC SURFAC Weather conditions improved. Currently phase 2 conditions. Mobilize
I AES Vac Trucks for mud displacement.
02:00 - 02:30 0.50 CASE CIRC SURFAC RIH, tag semi-firm cement and top of float collar at 6,494',
02:30 - 05:30 3.00 CASE CIRC SURFAC Circulate and condition mud for casing test.
05:30 - 06:30 1.00 CASE DEQT SURFAC Rig up test equipment. Chart 2,500 psi 10-3/4" casing test for 30 min.
I Good test. Rig down test equipment.
06:30 - 09:00 2.50 DRILL OTHR SURFAC Drill out float collar ( 6,494' ), float shoe ( 6,580' ), and 20' new 9-7/8"
I OH to 6,611'.
109:00 - 11 :00 I 2.00 DRILL CIRC SURFAC Circulate and condition mud for LOT. Change mud over to 9.8 ppg
LSND mud system.
11 :00 - 12:00 1.00 DRILL LOT SURFAC I Rig up test equipment. Chart LOT as per CPAI procedure. Observed
I LO at 1,140 surface pressure. MWE at 4,420' TVD = 14.8 ppg. Rig
down test equipment.
12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 6,611'MD (4,430' TVD) to 7,377'MD (
4,826'TVD). ART= 7.78 hrs, AST= 1.22 hrs, ADT= 9 hrs, ROP= 85'
FPH, PUW= 200k, SOW= 108k, ROTW= 140k, TKOFFBTM= 11 k,
TKONBTM= 12k, PPOFFBTM= 3,210 psi, PPONBTM= 2,930 psi @
575 GPM.
12/28/2004 00:00 - 06:30 6.50 DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/8" OH from 7,377'MD (4,826? TVD) to
7,683'MD (5,010?TVD). ART= 4.26 hrs, AST= .68 hrs, ADT= 4.94 hrs,
ROP= 62' FPH, PUW= 200k, SOW= 108k, ROTW= 140k, TKOFFBTM=
11 k, TKONBTM= 12k, PPOFFBTM= 3,210 psi, PPONBTM= 2,930 psi
i @ 575 GPM. Observed decrease in ROP. Adjusted drilling parameters
in effort to increase ROP. No Change. Consult with CPAI Drilling
Engineer. Decision was made to trip for new bit. Stop drilling at
7,683'MD.
06:30 - 08:00 1.50 DRILL TRIP INTRM1 Flow check well, static,POH, Pump out with top drive to 10-3/4" casing
108:00 -11:00 ì Ishoe at 6,580'.
3.00 DRILL TRIP INTRM1 I Flow check well, static, Mix and pump dry job, POH on elevators to
BHA. Hole in good condition.
11 :00 - 12:00 1.00 I DRILL TRIP INTRM1 Stand Back BHA, Break off bit. 9-7/8" PDC bit balled up and 2 jet
nozzles plugged off.
12:00 - 13:30 1.50 DRILL TRIP i INTRM1 PTSM, M/U new 9-7/8" HTC MX-C1 Tri-cone Rock Bit. RIH with BHA.
I M/U top drive. Break circulation and shollow test MWD tool. OK. Blow
I down top drive.
113:30 - 15:30 2.00 DRILL TRIP INTRM1 RIH, fill drillpipe. M/U top drive. Wash down last stand to bottom at
I 7,683'. Hole in good condition.
15:30 - 00:00 8.50 I DRILL DRLG INTRM1 Drill and survey 9-7/8" OH from 7,683'MD (5,010? TVD) to 8,215 'MD
I (5,341 ?TVD). ART= 4 hrs, AST= .42 hrs, ADT= 4.42 hrs, ROP= 120'
Printed: 1/3112005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 0-28
1 0-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
12/2S/2004 15:30 - 00:00 S.50 DRILL DRLG INTRM1 FPH, puw= 225k, SOW= 10Sk, ROTW= 145k, TKOFFBTM= 12k,
TKONBTM= 13k, PPOFFBTM= 3,200 psi, PPONBTM= 3,450 psi @
560 GPM.
12/29/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/S" OH from S,215'MD(5,341? TVD) to S,S20
'MD (5,690?TVD). ART= 4.6 hrs, AST= 1.57 hrs, ADT= 6.17 hrs,
ROP= 9S' FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM=
14k, TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,450 psi
@ 560 GPM. Precautionary backream after each stand is drilled down
for hole cleaning. Raising mud density as per well plan weight up
schedule.
112:00 - 20:00 S.OO DRILL DRLG INTRM1 PTSM, Drill and survey 9-7/S" OH from S,S20'MD(5,690? TVD) to
9,061 'MD (5,S26?TVD). ART= 3.20 hrs, AST= 1.47 hrs, ADT= 4.67 hrs,
ROP= 57' FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM=
14k, TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,5400 psi
@ 560 GPM. Precautionary backream after each stand is drilled down
for hole cleaning. Raising mud density as per well plan weight up
I schedule. Hole packing off. Reduce circulating rate. Work pipe.
120:00 - 22:30 2.50 DRILL CIRC INTRM1 Slowly increase pump rate while cleaning up hole. Rotate and
I reciprocate drill string. Circulate and condition mud at drilling rate. CBU
2X. Hole conditions improved. Discussed hole conditions with CPAI
Drilling Engineer. Decision was made to trip drill string to 10-3/4" casing
shoe.
122:30 - 00:00 1.50 DRILL TRIP INTRM1 POH, wiper trip to casing shoe. Pump out with top drive at 450 gpm,
2,600 psi. Hole in good condition.
12/30/2004 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 PTSM,POH, wiper trip to 10-3/4" casing shoe. Pump out with top drive
I at 450 gpm, 2,600 psi. Hole in good condition.
01 :00 - 02:30 1.50 DRILL CIRC INTRM1 Circulate and condition mud at 10-3/4" casing shoe. Reciprocate drill
string with 9-7/S" bit and mud motor outside casing shoe. Observed
increase in cuttings at shakers while circulating btms up. Circulating
rate 135 spm, 3,650 psi, 570 gpm. Hole conditions improved.
02:30 - 04:00 1.50 DRILL ITRIP INTRM1 Flow check, static, RIH, M/U top drive. Wash down last stand to btm at
19,061'. Hole in good condition.
04:00 - 12:00 S.OO DRILL DRLG INTRM1 Drill and survey 9-7/S" OH from 9,061'MD(5,S26? TVD) to 9,491'MD
(6,045?TVD). ART= 4.S hrs, AST= .74 hrs, ADT= 5.54 hrs, ROP= 7S'
FPH, PUW= 235k, SOW= 115k, ROTW= 155k, TKOFFBTM= 14k,
TKONBTM= 15k, PPOFFBTM= 3,320 psi, PPONBTM= 3,540 psi @
560 GPM. Hole conditions improved after wiper trip.
12:00 - 00:00 12.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/S" OH from 9,491'MD(6,045'TVD) to
10,OSS'MD (6,337?TVD). ART= 5.16hrs, AST= 4.05hrs, ADT= 9.21hrs,
ROP= 65' FPH, PUW= 190k, SOW= 135k, ROTW= 160k, TKOFFBTM=
9k, TKONBTM= 10k, PPOFFBTM= 3,640 psi, PPONBTM= 3,S90 psi @
1560 GPM. Start sliding at 1 O,OOS'MD(6,337'TVD) with mud motor to
I obtain directional objective at casing point. Precautionary backream
I after each slide for hole cleaning. Good hole conditions while sliding.
12/31/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/S" OH from 10,OSS'MD(6,337'TVD) to
10,566'MD (6,500?TVD). ART= 4.74hrs, AST= 3.65hrs, ADT= S.39hrs,
ROP= 60' FPH, PUW= 207k, SOW= 127k, ROTW= 1152k,
I TKOFFBTM= 12k, TKONBTM= 13k, PPOFFBTM= 3,490 psi,
PPONBTM= 3,700 psi @ 560 GPM. Continue to slide 2/3 of each stand
drilled down to achieve directional objectives. Precautionary backream
each slide for hole cleaning.
12:00 - 00:00 12.00 DRILL DRLG ¡INTRM1 . PTSM,Drill and survey 9-7/S" OH from 10,566'MD(6,500'TVD) to
i 10,S79'MD (6,560?TVD). ART= 6.26hrs, AST= 1.57hrs, ADT= 7.S3hrs,
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 D-28
1 D-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
ROP= 50' FPH, PUW= 210k, SOW= 130k, ROTW= 160k, TKOFFBTM=
10k, TKONBTM= 15k, PPOFFBTM= 3,420 psi, PPONBTM= 3,550 psi
@ 560 GPM. Geological markers 50' TVD deeper. Extend TD to 50' MD
, below top "C4" marker.
1/1/2005 00:00 - 03:00 3.00 DRILL DRLG INTRM1 PTSM,Drill and survey 9-7/8" OH from 10,879'MD(6,560'TVD) to
10,924'MD (6,567?TVD). ART= 2.02hrs, AST= .52hrs, ADT= 2.54hrs,
ROP= 18' FPH, PUW= 195k, SOW= 130k, ROTW= 160k, TKOFFBTM=
13k, TKONBTM= 14k, PPOFFBTM= 3,500 psi, PPONBTM= 3,550 psi
@ 560 GPM. ROP decreased. Stop drilling at 10,924'. Prepare to make
trip for new bit.
03:00 - 04:00 1.00 DRILL CIRC INTRM1 Circulate Bottoms up. 125 spm at 3,670 psi. Rotate and reciprocate drill
string while circulating. Hole in good condition.
04:00 - 09:00 5.00 DRILL TRIP INTRM1 POH, Pump out at drilling rate to 10-3/4" casing shoe at 6,580'.
09:00 - 10:00 1.00 DRILL CIRC INTRM1 Circulate bottoms up at casing shoe 1.5X. Observed increase in
cuttings at btms up. Circulate until hole cleans up. 125 spm at 3,450
psi. Rotate and reciprocate drill string, with bit and motor outside casing
shoe, while circulating. Hole in good condition.
10:00 - 12:00 2.00 DRILL TRIP INTRM1 Flow check, well static, Mix and pump dry job, POH to 3,400'
12:00 - 13:30 1.50 DRILL TRIP INTRM1 PTSM, POH to BHA
13:30 - 14:30 1.00 DRILL TRIP INTRM1 Stand back HWDP and flex collars, Break off bit, M/U new bit.
,14:30 - 16:00 1.50 DRILL DEQT INTRM1 Download MWD Tool in rotary table.
16:00 - 17:30 1.50 DRILL PULD INTRM1 C/O MWD pulsor and logging tool. M/U new collar. Orient Mudmotor.
17:30 - 18:00 0.50 DRILL DEQT INTRM1 Upload MWD Tool in rotary table.
18:00 - 18:30 0.50 DRILL TRIP INTRM1 RIH with new bit, flex collars, and HWDP from derrick.
18:30 - 19:00 0.50 DRILL DEQT INTRM1 Shallow test MWD tool, OK
19:00 - 22:00 3.00 DRILL TRIP INTRM1 RIH, P/U 9 jts. 4" drillpipe. Lay down 2 jts 5" drillpipe, pin end had
washout. RIH to 6,538', fill pipe.
22:00 - 23:00 1.00 DRILL OTHR INTRM1 PJSM, Slip and cut drilling line.
23:00 - 00:00 1.00 DRILL OTHR INTRM1 Service Rig.Perform weekly rig inspection.
1/2/2005 00:00 - 02:00 2.00 DRILL TRIP INTRM1 PTSM, RIH to 10,200', tight hole conditions, M/U top drive. Wash thru
tight hole, OK, Wash down to 10,650'. MADD pass depth.
02:00 - 04:00 2.00 DRILL DEQT INTRM1 Wash down +/- 200'/hr. MADD Pass from 10,650' to 10,924'.
04:00 - 10:30 6.50 DRILL DRLG INTRM1 Drill and survey 9-7/8" OH to 11,075'(6,587'TVD) TD as per onsite
Geologist.Top of "C4" sand 11,01 0'(6,578'TVD). AST=1.06 hrs,
ART=3.25 hrs, ADT=4.31 hrs.ROP= 35'/hr.PUW=220k, SOW=120k,
ROTW=160k, TQOFFBTM=13k, TQONBTM=14k, PPOFFBTM=3,410
psi, PPONBTM=3,600 psi.
10:30 - 12:00 1.50 DRILL CIRC INTRM1 Circulate and condition mud 2X, Rotate and reciprocate drill string. 90
RPM, 11 k TQ, 550 GPM at 3,750 psi.
12:00 - 13:00 1.00 DRILL CIRC INTRM1 PTSM, Circulate and condition mud 2X, Rotate and reciprocate drill
string. 90 RPM, 11k TQ, 550 GPM at 3,750 psi. Take SPR, Flow check,
Static.
13:00 - 19:00 6.00 DRILL TRIP INTRM1 POH, Pump out with top drive to 10-3/4" casing shoe. Hole in good
condition.
19:00 - 20:30 1.50 DRILL CIRC INTRM1 Circulate and condition mud, Circulate bottoms up at 550 gpm, 3,380
psi. Hole in good condition. Flow check, static. Mix and pump dry job.
20:30 - 21 :30 1.00 DRILL PULD INTRM1 POH, lay down 5" drillpipe.
21 :30 - 22:00 0.50 DRILL PULD INTRM1 Change out pipe handling equipment to 4".
22:00 - 23:30 1.50, DRILL TRIP INTRM1 POH, stand back 4" drillpipe.
23:30 - 00:00 0.50 DRILL ipULD INTRM1 Change out pipe handling equipment to 5". POH, lay down 5" HWDP.
1/3/2005 00:00 - 01 :00 1 1.00 DRILL PULD INTRM1 PTSM, POH, Lay down 5" HWDP & Flex collars.
01 :00 - 01 :30 0.50 DRILL DEQT INTRM1 Down load MWD in rotary table.
01 :30 - 02:00 0.50 DRILL PULD INTRM1 Lay down BHA, break off bit.
I
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
10-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
1/3/2005 02:00 - 02:30 0.50 CASE RURD INTRM1 Pull wear ring, set test plug.
02:30 - 03:30 1.00 CASE RURD INTRM1 C/O top rams in BOP stack to 7-5/8". Test doors seals to 1,500 psi, OK,
Pull test plug.
03:30 - 04:30 1.00 CASE RURD INTRM1 RlU 7-5/S" casing running tools and equipment.
04:30 - 04:45 0.25 CASE SFTY INTRM1 PJSM with all crew members on running 7-5/8" casing.
04:45 - 10:00 5.25 CASE RUNC INTRM1 RIH with 7-5/8" casing to 10-3/4" casing shoe at 6,581'.
10:00 - 11 :00 1.00 CASE CIRC INTRM1 Circulate casing volume at 70 spm 730 psi.
11:00-12:00 1.00 CASE RUNC INTRM1 Run 7-5/8" casing into open hole section to 8,200'. Hole in good
condition.
12:00 - 14:00 2.00 CASE RUNC INTRM1 PTSM, Run 7-5/S" casing to 11,065'. Hole in good condition. Land on
FMC mandrel casing hanger. Reciprocate casing, PUW 315k, SOW
115Ok.
14:00 - 14:30 0.50 CASE RURD INTRM1 Lay down top drive casing fill up tool. M/U Schlumberger cement head
with plugs loaded.
14:30 - 17:30 3.00 CEMEN CIRC INTRM1 Circulate and reciprocate casing. Break circulation at 3 bpm 400 psi.
Slowly ramp pump up to 7 bpm at 650 psi. PUW 290k, SOW 140k.
0.50 CEMENiPUMP CBU 2X. Hole in good condition.
17:30 - 18:00 INTRM1 PJSM, Schlumberger pump 5 bbls water. PT cement lines to 4,000 psi.
Pump 40 bbls CW-100, Pump 40 bbls mud push II spacer at 12.5 ppg.
Drop btm plug, Pump 52 bbls class 'G' cement at 15.S ppg. Kick out top
plug with 10 bbls water. Yield of 1.16 cu ftIsx, additives .3% D065 + .4%
D165 + .2% D046 + .02% B155. Continue to reciprocate casing. Hole
in good condition.
18:00 - 19:30 1.50 CEMEN DISP INTRM1 Displace cement with rig pumps at 7 bpm 500 psi. Bump plug after 495
bbls mud pumped. Pressure up to 2000 psi. Hold for 5 min. OK. CIP at
19:25 hrs. Continued reciprocating casing during displacement. Landed
casing prior to bumping the plug.
19:30 - 20:30 1.00 CEMEN SEQT INTRM1 Floats did not hold, slight flow back. Pressure up on casing to 500 psi.
Bleed off pressure. Floats held.
120:30 - 21 :00 0.50 CEMEN RURD INTRM1 Rig down cement head and surface lines. Break out and lay down
landing joint. Flush stack.
21 :00 - 22:00 1.00 CASE RURD INTRM1 Rig down casing elevators, long bales, clear rig floor of all casing
NUND IINTRM1 handling tools.
22:00 - 22:30 0.50 CASE Install 7-5/8" FMC Packoff. Test to 5,000 psi, hold for 10 min, OK.
Bleed off test pressure. Secure wellhead.
22:30 - 23:30 1.00 CASE RURD INTRM1 PJSM, set test plug, Change rams in BOP stack. Remove 7-5/8" rams,
install 3-1/2" x 6" VBR.
23:30 - 00:00 0.50 DRILL PULD INTRM1 Install short bales, rig up 5" drillpipe handling equipment.
1/4/2005 00:00 - 06:00 6.00 DRILL PULD INTRM1 B/D and UD 5" DP from mouse hole.
06:00 - 08:00 2.00 DRILL OTHR INTRM1 C/O saver sub, bell guide and back-up jaws on top drive, from 5" to 4".
108:00 - 12:30 4.50 DRILL OTHR INTRM1 RlU for BOP testing, test annular at 250 and 2,500 psi, BOP, top drive
and choke valves at 250 and 3,500 psi. RID test equip. Tested all OK
with state witness.
12:30 - 13:30 I 1.00 DRILL RIRD INTRM1 I Pull test plug, install wear ring, blow down circ lines, install short bales
and 4" elevators.
13:30 - 17:00 3.50 DRILL PULD INTRM1 I M/U mule shoe and P/U RIH with 4" DP from pipeshed to 4,400'.
17:00 - 17:30 0.50 DRILL CIRC INTRM1 Circ surface to surface.
17:30 - 21 :30 4.00 DRILL PULD INTRM1 Cont P/U and RIH, from 4,400' to 10,600' with 4" DP from pipeshed.
21 :30 - 23:00 1.50 DRILL CIRC INTRM1 I RlU and circ surf to surf, at 380 GPM with 2,600 psi, 50 RPM with 7K
, torque
23:00 - 00:00 1.00 DRILL TRIP INTRM1 I POOH from 10,600' to 7,700' and stnd back in derrick.
1/5/2005 00:00 - 02:00 2.00 DRILL TRIP INTRM1 I Cont POOH from 7,700' stnd back 4" DP.
02:00 - 06:00 4.00 DRILL PULD INTRM1 P/U and M/U BHA #7, up-load MWD and surface test at 50 SPM with
I
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
10-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
850 psi., load nuke source.
RIH with BHA #7, filling DP every 25 stnds, to 10,900'.
Circ surface to surface at 61 5PM with 2,350 psi, 60 RPM with 9K
torque.
11 :00 - 12:00 1.00 DRILL DEQT INTRM1 RIU and test casing to 3,500 psi for 30 min on chart. Test OK.
12:00 - 14:00 2.00 DRILL OTHR INTRM1 Cut and slip drill line, inspect brake bands and linkages, service rig and
top drive.
14:00 - 16:00 2.00 DRILL DRLG INTRM1 RIH and tag float collar at 10,976', drill out float collar and cement to
11,063'. WOB=10K, 246 GPM with 2,700 psi, 60 RPM with 11K torque.
16:00 - 18:30 2.50 DRILL CIRC INTRM1 Pump 35 bbl high vis sweep/spacer and displace well to 10.1 ppg
IINTRM1 Flo-Pro, ICP 1,800 psi at 246 GPM, 60 RPM with 11 K torque, FCP
0.50 I DRILL 2,080 psi at 246 GPM, 60 RPM with 6K torque.
18:30 - 19:00 I DRLG Drill out float shoe and new hole to 11,095'. Pulled up into casing.
19:00 - 23:00 4.00 DRILL CIRC INTRM1 Circ and cond mud for FIT at 254 GPM with 2,000 psi, 60 RPM with 6K
torque. Mud weight dropped due to lost calcium carb over shakers,
reduced screens from 180's to 100's and continuously adding S200 to
maintain 10.1 ppg in/out.
23:00 - 00:00 1.00 DRILL FIT INTRM1 RIU and perform FIT to 12.5 EMW. Press up to 820 psi at surface with
10.1 ppg. 7 5/S" shoe at 11,065' md /6,585' tvd.
1/6/2005 00:00 - 02:00 2.00 DRILL OTHR PROD Clean pits in preparation for mud swap from Flo-Pro to LSND.
02:00 - OS:OO 6.00 DRILL CIRC PROD Circ out of pit #1 at 35 SPM with 1,000 psi while bypassing shakers, to
reduce loss of weight material. Cont cleaning pits.
08:00 - 09:30 1.50 DRILL CIRC PROD On-load LSND mud into clean pits while circ, and build Safe-Sure pill.
09:30 - 13:00 3.50 DRILL CIRC PROD Displace well with 450 bbls 10.1 ppg LSND mud, chase with 30 bbl
Safe-Sure pill followed by 40 bbl Hi-Vis pill at 65 SPM with 2,150 psi
RPM at 60 with 7K torque. P/U wt 165K, S/O wt 11 OK, ROT wt 130K
I with 1 OK torque.
13:00 - 17:00 4.00 DRILL TRIP PROD I Check for flow, hole static, obtain SPR and POOH from 11,060' to 245'.
17:00 - 18:00 1.00 DRILL TRIP PROD PJSM on nuke source, stnd back jars and flex DC's, UD MWD and
motor.
1S:00 - 19:00 1.00 DRILL PULD PROD Clean and clear floor, P/U and M/U bit and scraper assem.
19:00 - 00:00 5.00 DRILL REAM PROD Wash and ream to mechanicaly clean casing with scraper at 275 GPM,
20 RPM at 1.5 min per stnd to 5,300'.
1m2005 00:00 - 05:30 5.50 DRILL REAM PROD Cont wash and ream to mechanicaly clean casing with scraper at 275
I GPM with 1,310 psi, 15 RPM with 5K torque from 5,300' to 11,075'.
05:30 - 06:30 1.00 DRILL CIRC PROD CBU while rot and recip at 15 RPM and 11 K torque, 65 SPM at 1,270
psi.
06:30 - 09:00 2.50 DRILL CIRC PROD Pump 30 bbl hi-vis sweep followed by 220 gal Super Pickle casing
I cleaner and chase with 30 bbls hi-vis sweep at 65 SPM with 1 ,2S0 psi.,
I 20 RPM with 11 K torque while rot and recip. Obtain SPR, check for
IfIOW, hole static, pump dry job.
09:00 - 13:00 4.00 DRILL TRIP PROD POOH from 11,075' to 263'.
13:00 - 13:30 0.50 DRILL PULD PROD I Stnd back jars and DC's, UD scraper assem.
13:30 - 16:00 2.50 DRILL PULD PROD I P/U motor, bit and stab, orient MWD, up-load and surface test MWD,
PJSM and load nuke source.
16:00 - 21:00 5.00 DRILL TRIP PROD RIH from 245' to 10,981 filling DP every 20 stnds, and wash from
10,981' to 11,095'.
21 :00 - 22:30 1.50 DRILL CIRC PROD CBU while rot and recip from 11,065' to 11,095' at 245 GPM with 1,9S0
psi.
22:30 - 00:00 1.50 DRILL CIRC PROD Displace well with 10.1 ppg Flo-Pro mud (no lubricants) at 250 GPM
with 2,100 psi., rot and recip at 60 RPM with 11 K torque. P/U wt 205K,
5/0 wt 95K, Rot wt 130K.
1/8/2005 00:00 - 00:30 0.50 DRILL CIRC PROD I Continue displacement of well with 10.1 ppg Flo-Pro mud (no
I
i
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 D-28
1 D-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
1/8/2005 00:00 - 00:30 0.50 DRILL CIRC PROD lubricants) at 250 GPM with 2,100 psi., rot and recip at 60 RPM until
Flo-Pro cleared the bit, then increased RPM to 80 with 11 K torque. P/U
wt 205K, S/O wt 95K, Rot wt 130K. Clean hole ECD at 10.9 ppg.
00:30 - 12:00 11.50 DRILL DRLG PROD UD top single and drill production from 11,095' to 11,436' and monitor
well for 20 min. Cont drilling from 11,436' to 11,454'. P/U wt 165K, S/O
I wt 108K, ROT wt 132K, wt on bit 4K, torque on bot! 10K, torque off bot!
IDRLG 10K, ART = 4.15 hrs, AST = 3.29 hrs, ADT = 7.44 hrs
12:00 - 16:30 4.50 DRILL PROD Cont drilling production from 11,454' to 11,554'. P/U wt 175K, S/O wt
110K, ROT wt 135K, wt on bit 7K, torque on bot! 11 K, torque off bot!
I 7K, ART = 5.29 hrs, AST = 4.89 hrs, ADT = 10.18 hrs. Entire field now
7.50 WAITONlwow in phase 3 condition.
16:30 - 00:00 PROD WOW, CBU and recip DP working low side of hole at 200 GPM with
I 1,680 psi., at!empting to drop angle from +90? to 817.
I
I
1/9/2005 00:00 - 05:00 5.00 WAlTON WOW PROD Phase 3 weather cond, cont trenching low side to drop INC to 87? INC
at 90.04? P/U wt 175K, S/O wt 110K, ROT wt 135K, torque 8K off bot!.
05:00 - 07:00 2.00 WAlTON WOW PROD CBU 2x at 275 GPM, with 2,500 psi while rot and recip at 80 RPM.
07:00 - 16:00 9.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 817. INC at 89.96?
16:00 - 17:00 1.00 WAlTON WOW PROD CBU 1x at 275 GPM, with 2,500 psi while rot and recip at 50 RPM,
torque at 6K off bot!.
17:00 - 00:00 7.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 87? INC holding at
89.96? P/U wt 175K, S/O wt 110K, ROT wt 135K, torque at 8K off bot!,
199 GPM with 1,680 psi., obtained SPR.
1/10/2005 00:00 - 09:00 9.00 WAlTON WOW PROD Cont trenching low side to drop INC from 90? to 817. INC holding at
89.96? P/U wt 160K, S/O wt 110K, ROT wt 135K, torque at 8K off bot!,
64 SPM with 2,300 psi. Still in phase 3 weather condo
09:00 - 21 :00 12.00 DRILL DRLH PROD Time drill from 11,554' to 11,573'. Lost high line power at 10:30 am,
switched to rig and camp generators. ABI increased from 90.2? to
90.9? in the last 15' drilled. Total slide hrs = 17.91, Total rot hrs = 5.04.
21 :00 - 00:00 3.00 DRILL TRIP PROD I Flow check, hole static, Pump OOH from 11,573' to 10,981' at 250
I GPM, and check for flow, hole static, cont POOH wet from 10,981' to
1/11/2005 00:00 - 02:00 2.00 DRILL TRIP PROD 15,400' .
Cont POOH from 5,400' to BHA.
02:00 - 04:00 2.00 DRILL PULD I PROD Stand back jar's and DC's, PJSM remove nuke source, dwn load MWD,
UD motor and bit.
04:00 - 07:00 3.00 DRILL PULD PROD M/U bit, motor and MWD, orient-program-function test MWD, PJSM
load nuke source, M/U DC's and jars.
07:00 - 10:30 3.50 DRILL TRIP PROD RIH with BHA #10 from 250' to 11,106' filling every 25 stnds.
10:30 - 16:00 5.50 DRILL CIRC PROD CBU 1x at 275 GPM with 2,760 psi, while rot and recip at 30 RPM and
6K torque. Blow dwn top drive. Pull into shoe to 11,060' and monitor
I well. Circ through mud cross and cont WOW.
16:00 - 17:00 1.00 DRILL CIRC PROD P/U one single 4" DP and work pipe from 11,075' to 11,109' while CBU
I at 275 GPM with 2,660 psi and rotlrecip at 30 RPM and 6K torque. UD
single, blow dwn top drive.
17:00 - 21 :00 4.00 DRILL CIRC PROD Pull into shoe and cont circ across the top, at 11,060'.
21 :00 - 22:00 1.00 DRILL CIRC PROD RIH to 11,109' and CBU while rotlrecip at 275 GPM with 2,700 psi at 30
RPM and 6K torque.
22:00 - 23:30 1.50 DRILL OTHR PROD Slip and cut drill line, inspect brake bands and linkage, lubricate
draw-works and top drive.
23:30 - 00:00 0.50 DRILL TRIP PROD RIH from 11,040' to 11,573' washing the last 20' to bot!. to resume
drilling.
1/12/2005 00:00 - 02:00 2.00 DRILL DRLG PROD Slide from 11,573' to 11,603' with a 1.76? bend on motor. INC
increased from 90.3? to 90.48? in 30' drilled.
Printed: 1/3112005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 D-28
1 D-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
1/12/2005 02:00 - 02:30 0.50 DRILL TRIP PROD Pumped OOH from 11,603' to 11,140' at 275 GPM.
02:30 - 07:00 4.50 DRILL OTHR PROD Trench low side from 11,140' to 11,170' for side track. Applied weight to
bit and attempted to drill to 11,200'.
07:00 - 11 :00 4.00 DRILL TRIP PROD Pump OOH from 11,200' to 11,040', check for flow, hole static, blow
dwn top drive and POOH wet from 11,040' to BHA.
11 :00 - 13:30 2.50 DRILL PULD PROD Stand back jars and DC's, PJSM and remove nuke source, UD MWD,
increase bend in motor from 1.76? to 2.0?, C/O bit from PDC to Mill
Tooth, M/U MWD, orient and pulse test OK, PJSM and load nuke
source, M/U DC's and jars.
13:30 - 18:00 4.50 DRILL TRIP PROD RIH from 243' to 11,603' filling DP every 25 stnds, washing from 11,554'
to 11,603'.
18:00 - 20:00 2.00 DRILL DRLG PROD Drilled from 11,603' to 11,632', INC dropped from 90.48? to 90.16?,
called town for engineer's recomendation, drilled from 11,632' to
11,663', INC increased from 90.16? to 91.12?
20:00 - 21 :00 1.00 DRILL TRIP PROD Pump OOH at 250 GPM, from 11,663' to 11,140' as per engineer's
recomendation, to trench for OHST.
21 :00 - 00:00 3.00 DRILL OTHR PROD Trenching low side of hole from 11,140' to 11,170' with Mill Tooth bit
and 2? bend in motor, INC at 86.2?, 69 SPM with 2,840 psi, P/U wt =
170K, S/O wt = 115K, AST = 2.4 hrs.
1/13/2005 00:00 - 00:30 0.50 DRILL OTHR PROD Cont trenching from 11,140' to 11,170'
00:30 - 04:00 3.50 DRILL OTHR PROD Side track from 11,170 ' to 11,211', 5K on bit, 70 SPM with 3,000 psi,
dropped INC from 86? to 83?
04:00 - 04:30 0.50 DRILL CIRC PROD CBU 1x at 300 GPM with 3,000 psi and recip DP.
04:30 - 05:00 0.50 DRILL TRIP PROD Pump OOH from 11,211' to 11,070' and flow check, hole static, blow
dwn top drive.
05:00 - 08:30 3.50 DRILL TRIP PROD POOH from 11,070' to BHA.
08:30 - 10:00 1.50 DRILL ,PULD PROD Stand back jars and DC's, PJSM and remove nuke source, drain-down
load-and UD MWD, UD Mill Tooth bit.
10:00 - 11 :30 1.50 DRILL PULD PROD M/U PDC, change motor angle to 1.5?, M/U-orient-prgram and function
test MWD, PJSM and load nuke source, M/U De's and jars.
11 :30 - 15:30 4.00 DRILL TRIP PROD RIH with BHA #12 from 243' to 10,979' filling DP every 25 stnds.
15:30 - 16:00 0.50 DRILL OTHR PROD Service rig and top drive.
16:00 - 16:30 I 0.50 DRILL TRIP I PROD Cont RIH through shoe at 11,065', orient low side and slide into OHST
I at 11,170' with no pump, tag bott at 11,211 '.
16:30 - 00:00 7.50 DRILL DRLG PROD Drill from 11,211' to 11,423' MD/6,600' TVD, at 80 RPM, 64 SPM with
3,040 psi, bit wt 8K, P/U wt = 165K, S/O wt = 11 OK, AST 3.39 hrs, ART
1.25 hrs, ADT 4.64 hrs.
1/14/2005 00:00 - 19:00 19.00 DRILL DRLG I PROD Cont drilling from 11,423' to 12,040', wt on bit 8K, 65 SPM with 2,900
I psi, 70 RPM, flow return rate dropped from 22% to 15%, with a drilling
break from 12,040' to 12,043'. TPV from 626 bbls to 614 bbls for a 12
bblloss. P/U wt 175K, S/O wt 118K with no pump.
19:00 - 20:00 1.00 DRILL DRLG PROD P/U and monitored hole for 5 min, tag bott and resumed drilling slowly,
I 64 SPM at 3,855 psi with ROP of 52' to 12,077' with 33 bbls lost, P/U
and monitored hole for 10 min, fluid loss at 24 bph static, 96 bph
dynamic, resumed pump rate to 64 SPM with 2,900 psi, flow rate at
19%, drilled to 12,089'
20:00 - 22:30 2.50 DRILL CIRC ¡PROD POOH to the above thief zone at 12,040', and build a 40 bbl cal/carb
LCM pill with 10.5 wt and 50 vis. Pump 30 bbls of pill at 20: 15 hrs, at 14
SPM with 684 psi for 1,320 strokes and H20 off, as pill cleared bit
increased H20 to 10 gpm, 22 RPM with 7K torque, recip DP pumping
at 1.4 bpm staging pump rate to 60 SPM with 2,350 psi, return flow rate
at 19%.
22:30 - 23:00 0.50 DRILL ,Shut dwn pump and H20 with bit at 12,026' and monitor static loss at 6
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 0-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
bph.
I Drill ahead from 12,089' to 12,100' at 74 RPM with a 10 bblloss in the
last 10' drilled.
23:30 - 00:00 0.50 DRILL TRIP PROD Pump OOH to 11,400', at a low pump rate of 40 SPM with 1,432 psi, to
spot cal/carb pill as per LCM decision tree. 189 bbls loss total at 00:00
hrs. Total slide hrs 9.95, total rot hrs 7.19, total drlng hrs 17.14
1/15/2005 00:00 - 00:30 0.50 DRILL CIRC PROD Cont pump DOH from 11,400' to 11,253'. Pumped #2 cal/carb pill at
250 GPM with 2,172 psi, started H20 at 20 gpm, at 1,320 strokes pill
exiting drill string, slowed pump rate to 1.5 bpm to spot pill below bit.
00:30 - 01 :00 0.50 DRILL ITRIP PROD Pump OOH and into casing at 10,97040 SPM with 1,432 psi.
01 :00 - 03:00 2.00 DRILL 10THR PROD Blow dwn top drive, close bag, RlU and perform hesitation squeeze of
LCM pill #2, down DP and back side, at 200 psi, 250 psi and 300 psi, 4x
at each pressure range. Squeezed 12 bbls in 1 hour. RID circ lines,
blow dwn surface equip and on-load 225 bbls Flo-Pro.
03:00 - 04:00 1.00 DRILL TRIP PROD RIH, orient through side track, KIU and wash last stnd to bott at 57
SPM with 2,100 psi with no problems.
04:00 - 04:30 0.50 DRILL DRLG PROD Tagged bott at 12,100', slide to 12,113' with 5K on bit, ROP at 90 fph.
At 12,113' encountered drilling break with 0 wt on bit, return flow
dropped from 19% to 0%, with a loss of 18 bbls.
04:30 - 06:00 1.50 DRILL CIRC PROD Built LCM pill #3 as per Engineer and lost circ decision tree, pumped pill
1 #3 at 10.5 ppg and 50 vis, 39 SPM with 1,310 psi, rot and recip, return
I 1.50 I DRILL I flow rate of 0% to 9% as pill exited bit, reduced pump rate to 14 SPM at
I
I I 1610 psi.
106:00 - 07:30 i CIRC PROD Shut dwn pump, pull BHA above LCM to 11,729' and monitor well, 24
bph static 96 bph dynamic loss rates. Pump LCM pill #4 with 10.4 ppg
and 59 vis, reducing pump rate to 1.5 bpm until pill cleared bit, shut dwn
and monitor to allow pill to reach thief zone.
07:30 - 18:30 11.00 DRILL CIRC PROD POOH to shoe with no problem, monitor well with loss of 30 bph static,
pump LCM pill #5, static loss at 24 bph, pump LCM pill #6 while recip
drill string, reduce mud wt to 9.9 ppg in pits, static loss at 18 bph, pump
LCM pill #7 with static loss at 18 bph, pump LCM pill #8 with static loss
at 24 bph/18 bph/ 24 bph/and 12 bph doing 10 min checks, RlU and
squeeze pill into formation for a loss of 8.5 bbls away at 300 psi at 1
bpm, static loss at 18 bpm.
18:30 - 20:30 2.00 DRILL TRIP PROD Orient MWD to low side and RIH to 12,027', attempt to break eire,
pressured up to 3,300 psi with no indication of circ, POOH 5 stnds to
111,520', filling hole on back side, attempt to break eire, DP pressured
I up to 4,000 psi with no indication of circ or press loss.
20:30 - 00:00 3.50 DRILL TRIP PROD I POOH from 12,034' to 2,324' wet, due to plugged BHA, contacted
IAOGCC Rep of up coming BOP test, calculated hole fill = 53 bbls,
actual hole fill = 114 bbls, fluid loss for trip at 00:00 hrs = 61 bbls, total
I fluid lost for last 24 hrs = 711 bbls, Total bbls lost to well since drilling
into thief zone = 900bbls.
1/16/2005 00:00 - 00:30 0.50 DRILL TRIP PROD Cont POOH from 2,324' to 243' due to plugged BHA.
00:30 - 02:30 2.00 DRILL PULD PROD Stnd back jar's and DC's, PJSM and remove nuke source, down-load
and LID MWD, remove bit from motor, attempted to rotate motor in
table for draining, motor would not rotate, bit had one plugged jet.
02:30 - 04:00 1.50 DRILL RIRD PROD Cleared and cleaned floor, pulled wear ring, installed test plug, RlU
BOP test equip, RlU injection line to tubing spool for hole fill while
testing.
04:00 - 09:00 5.00 DRILL OTHR PROD PJSM, test 13 5/8" BOP and associated equip at 250-3,500 psi, witness
waived by AOGCC rep Chuck Schieve.
09:00 - 09:30 0.50 DRILL RIRD PROD Pull test plug, install wear ring, RID test equip, blow dwn surface lines,
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
10-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
Spud Date: 12/20/2004
End: 1/26/2005
Group:
12/15/2004
1/26/2005
1/16/2005 109:00 - 09:30 0.50 DRILL RIRD PROD
109:30 - 12:30 3.00 DRILL PULD PROD
12:30 - 16:30 4.00 DRILL TRIP PROD
16:30 - 17:30 1.00 DRILL OTHR PROD
17:30 - 18:00 0.50 DRILL TRIP PROD
18:00 - 23:00 5.00 DRILL REAM PROD
23:00 - 00:00 1.00 DRILL DRLG PROD
1/17/2005
00:00 - 12:00
1
12:00 - 00:00 I
12.001 DRILL
DRLH PROD
12.00 DRILL
DRLH PROD
1/18/2005 00:00 - 11 :00 11.00 DRILL DRLH PROD
11 :00 - 13:30 2.50 DRILL CIRC PROD
13:30 - 17:00 3.50 I DRILL OTHR PROD
17:00 - 18:30 1.50 DRILL CIRC PROD
18:30 - 00:00 5.50 DRILL DRLH PROD
1/19/2005 00:00 - 15:00 15.00 DRILL DRLH PROD
15:00 - 16:30 1.50 DRILL CIRC PROD
16:30 - 19:00 2.50 DRILL WIPR PROD
static fluid loss at 13 bph.
M/U motor and bit #10 (re-run), M/U-orient-program and function test
MWD, PJSM and load nuke source, M/U De's and jars.
RIH with 4" DP to 9,831' filling pipe every 25 stnds.
PJSM, slip and cut drill line, service rig and top drive.
Cont RIH to 10,979', break eire, obtain SP rate's and orient to low side.
Cont RIH, washing to bot! from 10,979' to 12,113' at 275 gpm with
2,150 psi at 75 RPM rot.
Cant drilling from 12,113' to 12,155', wt on bit 8K, 80 RPM, 65 SPM
with 2,280 psi, P/U wt 175K, S/O wt 100K, ROT wt 135K, AST .21 hrs,
ART .53 hrs, ADT .74 hrs, 11 K torque on bot!, fluid loss for last 24 hrs
433 bbls, Total fluid lost to well since drlng into thief zone 1,333 bbls.
Mud additives at end of report time are as follows:
Mix" Fine and Mix II Medium were added while washing from shoe to
bot!om then stopped when losses were deemed tolerable. The Flo-Pro
NT was delivered to the rig with 20 ppb S-200 and 20 ppb Safe-Carb
250, then Safe-Carb 500 and Safe-Carb 1000 added at rig, 15 min per
sack each while drilling.
Cont drilling from 12,155' to 12,562', bit wt 5K, 75 RPM, P/U wt 165K,
I S/O wt 11 OK, ROT wt 135K, torque on bot! 8K, torque off bot! 7K, 65
SPM at 275 GPM with 2,560 psi.
Cont drilling from 12,562' to 12,802', bit wt 5K, 80 RPM, P/U wt 175k,
S/O wt 108K, ROT wt 135K, torque on bot! 7K, torque off bot! 6K, 65
SPM at 275 GPM with 2,580 psi, total slide hrs 6.48, total rot hrs 8.37,
bbls lost last 24 hrs= 1,230, total bbls lost since drlng into thief zone=
2,563.
Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II
Medium or Dyna Red Medium at 14 sacks per hour to control losses.
Directional Drill from 12802' to 13083' - WOB 10 - RPM 75 - TQ on 7 -
off 6 - GPM 250 - PP on 2710 - off 2370 - PU 160 - SO 105 - ROT 133
Monitor well - Static 6 BPH - Dynamic Loss 38 BPH - Pump LCM Pill
from surface to surface - Monitor well for 10 mins - 2.3 BPH Static Loss
Directional Drill from 13083' to 13130' - WOB 8 - GPM 250 - PP on
2600 - off 2370 - PU 165 - SO 105 -Dynamic loss - 30 BPH
Pump LCM pill thru bit @ 125 GPM 1310 psi - spot @ 12077' MD-
Monitor well for 10 mins - Static Loss 3 BPH - Dynamic Losses @ 24
BPH
Directional Drill from - 13130' to 13280' - WOB 8 - RPM 75 - TQ on 7.5-
off 6 - GPM 254 - PP on 2440 - off 2170 - PU 16 - SO 105 - ROT 133
-Dynamic loss - 38 BPH - Total Slide hrs 7.48 - Total ROT hrs 4.37 -
BBLS lost last 24 hrs = 798 - Avg BPH loss 33 - Total bbls lost since
I drilling into thief zone = 3361
I Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II
Medium or Dyna Red Medium at 18 sacks per hour to controllosses.-
Avg back ground gas 65 units - Max 250 units 12972' - 190 units 12993'
- 200 units 13275'
Directional Drill from 13280' to 13665' - WOB 8 to 10 - RPM 85 - TQ on
8 - off 6.5 - GPM 254 - PP on 2480 - off 2150 - PU 160 - SO 102 - ROT
130-ECD11.05
CBU - GPM 250 - PP 2180
Pump out from 13665' to 12272' - Pump at drlg rate - Pull 3 stands
without pump across theif zone from 12272' to 11983 - Con't Pump out
Printed: 1/3112005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
10-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
from 11983' to 11024' - Hole in excellent shape no problems on trip out
I - 52 bbls to fill hole on trip out - Calulated bbls 15.3 - 37 bbls over
calulated vol
19:00 - 20:00 1.00 DRILL ICIRC PROD CBU at shoe - GPM 250 - PP 1940 - RPM 55 - Lost 40 bbls on CBU -
Clean hole ECD with rotary 10.51 - Without rotary 10.38
20:00 - 22:00 2.00 DRILL IWIPR PROD Orient to low side - RIH slow from 11024' to 13665' - Fill every 5 stands
! - Hole in excellent shape - Lost 17 bbls on trip in
22:00 - 23:00 1.00 DRILL ICIRC PROD CBU - GPM 250 - PP 2130 - Trip gas from 25 units to 173 units - No cut
I in mud weight
23:00 - 00:00 1.00 DRILL DRLH PROD Drill from 13665' to 13686 - WOB 5 - RPM 70 - TQ on 8.5 - off 7 - GPM
250 - PP on 2400 - off 2150 - PU 160 - SO 102 - ROT 130 - ECD 10.8-
Dynamic loss - 30 BPH - Total Slide hrs 4.80 - Total ROT hrs 4.59 -
BBLS lost last 24 hrs = 613 - Avg BPH loss 28 - Total bbls lost since
drilling into thief zone = 3974
Continue with additions of sized Calcuim Carbonate 15 min/sx. Mix II
Medium or Dyna Red Medium at 18 sacks per hour to controllosses.-
Avg back ground gas 100 units - Max 600 units 13575' -
1/20/2005 100:00 - 05:00 5.00 DRILL DRLH PROD Directional Drill from 13686' to 13745' - WOB 5 to 10 - RPM 75 to 80-
I TQ on 8.5 - off 7 - GPM 250 - PP on 2400 - off 2130 - PU 165 - SO 102
- ROT 130 - ECD 10.5 - Losses @ 60 BPH starting @ 13711'
05:00 - 05:30 0.50 DRILL CIRC PROD I Pump 9.8 LCM pill - Circ pill from bit to outside of BHA @ 3 BPM
05:30 - 16:00 10.50 DRILL DRLH PROD Con't Directional Drill from 13745' to 13816' - WOB 10 to 12 - RPM 80 -
TO on 8 - off 7 - GPM 250 - PP 2430 - off 2100 - PU 165 - SO 102-
I ROT 128 - ECD 10.4 - Total Slide hrs 2.44 - Total ROT hrs 7.69 - BBLS
lost last 24 hrs drilling = 831 - Avg BPH loss 35 - Total bbls lost = 4795
16:00 - 17:30 1.50 DRILL TRIP PROD Pump out from 13816' to 12322' - Pump at Drilling rate GPM 250 - PP
1940 - Calulated hole fill 8.3 bbls - Actual hole fill 33 bbls - 24.7 bbls
ICIRC over
17:30 - 18:00 0.50 DRILL PROD Pump and spot 30 bbl LCM Pill from 12322' to 11252' - Loss 25 bbls
18:00 - 19:30 1.50 DRILL TRIP PROD POH from 12322' to 11554' - Hole not taking correct fill - Pump out from
11554' to 10979' - Pump 250 GPM - PP 1820 - Flow check well - Well
Static
19:30 - 20:30 1.00 DRILL CIRC ¡PROD CBU - GPM 275 - PP 2050 - RPM 35 - Loss 42 bbls
20:30 - 00:00 3.50 DRILL TRIP I PROD POH from 10979' to BHA @ 243' - Total vol for fill 89 bbls - Calulated fill
I 64 bbls - 25 bbls over to fill on trip out
1/21/2005 00:00 - 02:30 2.50 DRILL TRIP PROD Stand back Jars - DC's - Remove sources - Drain MWD - Breakoff Bit -
Download MWD - Lay down Neutron tool
02:30 - 05:00 2.50 DRILL PULD PROD Function Blind rams - Pick up Motor - Make up bit - Re-mobilize MWD -
Orient same - Program MWD - Make up Jars - Function test MWD
05:00 - 09:30 4.50 DRILL TRIP PROD RIH with BHA # 14 - From 217' to 11049' @ controlled running speed to
reduce surge pressure - Fill pipe every 25 stands
09:30 - 11 :00 1.50 DRILL DRLG PROD PJSM - Cut drlg line - Top drive service
11 :00 - 14:00 3.00 DRILL DRLH PROD Orient to low side - Wash in @ 2 BPM from 11065' to 12589' - Con't
RIH from 12489' to 13545' filling pipe every 5 stands
14:00 - 14:30 0.50 DRILL REAM PROD Wash and ream from 13545' to 13816' @ 275 GPM - PP 2140 - RPM
75 - TO 8
14:30 - 00:00 9.50 DRILL DRLH PROD Directional Drill from 13816' to 13927' - WOB 12 to 20 - RPM 75 to 85-
TO on 9 - off 8 - GPM 275 - PP 2990 - off 2890 - PU 170 - SO 95 - ROT
130 - ECD - Total Slide hrs 1.77 - Total ROT hrs 5.10 - BBLS lost last
24 hrs drilling = 559 - Total bbls lost = 5354 - Trip gas Max 200 units
1/22/2005 00:00 - 01 :30 1.50 DRILL DRLH PROD Directional Drill from 13927' to 13937' - WOB 12 to 25 - RPM 80 to 85 -
GPM 250 - PP on 2970 - off 2580 - PU 168 - SO 95 - ROT 130 - ECD
10.95
Printed: 1/31/2005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
1 D-28
1 D-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
1/22/2005 01 :30 - 02:30 1.00 DRILL OTHR PROD POOH to 13766' - Mad pass !from 13766' to 13800' as per Geolgist -
GPM 250 - PP 2700 - RIH
02:30 - 00:00 21.50 DRILL DRLH PROD Directional Drill from 13937' to 14174' - WOB 12 to 23 - RPM 80 to 85-
GPM 270 - PP on 3250 - off 2950 - PU 170 - SO 94 - ROT 130 - ECD
11.09 - Total Slide hrs 3.07 - Total ROT hrs 9.67 - BBLS lost last 24 hrs
drilling = 541 - Total bbls lost = 5895 - Max background gas 100 units
I@ 13938'
1/23/2005 00:00 - 10:30 10.50 DRILL DRLH PROD Directional Drill from 14127' to 14672' - TD 6 3/4" Production hole-
WOB 12 - RPM 80 to 85 - TQ on 9 - off 8 - GPM 300 - PP on 3300 - off
12990 - PU 170 - SO 95 - ROT 130 - ECD 11.38 - Total Slide hrs 4.57 -
I Total ROT hrs 7.33 - BBLS lost last 24 hrs drilling = 527 - Total bbls lost
= 6422 - Max gas 2938 units @ 14400'
10:30 - 13:00 2.50 DRILL CIRC PROD CBU 2 X - GPM 300 - PP 3050 - RPM 85 - TQ 8 - Flow check well -
I Well static
13:00 - 14:30 1.50 DRILL TRIP PROD I Pump out from 14672' to 14119' @ 275 GPM - PP 2780 - From 14119'
1 to 13545' Pump @ 85 GPM - PP 720 - Due to mud line wash out
14:30 - 16:30 2.00 DRILL TRIP PROD i POOH without pump due to mud line washout - From 13545' to 11030'
16:30 - 23:00 6.50 DRILL OTHR PROD I Circulate GPM 130 - PP 1240 - Repair mud line
23:00 - 00:00 1.00 DRILL TRIP PROD I Orient to low side - RIH from 11030' to 12853' - Fill string - Blow down
TOp drive
1/24/2005 00:00 - 01 :00 1.00 DRILL TRIP PROD ICon't RIH from 12653' to 14672' - From 13800' to 14300' taking 20 to
! 40k through spots in that section - No other problems on trip in
01 :00 - 03:00 2.00 DRILL CIRC PROD I CBU 2 X - GPM 300 - PP 3040' - RPM 90 - TQ 8K - Trip gas 315 units -
03:00 - 04:30 1.50 DRILL TRIP PROD I Flow check well - Well static - Pump out @ drilling rate to 13500' - Hole
in good shape - No problems
04:30 - 05:00 0.50 DRILL TRIP PROD Flow check - Well static - RIH from 13500' to 14672' - Tight spot @
114230' - Work through - Clean up - Con't RIH from 14230' to 14672'
05:00 - 08:30 3.50 DRILL CIRC PROD CBU 3 X - GPM 300 - PP 3000' - RPM 90 - TQ 8 - Trip gas 100 units -
Flow check - Well static
08:30 - 11 :30 3.00 DRILL TRIP PROD Pump out of hole @ drlg rate - From 14672' to 11030'
11 :30 - 12:30 1.00 DRILL CIRC PROD CBU 1 X - GPM 300 - PP 2550 - RPM 40 - TQ 5K - Flow check - Well
static
12:30 - 16:00 3.50 DRILL TRIP PROD POOH from 11030' to BHA 217'
16:00 - 17:30 1.50 DRILL PULD PROD LD BHA - Jars - Flex Collars - MWD - Flush motor - Break bit - Lay
down motor
17:30 - 18:30 1.00 DRILL RIRD PROD Lay down handling tools - Clear rig floor - Rig up 41/2" liner running
tools
18:30 - 23:00 4.50 CASE PULR PROD PJSM - Pick up 4 1/2" Slotted liner - Total Slotted 74 joints - Total Solid
jts - 39 - 5 Swell Packers - Picked up
23:00 - 23:30 0.50 CASE PULR PROD Change handling equipment - PU and make up Baker 5 1/2" Seal
Assembly - Baker Flex-Lock Hanger 5 1/2" X 7 5/8" - Baker ZXP Liner
Top Packer 5 1/2" X 7 5/8" - Liner PUW 85 - SOW 82
23:30 - 00:00 0.50 CASE OTHR PROD Load hanger fluid in hanger
00:00 - CASE PROD BBLS lost last 24 hrs drilling = 381 - Total bbls lost = 6803
1/25/2005 00:00 - 03:00 3.00 CASE RUNL PROD RIH with 4 1/2" 12.6# L-80 IBT-M Slotted liner from 3754' to 11050'
03:00 - 03:30 0.50 CASE CIRC PROD Circ drill pipe vol- @ 146 GPM - PP 600 psi - Liner PUW 160 - SOW
115
03:30 - 05:00 1.50 CASE RUNL PROD Con't RIH with liner from 11030' to 14672' - Tag bottom pick up 1 foot-
Work through tight spot @ 14235' on trip in - On Bottom POW 185-
SOW 100
05:00 - 05:30 0.50 CASE CIRC PROD Circ one drill pipe vol @ 180 GPM - PP 940
I
i 05:30 - 06:00 0.50 CASE CIRC PROD Drop packer setting ball - Pump at 180 GPM - PP 950 - for 600 stks -
I
Printed: 1/3112005 3:04:35 PM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
10-28
10-28
ROT - DRILLING
d 14cm@conocophillips.com
Doyon 14
Start:
Rig Release:
Rig Number:
12/15/2004
1/26/2005
Spud Date: 12/20/2004
End: 1/26/2005
Group:
1/25/2005 05:30 - 06:00 0.50 CASE CIRC PROD Reduce rate to 100 GPM - PP 620 for 300 stks
06:00 - 06:30 0.50 CASE OTHR PROD Pressure up to 2000 psi to set hanger - Con't Pressure up to 3800 psi
to release HR setting tool - PU to verify release from liner - Rotate
slowly slack off 70K three times to set ZXP packer - Close Annular -
pressure up to 1500 psi on annulus and hold for 10 mins to confirm
ZXP is set - Bleed off pressure - TOP 10922.47 - BOL 14671
06:30 - 07:30 1.00 CASE CIRC PROD CBU - GPM 381 - PP 2140 - Reciprocated DP while CBU - Flow Check
- Well static
07:30 -15:00 7.50 CASE OTHR PROD POOH - Laying down 4" drill pipe
15:00 -15:30 0.50 CASE OTHR PROD Lay down Baker Liner running tool - Make service breaks
15:30 - 16:30 1.00 CASE OTHR PROD RIH - 40 stands 4" drill pipe out of derrick
16:30 - 19:30 3.00 CASE OTHR PROD POOH - Laying down 4" drill pipe
19:30 - 20:00 0.50 CMPL TN RURD CMPL TN Pull wear ring - Clear rig floor - Rig up completion running equipment
20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN PJSM on running completion - Pick up and run 4 1/2" L-80 12.6# IBT-M
I I completion - Total jts ran 135 - Depth @ 4295'
I
1/26/2005 00:00 - 05:00 5.00 CMPL TNI RUNT PROD Con't RIH with 41/2" completion to 10900' ".
05:00 - 06:30 1.50 CMPL TNi SOHO PROD I Space out - Install hanger - Land string - RILDS
06:30 - 07:00 0.50 CMPL TNI SEQT PROD ¡Test TWC to 1000 psi from top - LD Landing Jt
07:00 - 09:00 2.00 CMPL TNi NUND PROD I Blow down lines on rig flooor - ND Nipple down BOP stack
09:00 - 10:30 1.50 CMPL TN! NUND PROD I NU FMC Adapter flange test to 5000 for 10 mins - NU Tree /
10:30 - 12:00 1.50 CMPL TN! RURD PROD I Rig up hot oil truck to test tree -
12:00 - 13:30 1.50 CMPL TNi SEQT PROD Test Tree - 250 low 5000 high
13:30 - 15:00 1.50 CMPL TNI FRZP PROD I Pull TWC - Rig up to Annulus - Pump 84 bbls - Pump 32 bbls before
I I getting returns - Pump @ 1.75 bpm - PP 850
15:00 - 16:00 1.00 CMPL TNi FRZP PROD I U-Tube freeze protect - IA 25 psi - Tubing 0 psi - PJSM change out
i saver sub on top drive while U-tubing well
16:00 - 19:00 3.00 CMPL TNi RURD PROD Blow down lines - Install BPV with dry rod - Install 'VR" plugs in IA - OA
- OA 50 psi - Secure well - Release rig 19:00 hrs
Printed: 1/31/2005 3:04:35 PM
1 D..28 Ho ntal Well
Completion Schematic
~/~/
ConocoPhillips
l
4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-80 NSCT pin down (Special Drin to 3.91")
4-1/2" 12.6# L-80 IBT Spaceout Pups as Required (Special Drift to 3.91")
4-1/2" 12.6# L-80 IBT Tubing to Surface (Special Drift to 3.91")
4-1/2" Camco 'DS' nipple wi 3.875" No-Go Profile set at 506' MD
Surface csg.
10-3/4" 45.5# L-80 BTC
Special Drift - 9.875"
6581' MD 14413' TVD
4-1/2" 12.6# L-80 IBT tubing to landing nipple (Special Drift to 3.843")
20" conductor
118' BGL
4-1/2" xi" Camco 'KBG-Z' Mandrels w/ DV's (Maj(. 005.984", ID 3.833") Spaced
out wi 4-1/2" 12.6# L-80 IBT tubing (Special Drift to 3.843") as follows:
GLM#
1
2
3
4
5
6
MD-RKB
3056
5377
6949
8203
9181
9973
4-1/2" Camco 'DB' nipple w/3813" No-Go Profile set @bottom of
tangent section 10,018 MO
4-1/2" 12.6# L-80 IBT tubing from 'DB' nipple to sliding sleeve
(Special Drift to 3.843")
Baker4-Yo," CMU Sliding Sleeve, 3.81" DB Profile (Ran in open
position) 10,890' MO
1 jt 4-1/2" 12.6# L-80 IBT tubing (Special Drift to
4.75" 00 Saker casing seal assembly w/17 Ft.istroke, 4c1/2"1;2.6#
L-80 IBT box up (landed 4' off fully landed pOsition) top @ 10,936'MO
Intermediate csg.
7518" 29.7# L-80 BTCM
11,065' MO 16587' TVO
4 y,," x 6.3" Swell Packers for isolation ofpotential
conductive faults or wet intervals
---
Liner Assemblv - Top of tie-back sleeve æ;p 10 922' MO
Baker 5 Yo," x 7 5/8" 'ZXP' Liner Top Isolation Packer wi HRO running profile
Baker 5 Yo," x 7 5/8" RS Nipple
Abandoned lateral 11 , 170' - 11,663' MO
10-28 L 1 PTO 204-238 (lateral was not
cased or plugged)
Main lateral is designated as 10-28 PTD
204-237
Baker 5 Yo," x 7 5/8" 'Flexlock' Liner Hanger
Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore)
4 h" 12.6# L-80 IBT alternating slotted and blank pipe wi swell packers
C4/C3 Lateral to 14,672' MD
4 Yo," ROT 'Silver Bullet' Shoe ran on a bent joint of 4 Yo," 12.6# L-80 liner
4 Yo," x 6.3" Swell Packer ran in conjuntion with blank pipe _ top
of swell packer @ 11,110' MD
Scott Lowry 2/08/05
-
ConocJr)'hillips
Alaska
.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Scott L Lowry
Phone (901) 265-6869
Email: Scott.L.Lowry@conocophillips.com
R EIVED
JAN 2 lD05
January 20,2005
Alaska ¿t¿
Commission
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
Re: Changes to Permits to Drill, Kuparuk Producers, 10-28 & 10-28 L1
Dear Commissioners:
ConocoPhillips Alaska, Inc. hereby requests to alter the permits to drill for Kuparuk producers 10-28 and
10-28 Ll. Due to unexpected reservoir conditions, CPAI did not drill the originally planned 1D-28 (PTD
204-237, API 50-029-23237-00). Therefore, the 10-28 L1 (PTD 204-238, API 50-029-23237-60) will be
the only well drilled from this slot on drill site 1D. Additionally, an open-hole sidetrack was necessary due
to difficulties steering the well bore. 493' of open hole was abandoned. The abandoned hole is within
the oil-bearing Kuparuk reservoir sands. It was not cemented, and will likely stay open and contribute
production to the main well bore.
To simplify record keeping, CPAI proposes the following:
Re-name 10-28 L1 existing records as 1D-28, with a permit to drill number of 204-237 and an
API number of 50-029-23237-00. This name, permit number, and API number will be used for all
subsequent reporting purposes for the well.
Re-name all data from the abandoned 493' interval as 10-28 L1, with a permit to drill number of
204-238 and an API number of 50-029-23237-60. This name, permit number, and API number
will be used for all subsequent reporting purposes for this interval.
ConocoPhillips Alaska, Inc. will submit a completion report (form 10-407) for both wells.
If you have any questions or require any further information, please contact me at 265-6869.
s¡ncerelyt ,¿J
;JaJf ~
Scott Lowry /
Drilling Engineer
0, R I f~ ~,L^ r
I!,,'":) G ':">;,._)' ~ ,,],l..,,\ L
Re: lD-28 (204-237) / lD-28 L1 (204-238)
Scott,
Let me know if I don't properly state what happened:
1. CPAI first drilled the proposed ID-28Ll (Permit to Drill204~238, API Number 50-029-23237-60), but
2. due to unexpected reservoir conditions, CPAI is not going to drill the planned ID-28 (PTD 204-237, API Number
50-029-23237-00), and
3. therefore, ID-28Ll (PTD 204-238) will be the only well drilled from this slot on the drilling pad.
4. While drilling ID-28Ll, an openhole sidetrack was needed to get past a "hard spot" within the Kuparuk reservoir
sands, and
a. the open interval that was abandoned is about 500' in length and it lies within the oil-bearing Kuparuk
reservoir sands,
b. the abandoned open interval was not cemented, and
c. the abandoned open interval will likely stay open and could contribute production to the main well bore.
So, to simplify record-keeping, CPAI should (if this doesn't cause CPAI a large amount of work and confusion):
1. Re-label the ID-28Ll existing records as ID-28, with a Permit to Drill number of204-237, and an API number of
50-029-23237-00. Use that name, PTO and API for all subsequent reporting purposes for the well.
2. Re-label any data from the existing, abandoned 500' open interval as ID-28L 1, with a Permit to Drill number of
204-238, and an API number of 50-029-23237-60. Use this name, PTD and API for all subsequent reporting
purposes. To close out Commission's well file for this abandoned, open interval, CPAI should also submit a
Completion report (Commission form 10-407) for it.
3. Send a letter to the Commission that explains what happened and details the name and number changes for the
existing well and the abandoned, open interval for our files.
My intent is clear record-keeping, and my reasoning is as follows:
1. The current well bore that is completed with a slotted liner will likely contribute most of the production, so it
seems best to consider it as 10-28, rather than as a lateral to the much shorter, abandoned, open interval.
2. This abandoned, open interval is similar to the pilot holes that are drilled in the Alpine Field. There, a pilot hole
is drilled first to test sand quality or thickness, then it is plugged back and the main well bore (for example: CDI-99,
50-103-23456-00) is drilled. To properly segregate and track drilling and logging information, each pilot hole is
given a separate name and API number (example: CDI-99PH1,50-103-23456-70). In your case, the abandoned,
open interval is like a pilot hole -- it was drilled first and then abandoned, but it is still open and capable of
production (like the open hole completions at Alpine), so it really should have an "L 1 " appended to the name and a
"-60" suffix to the API number to indicate it is a lateral. For clear record-keeping, it has been the Commission's
policy to assign a separate permit to drill number to each lateral, so it won't hurt to apply PTD 204-238 to this open
"lateral. "
Let me know if this is not workable for you, or if it is confusing.
Thanks,
Steve Davies
Lowry, Scott L wrote:
Steve,
I am a little confused on our naming convention for this well. I am hoping you can provide some assistance. We
have deviated from our original plans. Originally, we planned to drill a lower lateral in the Kuparuk "C1", which was
1 of2
1/21/20053:46 PM
Re: lD-28 (204-237) / lD-28 L1 (204-238)
designated as 1 D-28, and the! would drill an upper lateral in the Kuparuk ".3" intervals which would be
designated as 1 D-28 L 1. The zones came in deeper than expected and the "C1" is believed to be below the oil-water
contact. Thus, the lateral designated as 1 D-28 (PTD 204-237) will not be drilled. However, the upper lateral
(originally permitted as 1 D-28 L 1 PTD 204-238) is being drilled. Should the naming convention for the 1 D-28 L 1
lateral be changed since it is now the only lateral?
To add to the confusion, we performed an open hole sidetrack in this lateral (the lateral originally named 1 D-28 L 1)
because we were having problems steering. We had to back up about 500' to find a spot soft enough to allow an
open hole sidetrack. We did not pump cement in the abandoned lateral, nor did we put casing in it.
Please feel free to call me if I have confused you. I want to make sure we are consistent in naming these laterals.
Thanks,
Scott L Lowry
Operations Drilling Engineer
ConocoPhillips Alaska, Inc.
Office: 907-265-6869
Cell: 907-240-5322
20f2
1/21/20053:46 PM
Subject: ~8 (204-~ 1D-28 L1 (204-238) .
From: "Lowry, Scott L" <..L.Lowry@conocophillips.com>
Date: Mon, 17 Jan 200506:08:01 -0900
To: Thomas Maunder <tom_maunder@admin.state.ak.us>
CC: steve_davies@admin.state.ak.us, "Thomas, Randy L" <Randy.L.Thomas@conocophillips.com>
Tom,
The "abandoned" portion of the hole does have pay and is expected to be productive. The new well bore
will be covered with a slotted liner.
Scott L Lowry
Operations Drilling Engineer
ConocoPhillips Alaska, Inc.
Office: 907-265-6869
Cell: 907-240-5322
-----Original Message-----
From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us]
Sent: Friday, January 14, 20056:42 PM
To: Lowry, Scott L
Cc: steve_davies@admin.state.ak.us; Thomas, Randy L
Subject: Re: 10-28 (204-237) / 10-28 L1 (204-238)
Scott,
Does the "abandoned" portion ofthe hole have pay in it that you expect to be productive?? I
don't have the file right here. Is some portion of the new well to be covered with casing/liner??
In some of the wells in Alpine when the extra portions are going to contribute so section has
been an L1. I will have to leave this one for Steve.
Tom
Lowry, Scott L wrote:
Steve,
I am a little confused on our naming convention for this well. I am hoping you can provide
some assistance. We have deviated from our original plans. Originally, we planned to drill a
lower lateral in the Kuparuk "C1 ", which was designated as 1 0-28, and then we would drill an
upper lateral in the Kuparuk "C4/C3" intervals which would be designated as 1 0-28 L 1. The
zones came in deeper than expected and the "C1" is believed to be below the oil-water
contact. Thus, the lateral designated as 1 0-28 (PTO 204-237) will not be drilled. However, the
upper lateral (originally permitted as 10-28 L 1 PTO 204-238) is being drilled. Should the
naming convention for the 10-28 L 1 lateral be changed since it is now the only lateral?
To add to the confusion, we performed an open hole sidetrack in this lateral (the lateral
originally named 10-28 L 1) because we were having problems steering. We had to back up
about 500' to find a spot soft enough to allow an open hole sidetrack. We did not pump cement
in the abandoned lateral, nor did we put casing in it.
Please feel free to call me if I have confused you. I want to make sure we are consistent in
naming these laterals.
lof2
1/21/20053:43 PM
Thanks,
.
.
Scott L Lowry
Operations Drilling Engineer
ConocoPhillips Alaska, Inc.
Office: 907-265-6869
Cell: 907-240-5322
20f2
1/21/20053:43 PM
,7
U
.
(ID~ ~~~~æ~
A'fA~1iA. OIL AND GAS
CONSERVATION COMMISSION
Randy Thomas
Greater Kuparuk Area Drilling Team Leader
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, AK 99510-0360
.
/
FRANK H. MURKOWSKI, GOVERNOR
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE. ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Kuparuk ID-28
ConocoPhillips Alaska, Inc.
Permit No: 204-237
Surface Location: 357' FNL, 419' FEL, SEe. 23, TIIN, RI0E, UM
Bottomhole Location: 4876' FNL, 1684' FEL, SEC. 18, TllN, RllE, UM
Dear Mr. Thomas:
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 approvals 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. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's petroleum field inspector at (907) 659-3607 (pager).
Daniel T: Seamount, II.
Commissioner
DATED this-L day of December, 2004
cc: Department ofFish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
Conoc~illips
Alaska
.
Post Office Box 100360
Anchorage, Alaska 99510-0360
Randy Thomas
Phone (907) 265-6830
Email: Randy.L.Thomas@conocophillips.com
November 22, 2004
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Suite 100
Anchorage, Alaska 99501
Re: Applications for Permit to Drill, Kuparuk Producer, 10-28 & 10-28 L1
Dear Commissioners:
/
,-
ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore production well, a
multilateral horizontal well in the Kuparuk "(1" and "C4/C3" sands. The main bore of the well will be
designated 1D-28, and the lateral bore of the well will be designated 1O-28Ll. /
Please find attached for the review of the Commission a Form 10-401 and the information required by 20
ACC 25.005 for each of these well bores.
The expected spud date of 10-28 is December 11, 2004.
If you have any questions or require any further information, please contact Scott Lowry at 265-6869.
Sincerely,
\ ,.~ \.
Randy Thomas
Greater Kuparuk Area Drilling Team Leader
ORIGiNAL
PERMIT TO DRILL
20 AAC 25.005
t-
tll
It)q
.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
.
1a. Type of Work: Drill~ RedrillU 1 b. Current Well Class: ExploratoryU Development Oil ~ Multiple Zone 0
Re-entry 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0
2. Operator Name: 5. Bond: ~ Blanket U Single Well 11. Well Name and Number:
ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1 D-28
3. Address: 6. Proposed Depth: 12. FieldlPool(s):
<" f
P.O. Box 100360 Anchorage, AK 99510-0360 MD: 11929' TVD: 6624' Kuparuk River Field
4a. Location of Well (Govemmental Section): 7. Property Designation:
, -
Surface: 357' FNL, 419' FEL, Sec. 23, T11 N, R10E, UM / ADL 25650 & 28243 Kuparuk Oil Pool
Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date:
4760' FNL, 2982' FEL, Sec. 18, T11N, R11E, UM ALK 468 & 3814 12/11/2004
Total Depth: 9. Acres in Property: 14. Distance to
. Nearest Property: 12260'
4876' FNL, 1684' FEL, Sec. 18, T11N, R11E, UM 2560
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest ./
Surface: x- < Well within Pool: 10-12,2343' @ 10615'
560671 y- 5959309 Zone- 4 (Height above GL): 34 feet
16. Deviated wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035)
. ..
Kickoff depth: 300' ft. Maximum Hole Angle: 89° Downhole: 3511 psig Surface: 2782 psig
18. Casing Program Setting Depth Quantity of Cement
Size Specifications Top Bottom c. f. or sacks
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data)
30" 20" 91.5# H-40 Welded 118' 34' 34' 152' 152' 16 cu yds ABI, Type III
13.5" 10.75" 45.5 L-80 BTC 6537' 34' 34' 6571' 4413' 830 sx AS Lite, 460 sx LiteCrete
9-7/8" 7-5/8" 29.7 L-80 BTCM 10631 ' 34' 34' 10665' 6522' 240 sx Class G
6.75" 4.5" 12.6# L-80 IBT 1214' 10715' 6525' 11929' 6624' slotted liner
19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations)
Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured)
Casing Length Size Cement Volume MD rvD
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation Depth MD (ft): Perforation Depth TVD (ft):
20. Attachments: Filing Fee 0 BOP SketchD Drilling program~ Time v. Depth Plot U Shallow Hazard Analysis I,;J
Property Plat 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 requirements 0
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Scott Lowry @ 265-6869
Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader
Signature ~~ Phone ·2.b~6(J 30 Date H/'Z-?../O'1
p~ . ·~h"ron AII.~UD-Drake
\. Commission Use Only
Permit to D~ API Number: Permit Approì /i See cover letter
Number: . -237 50-tJZq ~ 2..3 237- Db Date: 1;;'- J 0 L/' for other requirements
Conditions of approval : Samples required o Yes ~ No Mud log required iYes ~ No
Hydrogen sulfide measures ~Yes LJ No Directional survey required Yes 0 No
Other: 'Ssca ~\. "'" c'\ ~\h'"\... \S~ \' ~s~" ~~ ~s\,\,,-\(t-\)(). \ t- \ L\.1)().,'t~,
Original Sig~Ie, BY ORDER OF /"t,.,// //)1/
Approved by: nÃN NT THE COMMISSION Date:
ORIGINAL I {
Form 10-401 Revised 12/2003 Submit in Duplicate
·
.Plication for Permit to Drill. Well 1 D-28
Revision No.O
Saved: 19-Nov-04
Permit It - Kuparuk Well #1 D-28
Application for Permit to Drill Document
Moximize
Well VOII,II¡!
Table of Contents
1. Well Name...... ................... ........................ ............. ...................... ........ .............. ....... 2
Requirements of 20 AAC 25.005 (f)........................................................................................................2
2. Location Summary........ .... ........................ ... .... ..... ..... .............. ..... .......... ............ ....... 2
Requirements of 20 AAC 25.005(c)(2) .......................... ............................... .......................................... 2
Requirements of 20 AAC 25. 050(b).. ....................................................... .................... ..... ...................... 3
3. Blowout Prevention Equipment Information ......................................................... 3
Requirements of 20 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. Dri II i ng FI u id Program ........................... ........................................................... ....... 5
Requirements of 20 AAC 25.005(c)(B) ... .............. ..... .... .................. ..... .................... ............... ....... ........ 5
Surface Hole Mud Program (extended bentonite) .................................................................................. 5
Intermediate Hole Mud Program (LSND) . ........... .................... ....... ........... ...... ..... ..... ........ ...... .......... ..... 5
Lateral Mud Program (MI FloPro)....................................................................... .................................... 5
9. Abnormally Pressured Formation Information ...................................................... 6
Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6
10. Seismic Analysis.... ..... ....... ............. .......................... ........................... ........ ....... ...... 6
Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 6
11. Seabed Condition Analysis .....................................................................................6
Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6
10-28 PERMIT IT. doc
Page 10t8
Printed: 19-Nov-04
ORIGINAL
·
.Plication for Permit to Drill. Well 1 D-28
Revision No.O
Saved: 19-Nov·04
12. Evidence of Bonding ...............................................................................................6
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6
13. Proposed Drilling Program .....................................................................................6
Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6
14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7
Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7
15. Attach ments .... ............. ..... ................ ..... .............. ....................... ...................... .................. ....... ....... ...... 8
Attachment 1 Directional Plan....................................... ................ ......................................................... 8
Attachment 2 Drilling Hazards Summary.......... ......... ............ .................. ................... .............. .............. 8
Attachment 3 Cement Summary.... ......... ................................................. ......... ............... ...... ................ 8
Attachment 4 Well Schematic. .................................... ........................................................................... 8
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the o¡.:>erator and a unique API number assigned by the commission
under 20 MC 25.040(b). For a well with multip/e we/I branche~ each branch must similady be identified by a unique name and API
number byaddlilg a suffix to the name designated for the well by the operator and to the number as:.1gned to the well by the
commission.
The well for which this Application is submitted will be designated as lD-28.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An application for a Permit to Drill must be aa-ompanied by each of the following item~ except for an item already on file with the
commission and Identified in the application:
(2) a plat identifying 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 eal.:ÝJ objective formation and at total depth,
referenced to governmental section lines.
(B) the coordinates of tIle proposed location of the wel/ at the surface, referenced to the state plane coordinate system for this
state as maintained by the Nationa/ Geodetic Survey in the Nationa/ Oceanic and Atmospheric Administration;
(C) the proposed depth of the well at the top of each objective fomlation and at total depth;
Location at Surface
ASP Zone 4 NAD 27 Coordinates
Nothings: 5,959,309 ~'Eastings: 560,671 '
I
357' FNL. 419' FEL Section 23, TllN, Rl0E, UM
I RKB Elevation-' 105.4' AMSL
I Pad Elevation-' 70.9' AMSL
Location at Top of
Productive Interval
Ku aruk "C4" Sand
ASP Zone 4 NAD 27 Coordinates
Northings: 5,960,251 Eastings: 568,327
4760' FNL, 2982' FEL, Section 18, TllN, RllE, UM
Location at Total De th
ASP Zone 4 NAD 27 Coordinates
Northings: 5,960,148 Eastings: 569,626
10 615
6517
6412
4876' FNL 1684' FEL Section 18 TllN RllE UM
Measured De th RKB: 11 929
Total Vertical De th RKB: 6 624
Total Vertical De th 55: 6 519
and
(D) other info/mation required by 20 MC 25.050(b);
10-28 PERMIT IT. doc
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·
.Plication for Permit to Drill, Well 1 D-28
Revision No.O
Saved: 19-Nov-04
Requirements of 20 AAC 25.050(b)
If a well is to be intentionally deviate~ 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 witl7in 200
feet or any portion of the proposed well¡
Please see Attachment 1: Directional Plan
and
(2) for all wells within 200 feet of the proposed wel/cae
(A) list the names of the operators of those wells, to the extent that those names are known or discoverable In public record~
and show that each named operator has been fumisl¡ed a copy of the applIcation by certífìed mai~' or
(B) state that the applicant is the only affected owner.
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 Dnll must be accompanied by each of the followIng item." except for an Item already on file with the
commIssion and identified In the applIcation:
(3) a dIagram and desCliptlon of the blowout prevention equipment (SOPE) as requIred by 20 MC 25.035, 20 AAC 25.03~ or 20
MC 25.03~ as applkable;
An API 13-5/8" x 5,000 psi BOP stack will be utilized to drill and complete weIl1D-28. Please see
information on the Doyon Rig 14 blowout prevention equipment placed on file with the Commission.
1
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 Item~ except for an Item already on file with the
commission and identified in the application:
(4) information on drilling hazard~ including
(A) the maximum downhole pressure that may be encounteretí CrIteria used to determine it, and maximum potential surface
pressure based on a methane gradient;
The expected reservoir pressures in the Kuparuk sands in the 1D-28 area vary from 0.49 to 0.53 psi/ft, or ...
9.5 to 10.2 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom
hole pressure data from the nearby Kuparuk wells.
The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a
methane gradient (0.11) and the deepest planned vertical depth of the Kuparuk sand formation is 3,510
psi, calculated thusly:
MPSP =(6,624 ft)(0.53 - 0.11 psi/ft)
= 2,782 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 zone~ 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 AAC 25.005 (c)(5)
An application for a Permit to Drill must be accompanied by each of the following Item0 exæpt for an item already on file with the
commission and Identified in the application:
(5) a description ofthe procedure for conducting formation integnty test~ as requIred under 20 MC 25.030(t}/
10-28 PERMIT IT. doc
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.Plication for Permit to Drill, Well 1 D-28
Revision No.O
Saved: 19-Nov-04
A procedure is on file with the commission for performing LOT's. For 1D-28 the procedure will be
followed with one exception. The surface casing shoe will be pressured until leak-off occurs and the 16.0
ppg EMW maximum will not be observed. (see step 6 in the procedure)
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An application for a Pem¡it to Dnll 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 MC 25.030., and a description of any slotted liner; pre-
perforated liner" or screen to be installed;
6-3/4"
Lower
Lateral
1D-:2.
6-3/4"
Upper
Lateral
(lD-28
Ll
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
(vmmission and identified in the application:
(7) a diagram and description of tile diverter system as required by 20 MC 25. 035; unless this requirement is waived by the
commission under 20 MC 25-035(17)(2);
Casing and Cementing Program
See also Attachment 3: Cement Summa
Hole
Size
in Grade
H40
Btm
MD/TVD
ft
152 / 152
Top
MD/TVO
ft
34 / 34
Length
ft
118
Connection
Welded
10-3/4
13-1/2
34 / 34
6571 /4413
BTC
6537
45.5
L-80
7-5/8
10665 / 6522
9-7/8
10631
34 / 34
29.7
L-80
BTCM
.~"~..'~...,,._,,-.,.,.-
__"._tl~'''_'''~''''''''~''·_''·M"n~'~
10715 / 6525
11929 / 6624
12.6
L-80
1BT
1214
-'-
10515 / 6507
14873 / 6609
12.6
L-80
1BT
4358
slotted
Cement Pro ram
Cemented to
surface with
16 cu yd AB1,
T eIII
Cemented to
Surface with
830 sx ASLite
Lead, 460 sx
LiteCRETE Tail
Cement Top
planned @
9815' MD /
6227' 1VD.
Cemented w/
Slotted- no
cement
A 21-1/4",2000 psi annular with a 16" diameter diverter line will be the diverter system used in the
drilling of 1D-28. Please see diagrams of the Doyon 14 diverter system on file with the Commission.
ORIGINAL
10-28 PERMIT IT. doc
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·
.Plication for Permit to Drill, Well1D-28
Revision No.O
Saved: 19-Nov-04
8. Drilling Fluid Program
Requirements of 20 AAC 25.005(c)(B)
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 app!ìcation;
(B) a drilling fluid program, including a diagram and description of the drilling fluid ::.ystem, as required by 20 AAC 25.033/
Drilling will be done with muds having the following properties over the listed intervals:
Surface Hole Mud Program (extended bentonite)
Spud to Base of Permafrost Base of Permafrost to Total Depth
Initial Value Final Value Initial Value Final Value
Density (ppg) 8.5 - 8.6 <9.6 <9.6 10.1
Funnel Viscosity 250 - 300 250 - 300 200 - 250 200 -250
(sec)
Yield Point 50 - 80 50 - 80 30 - 60 30 - 60
(cP)
Plastic Viscostiy 8 - 15 11 - 22 12 - 30 12 - 30
(lb1100 sf)
10 second Gel 15 - 30 15 - 30 15 - 30 15 - 30
Strenqth (lb1100 sf)
10 minute Gel 25 - 55 25 - 55 25 - 65 25 - 65
Strength (lb1100 sf)
pH 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5
API Filtrate(cc) 8-15 <8 <8 <6
Solids (%) 5-8 5-8 5-8 6 - 10
,
Intermediate Interval Mud Program (LSND)
Initial Value Final Value through HRZ
Density (ppg) 9.8 - 10.0 10.5
FunneIVŒcosiW(seconds) 35 - 41 38 - 45
Yield Point (cP) 24 - 30 24 - 30
Plastic Viscostiy (lb1100 sf) 10 - 15 15 - 20
Chlorides <600 <600
pH 9-9.5 9-10
API filtrate <6 4-5
HTHP filtrate <10 <10
MBT <20 <20
Solids ppb <11 <12
Production Interval Mud Program (Flopro NT)
Kuparuk Sand
Initial Value Final Value
Densitv (pP.o) 10.0 - 10.2 10.0 - 10.2
FunneIVŒcosfty(seconds) 35-45 35 - 45
Yield Point (cP) 20 - 30 20 - 30
Plastic Viscostiy (lb1100 sf) 10 - 15 10 - 15
Chlorides <600 <600
pH 9-9.5 9-9.5
API filtrate <6 <6
*HTHP filtrate <10 <10
MBT <5 <5
Solids ppb <3 <3
10-28 PERMIT IT. doc
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ORIGINAL
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.Plication for Permit to Drill, Well 1 D-28
Revision No.O
Saved: 19-Nov-04
Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. Please
see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon
Rig 14.
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 item~ except for an item already on file wIth the
commission and identified in the applit.:-atian:
(9) for an exploratory or stratigraphic test wel? a tabulation setting out the depths of predicted abnormally geo-pressured strata as
required by 20 AAC 25.033(1);
Not applicable: 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 Identifìed in the application:
(10) far an explorator¡ or stratigraphic test wel? a seismic ref¡"ction or reflection analY~iis as required by 20 MC 25061(a);
Not applicable: 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 itemfir except for an Item already on file with the
commission and identified in the application:
(11) for a well drHled from an offshore platform, mobHe bottom-founded structure, jack-up rig or floating drilling vessel, an analysis
of seabed conditions as required by 20 MC 25.061(bJ·
Not applicable: 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 mu:.,t be accompanied by each of the following item~ 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 metro
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 item~ except for an item already on file with the
commission and identified in the applìcatfon:
The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics.
1. Move in / rig up Doyon Rig 14. Install 21-1/4" Annular with 16" diverter line and function test.
'"--"'...-- ---
2. Spud and directionally drill 13-1/2" hole to casing point at +/- 6571' MD / 4413' ìVD as per directional .
plan. Run MWD tools as required for directional monitoring.
3. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud. Perform top
job if required.
4. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's and test to 5000 psi (annular
preventer to 3500 psi) Notify AOGCC 24 hrs before test. ,-'--
.I
5. PU 9-7/8" bit and 6-1/4" drilling assembly, with MWD, LWD (GRjRES) & PWD. RIH, clean out cement to
top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results.
6. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off,
recording results. Do not exceed 18.0 ppg EMW.
7. Directionally drill to 7-5/8" casing point at 10,665 MD /6,522' ìVD. ~
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.Plication for Permit to Drill, Well 1 D-28
Revision No.O
Saved: 19-Nov-04
8. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud.
9. Install wellhead 7-5/8" packoff and test to 5000 psi.
10. Flush 10-3/4" x 7-5/8" annulus with wa~r, followed by diesel.
~.....,._._._~ ,1·
11. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD (GR/RES/DENS-NEU) logging tools.
RIH, clean out cement to top of float equipment. Pressure test casing to 3500 psi for 30 minutes and
record results.
12. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform
formation integrity test to leak off, recording results. Do not exceed 16.0 ppg EMW.
13. Directionally drill 6-3/4" hole to TD at +/- 11,929' MD / 6,624'1VD as per directional plan.
14. POOH, back reaming out of lateral. POOH.
15. PU and run 4-1/2" slotted liner with aluminum billet. -
16. Set liner on bottom with top of liner at approximately 10,715' MD / 6,525'1VD (50' MD below the 7 5/8"
casing shoe) in open hole. Release from liner and POOH. -
Note: Remaining operations are covered under the 1D-28L1 Application for Permit to Drill, and are provided
here for information only. ----
17. Pick up 6-3/4" drilling assembly with LWD (GR/RES/DENS-NEU), MWD and PWD. RIH.
18. Sidetrack well off of aluminum billet. Drill to TD of "C4/C3" sand lateral at 14,873' MD / 6,609'1VD, as
per directional plan.
19. POOH, back reaming out of lateral. POOH.
20. PU and run 4-1/2" slotted liner.
21. Set liner hanger and ZXP liner top isolation packer. Release hanger running tool. POOH.
22. POOH, laying down drill pipe as required.
23. P/U and run 4-1/2" completion equipment and tubing as required and RIH to depth. Land tubing. Set
BPV.
24. Nipple down BOPE, nipple up tree and test.
25. Move rig off.
26. Pump corrosion inhibited brine into the 4-1/2" x 7-5/8" annulus, and freeze protect the tubing and IA.
27. Pull BPV. Shift sliding sleeve closed. MmA.
28. Set gas lift valves in mandrels.
29. Flow back well to portable test separator to clean up well.
30. Secure well for facility hook-up.
14. Discussion of Mud and Cuttings Disposal and Annular Disposal
Requirements of 20 AAC 25.005 (c)(14)
An application for a Permit to Drill mustc 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 authorization under 20 MC 25.080 for an annular disposal operation in the well.;
Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids
into a permitted annulus on 1D Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings
generated will be disposed of either down a permitted annulus on 1D Pad, hauled to the Prudhoe Bay
Grind and Inject Facility for temporary storage and eventual processing for injection down an approved
1D-28 PERMIT IT. doc
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ORIGINAL
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.Plication for Permit to Drill. Well 1 D-28
Revision No.O
Saved: 19-Nov-04
disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on
pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska.
ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal
operations.
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Cement Summary
Attachment 4 Well Schematic
10-28 PERMIT IT. doc
Page 8 of 8
Printed: 19-Nov-04
ORIGINAL
.
.
19 November, 2004
ConocóPÍ1i1lips
ConocoPhillips Alaska Inc.
(Kuparuk)
Kuparuk River Unit
Kuparuk 1 D Pad
Plan 1 D-28
Plan 1 D-28
Plan: Plan 1D-28 (wp07)
Standard Planning Report
ORiGINAL
un
Kuparuk
Calculation Method:
Error System:
Scan Method:
Error Surface:
Warning Method:
Minimum Curvature
ISCWSA
Elliptical Conic
Rules Based
Trav. Cylinder North
o
o
o
ð 1000
~
-£
o
z
-;-
.s::;;
:5
ð5 -1000
5000
6000
400
3000
2000
-2000
-3000
-4000
-1000
o
1000
2000
3000
4000
5000
6000
7000
8000
9000
10000
11 000
12000
13000
West(-)/East(+) (2000 ftlín)
Curvature
ISCWSA
Error System:
Calculation Method:
Scan Method:
¡Iii
Trav. Cylinder North
Conic
Error Surface:
Rules Based
Warning Method:
.
.
ConocJPhillips
SPERRY_SUN HES
Planning Report
EDM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 1 D Pad
Plan 1 D-28
Plan 10-28
Plan 1 D-28 (wp07)
Well Plan 1 D-28
RKB-34.5 + 70.9GL-105.4 @ 105.400ft (RKB-34.5 + 70.9GL-·
RKB-34.5 + 70.9GL-105.4@ 105.4OOfI (RKB-34.5 + 70.9GL-·
True .
inimum Curvature
Kuparuk River Unit, North Slope Alaska, United states
Map System:
Geo Datum:
Map Zone:
US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Alaska Zone 04
System Datum:
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Site
Kuparuk 10 Pad, KRU
O.OOOft
Northing:
Easting:
Slot Radius:
5,959,669.675ft
561,086.445ft
1000"
Latitude:
Longitude:
Grid Convergence:
Site Position:
From:
Position Uncertainty:
Map
O.oooft
O.oooft
O.OOOft
Northing:
Easting:
Wellhead Elevation:
5,959,309200 ft
560,670.720 ft
ft
Latitude:
Longitude:
Ground Level:
---~----
Plan 1 D-28
34.500 0.000 0.000 34.500 0.000 0.000 0.00 0.00 0.00 0.00
300.000 0.000 0.000 300.000 0.000 0.000 0.00 0.00 0.00 0.00
2,066.667 53.000 63.000 1,825.281 345.249 677.590 3.00 3.00 000 63.00
3,200.000 53.000 63.000 2,507.338 756.165 1,484.058 0.00 0.00 0.00 0.00
3,936.989 56.000 90.000 2,940.553 891 .455 2,058.922 3.00 0.41 3.66 90.31
9,982.097 56.000 90.000 6,320.934 891.455 7,070.544 0.00 0.00 0.00 0.00
10,563.085 85.000 91.823 6,512.823 882.044 7,612.271 5.00 4.99 0.31 3.74
10,799.180 85.000 91.823 6,533.400 874.560 7,847.348 0.00 0.00 0.00 0.00 1 D-28 Upper Mid San
10,814.180 85.000 91.823 6,534.707 874.085 7,862.283 0.00 0.00 0.00 0.00
10,969.546 73.982 97.683 6,563.025 861.590 8,014.224 8.00 -7.09 3.77 152.88
11,053.771 73.982 97.683 6,586267 850.767 8,094.453 0.00 0.00 0.00 0.00
11,277. 734 89.472 95.238 6,618.400 826.000 8,314.000 7.00 6.92 -1.09 -9.09 1 D-28 Lower C-Sand
11,929.100 89.472 95.238 6,624.400 766.542 8,962.619 0.00 0.00 0.00 0.00 1 D-28 Lower C-Sand
--~--~-
11/19I2oo410:38:14AM
Page 2 of6
COMPASS 2003.11 Build41
ORIGINAL
.
ConocJ'Phillips
SPERRY_SUN HES
Planning Report
.
EDM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 1 D Pad
Plan 1 D-28
34.500 0.000 0.000 34.500 0.000 0.000 447.591 0.00 0.00 0.00
StiL·- 357ft FNL & 419ft FEL, Sec23·T11N-R10E
100.000 0.000 0.000 100.000 0.000 0.000 447.591 0.00 0.00 0.00
199.999 0.000 0.000 199.999 0.000 0.000 447.591 0.00 0.00 0.00
300.000 0.000 0.000 300.000 0.000 0.000 447.591 0.00 0.00 0.00
Begin Dir @ 3.00 DLS: .300.100ft MD,300.100ft TVD
400.000 3.000 63.000 399.954 1.188 2.332 450.016 3.00 0.00
500.000 6.000 63.000 499.635 4.750 9.322 457.284 3.00 3.00 0.00
600.000 9.000 63.000 598.768 10.675 20.951 469.375 3.00 3.00 0.00
700.000 12.000 63.000 697.082 18.947 37.186 486.256 3.00 3.00 0.00
800.000 15.000 63.000 794.308 29.544 57.984 507.881 3.00 3.00 0.00
900.000 18.000 63.000 890.179 42.437 83.287 534.191 3.00 3.00 0.00
1,000.000 21.000 63.000 984.432 57.590 113.026 565.113 3.00 3.00 0.00
1,100.000 24.000 63.000 1,076.810 74.961 147.119 600.563 3.00 3.00 0.00
1 ,200.000 27.000 63.000 1,167.058 94.504 185.474 640.443 3.00 3.00 0.00
1,300.000 30.000 63.000 1,254.930 116.164 227.984 684.645 3.00 3.00 0.00
1,400.000 33.000 63.000 1,340.184 139.882 274.534 733.046 3.00 3.00 0.00
1,500.000 36.000 63.000 1,422.587 165.593 324.995 785.515 3.00 3.00 0.00
1,600.000 39.000 63.000 1,501.913 193.227 379.230 841.907 3.00 3.00 0.00
1,700.000 42.000 63.000 1,577.945 222.708 437.090 902.069 3.00 3.00 0.00
1,800.000 45.000 63.000 1 ,650.474 253.955 498.416 965.834 3.00 3.00 0.00
1,809.819 45.295 63.000 1,657.400 257.116 504.618 972.284 3.00 3.00 0.00
Base Permafrost
1,900.000 48.000 63.000 1,719.302 286.883 563.039 1,033.029 3.00 3.00 0.00
2,000.000 51.000 63.000 1,784.239 321.401 630.784 1,103.469 3.00 3.00 0.00
2,066.667 53.000 63.000 1,825.281 345.249 677. 590 1,152.137 3.00 3.00 0.00
En!! Dir, Start Sail @53.000: 2066.670ft MD, 1825.283ft TVD
2,100.000 53.000 63.000 1,845.342 357.335 701.310 1,176.800 0.00 0.00
2,200.000 53.000 63.000 1,905.523 393.593 772.469 1,250.790 0.00 0.00 0.00
2,300.000 53.000 63.000 1 ,965.705 429.850 843.628 1,324.780 0.00 0.00 0.00
2,400.000 53.000 63.000 2,025.886 466.107 914.787 1,398.770 0.00 0.00 0.00
2,500.000 53.000 63.000 2,086.068 502.364 985.946 1,472.759 0.00 0.00 0.00
2,600.000 53.000 63.000 2,146.249 538.622 1,057.105 1,546.749 0.00 0.00 0.00
2,700.000 53.000 63.000 2,206.431 574.879 1,128.264 1,620.739 0.00 0.00 0.00
2,800.000 53.000 63.000 2,266.612 611.136 1,199.422 1,694.729 0.00 0.00 0.00
2,900.000 53.000 63.000 2,326.794 647.394 1,270.581 1,768.719 0.00 0.00 0.00
3,000.000 53.000 63.000 2,386.975 683.651 1,341.740 1,842.708 0.00 0.00 0.00
3,100.000 53.000 63.000 2,447.157 719.908 1,412.899 1,916.698 0.00 0.00 0.00
3,200.000 53.000 63.000 2,507.338 756.165 1,484.058 1,990.688 0.00 0.00 0.00
3,200.100 53.000 63.000 2,507.399 756.202 1,484.129 1,990.762 0.00 0.00 0.00
Begin Dir @ 3.00DLS: 3200.100ft MD,2507.399ft TVD
3,300.000 53.043 66.755 2,567.504 790.070 1,556.365 2,065.621 3.00 0.04 3.76
3,400.000 53.204 70.500 2,627.527 819.210 1,630.835 2,142.304 3.00 0.16 3.75
3,500.000 53.481 74.224 2,687.243 843.505 1,707.265 2,220.525 3.00 0.28 3.72
3,600.000 53.874 77.915 2,746.489 862.889 1,785.443 2,300.071 3.00 0.39 3.69
3,700.000 54.378 81.565 2,805.103 877.309 1,865.157 2,380.724 3.00 0.50 3.65
3,800.000 54.991 85.184 2,862.922 886.724 1 ,946.187 2,462.262 3.00 0.61 3.60
3,900.000 55.709 88.706 2,919.790 891.110 2,028.313 2,544.462 3.00 0.72 3.54
3,936.989 56.000 90.000 2,940.553 891.455 2,058.922 2,574.990 3.00 0.79 3.50
End Dir, Start Sail @.56.000: 3936.990ft MD, 2940.553ft TVD
4,000.000 56.000 90.000 2,975.788 891.455 2,111.161 2,627.038 0.00 0.00 0.00
4,100.000 56.000 90.000 3,031.707 891.455 2,194.064 2,709.640 0.00 0.00 0.00
11/19/200410:38:14AM Page 3 of6 COMPASS 2003.11 Buìld 41
ORIGINAL
. .
ConocÓÂ1i11ips SPERRY_ SUN HES
Planning Report
EOM2003.n Single USer Ob
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk Rìver Unit
Kuparuk lpPad
Plan 10-28
Plan 10-28
Plan.10.28 (wp07)
4,200.000 56.000 0.00
4,208.536 56.000 0.00
Top Ugnu
4,300.000 56.000 90.000 3,143.546 891.455 2,359.872 2,874.845 0.00 0.00 0.00
4,400.000 56.000 90.000 3,199.465 891.455 2,442.776 2,957.447 0.00 0.00 0.00
4,500.000 56.000 90.000 3,255.384 891.455 2,525.679 3,040.049 0.00 0.00 0.00
4,600.000 56.000 90.000 3,311.304 891.455 2,608.583 3,122.651 0.00 0.00 0.00
4,700.000 56.000 90.000 3,367.223 891.455 2,691 .487 3,205.253 0.00 0.00 0.00
4,800.000 56.000 90.000 3,423.142 891.455 2,774.391 3,287.856 0.00 0.00 0.00
4,900.000 56.000 90.000 3,479.062 891.455 2,857.294 3,370.458 0.00 0.00 0.00
5,000.000 56.000 90.000 3,534.981 891.455 2,940.198 3,453.060 0.00 0.00 0.00
5,100.000 56.000 90.000 3,590.900 891.455 3,023.102 3,535.662 0.00 0.00 0.00
5,200.000 56.000 90.000 3,646.820 891.455 3,106.006 3,618.264 0.00 0.00 0.00
5,300.000 56.000 90.000 3,702.739 891.455 3,188.909 3,700.867 0.00 0.00 0.00
5,365.561 56.000 90.000 3,739.400 891.455 3,243.262 3,755.021 0.00 0.00 0.00
Top West Sak
5,400.000 56.000 90.000 3,758.658 891.455 3,271.813 3,783.469 0.00 0.00 0.00
5,500.000 56.000 90.000 3,814.577 891.455 3,354.717 3,866.071 0.00 0.00 0.00
5,600.000 56.000 90.000 3,870.497 891.455 3,437.621 3,948.673 0.00 0.00 0.00
5,700.000 56.000 90.000 3,926.416 891.455 3,520.524 4,031.275 0.00 0.00 0.00
5,800.000 56.000 90.000 3,982.335 891.455 3,603.428 4,113.878 0.00 0.00 0.00
5,900.000 56.000 90.000 4,038.255 891.455 3,686.332 4,196.480 0.00 0.00 0.00
6,000.000 56.000 90.000 4,094.174 891.455 3,769.236 4,279.082 0.00 0.00 0.00
6,100.000 56.000 90.000 4,150.093 891.455 3,852.139 4,361.684 0.00 0.00 0.00
6,200.000 56.000 90.000 4,206.012 891.455 3,935.043 4,444.286 0.00 0.00 0.00
6,213.211 56.000 90.000 4,213.400 891.455 3,945.996 4,455.199 0.00 0.00 0.00
Base West. SAk
6,300.000 56.000 90.000 4,261.932 891.455 4,017.947 4,526.889 0.00 0.00 0.00
6,400 .000 56.000 90.000 4,317.851 891.455 4,100.851 4,609.491 0.00 0.00 0.00
6,500.000 56.000 90.000 4,373.770 891.455 4,183.755 4,692.093 0.00 0.00 0.00
6,570.900 56.000 90.000 4,413.417 891.455 4,242.533 4,750.658 0.00 0.00 0.00
103/4"
6,600.000 56.000 90.000 4,429.690 891.455 4,266.658 4,774.695 0.00 0.00 0.00
6,700.000 56.000 90.000 4,485.609 891.455 4,349.562 4,857.297 0.00 0.00 0.00
6,800.000 56.000 90.000 4,541.528 891.455 4,432.466 4,939.900 0.00 0.00 0.00
6,900.000 56.000 90.000 4,597.447 891.455 4,515.370 5,022.502 0.00 0.00 0.00
6,914.221 56.000 90.000 4,605.400 891.455 4,527.160 5,034.249 0.00 0.00 0.00
C.sO
7,000.000 56.000 90.000 4,653.367 891.455 4,598.273 5,105.104 0.00 0.00 0.00
7,100.000 56.000 90.000 4,709.286 891.455 4,681.177 5,187.706 0.00 0.00 0.00
7,200.000 56.000 90.000 4,765.205 891.455 4,764.081 5,270.308 0.00 0.00 0.00
7,300.000 56.000 90.000 4,821.125 891.455 4,846.985 5,352.911 0.00 0.00 0.00
7,400.000 56.000 90.000 4,877.044 891.455 4,929.888 5,435.513 0.00 0.00 0.00
7,500.000 56.000 90.000 4,932.963 891.455 5,012.792 5,518.115 0.00 0.00 0.00
7,600.000 56.000 90.000 4,988.882 891.455 5,095.696 5,600.717 0.00 0.00 0.00
7,700.000 56.000 90.000 5,044.802 891.455 5,178.600 5,683.319 0.00 0.00 0.00
7,800.000 56.000 90.000 5,100.721 891.455 5,261 .503 5,765.922 0.00 0.00 0.00
7,900.000 56.000 90.000 5,156.640 891.455 5,344.407 5,848.524 0.00 0.00 0.00
8,000.000 56.000 90.000 5,212.560 891.455 5,427.311 5,931.126 0.00 0.00 0.00
8,100.000 56.000 90.000 5,268.479 891.455 5,510.215 6,013.728 0.00 0.00 0.00
8,200.000 56.000 90.000 5,324.398 891.455 5,593.118 6,096.330 0.00 0.00 0.00
8,300.000 56.000 90.000 5,380.318 891.455 5,676.022 6,178.933 0.00 0.00 0.00
8,400.000 56.000 90.000 5,436.237 891.455 5,758.926 6,261.535 0.00 0.00 0.00
8,500.000 56.000 90.000 5,492.156 891.455 5,841.830 6,344.137 0.00 0.00 0.00
8,600.000 56.000 90.000 5,548.075 891.455 5,924.733 6,426.739 0.00 0.00 0.00
8,700.000 56.000 90.000 5,603.995 891.455 6,007.637 6,509.341 0.00 0.00 0.00
8,800.000 56.000 90.000 5,659.914 891.455 6,090.541 6,591.944 0.00 0.00 0.00
~~oo.ooq_ 56.000 90.000 5,715.833 891.455 6,173.445 6,674.546 0.00 000 0.00
11/19I2oo410:38:14AM Page 4 0'6 COMPASS 2003.11 Build 41
ORIGINAL
.
c:onocJ'Phillips
SPERRY_SUN HES
Planning Report
.
5,771.753 6,757.148
9,100.000 56.000 90.000 5,827.672 891.455 6,339.252 6,839.750 0.00 0.00 0.00
9,200.000 56.000 90.000 5,883.591 891.455 6,422.156 6,922.352 0.00 0.00 0.00
9,300.000 56.000 90.000 5,939.510 891.455 6,505.060 7,004.954 0.00 0.00 0.00
9,400.000 56.000 90.000 5,995.430 891.455 6,587.963 7,087.557 0.00 0.00 0.00
9,500.000 56.000 90.000 6,051.349 891.455 6,670.867 7,170.159 0.00 0.00 0.00
9,600.000 56.000 90.000 6,107.268 891.455 6,753.771 7,252.761 0.00 0.00 0.00
9,700.000 56.000 90.000 6,163.188 891.455 6,836.675 7,335.363 0.00 0.00 0.00
9,800.000 56. 000 90.000 6,219.107 891.455 6,919.578 7,417.965 0.00 0.00 0.00
9,900.000 56.000 90.000 6,275.026 891.455 7,002.482 7,500.568 0.00 0.00 0.00
9,982.097 56.000 90.000 6,320.934 891.455 7,070.544 7,568.382 0.00 0.00 0.00
Begin Dir @ 5.00 DLS: 9982.100ft MD,6320.936ft TVD
10,000.000 56.891 90.070 6,330.829 891.446 7,085.463 7,583246 4.99 4.98 0.39
10,029.075 58.344 90.180 6,346.400 891.392 7,110.016 7,607.705 5.01 5.00 0.38
Base HRZ
10,100.000 61.881 90.435 6,381.735 891.059 7,171.499 7,668.936 5.00 4.99 0.36
10,200.000 66.872 90.769 6,424.963 890.106 7,261.633 7,758.660 5.00 4.99 0.33
10,216.672 67.706 90.822 6,431.400 889.893 7,277.011 7,773.965 5.01 5.00 0.32
K-1
10,300.000 71.864 91 .078 6,460.185 888.594 7,355.178 7,851.737 5.00 4.99 0.31
10,400.000 76.856 91.370 6,487.133 886.535 7,451.424 7,947.457 5.00 4.99 0.29
10,460.902 79.898 91.542 6,499.400 885.0.19 7,511.051 8,006.738 5.00. 5.00 0.28
Top Kuparuk-D
10,500.000 81.848 91.650 6,505.601 883.944 7,549.637 8,045.092 4.99 4.99 0..28
10.,563.085 85.000 91.823 6,512.823 882.044 7,612.271 8,10.7.336 5.00 5.00 0.27
10.,600.0.00. 85.0.0.0 91.823 6,516.040 880.874 7,649.027 8,143.859 0.00 0..0.0. 0..00
10.,615.60.0. 85.00.0 91.823 6,517.400 880.379 7,664.560. 8,159.293 0.00 0..00. 0.00
Top C4 Sand
10.,665.60.0. 85.00.0. 91.823 6,521.758 878.794 7,714.344 8,208.761 0.00 0..00. 0.00
7-518" CS9 pt ... Begin 6-314" hole: 10665.600ft MD, 6521.758ft TVD -- Continuè Dir ; 4762 ftFNL & 2932 ft FEL;Sec:1S-T11N-R11E.751S"
10.,700.0.00 85.000 91.823 6,524.756 877.704 7,748.596 8,242.795 0.00 0.0.0.
10.,799.180 85.00.0 91.823 6,533.400 874.560 7,847.348 8,340.921 0.00 0..00 0.00
Target (Heel) GeOSteer, 10799.1S0ft MD, 6533.400ft TVD, (4766ft FNL, 2799ft FEL, Sec18-T11N-R11E-1D-28 Upper Mid SandC..tieè\
10.,800.0.00 85.000 91.823 6,533.471 874.534 7,848.165 8,341.732 0..00. 0.00 0..00
10,814.180 85.000 91.823 6,534.70.7 874.085 7,862.283 8,355.761 0.00. 0.0.0. 0.00
10,818.150 84.717 91.969 6,535.063 873.954 7,866.235 8,359.688 8.00. -7.12 3.66
Begin Dir @ 8.00 DLS:10818.150ft MD,6535.063ft TVD
10,900.000 78.903 95.006 6,546.723 869.043 7,947.057 8,439.796 8.0.0. -7.10. 3.71
10.,969.546 73.982 97.683 6,563.025 861.590 8,014224 8,506.0.85 8.0.1 -7.08 3.85
End pir, Start Sail @ 73.982: 10969.550ft MD, 65¡¡3.026ft TVD
11,0.00.00.0 73.982 97.683 6,571.429 857. 677 8,043.233 8,534.655 0.00 0.00. 0..00
11,053.771 73.982 97.683 6,586.267 850.767 8,094.453 8,585.099 0.00 0..00 0..00
Begin Dir@ 7.00PLS: 11053.780ft MD,6586.269ft TVD
11,100.0.0.0. 77. 175 97.160 6,597. 778 844.986 8,138.844 8,628.836 6.99 6.91 -1.13
11,200.00.0 84.091 96.067 6,614.040 833.639 8,236.795 8,725.464 7.00 6.92 -1.09
11,277.734 89.472 95.238 6,618.400 826.000 8,314.000 8,801.737 7.00 6.92 -1.07
Target (Lower Cpt 1) : 11277.730ft MD, 661S.400ft TVD, -1D-28 Lower C-5and Pt1_0ut
11,300.000 89.472 95.238 6,618.605 823.967 8,336.173 8,823.656 0.00 0.0.0 0.00
11,400.000 89.472 95.238 6,619.526 814.839 8,435.751 8,922.094 0..00. 0.0.0 0.00
11 ,500.0.00 89.472 95.238 6,620.447 805.711 8,535.329 9,0.20.532 0.00 0.00 0.00
11,600.0.00. 89.472 95.238 6,621.369 796.583 8,634.907 9,118.970 0.00 0.00 0.00
11,700.000 89.472 95.238 6,622.290 787.455 8,734.486 9,217.409 0.00 0.00 0.00
11,800.000 89.472 95.238 6,623.211 778.327 8,834.064 9,315.847 0.00. 0.00 0.00
11,900.000 89.472 95238 6,624.132 769.199 8,933.642 9,414285 0.00 0.00 0.00
11,929.100 89.472 95238 6,624.400 , 766.542 8,962.619 9,442.930 0.00 0.00 0.00
Target (Toe): 11929.090ftMD,6624.400ftTVD, (4876ft FNL, 1684ft FEL, Sec:18-T11N.R11E-1D-2SLowerC-SandPt 2
11/191200410:38:14AM
Page 5 of 6
COMPASS 2003.11 Build 41
ORIGINAL
ConocJ)hillips
.
.
SPERRY_SUN HES
Planning Report
EDM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 10 Pad
Plan 1 D-28
Plan 1 D-28
Plan 1 D-28 (wp07)
Well Plan 1 D-28
RKB-34.5 + 70.9GL-105.4 @ 105.400ft (RKB-34.5 + 70.9GL-'
RKB-34.5 + 70.9GL-105.4@ 105.4QOft (RKB-34.5 + 70.9GL-·
True
Minimum Curvature
1 D-28 Upper Mid Sand 0.00 0.00 6,533.400 874.560 7,847.348 5,960,247.000 568,510.000 70° 18' 06.366" N 149° 26' 42.333" W
- plan hits target
- Point
1 D-28 Lower C-Sand F 0.00 0.00 6,618.400 826.000 8,314.000 5,960,202.214 568,976.984 70° 18' 05.884" N 149° 26' 28.729" W
- plan hits target
- Point
1 D-28 Lower C-Sand F 0.00 0.00 6,624.400 766.542 8,962.619 5,960,148.000 569,626.000 70° 18' 05.291" N 149° 26' 09.820" W
- plan hits target
- Point
-~~--,----~~~-
1,809.819
4,208.536
5,365.561
6,213.211
6,914.221
10,029.075
10,216.672
10,460.902
10,615.600
1,657.400 Base Permafrost
3,092.400 Top Ugnu
3,739.400 Top West Sak
4,213.400 Base West SAk
4,605.400 C-80
6,346.400 Base HRZ
6,431.400 K-1
6,499.400 Top Kuparuk-D
6,517.400 Top C4 Sand
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
0.000
34.510
300.100
2,066.670
3,200.100
3,936.989
9,982.100
10,665.600
10,799.180
10,818.150
10,969.550
11,053.780
11,277.730
11,929.090
34.510
300.100
1,825.283
2,507.399
2,940.553
6,320.936
6,521.758
6,533.400
6,535.063
6,563.026
6,586.269
6,618.400
6,624.400
0.000
0.000
345.251
756.202
891.455
891.455
878.794
874.560
873.954
861 .590
850.766
826.000
766.544
s
+E/.W
(ft)
0.000
0.000
677.593
1,484.129
2,058.922
7,070.546
7,714.344
7,847.348
7,866.235
8,014.228
8,094.461
8,313.997
8,962.609
~---~---
-~~--~~
SHL -- 357ft FNL & 419ft FEL, Sec23-T11N-R10E
Begin Dir@ 3.00 DLS: 300. 100ft MD,3oo.100ft TVD
End Dir, Start Sail @ 53.000: 2066.67Oft MD, 1825.283ft TVD
Begin Dir@ 3.ooDLS: 3200.100ft MD,2507.399ft TVD
End Dir, Start Sail @ 56.000: 3936.99Oft MD, 2940.553ft TVD
Begin Dir@5.oo DLS: 9982.100ft MD,6320.936ft TVD
7-5If'J' Csg Pt... Begin 6-3/4" hole: 1 0665. 600ft MD, 6521.758ft TVD -- ContinuE
Target (Heel) GeoSteer, 10799.18Oft MD, 6533.400ft TVD, (4766ft FNL, 279911
Begin Dir @ 8.00 DLS: 10818.15011 MD,6535.063ft TVD
End Dir, Start Sail @ 73.982: 10969.55Oft MD, 6563.0200 TVD
Begin Dir @ 7.00 DLS: 11053.78Oft MD,6586.269ft TVD
Target (Lower CPt 1) : 11277.73Oft MD, 6618.40Oft TVD,
Target (Toe): 11929.09Oft MD, 6624.400ft TVD, (4876ft FNL, 1684ft FEL, Sec1
11/19/200410:38:14AM
COMPASS 2003.11 Build 41
Page 6 of6
ORIGINAL
WEllDEfPiLS: PJan1D-26
Groundla\!e!: 0.000
,NI.s Northing EastJng latlltude longltw* Sl~
0.000 5.9&9309.200 560670.720 70"t7'57.8OSN 14if3O'3t.126W
Engineering
Kuparuk
Caicuiation Method: Mininum Curvature
Error System ISCWSA
Scan Method: Trav. Cylinder North
Error Surface: Ellipticai Conic
Warning Method: Ruies Based
270
180
Travelling Cylinder Azimuth (TFÛ+AZI) [Q] vs Centre to Centre Separation [50 ft/in]
From Colour To MD
34 300
300 400
400 500
500 - 750
750 1000
1000 1250
1250 1500
1500 2000
2000 - 3000
3000 4000
4000 5000
5000 6000
6000 7000
7000 8000
8000 9000
9000 10000
10000 - 11000
Af'HI-COLUSION SETTINGS
interpolation Method:
MD interval: 25 ft Stations
Depth Range From:
34.500 To 11929.100
Reference:
Plan: Plan 10-28 (wp07)
90
180
Travelling Cylinder Azimuth (TFO+AZI) [9Jvs Centre to Centre Separation [10 ft/in]
.
.
19 November, 2004
ConocoPhillips Alaska Inc.
(Kuparuk)
Kuparuk River Unit
Kuparuk 10 Pad
Plan 10-28
Plan 10-28
Plan 10-28 (wp07)
Travelling Cylinder Report
ORIGINAL
.
.
SPERRY_SUN HES
Anticollision Report
Filter type:
Interpolation Method:
Depth Range:
Results Limited by:
GLOBAL FILTER: Using user defined selection & filtering criteria
MO Interval 25.000ft Error Model:
Unlimited Scan Method:
Maximum center-center distance of 1,745.366ft Error Surface:
ISCWSA
Trav. Cylinder North
Elliptical Conic
700.000 Plan 1 0-28 (wp07) (Plan 1 0-28)
11,929.100 Plan 1 D-28 (wp07) (Plan 1 D-28)
CC - Mín centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
11/19/2004 9:42:36AM Page 2 of 166 COMPASS 2003.11 Build 41
ORIGINAL
.
.
SPERRY_SUN HES
Anticollision Report
1C-135-1C-135-1C-135 5,122.022 10,275.000 202.978 127.95 75.027 Pass - Major Risk
1 127.94
1 C-135 -1C-135PB1 - 1 C-135 (wp02) 5,133.531 10,325.000 206.199 148.11 58.087 Pass - Major Risk
148.04
1C-135-1C-135PB1-1C-135PB1 5,205.625 10,350.000 164.058 133.03 31 .027 Pass - Major Risk
133.01
Kuparuk 1ÐPad
1 0-05 - 1 D-05 - 1 D-05 395.036 400.000 214.013 8.53 205.488 Pass - Major Risk
1 0-06 - 1 0-06 - 1 0-06 346.433 350.000 181.549 7.25 174.296 Pass - Major Risk
1 D-07 - 1 0-07 - 1 D-07 326.387 325.000 219.931 5.68 214.251 Pass - Major Risk
1 D-09 - 1 0-09 - 1 D-09 390.865 400.000 286.285 6.60 279.689 Pass - Major Risk
1 D-117 - 10-117 - 10-117 1,011.393 1,025.000 330.860 22.08 308.775 Pass - Major Risk
10-12 -1 D-12 -1 0-12 2,815.934 3,000.000 436.483 48.48 388.006 Pass - Major Risk
1 D-120 - 10-120 - 10-120 342.179 350.000 262.913 6.24 256.673 Pass - Major Risk
10-121 - 10-121 - 10-121 365.660 375.000 252.261 6.73 245.534 Pass - Major Risk
10-122 - 10-122 - 10-122 317.489 325.000 241.731 5.68 236.049 Pass - Major Risk
1 D-123 - 10-123 -10-123 293.279 300.000 230.112 5.06 225.055 Pass - Major Risk
1 D-124 - 1 D-124 - 10-124 341.493 350.000 199.307 6.23 193.073 Pass - Major Risk
1 D-125 - 10-125 - 10-125 317.427 325.000 194.596 5.47 189.125 Pass - Major Risk
1 D-125 - 1O-125A - 1O-125A 328.257 325.000 194.735 5.62 189.119 Pass - Major Risk
10-126 - 10-126 - 10-126 244.095 250.000 188.932 4.49 184.445 Pass - Major Risk
1D-126-1O-126-1O-139WP2 341.187 350.000 188.520 6.03 182.490 Pass - Major Risk
10-127 -10-127 -10-127 168.597 175.000 184.845 3.10 181.743 Pass - Major Risk
10-128 - 10-128 - 10-128 317.254 325.000 182.649 5.77 176.879 Pass - Major Risk
1D-129-1D-129-1O-129 243.897 250.000 183.209 4.41 178.795 Pass - Major Risk
1 D-130 -10-130 -10-130 340.069 350.000 186.681 6.13 180.552 Pass - Major Risk
10-131 -10-131 -10-131 193.396 200.000 192.098 3.51 188.587 Pass - Major Risk
1 D-132 - 10-132 - 1 D-132 168.498 175.000 197.383 3.03 194.355 Pass - Major Risk
10-133 - 1 D-133 -10-133 317.032 325.000 204.709 5.49 199.223 Pass - Major Risk
10-133 - 1O-133PB1 - 1O-133PB1 317.032 325.000 204.709 5.49 199.223 Pass - Major Risk
1D-134-1O-134-1O-134 316.410 325.000 237.311 5.51 231.800 Pass - Major Risk
1D-141 -10-141 -10-141 1,648.753 1,775.000 151.740 33.16 118.582 Pass - Major Risk
10-141 -1O-141L1 -1O-141L1 1,648.753 1,775.000 151.740 33.16 118.582 Pass - Major Risk
10-141 -1O-141L1PB1 -1O-141L1PB1 1,648.753 1,775.000 151.740 33.16 118.582 Pass - Major Risk
1D-141-1O-141L1PB2-1D-141L1PB2 1,648.753 1,775.000 151.740 33.16 118.582 Pass - Major Risk
10-141 - 10-141 PB1 - 10-141 PB1 1,648.753 1,775.000 151.740 33.16 118.582 Pass - Major Risk
1 0-30 - 1 D-30 - 1 0-30 349.724 350.000 31.085 6.12 24.963 Pass - Major Risk
1 D-30 - 1 0-30L 1 - 1 D-30L 1 349.724 350.000 31.085 6.12 24.963 Pass - Major Risk
1 D-32 - 1 D-32 - 1 D-32 399.998 400.000 60.333 7.25 53.083 Pass - Major Risk
1 D-34 - 1 D-34 - 1 D-34 422.732 425.000 91.207 7.14 84.071 Pass - Major Risk
1 D-36 - 1 0-36 - 1 D-36 348.695 350.000 120.400 6.03 114.369 Pass - Major Risk
1 D-36 - 1 D-36 - 1 D-36WP4(Baker) 372.993 375.000 120.829 6.71 114.114 Pass - Major Risk
1 0-37 - 1 D-37 - 1 0-37 373.099 375.000 135.601 6.79 128.812 Pass - Major Risk
1 D-38 - 1 D-38 - 1 0-38 348.800 350.000 151.069 5.97 145.097 Pass - Major Risk
1 D-39 - 1 0-39 - 1 D-39 372.846 375.000 165.318 6.44 158.882 Pass - Major Risk
1 D-4O - 1 0-40 - 1 0-40 371.963 375.000 180.381 6.52 173.860 Pass - Major Risk
1 0-40 - 1 D-40A - 1 D-4OA 372.776 375.000 180.394 6.53 173.861 Pass - Major Risk
1 D-42 - 1 D-42 - 1 D-42 324.167 325.000 210.039 5.69 204.345 Pass - Major Risk
1 0-42 - 1 D-42 - 1 0-42 (Baker) 371.730 375.000 210.676 6.91 203.765 Pass - Major Risk
CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation
11/1912004 9:42:36AM Page 3 of 166 COMPASS 2003.11 Build 41
ORIGINAL
PJaD: Pbn
tD·2BJPlan lD·28)
-------------- ------------------
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·250 ·200 -150 ·100 ·50 0 50 100 150 200 250 300 350 400 450 500 550 600 650 700 750 800 850 900 950 1000 1050 1100 1150 1200 1250
" .
40
Measured Depth [it]
vo
IJ7
.
.
eonocóPhillips
ConocoPhillips Alaska Inc.
(Kuparuk)
Kuparuk River Unit
Kuparuk 1 D Pad
Plan 1 D-28
Plan 1 D-28
Plan: Plan 1 D-28 (wp07)
Standard Planning Report - Geographic
19 November, 2004
ORJG ;~J,)4L
.
.
eonoa;p¡,illips
SPERRY_SUN HES
Planning Report - Geographic
EDM 2003.11 Single User Ob
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 10 Pad
Plan 1 D-28
Plan 1 0-28
Plan 1 D-28 (wp07)
Map System:
Geo Datum:
Map Zone:
US State Plane 1927 (Exact solution)
NAD 1927 (NADCON CONUS)
Alaska Zone 04
System Datum:
Mean Sea Level
Using Well Reference Point
Using geodetic scale factor
Site
Kuparuk 1 D Pad, KRU
Site Position:
From: Map
Position Uncertainty:
0.000 ft
Northing:
Easting:
Slot Radius:
5,959,669.675ft
561,086.445ft
1000"
Latitude:
Longitude:
Grid Convergence:
70° 18' 01.317" N
149° 30' 18.921" W
0.47 °
Wen
Plan 1 D-28
Well Position +N/-S
+E/-W
Position Uncertainty
0.000 ft
0.000 ft
0.000 ft
Northing:
Easting:
Wellhead Elevation:
5,959,309.200 ft
560,670.720 ft
ft
Wellbore
Plan 10-28
bggm2004
11/18/2004
DeSign
Audit Notes:
Version:
Plan 1 D-28 (wp07)
2 Phase:
PLAN
34.500 0.000 0.000 34.500 0.000 0.000 0.00 0.00 0.00 0.00
300.000 0.000 0.000 300.000 0.000 0.000 0.00 0.00 0.00 0.00
2,066.667 53.000 63.000 1,825.281 345.249 677.590 3.00 3.00 0.00 63.00
3,200.000 53.000 63.000 2,507.338 756.165 1 ,484.058 0.00 0.00 0.00 0.00
3,936.989 56.000 90.000 2,940.553 891.455 2,058.922 3.00 0.41 3.66 90.31
9,982.097 56.000 90.000 6,320.934 891.455 7,070.544 0.00 0.00 0.00 0.00
10,563.085 85.000 91.823 6,512.823 882.044 7,612.271 5.00 4.99 0.31 3.74
10,799.180 85.000 91.823 6,533.400 874.560 7,847.348 0.00 0.00 0.00 0.00 1 D-28 Upper Mid S1
10,814.180 85.000 91.823 6,534.707 874.085 7,862.283 0.00 0.00 0.00 0.00
10,969.546 73.982 97.683 6,563.025 861.590 8,014.224 8.00 -7.09 3.77 152.88
11,053.771 73.982 97.683 6,586.267 850.767 8,094.453 0.00 0.00 0.00 0.00
11 ,277. 734 89.472 95.238 6,618.400 826.000 8,314.000 7.00 6.92 -1.09 -9.09 1 D-28 Lower C-San
11,929.100 89.472 95.238 6,624.400 766.542 8,962.619 0.00 0.00 0.00 0.00 1 D-28 Lower C-San
11/191200410:38:43AM
Page 2 of6
COMPASS 2003.11 Build 41
ORIGINAL.
.
.
eonoa;p.,illips
SPERRY_SUN HES
Planning Report - Geographic
EOM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparul< 1 D Pad
Plan 1 0-28
Plan 1 0-28
Plan 1 D-28 (wp07)
Well Plan 10-28
RKB-34.5 + 70.9GL-105.4 @ 105.4OOfI (RKB-34.5 + 70.
RKB-34.5 + 70.9GL-105.4@ 105.4OOft (RKB-34.5 + 70.
True
Minimum Curvature
34.500 0.000 0.000 34.500 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W
SHL -- 357ft FNL & 419ft FEL,Sec23-T11N-R10E
100.000 0.000 0.000 100.000 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W
199.999 0.000 0.000 199.999 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W
300.000 0.000 0.000 300.000 0.000 0.000 5,959,309.200 560,670.720 70° 17' 57.805" N 149° 30' 31.126" W
Eregin Dir @ 3.00DLS: 30Ó.100ft MD,300.100ft TVD
400.000 3.000 63.000 399.954 1.188 2.332 5,959,310.407 560,673.042 70° 17' 57.817" N 149° 30' 31 .058" W
500.000 6.000 63.000 499.635 4.750 9.322 5,959,314.024 560,680.003 70° 17' 57.852" N 149° 30' 30.854" W
600.000 9.000 63.000 598.768 10.675 20.951 5,959,320.043 560,691.582 70° 17' 57.910" N 149° 30' 30.515" W
700.000 12.000 63.000 697.082 18.947 37.186 5,959,328.445 560,707.748 70° 17' 57.991" N 149° 30' 30.042" W
800.000 15.000 63.000 794.308 29.544 57.984 5,959,339.209 560,728.458 70° 17' 58.096" N 149° 30' 29.436" W
900.000 18.000 63.000 890.179 42.437 83.287 5,959,352.304 560,753.654 70° 17' 58.222" N 149° 30' 28.698" W
1,000.000 21.000 63.000 984.432 57.590 113.026 5,959,367.695 560,783.267 70° 17' 58.371" N 149° 30' 27.831" W
1,100.000 24.000 63.000 1,076.810 74.961 147.119 5,959,385.339 560,817.215 70° 17' 58.542" N 149° 30' 26.837" W
1,200.000 27.000 63.000 1,167.058 94.504 185.474 5,959,405.189 560,855.407 70° 17' 58.735" N 149° 30' 25.719" W
1,300.000 30.000 63.000 1,254.930 116.164 227.984 5,959,427.189 560,897.737 70° 17' 58.948" N 149° 30' 24.480" W
1,400.000 33.000 63.000 1,340.184 139.882 274.534 5,959,451.280 560,944.089 70° 17' 59.181" N 149° 30' 23.123" W
1,500.000 36.000 63.000 1,422.587 165.593 324.995 5,959,477.396 560,994.337 70° 17' 59.434" N 149° 30' 21.652" W
1,600.000 39.000 63.000 1 ,501 .913 193.227 379.230 5,959,505.464 561,048.341 70° 17' 59.705" N 149° 30' 20.071" W
1,700.000 42.000 63.000 1,577.945 222.708 437.090 5,959,535.408 561 ,105.956 70° 17' 59.995" N 149° 30' 18.384" W
1,800.000 45.000 63.000 1,650.474 253.955 498.416 5,959,567.147 561,167.021 70° 18' 00.303" N 149° 30' 16.596" W
1,809.819 45.295 63.000 1,657.400 257.116 504.618 5,959,570.357 561,173.198 70° 18' 00.334" N 149° 30'16.415" W
Base Permafrost
1,900.000 48.000 63.000 1,719.302 286.883 563.039 5,959,600.592 561,231.371 70° 18' 00.626" N 149° 30'14.712" W
2,000.000 51.000 63.000 1,784.239 321.401 630.784 5,959,635.652 561 ,298.829 70° 18' 00.966" N 149° 30'12.737" W
2,066.667 53.000 63.000 1,825.281 345.249 677.590 5,959,659.875 561,345.436 70° 18' 01.200" N 149° 30' 11.372" W
End Dir, Start Sail @ 53.000: 2066.670ft MD, 1825.283ft TVD
2,100.000 53.000 63.000 1,845.342 357.335 701.310 5,959,672.151 561,369.055 70° 18' 01.319" N 149° 30' 10.681" W
2,200.000 53.000 63.000 1,905.523 393.593 772.469 5,959,708.978 561 ,439.912 70° 18' 01.676" N 149° 30' 08.606" W
2,300.000 53.000 63.000 1 ,965.705 429.850 843.628 5,959,745.805 561,510.769 70° 18' 02.032" N 149° 30' 06.531" W
2,400.000 53.000 63.000 2,025.886 466.107 914.787 5,959,782.632 561,581.626 70° 18' 02.389" N 149° 30' 04.457" W
2,500.000 53.000 63.000 2,086.068 502.364 985.946 5,959,819.460 561,652.483 70° 18' 02.745" N 149° 30' 02.382" W
2,600.000 53.000 63.000 2,146.249 538.622 1,057.105 5,959,856.287 561,723.341 70° 18' 03.102" N 149° 30' 00.307" W
2,700.000 53.000 63.000 2,206.431 574.879 1 ,128.264 5,959,893.114 561,794.198 70° 18' 03.458" N 149° 29' 58.232" W
2,800.000 53.000 63.000 2,266.612 611.136 1 ,199.422 5,959,929.941 561,865.055 70° 18' 03.815" N 149° 29' 56.158" W
2,900.000 53.000 63.000 2,326.794 647.394 1,270.581 5,959,966.768 561 ,935.912 70° 18' 04.171" N 149° 29' 54.083" W
3,000.000 53.000 63.000 2,386.975 683.651 1,341.740 5,960,003.595 562,006.769 70° 18' 04.528" N 149° 29' 52.008" W
3,100.000 53.000 63.000 2,447.157 719.908 1,412.899 5,960,040.422 562,077.626 70° 18' 04.884" N 149° 29' 49.933" W
3,200.000 53.000 63.000 2,507.338 756.165 1,484.058 5,960,077.249 562,148.483 70° 18' 05.241" N 149° 29' 47.858" W
3,200.100 53.000 63.000 2,507.399 756.202 1,484.129 5,960,077.286 562,148.554 70° 18' 05.241" N 149° 29' 47.856" W
Begin Dir @ 3.00DLS: 3200.100ft MD,2507.399ft TVD
3,300.000 53.043 66.755 2,567.504 790.070 1,556.365 5,960,111.733 562,220.507 70° 18' 05.574" N 149° 29' 45.750" W
3,400.000 53.204 70.500 2,627.527 819.210 1,630.835 5,960,141.471 562,294.733 70° 18' 05.860" N 149° 29' 43.579" W
3,500.000 53.481 74.224 2,687.243 843.505 1,707.265 5,960,166.380 562,370.956 70° 18' 06.099" N 149° 29' 41.350" W
3,600.000 53.874 77.915 2,746.489 862.889 1,785.443 5,960,186.392 562,448.968 70° 18' 06.289" N 149° 29' 39.071" W
3,700.000 54.378 81.565 2,805.103 877.309 1,865.157 5,960,201.453 562,528.555 70° 18' 06.431" N 149° 29' 36.747" W
3,800.000 54.991 85.164 2,862.922 886.724 1 ,946.187 5,960,211.522 562,609.499 70° 18' 06.524" N 149° 29' 34.384" W
3,900.000 55.709 88.706 2,919.790 891.110 2,028.313 5,960,216.570 562,691.578 70° 18' 06.566" N 149° 29' 31.990" W
3,936.989 56.000 90.000 2,940.553 891.455 2,058.922 5,960,217.162 562,722.181 70° 18' 06.570" N 149° 29' 31.097" W
End Dir, Start sail @ 56.000: 3936.990ft MD, 2940.553ft TVD
4,000.000 56.000 90.000 2,975.788 891.455 2,111.161 5,960,217.584 562,774.413 70° 18' 06.570" N 149° 29' 29.574" W
4,100.000 56.000 90.000 3,031.707 891.455 2,194.064 5,960,218.253 562,857.306 70° 18' 06.569" N 149° 29' 27.157" W
4,200.000 56.000 90.000 3,087.627 891 .455 2,276.968 5,960,218.922 562,940.199 70° 18' 06.569" N 149° 29' 24.740" W
4,208.536 56.000 90.000 3,092.400 891.455 2,284.045 5,960,218.979 562,947.275 70° 18' 06.569" N 149° 29' 24.534" W
Top Ugnu
4,300.000 56.000 90.000 3,143.546 891.455 2,359.872 5,960,219.592 563,023.092 70° 18' 06.569" N 149° 29' 22.323" W
4 400.000 56.000 90.000 3199.465 891.455 2 442.776 5960220.261 563 105.985 70° 18' 06.569" N 149° 29' 19.906" W
11/19/200410:38:43AM Page 3 of6 COMPASS 2003.11 BuDd 41
o R 1 G I ~~A, L
.
.
eonoOOPhillips
SPERRY_SUN HES
Planning Report - Geographic
EOM 2003.11 Single User Db
ConocoPhillìps Alaska Inc, (Kuparuk)
Kuparuk River Unit
KUparuk 10 Pad
Plan 1 0-28
Plan 1 0-28
Plan 10-28 (wp07)
4,500.000 56.000 90,000 3,255.384 891.455 2,525.679 5,960,220.930 563,188.878 70° 18' 06,568" N 149° 29' 17.489" W
4,600.000 56.000 90.000 3,311.304 891 .455 2,608.583 5,960,221.599 563,271.771 70° 18' 06.568" N 149° 29' 15.071" W
4,700.000 56.000 90,000 3,367223 891.455 2,691.487 5,960,222269 563,354.664 70° 18' 06.568" N 149° 29' 12.654" W
4,800.000 56.000 90.000 3,423.142 891.455 2,774.391 5,960,222.938 563,437,558 70° 18' 06.567" N 149° 29' 10237" W
4,900.000 56.000 90.000 3,479.062 891 .455 2,857294 5,960,223.607 563,520.451 70° 18' 06.567" N 149° 29' 07.820" W
5,000.000 56,000 90.000 3,534.981 891.455 2,940.198 5,960,224277 563,603.344 70° 18' 06.567" N 149° 29' 05.403" W
5,100.000 56.000 90.000 3.590.900 891.455 3,023.102 5,960,224.946 563,686237 70° 18' 06.567" N 149° 29' 02.986" W
5,200.000 56.000 90.000 3,646.820 891.455 3,106.006 5,960,225.615 563,769.130 70° 18' 06.566" N 149° 29' 00.569" W
5,300.000 56.000 90.000 3,702.739 891.455 3,188.909 5,960,226284 563,852.023 70° 18' 06.566" N 149° 28' 58.152" W
5,365.561 56.000 90.000 3,739.400 891.455 3,243262 5,960,226.723 563,906.369 70° 18' 06.566" N 149° 28' 56.567" W
Top West Sak
5,400.000 56.000 90.000 3,758.658 891 .455 3,271.813 5,960,226.954 563,934.916 70° 18' 06.566" N 149° 28' 55.735" W
5,500.000 56.000 90.000 3,814.577 891.455 3,354.717 5,960,227.623 564,017.809 70° 18' 06.565" N 149° 28' 53.318" W
5,600.000 56.000 90.000 3,870.497 891 .455 3,437.621 5,960,228292 564,100.702 70° 18' 06.565" N 149° 28' SO.900" W
5,700.000 56.000 90.000 3,926.416 891.455 3,520.524 5,960,228.962 564,183.596 70° 18' 06.564" N 149° 28' 48.483" W
5,800.000 56.000 90.000 3,982.335 891.455 3,603.428 5,960,229.631 564,266.489 70° 18' 06.564" N 149° 28' 46.066" W
5,900.000 56.000 90.000 4,038.255 891.455 3,686.332 5,960,230.300 564,349.382 70° 18' 06.564" N 149° 28' 43.649" W
6,000.000 56.000 90.000 4,094.174 891.455 3,769.236 5,960,230.970 564,432275 70° 18' 06.563" N 149° 28' 41.232" W
6,100.000 56.000 90.000 4,150.093 891.455 3,852.139 5,960,231.639 564,515.168 70° 18' 06.563" N 149° 28' 38.815" W
6,200.000 56.000 90.000 4,206.012 891 .455 3,935.043 5,960,232.308 564,598.061 70° 18' 06.562" N 149° 28' 36.398" W
6,213.211 56.000 90.000 4,213.400 891.455 3,945.996 5,960,232.397 564,609.012 70° 18' 06.562" N 149° 28' 36.078" W
Base WestSAk
6,300.000 56.000 90.000 4,261.932 891.455 4,017.947 5,960,232.977 564,680.954 70° 18' 06.562" N 149° 28' 33.981" W
6,400.000 56.000 90.000 4,317.851 891.455 4,100.851 5,960,233.647 564,763.847 70° 18' 06.562" N 149° 28' 31.564" W
6,500.000 56.000 90.000 4,373.770 891.455 4,183.755 5,960,234.316 564,846.740 70° 18' 06.561" N 149° 28' 29.146" W
6,570.900 56.000 90.000 4,413.417 891.455 4,242.533 5,960,234.791 564,905.512 70° 18' 06.561" N 149° 28' 27.433" W
103/4"
6,600.000 56.000 90.000 4,429.690 891.455 4,266.658 5,960,234.985 564,929.634 70° 18' 06.561" N 149° 28' 26.729" W
6,700.000 56.000 90.000 4,485.609 891.455 4,349.562 5,960,235.655 565,012.527 70° 18' 06.560" N 149° 28' 24.312" W
6,800.000 56.000 90.000 4,541.528 891.455 4,432.466 5,960,236.324 565,095.420 70° 18' 06.560" N 149° 28' 21.895" W
6,900.000 56.000 90.000 4,597.447 891.455 4,515.370 5,960,236.993 565,178.313 70° 18' 06.559" N 149° 28' 19.478" W
6,914221 56.000 90.000 4,605.400 891 .455 4,527.160 5,960,237.088 565,190.102 70° 18' 06.559" N 149° 28'19.134" W
C-80
7,000.000 56.000 90.000 4,653.367 891.455 4,598.273 5,960,237.662 565,261.206 70° 18' 06.559" N 149° 28' 17.061" W
7,100.000 56.000 90.000 4,709.286 891.455 4,681.177 5,960,238.332 565,344.099 70° 18' 06.558" N 149° 28' 14.644" W
7,200.000 56.000 90.000 4,765205 891.455 4,764.081 5,960,239.001 565,426.992 70° 18' 06.558" N 149° 28' 12227" W
7,300.000 56.000 90.000 4,821.125 891.455 4,846.985 5,960,239.670 565,S09.885 70° 18' 06.557" N 149° 28' 09.810" W
7,400.000 56.000 90.000 4,877.044 891.455 4,929.888 5,960,240.340 565,592.778 70° 18' 06.557" N 149° 28' 07.393" W
7,500.000 56.000 90.000 4,932.963 891.455 5,012.792 5,960,241.009 565,675.672 70° 18' 06.556" N 149° 28' 04.975" W
7,600.000 56.000 90.000 4,988.882 891 .455 5,095.696 5,960,241.678 565,758.565 70° 18' 06.556" N 149° 28' 02.558" W
7,700.000 56.000 90.000 5,044.802 891.455 5,178.600 5,960,242.347 565,841.458 70° 18' 06.555" N 149° 28' 00.141" W
7,800.000 56.000 90.000 5,100.721 891.455 5,261.503 5,960,243.017 565,924.351 70° 18' 06.554" N 149° 27' 57.724" W
7,900.000 56.000 90.000 5,156.640 891.455 5,344.407 5,960,243.686 566,007.244 70° 18' 06.554" N 149° 27' 55.307" W
8,000.000 56.000 90.000 5,212.560 891.455 5,427.311 5,960,244.355 566,090.137 70° 18' 06.553" N 149° 27' 52.890" W
8,100.000 56.000 90.000 5,268.479 891.455 5,510215 5,960,245.025 566,173.030 70° 18' 06.553" N 149° 27' 50.473" W
8,200.000 56.000 90.000 5,324.398 891.455 5,593.118 5,960,245.694 566,255.923 70° 18' 06.552" N 149° 27' 48.056" W
8,300.000 56.000 90.000 5,380.318 891.455 5,676.022 5,960,246.363 566,338.816 70° 18' 06.551" N 149° 27' 45.639" W
8,400.000 56.000 90.000 5,436237 891.455 5,758.926 5,960,247.032 566,421.710 70° 18' 06.551" N 149° 27' 43221" W
8,500.000 56.000 90.000 5,492.156 891.455 5,841.830 5,960,247.702 566,504.603 70° 18' 06.5SO" N 149° 27' 40.804" W
8,600.000 56.000 90.000 5,548.075 891.455 5,924.733 5,960,248.371 566,587.496 70° 18' 06.5SO" N 149° 27' 38.387" W
8,700.000 56.000 90.000 5,603.995 891.455 6,007.637 5,960,249.040 566,670.389 70° 18' 06.549" N 149° 27' 35.970" W
8,800.000 56.000 90.000 5,659.914 891.455 6,090.541 5,960,249.710 566,753282 70° 18' 06.548" N 149° 27' 33.553" W
8,900.000 56.000 90.000 5,715.833 891.455 6,173.445 5,960,250.379 566,836.175 70° 18' 06.548" N 149° 27' 31 .136" W
9,000.000 56.000 90.000 5,771.753 891.455 6,256.348 5,960,251.048 566,919.068 70° 18' 06.547" N 149° 27' 28.719" W
9,100.000 56.000 90.000 5,827.672 891.455 6,339252 5,960,251.718 567,001.961 70° 18' 06.546" N 149° 27' 26.302" W
9,200.000 56.000 90.000 5,883.591 891.455 6,422.156 5,960,252.387 567,084.854 70° 18' 06.546" N 149° 27' 23.885" W
9,300.000 56.000 90.000 5,939.510 891.455 6,505.060 5,960,253.056 567,167.748 70° 18' 06.545" N 149° 27' 21.468" W
9400.000 56.000 90.000 5995.430 891.455 6 587.963 5 960 253.725 567250.641 70° 18' 06.544" N 149° 27' 19.0SO" W
11/19/20041O:38:43AM Page 4 0'6 COMPASS 2003.11 Build 41
ORIGI~\'lY~~L
.
~illips
.
SPERRY_SUN HES
Planning Report - Geographic
9,500.000 56.000 90.000 6,051.349 891.455
9,600.000 56.000 90.000 6,107.268 891.455
9,700.000 56.000 90.000 6,163.188 891.455
9,800.000 56.000 90.000 6,219.107 891.455
9,900.000 56.000 90.000 6,275.026 891.455
9,982.097 56.000 90.000 6,320.934 891.455
Begin Dir @ 5.00 DLS:. 9982.100ft MD,6320.936ft TVD
10,000.000 56.891 90.070 6,330.829 891.446 7,085.463 5,960,257.733 567,748.077 70° 18' 06.540" N 149° 27' 04.546" W
10,029.075 58.344 90.180 6,346.400 891.392 7,110.016 5,960,257.877 567,772.627 70° 18' 06.539" N 149° 27' 03.830" W
Base HRZ
10,100.000
10,200.000
10,216.672
K-1
10,300.000 71.864
10,400.000 76.856
10,460.902 79.898
TOp Kuparuk-D
10,500.000 81.848
10,563.085 85.000
10,600.000 85.000
10,615.600 85.000
Top C4 Sand
10,665.600 85.000 91.823 6,521.758 878.794 7,714.344 5,960,250.160 568,376.979 70° 18' 06.409" N 149° 26' 46.211" W
7--5/8" Csgpt... Begin 6-3/4" hole: 10665.600ft MD, 6521.758ft TVD --Continue Dir ; 476211 FNL & 2932ftFEL; SeC18-TON
10,700.000 85.000 91.823 6,524.756 877.704 7,748.596 5,960,249.346 568,411.235 70° 18' 06.398" N 149° 26' 45.212" W
10,799.180 85.000 91.823 6,533.400 874.5607,847.348 5,960,247.000 568,510.000 70018'06.366"N 149°26'42.333"W
Target (Heel) GeoSteer, 10799.18011 MD, 6533.400ftTVD, (4766ft FNL, 2799ft FEL, Sec18-T11N-R11E-1D-28UpperMidSaJ
10,800.000 85.000 91.823 6,533.471 874.534 7,848.165 5,960,246.981 568,510.817 70° 18' 06.366" N 149° 26' 42.309" W
10,814.180 85.000 91.823 6,534.707 874.085 7,862.283 5,960,246.645 568,524.937 70° 18' 06.361" N 149° 26' 41.898" W
10,818.150 84.717 91.969 6,535.063 873.954 7,866.235 5,960,246.546 568,528.890 70° 18' 06.360" N 149° 26' 41.782" W
Begin Dir @ 8_00 DLS: 10818.150ft MD,653U63ft TVD
10,900.000 78.903 95.006 6,546.723 869.043 7,947.057 5,960,242.289 568,609.740 70° 18' 06.311" N 149° 26' 39.426" W
10,969.546 73.982 97.683 6,563.025 861.590 8,014.224 5,960,235.379 568,676.960 70° 18' 06.237" N 149° 26' 37.468" W
End Dir, Start Sail@ 73.982: 10969.550ft MD, 6563.026ft TVD
11,000.000 73.982 97.683 6,571.429 857.677 8,043.233 5,960,231.700 568,705.996 70" 18' 06.198" N 149° 26' 36.622" W
11,053.771 73.982 97.683 6,586.267 850.767 8,094.453 5,960,225.205 568,757.265 70" 18' 06.129" N 149" 26' 35.129" W
BeginDir @ 7.00 DLS:11053.780ft MD,6586.269ft TVD
11,100.000 77.175 97.160 6,597.778 844.986 8,138.844 5,960,219.783 568,801.697
11,200.000 84.091 96.067 6,614.040 833.639 8,236.795 5,960,209.229 568,899.727
11,277.734 89.472 95.238 6,618.400 826.000 8,314.000 5,960,202.214 568,976.984
Target (Lower C pt 1) : 11277.730ft MD, 6618.400ft TVD, - 1D-28 Lower C-Sðnd ptL0ut
11,300.000 89.472 95.238 6,618.605 823.967 8,336.173 5,960,200.360 568,999.170 70° 18' 05.863" N
11,400.000 89.472 95.238 6,619.526 814.839 8,435.751 5,960,192.037 569,098.809 70° 18' 05.772" N
11,500.000 89.472 95.238 6,620.447 805.711 8,535.329 5,960,183.714 569,198.448 70° 18' 05.682" N
11,600.000 89.472 95.238 6,621.369 796.583 8,634.907 5,960,175.391 569,298.088 70° 18' 05.591" N
11,700.000 89.472 95.238 6,622.290 787.455 8,734.486 5,960,167.068 569,397.727 70° 18' 05.500" N
11,800.000 89.472 95.238 6,623.211 778.327 8,834.064 5,960,158.745 569,497.366 70" 18' 05.409" N
11,900.000 89.472 95.238 6,624.132 769.199 8,933.642 5,960,150.422 569,597.005 70° 18' 05.318" N
11,929.100 89.472 95.238 6,624.400 766.542 8,962.619 5,960,148.000 569,626.000 70° 18' 05.291" N
Target (Toe) : 11929.09011 .MD, 6624.400ft TVD, (487611 FNL, 1684ftFEL, Sec18-T11N-R11E -1D-28Lower C.sandPl 2
EDM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 1 D Pad
Plan 1 D-28
Plan 1 D-28
Plan 1 D-28 (wp07)
61.881
66.872
67.706
90.435
90.769
90.822
6,381.735
6,424.963
6,431.400
91.078
91.370
91.542
6,460.185
6,487.133
6,499.400
91.650
91.823
91.823
91.823
6.505.601
6,512.823
6,516.040
6,517.400
6,670.867
6,753.771
6,836.675
6,919.578
7,002.482
7,070.544
891.059 7,171.499
890.106 7,261.633
889.893 7,277.011
888.594 7,355.178
886.535 7,451.424
885.019 7,511.051
883.944 7,549.637
882.044 7,612.271
880.874 7,649.027
880.379 7,664.560
5,960,254.395
5,960,255.064
5,960,255.733
5,960,256.403
5,960,257.072
5,960,257.621
5,960,258.041
5,960,257.816
5,960,257.726
5,960,257.059
5,960,255.777
5,960,254.743
5,960,253.979
5,960,252.585
5,960,251.712
5,960,251.343
567,333.534
567,416.427
567,499.320
567,582.213
567,665.106
567,733.159
567,834.104
567,924.234
567,939.612
568,017.780
568,114.030
568,173.661
568,212.252
568,274.892
568,311.653
568,327.188
70° 18' 06.543" N
70° 18' 06.543" N
70° 18' 06.542" N
70° 18' 06.541" N
70° 18' 06.540" N
70° 18' 06.540" N
70° 18' 06.535" N
70° 18' 06.525" N
70° 18' 06.523" N
70° 18' 06.509" N
70° 18' 06.488" N
70° 18' 06.472" N
70° 18' 06.461" N
70" 18' 06.442" N
70" 18' 06.430" N
70" 18' 06.425" N
70° 18' 06.072" N
70° 18' 05.960" N
70° 18' 05.884" N
149° 27' 16.633" W
149° 27' 14.216" W
149° 27' 11.799" W
149° 27' 09.382" W
149° 27' 06.965" W
149° 27' 04.981" W
149" 27' 02.037" W
149° 26' 59.409" W
149° 26' 58.961" W
149° 26' 56.682" W
149° 26' 53.876" W
149° 26' 52.138" W
149° 26' 51.013" W
149" 26' 49.187" W
149° 26' 48.115" W
149° 26' 47.662" W
149" 26' 33.835" W
149" 26' 30.980" W
149° 26' 28.729" W
149° 26' 28.083" W
149° 26' 25.180" W
149° 26' 22.277" W
149° 26' 19.374" W
149° 26' 16.471" W
149° 26' 13.568" W
149° 26' 10.665" W
149° 26' 09.820" W
11/19/200410:38:43AM
COMPASS 2003.11 BuDd 41
Page 5 of6
ORIGINAL
.
.
~illips
SPERRY_SUN HES
Planning Report - Geographic
1 D-28 Upper Mid Sa,
- plan hits target
- Point
1 D-28 Lower C-Sand
- plan hits target
- Point
1 D-28 Lower C-Sand
- plan hits target
- Point
EDM 2003.11 Single User Db
ConocoPhillips Alaska Inc. (Kuparuk)
Kuparuk River Unit
Kuparuk 10 Pad
Plan 1 D-28
Plan 1 D-28
Plan 1 D-28 (wp07)
0.00
0.006,533.400 874.560 7,847.348 5,960,247.000 568,510.000 70°18' 06.366" N 149° 26' 42.333" W
0.00
0.006,618.400 826.000 8,314.000 5,960,202.214 568,976.984 70°18' 05.884" N 149° 26' 28.729" W
0.00
0.00 6,624.400 766.542 8,962.619 5,960,148.000 569,626.000 70° 18' 05.291" N 149° 26' 09.820" W
1,809.819 Base Permafrost 0.00 0.000
4,208.536 Top Ugnu 0.00 0.000
5,365.561 Top West Sak 0.00 0.000
6,213.211 Base West SAk 0.00 0.000
6,914.221 C-80 0.00 0.000
10,029.075 Base HRZ 0.00 0.000
10,216.672 K-1 0.00 0.000
10,460.902 Top Kuparuk-D 0.00 0.000
10,615.600 Top C4 Sand 0.00 0.000
34.510
300.100
2,066.670
3,200.100
3,936.989
9,982.100
10,665.600
10,799.180
10,818.150
10,969.550
11,053.780
11 ,277. 730
11,929.090
34.510
300.100
1 ,825.283
2,507.399
2,940.553
6,320.936
6,521.758
6,533.400
6,535.063
6,563.026
6,586.269
6,618.400
6,624.400
SHL -- 357ft FNL & 419ft FEL, Sec23-T11 N-R10E
Begin Dir @ 3.00 DLS: 300.100ft MD,3oo.100ft TVD
End Dir, Start Sail @ 53.000: 2066.670ft MD, 1825.283ft TVD
Begin Dir@ 3.00DLS: 32oo.1ooft MD,2507.399ft TVD
End Dir, Start Sail @ 56.000: 3936.990ft MD, 294O.553ft TVD
Begin Dir @ 5.00 DLS: 9982.1 OOft MD,6320.936ft TVD
7-518" Csg pt.u Begin 6-3/4" hole: 10665.600ft MD, 6521.758ft TVD -- C
Target (Heel) GeoSteer, 1 0799.180ft MD, 6533.4ooft TVD, (4766ft FNL, :
Begin Dir@ 8.00 DLS: 10818.150ft MD,6535.063ft TVD
End Dir, Start Sail @ 73.982: 10969.550ft MD, 6563.026ft TVD
Begin Dir @ 7.00 DLS: 11 053.780ft MD,6586.269ft TVD
Target (Lower C pt 1) : 11277.73Oft MD, 6618.400ft TVD,
Target (Toe) : 11929.090ft MD, 6624.400ft TVD, (4876ft FNL, 1684ft FEL
11/19/200410:38:43AM
COMPASS 2003.11 Build 41
Page 6 0(6
OR'GI~JAJ
· .
lD-28 Drilling Hazards Summary
13-1/2" Hole 110-3/4" 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.
Gravel/Sand Sloughing Moderate Increase mud weight / viscosity, High viscosity sweeps.
Monitor fill on connections
Hole Swabbing(Tight Hole on Trips Moderate Circulate hole clean prior to trip. Proper hole fill (use of
trip sheets), PumpinQ 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 I 7-5/8" Casing Interval
Event Risk Level Mitiaation Strateay
Shale stability in HRZ and K-l Low Control with hiQher MW and proper drillinQ 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.
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 drillinQ pav interval.
Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates,
Mud rheology, LCM. Use GKA LC decision tree.
6-3/4" Hole I 4-1/2" Liner Interval
Event Risk Level Mitigation Strategy
Trouble sidetracking off of Moderate AKO setting on motor and bit selection will be tailored to
aluminum billet this operation. Hole will be trenched prior to engaging
the billet to aid in sidetrackinQ.
Trouble Sliding / Steering Moderate Bit/BHA design will take into account historical problems
in offset horizontal wells with steering. Although LOTAD's
should not be needed, torque/drag will be monitored to
pro-actively identify a need for friction reduction devices
to prevent weight transfer problems.
Differential Sticking Moderate Periodic wiper trips. 00 not leave pipe static for extended
period of time.
Difficulties getting upper liner to Moderate Torque/drag will be monitored while drilling the interval.
bottom with swell packers Check with the drilling assembly to ensure the hole
section through the billet is fully open. A bent joint with a
silver bullet shoe will be used on the end of the liner.
Lost Circulation Moderate Use PWD to monitor hole cleaning. Reduced pump rates,
Mud rheology, pre-treat with LCM prior to drilling fault
crossings. Use LC decision tree designed for production
laterals. An extensive LC strategy will be documented in
the well plan.
10-28 Drilling Hazards Summary. doc
prepared by Scott Lowry
11/18/04
Page 1 of 1
OR J G'N,A L_
Rig: Doyon 14
Location: Kuparuk
Client: CPAI
Revision Date: 11119/2004
Prepared by: Mike Martin
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 229-6266
email: martin13@slb.com
< Toe at Surface
Previous Csg.
< 20", 91.5# casing
at 118' MD
< Base of Permafrost at
1,810' MD (1,657' TVD)
< Top of Tail at
4,565' MO
< 103/4",45.5# casing
in 13 1/2" OH
TO at 6,571' MD
(4,413' TV D)
Mark of Schlumberger
Schllm
gep
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
Volumes are based on 250% excess in the permafrost and 35% excess below the
permafrost. The top of the tail slurry is designed to be at 4,565' MD.
Lead Slurry Minimum pump time: 310 min. (pump time plus 90 min.)
ARCTICSET lite @ 10.7 ppg - 4.45 ft3/sk
3
1.3644 ft 1ft x (118') x 1.00 (no excess) =
0.3637ft3/ft x (1810' -118') x 3.50 (250% excess) =
0.3637ft3/ft x (4565' -1810') x 1.35 (35% excess) =
161 ft3 + 2153.8 ft3+ 1352.7 ft3 =
3667.5 ft3 14.45 ft3/sk =
Round up to 830 sks
161 ft3
2153.8 ft3
1352.7 ft3
3667.5 ft3
824.2 sks
Have 290 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurrv Minimum pump time: 220 min. (pump time plus 90 min.)
liteCRETE @ 12.5 PP9 - 2.24 ft3/sk
0.3637 ft3/ft x (6571' - 4565') x 1.35 (35% excess) =
0.5400 ft3/ft x 80' (Shoe Joint) =
984.9 ft3 + 43.2 ft3 =
1028.1 ft31 2.24 ft3/sk =
Round up to 460 sks
984.9 fe
43.2 ft3
1028.1 ft3
459 sks
BHST = 97°F, Estimated BHCT = 89°F.
(BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost)
PUMP SCHEDULE
Stage
Pump Rate
(bpm)
Stage
Volume
Cumulative
Stage Time Time
(min)
(bbl) (min)
CW100 5.0 10.0 2.0 2.0
Pressure test lines 0.0 0.0 10.0 12.0
CW100 5.0 40.0 8.0 20.0
Drop bottom plug 0.0 0.0 5.0 25.0
MUDPUSH II 6.0 50.0 8.3 33.3
ASL 6.0 653.3 108.9 142.2
liteCRETE 6.0 183.1 30.5 172.7
Drop top plug 0.0 0.0 5.0 177.7
Water 5.0 20.0 4.0 181.7
Switch 0 rig pumps 0.0 0.0 5.0 186.7
Mud 7.0 592.3 84.6 271.3
Slow & bump plug 3.0 12.0 4.0 275.3
MUD REMOVAL
Recommended Mud Properties: 10.1 ppg, Pv < 25, Ty < 30. As thin and light as possible
to aid in mud removal durin9 cementing.
Spacer Properties: 10.5 ppg MudPUSH* II, Pv = 17-21, Ty = 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
ORIGINAL.
Rig: Doyon 14
Location: Kuparuk
Client: CPAI
Revision Date: 11/19/2004
Prepared by: Mike Martin
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 229-6266
email: martin13@slb.com
Previous Csg.
< 103/4",45.5# casing
at 6,571' MO
< Top of Tail at
9,815' MO
< 75/8",29.7# casing
in 9 7/8" OH
TO at 10,665' MD
(6,522' TVO)
amb8Pgop
Preliminary Job Design based on limited input data. For estimate purposes only.
Volume Calculations and Cement Systems
Volumes are based on 40% excess. Tail slurry is designed for 800' MD above target-
(850' MD annular length).
Tail Slurry Minimum thickening time: 180 min. (Pump time plus 90 min.)
15.8 ppg Class G + 0.2%D46, 0.3%D65, 0.02%B155, 0.4% D167 - 1.16 ft3fsk
0.2148 ft31ft x 850' x 1.40 (40% excess) =
0.2578 ft3fft x 80' ¡Shoe Joint) =
255.6 ft3 + 20.6 ft =
276.2 ft3f 1.16 ft3fsk =
Round up to 240 sks
255.6 ft3
20.6 ft3
276.2 ft3
238.1 sks
BHST = 151°F, Estimated BHCT = 117°F.
(BHST calculated using a gradient of 2.6°Ff100 ft. below the permafrost)
PUMP SCHEDULE
Stage
Pump Rate
(bpm)
Stage
Volume
(bbl)
Cumulative
Stage Time Time
(min) (min)
CW100 5.0 10.0 2.0 2.0
Pressure test lines 0.0 0.0 10.0 12.0
CW100 5.0 30.0 6.0 18.0
Drop bottom plug 0.0 0.0 5.0 23.0
MUDPUSH II 6.0 40.0 6.7 29.7
Tail 6.0 49.2 8.2 37.9
Drop top plug 0.0 0.0 5.0 42.9
Mud 7.0 474.0 67.7 110.6
Slow & bump plug 3.0 12.0 4.0 114.6
MUD REMOVAL
Recommended Mud Properties: 10.6 ppg, Pv < 20, Ty < 20. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.5 ppg MudPUSH* II Pv = 19-22, Ty = 22-29
Centralizers: Recommend 1 -Y2 per joint across zones of interest for proper cement
placement.
OR1GI,NAl-
1 D..28 Horizon Well Base Case
Proposed Completion Schematic
~/
ConocoPhillips
l
4-1/2" FMC Gen V Tubing Hanger, 4-1/2" L-SO IBT pin down (Special Drift to 3.91")
4-1/2" 12.6# L-SO IBT Spaceout Pups as Required (Special Drift to 3.91")
4-1/2" 12.6# L-SO IBT Tubing to Surface (Special Drift to 3.91")
4-1/2" Cameo 'DB' nipple w/3.S75" No-Go Profile set at +1- 500' MD
Liner Assemblv - Hanqer Set +1- 150' above intermediate csq shoe
Baker 5 )1," x 7 5/S" 'ZXP' Liner Top Isolation Packer wi HRD running profile
4-1/2" 126# L-SO IBT tubing to landing nipple (Special Drift to 3.843")
4-1/2" xi" Camco 'KBG-2' Mandrels wI OV's (Max. 00 5.9S4",ID
out wi 4-1/2" 126# L-SO IBT tubing (Special Drift to 3.843") as follows:
GLM # TVD-RKB
MD-RKB
GLM Setting Depths TBO
Surface csg.
10-3/4" 455# L-SO BTC
Special Drift - 9.S75"
6571' MO 14413' TVD
(200' TVD below Base
West Sak)
4-1/2" Cameo 'DB' nipple w/3.S13" No-Go Profile set @
tangent section +1- 10,000 MD 16330' TVD
4-1/2" 12.6# L-SO IBT tubing from 'DB' nipple to sliding sleeve
(Special Drift to 3.843")
Baker 4-JI," CMU Sliding Sleeve, 3.S1" DB Profile
1 jt 4-1/2" 12.6# L-SO IBT tubing (Special Drift
4.75" 00 Baker casing seal assembly w/17 Ft. stroke,
# L-SO IBT box up (landed 3-4' off fully landed position)
Intermediate csg.
7 5/S" 29.7# L-SO BTCM
10,665' MD 16522' TVD
(App 50' MD below top ofC4)
4 )1," x 6.3" Swell Packers forisolation of potentially
conductive faults or wet intervals
Slotted Liner
4-112" 12.6# L-SO IBT
-----
Scott LowryJ1/1S/04
-----
Baker 5 JI," x 7 5/S" RS Nipple
, 'Slotte; Llne;- Î
'~' ~ '!. 6#ï";..Bj
C1 Lateral
"Plop &: Drop" liner to 11,929' MD(top of
billet appro 50' below 7 5/8" csg shoe)
Baker 5 )1," x 7 5/S" 'Flexlock' Liner Hanger
Baker 190-47 Casing Seal-Bore Receptacle (4.75" Polished Bore)
4 )1," 12.6# L-SO IBT alternating slotted and blank pipe wI swell packers
(installation of blank pipe & swell pkrs TBD with well logs)
4 )1," ROT 'Silver Bullet' Shoe ran on a bent joint of4 )1," 12.6# L-SO liner
N
l
SFD
1077
DATE.I Z)!OJt!fw.~ ~-14/311
-.--J $100. CÒ
- ßI SeçurilyFea'ut( ·
DOLLARS t ~nBack.
SHARON K. ALLSUP-DRAKE
CONOCOPHILLlPS
ATO 1530
700 G STREET
ANCHORAGE AK 99501
.
5000 Dollars
2?~~~~~Jd~
Valid Up T
anhattiDl Bank USA. N.A.
Clay Center Dr.. Newark, DE. 191
.
ib- f()2 bf ,_.,Q
MEMO 7 { ~
.:03 ~ ~OO ~.......: 2 ~8"'? ~c¡0?c¡
.
.
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRlA TE LETTER/P ARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME k£¿( I b - 2~
PTD# wv- 2,37
V-/ Development
Service
Exploration
Stratigraphic
CHECK WBA T ADD-ONS ~'CLUE ",
APPLIES (OPTIONS)
MULTI Tbe permit is for a new we1lboresegment of
LATERAL existing weD .
Permit No, API No. .
(If API number Production.sbould continue to be reported as
last two. (2) digits a function' of tbe original API number. stated
are between 60-69) above.
PILOT HOLE In accordance witb 20 AAC 25.005(1), a))
(PH) records, data and logs acquired for tbe pilot
bole must be dearly differentiated In botb
name (name on permit plus PH)
.' and API Dumber (SO -
70/80) from records, data and logs acquired
for wen (name on permit).
SPACING Tbe permit is approved subject ·to full
EX CEPTJ ON compliance witb 20 AAC 25.0SS~ Approval to
perforate and produce is contingent upon
issuance of ~ conservation order approving a
spacing e:J cep1ion.
(Company Name) assumes the liability of any
protest to tbe spacing ,exception that may
occur.
DRY DITCH AU dry ditcb sample sets submitted to the
SAMPLE Commission must be in no greater 1han 30'
sample intervals from below tbe permafrost
or from where samples are first caught and
] 0' sample h:iter:vals through target zones.
..
Field & Pool KUPARUK RIVER, KUPARUK RV OIL - 490100 Well Name: KUPARUK RIV UNIT 1 D-28 Program DEV__~ Well bore seg ~
PTD#: 2042370 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal D
Administration 1 P~rmiUee attaçhed_ _ _ _ _ _ _ _ .. y~s _
2Leas~numberappropri<lte. . _ . . . . . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . . . y~s _ _ _ _ _ _ Surfaçe Ipca.tion in ADL025650, prod interv<lL& TO tnAD.L.0282A3
3 _U_ntque weILn_a(l1~_aod [luJnb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _
4 WellJoc¡:¡t~d in a defineJ:tppol_ _ . . _ _ . . _ _ _ _ _ _ _ . . . y~s _ _ Kup_aruI<RivßrOil~ool,9-ovemedby_CPllserv<ltioRQrderNp..432C_ _ _ _
5 WeJUoc<ltßd proper dtstance_ from driJling unitb_ound_ary_ . . . _ _ . _ _ _ _ _ _ . _ . y~s _ _ _ _ _ No inter-well restrjc_tions, morethan50Q' from ~¡cternalbpun.d<lry._ . _ _ _ _ . . .
6 WellJoc¡:¡tßd proper .dtstance from other wßlJs Xes. _ _ _ _ _ _ . _ .
7 _SuffiçienLaçrßa9-e_aYail<lble in.dJillillg unjL _ . . _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ Xes. _ _ _ _ _ . . _ . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ .
8 Jtd~viated, js wellbore platincJuded _ _ _ _ _ _ _ _ . _ _ _ . . . . _ _ _ _ . . . _ y~s _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . _ . . . . _
9 _Operator only affeçtßd party _ _ _ . . _ _ y~s _ _ _ _ . . _ _ . . _ . . _ _ _ _ _ _
10 _OPßrator bas_apprppriate_ bond tnJorce . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
11 P~rmit can Þe tssued witbout COMervation order _ . y~s _ _ _ _ _ _ _ _ . . _ _ _ . . .
Appr Date 12 P~rmitc.an Þe tssued without adminÎstratilleapproval _ . _ _ _ _ _ _ _ . . . _ _ y~s _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ . .
SFD 11/24/2004 13 Can permit be approved before 15-day wait Yes
14 WeJUocatßd wtthin area alldstrat<lauthortzed by_lnjectipll Order # (puUO# in_colll(l1~nts). (for NA _ _ _ _ _ _ . . _ _ _ . . _ _ _ . _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ . . . .
15 _AJIWßlJs_wit!1tnJl4J-oile_area_ofreyißwid_elltified(FprseNj~)V_ellpnly>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __
16 Pre-produced iojßctor; dur<itionof prß-produc;tiplll~ss than 3 months_ (for_sßrvtce well only) _ . NA _ _ _ _ _ _ _ _ _ _ . .
17 ACMPFJlldjngof Con_sisteocy_h_as Þee.nis.sued_ fpr.tbis projeçt _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ NA
18
19
20
21
22
23
24
25
26
27
Date 28
11/29/2004 29
30
31
32
133
34
Engineering
Appr
TEM
Appr
SFD
35
36
Date 37
11/24/2004 38
39
Geology
Geologic
Commissioner:
Dí5
Conductor st(ÍllgpJovidßd _ . _ . _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . . _ . . _ Xes _ _ _ _ _ _ .
Surfacecas.ing_PJotects.aILknown_USQWs. . NA _ _ _ _ _ . .Allaquifersexe(l1pt~d,40CFR1<47.:tQ2_M(3L _ _ _ . .
_CMT vol adßqu.ate.to çirc_ulate_on.cpnd_uctpr & surfC$g _ . Xes_
CMTvoladßquate.totie-inJong string tosurfcsg. . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _. No_ _ _ _ _ _ _AllhydroçarbonzPlleswillbecovered. Annular_dispos_alm.wbe_proppsed.
.CMT will coyer.aJll<llownproductiye borizons . _ _ _ _ _ _ _ _ _ _ . _ _No _ _ _ _ _ _ Slotted Jiller planne_d. _
_C_asing designs adequate for C,T, B&permafrost _ _ _ _ . . _ y~s _ _ _ _ _ _ _ _ _ _ _ . . . .
Adequ<itetanJ<age_oJ re.serve pit. _ _ _ _ _ _ _ _ . y~s. . _ _ . _ Rig is equipped_with st~eLpits.. No_ rßse.Ne_pjtplanlled. Wasteto approved annulus ordispos.a! welt _ _ _ . . . .
Jfare-drilt basa lO-403 for <lbandollment be~1l <lPPJovßd . . . _ _ _ _ _ _ _ _ . _ NA _ _ _ _ _ _ .
Adequ<itewellbore separation-Pfoposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ y~s _ _ _ _ _ _ _ I?rp~imtty an<ilysis performe_d. Jrayeling çyJinder plptillcJu_ded.. Gyros_possible. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
Jfdivßcter Jeq.uired, does iLmeet regula.tions . . _ _ _ Xes _ _ . . _ _ . . . .
_DJilIillg fluid. program schematic&. eQ.uipJistadequat~ _ _ _ _ . _ _ _ . . . . _ _ _ _ Xes _ _ _ _ _ _ _ Maximum expected formation pres.sureJO.2EMW.l?lann~d mud weight1Q.5 in9~7/8" hole <llld_ lO,2. in KUP.
BOPEs, do they meet regula_tion _ . . y~s _ _ _ _ _ . _ _ . . _ _ _ _ _ _ _
B_OPE_press rating appropriate; .test to (pu.t psig in comments) . . . y~s _ . _ _ _ _ _ MAS~ calcuJate_dat 27:82 psi.. 35QO_p.siappr.opriate.CPAJ normally tests to 50QOp-sL _
_CMke.mC!nifold complies w/APl RP-53 (May 84) _ _ . _ . . _ . . . y~s _ _ _ _ . . _ _
Work will occw withputoperationsbutdown _ _ _ _ _ . _ _ . . _ y~s . _ _ _ _ _ . _ _ _ _ . _ . . _ . _ _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _
Is. pres.ence. of H2S gas. probaÞle . No_ _ _ _ _ _ _ H2S may be_PJeselltin KU~ per offsets. .Mud.should preclude Pll rig. Rig is eQuipped witb sen.sors alld alC!rIllS..
MechanicaLcollditionofwells wtthin AORyerified (Fpr.s.ervicewell only) _ _ _ _ _ _ _. _. _ _ _ NA _ _ _ _. _. . _ _ _ _ _ _..... _ _ _ _ _ _ _ _. _ _ _.
- - - - - - - - - -
- - - - - - - - - - - - - - - - - - - - - - - -
- - - - - - - - - -
P~rmit c.an Þe tssued wlo hydrogen sulfide meC!sµres
_D_ata_pJesellted Ol'! pote_ntiC!1 pveJpressurezones_
_S~islllic.analysjs. of shallow gC!s_z_olles_
S~abedconditioll survey -(if off-sh_ore) .
_ Contactnamelphoneforweekly progress_reports [explorç¡tpryonly]
. . _ _ _ _ _ _ _ . . _ _ _ _ _No _ _ _ _ _ _ . WßlJs.tC,.t2.a.nd '1 D-04, t mito east alldwest (espectillely, measured 90 ç¡nd.47.PPIll_H2.8.in 2Q03._
. y~s _ _ _ _ _ _ _ Expected reservoir pre_sSUJe is _9.5. -10.2 ppg EMW, wiJl be drjllßd with lO,2 ppgmu_d. _
.. NA
.NA.
. _ _ _ _ __ _ _ _ _.. _. _ NA
- - - - - - - - - - - - - - - - - - - - -
- - - - - - - - -
- - - - - -
- - - - - - - - - -
Date:
Engineering
Commissioner:
Date
Public
Commissioner
Original Signed By
John K. Norman
Date'\.~
.~.~~.
~
11/2-1/ rr
.
.
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
simplify 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.
.
Sperry-Sun Drilling Services
LIS Scan Utility
$Revision: 3 $
LisLib $Revision: 4 $
Wed Feb 16 16:21:20 2005
2£;4- ;L. 3 7
.
# I )0 ~1
I
Reel Header
Service name....... ......LISTPE
Date. . . . . . . . . . . . . . . . . . . . .05/02/16
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. . . . . . . . . . . . . . . . . . . . .05/02/16
Origin. . . . . . . . . . . . . . . . . . . STS
Tape Name.............. ..UNKNOWN
Continuation Number......Ol
Previous Tape Name..... ..UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
Physical EOF
Comment Record
TAPE HEADER
Kuparuk
MWD/MAD LOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 4
MW0003444739
C.A. DEMOSKI
D. GREEN
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 7
MW0003444739
T. MCGUIRE
E. VAUGHN
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 12
MW0003444739
C.A. DEMOSKI
D. GREEN
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
ID-28
500292323700
ConocoPhillips Alaska, Inc.
Sperry-Sun Drilling Services
16-FEB-05
MWD RUN 5
MW0003444739
T. MCGUIRE
E. VAUGHN
MWD RUN 8
MW0003444739
T. MCGUIRE
E. VAUGHN
MWD RUN 13
MW0003444739
C.A. DEMOSKI
D. GREEN
23
llN
10E
357
419
MWD RUN 6
MW0003444739
T. MCGUIRE
E. VAUGHN
MWD RUN 11
MW0003444739
C.A. DEMOSKI
D. GREEN
MWD RUN 14
MW0003444739
C.A. DEMOSKI
D. GREEN
.
.
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
104.65
70.90
#
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
OPEN HOLE
BIT SIZE (IN)
9.875
6.750
CASING
SIZE (IN)
10.750
7.625
DRILLERS
DEPTH (FT)
6581. 0
11065.0
#
REMARKS:
1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED.
THESE DEPTHS ARE
MEASURED DEPTH (MD).
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. THIS WELLBORE EXITS 1D-28PB1 AT 11140'MD/6590'TVD BY
MEANS OF AN OPENHOLE
SIDETRACK.
4. MWD RUNS 1-3 WERE DIRECTIONAL ONLY - NO DATA ARE
PRESENTED.
5. MWD RUNS 4-8, 11-14 COMPRISED DIRECTIONAL WITH DUAL
GAMMA RAY (DGR)
UTILIZING GEIGER-MUELLER TUBE DETECTORS¡
ELECTROMAGNETIC WAVE RESISTIVITY
PHASE-4 (EWR4)¡ AND PRESSURE-WHILE-DRILLING (PWD).
MWD RUNS 7,8,11-13 ALSO
INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN) ¡
STABILIZED LITHO-
DENSITY (SLD) ¡ AND AT-BIT INCLINATION (ABI).
MAD-PASS DATA ACQUIRED AFTER
RUNS 6 & 8 TO FILL DATA GAPS WERE MERGED WITH MWD
DATA FROM RUNS 6 & 8.
RUN 14 ALSO INCLUDED ABI. BECAUSE OF THE SHORT
INTERVAL OF RUN 7, THE
SENSORS NEVER EXITED THE CASING¡ THEREFORE, ONLY
SROP DATA ARE PRESENTED
FOR RUN 7.
6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL,
DATED 12/16/04, FROM M.
WERNER (CPAI) TO R. KALISH (SSDS). MWD DATA ARE
CONSIDERED PDC.
7. MWD RUNS 4-8, 11-14 REPRESENT WELL 1D-28 WITH API#:
50-029-23237-00. THIS
WELL REACHED A TOTAL DEPTH (TD) OF
14672'MD/6633'TVD.
SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED
SHALLOW SPACING) .
SESP = SMOOTHED PHASE SHIFT-DERIVED
SPACING) .
SEMP = SMOOTHED PHASE SHIFT-DERIVED
SPACING) .
SEDP = SMOOTHED PHASE SHIFT-DERIVED
SPACING) .
SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) .
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE
MATRIX, FIXED HOLE SIZE) .
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
RESISTIVITY (EXTRA
RESISTIVITY ( SHALLOW
RESISTIVITY (MEDIUM
RESISTIVITY (DEEP
CTNA = SMOOTHE~VERAGE OF NEAR DETECTOR'S COUNtlltTE.
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT
BIN) .
SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) .
SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW-COUNT BIN) .
SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS.
SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR
DEPTHS.
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZES: 6.75"
MUD WEIGHT: 10.0 - 10.1 PPG
MUD SALINITY: 68,000 - 129,000 PPM CHLORIDES
FORMATION WATER SALINITY: 25,000 PPM CHLORIDES
FLUID DENSITY: 1.0 G/CC
MATRIX DENSITY: 2.65 G/CC
LITHOLOGY: SANDSTONE
$
File Header
Service name............ .STSLIB.001
Service Sub Level Name...
Version Number......... ..1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type... ..... ...... ..LO
Previous File Name...... .STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
FET
RPS
RPM
RPD
RPX
ROP
NCNT
FCNT
NPHI
RHOB
PEF
DRHO
$
1
and clipped curveSj all bit runs merged.
.5000
START DEPTH
6553.5
6560.0
6560.0
6560.0
6560.0
6560.0
6591. 5
11002.5
11002.5
11003.5
11049.5
11049.5
11049.5
STOP DEPTH
14615.5
14622.5
14622.5
14622.5
14622.5
14622.5
14672.0
13723.5
13723.5
13723.5
13738.0
13738.5
13738.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED DATA SOURCE
PBU TOOL CODE
MWD
MWD
MWD
MWD
MWD
MWD
BIT RUN NO
4
5
6
7
8
11
MERGE TOP
6553.5
7683.5
10924.5
11075.5
11095.0
11140.5
MERGE BASE
7683.5
10924.5
11075.0
11095.0
11140.0
11211.0
.
MWD
MWD
MWD
$
12
13
14
11211.0
12113.0
13816.0
12113.0
13816.0
14672.0
.
#
REMARKS:
MERGED MAIN PASS.
$
#
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...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD CNTS 4 1 68 4 2
NCNT MWD CNTS 4 1 68 8 3
RHOB MWD G/CM 4 1 68 12 4
DRHO MWD G/CM 4 1 68 16 5
RPD MWD OHMM 4 1 68 20 6
RPM MWD OHMM 4 1 68 24 7
RPS MWD OHMM 4 1 68 28 8
RPX MWD OHMM 4 1 68 32 9
FET MWD HOUR 4 1 68 36 10
GR MWD API 4 1 68 40 11
PEF MWD BARN 4 1 68 44 12
ROP MWD FT/H 4 1 68 48 13
NPHI MWD PU-S 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 6553.5 14672 10612.8 16238 6553.5 14672
FCNT MWD CNTS 116.64 756.35 424.58 5443 11002.5 13723.5
NCNT MWD CNTS 12841.8 30894.1 22578 5443 11002.5 13723.5
RHOB MWD G/CM 1.3 4.97 2.47795 5378 11049.5 13738
DRHO MWD G/CM -0.598 2.08 0.114078 5378 11049.5 13738
RPD MWD OHMM 0.08 2000 18.8039 16126 6560 14622.5
RPM MWD OHMM 1. 01 2000 14.2239 16126 6560 14622.5
RPS MWD OHMM 0.07 1814.88 6.24427 16126 6560 14622.5
RPX MWD OHMM 0.07 1112.37 4.52541 16126 6560 14622.5
FET MWD HOUR 0.26 135.54 4.59625 16126 6560 14622.5
GR MWD API 37.4 404.67 119.84 16125 6553.5 14615.5
PEF MWD BARN 1. 26 13 .47 2.85226 5379 11049.5 13738.5
ROP MWD FT/H 0.04 599.62 82.4749 16162 6591. 5 14672
NPHI MWD PU-S 15.38 52.44 23.7321 5441 11003.5 13723.5
First Reading For Entire File...... ... .6553.5
Last Reading For Entire File.......... .14672
File Trailer
Service name. ......... ...STSLIB.001
Service Sub Level Name...
version Number.... ...... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
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...... .05/02/16
Maximum Physical Record. .65535
File Type.............. ..LO
Previous File Name. ......STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
FET
RPS
RPX
RPD
RPM
ROP
$
2
.
header data for each bit run in separate files.
4
.5000
START DEPTH
6553.5
6560.0
6560.0
6560.0
6560.0
6560.0
6591.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
STOP DEPTH
7645.5
7638.0
7638.0
7638.0
7638.0
7638.0
7683.5
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RES IS. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
28-DEC-04
Insite
66.37
Memory
7683.0
6553.0
7683.0
55.3
57.3
TOOL NUMBER
132482
66259
9.875
6581. 0
LSND
9.75
50.0
9.0
300
5.8
2.700
1.803
3.500
72.0
111. 2
72.0
·
MUD CAKE AT MT:
2.500
7.
#
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.....O
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...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD040 OHMM 4 1 68 4 2
RPM MWD040 OHMM 4 1 68 8 3
RPS MWD040 OHMM 4 1 68 12 4
RPX MWD040 OHMM 4 1 68 16 5
FET MWD040 HOUR 4 1 68 20 6
GR MWD040 API 4 1 68 24 7
ROP MWD040 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 6553.5 7683.5 7118.5 2261 6553.5 7683.5
RPD MWD040 OHMM 0.08 1877 . 35 14.4109 2157 6560 7638
RPM MWD040 OHMM 1. 64 1020.56 5.05975 2157 6560 7638
RPS MWD040 OHMM 1. 58 19.74 3.97631 2157 6560 7638
RPX MWD040 OHMM 1.53 12.61 3.83097 2157 6560 7638
FET MWD040 HOUR 0.27 82.25 3.30987 2157 6560 7638
GR MWD040 API 45.4 149.42 95.91 2185 6553.5 7645.5
ROP MWD040 FT/H 0.04 318.42 118.714 2185 6591. 5 7683.5
First Reading For Entire File......... .6553.5
Last Reading For Entire File.... ...... .7683.5
File Trailer
Service name....... ..... .STSLIB.002
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation. ..... .05/02/16
Maximum Physical Record..65535
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...... .05/02/16
Maximum Physical Record. .65535
File Type............... .LO
Previous File Name...... .STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
RPD
RPS
RPM
FET
RPX
GR
ROP
$
3
.'
header data for each bit run in separate files.
5
.5000
START DEPTH
7638.5
7638.5
7638.5
7638.5
7638.5
7646.0
7684.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
STOP DEPTH
10651.0
10651.0
10651.0
10651.0
10651.0
10887.0
10924.5
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTRO MAG. RES IS. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
01-JAN-05
Insite
66.37
Memory
10925.0
7683.0
10925.0
56.5
82.9
TOOL NUMBER
132482
66259
9.875
6581.0
LSND
10.00
54.0
9.0
300
4.7
2.600
1.815
2.800
2.100
73.0
107.5
73.0
73.0
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.
.
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type... ......... ......0
Data Specification Block Type.....O
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...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD050 OHMM 4 1 68 4 2
RPM MWD050 OHMM 4 1 68 8 3
RPS MWD050 OHMM 4 1 68 12 4
RPX MWD050 OHMM 4 1 68 16 5
FET MWD050 HOUR 4 1 68 20 6
GR MWD050 API 4 1 68 24 7
ROP MWD050 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 7638.5 10924.5 9281.5 6573 7638.5 10924.5
RPD MWD050 OHMM 0.91 2000 6.82743 6026 7638.5 10651
RPM MWD050 OHMM 1. 01 2000 5.72694 6026 7638.5 10651
RPS MWD050 OHMM 0.94 24.03 3.39419 6026 7638.5 10651
RPX MWD050 OHMM 0.86 12.4 3.09317 6026 7638.5 10651
FET MWD050 HOUR 0.26 10.84 1. 48896 6026 7638.5 10651
GR MWD050 API 37.4 404.67 147.522 6483 7646 10887
ROP MWD050 FT/H 1. 68 516.2 90.2176 6482 7684 10924.5
First Reading For Entire File......... .7638.5
Last Reading For Entire File.......... .10924.5
File Trailer
Service name............ .STSLIB.003
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation.. .....05/02/16
Maximum Physical Record. .65535
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... ... .05/02/16
Maximum Physical Record..65535
File Type.... ........... .LO
Previous File Name...... .STSLIB.003
.
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
RPX
RPS
RPD
FET
RPM
GR
ROP
$
4
.
header data for each bit run in separate files.
6
.5000
START DEPTH
10651.5
10651.5
10651.5
10651.5
10651.5
10887.5
10925.0
STOP DEPTH
11029.5
11029.5
11029.5
11029.5
11029.5
11037.5
11075.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
02-JAN-05
Insite
66.37
Memory
11075.0
10925.0
11075.0
82.1
82.3
TOOL NUMBER
132477
134760
9.875
6581.0
LSND
10.60
63.0
9.0
300
4.0
1. 600
1.018
2.600
2.800
72.0
117.0
72.0
72.0
.
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...O
.
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD060 OHMM 4 1 68 4 2
RPM MWD060 OHMM 4 1 68 8 3
RPS MWD060 OHMM 4 1 68 12 4
RPX MWD060 OHMM 4 1 68 16 5
FET MWD060 HOUR 4 1 68 20 6
GR MWD060 API 4 1 68 24 7
ROP MWD060 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 10651.5 11075 10863.3 848 10651.5 11075
RPD MWD060 OHMM 3.86 10.35 5.21254 757 10651.5 11029.5
RPM MWD060 OHMM 3.62 9.65 4.8844 757 10651. 5 11029.5
RPS MWD060 OHMM 2.95 9.2 3.89874 757 10651.5 11029.5
RPX MWD060 OHMM 2.53 8.29 3.46553 757 10651. 5 11029.5
FET MWD060 HOUR 1. 48 35.88 23.2968 757 10651. 5 11029.5
GR MWD060 API 71 139.17 119.376 301 10887.5 11037.5
ROP MWD060 FT/H 1.13 297.79 51.4741 301 10925 11075
First Reading For Entire File......... .10651.5
Last Reading For Entire File.. ........ .11075
File Trailer
Service name..... ........STSLIB.004
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type.... ......... ...LO
Next File Name.......... .STSLIB.005
Physical EOF
File Header
Service name........... ..STSLIB.005
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type............... .LO
Previous File Name...... .STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
5
header data for each bit run in separate files.
7
.5000
.
#
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
ROP 11075.5
$
STOP DEPTH
11095.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
$
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type..... .............0
Data Specification Block Type.....O
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...O
.
05-JAN-05
Insite
66.37
Memory
11095.0
11075.0
11095.0
82.1
82.1
TOOL NUMBER
6.750
11065.0
Flo-Pro
10.10
55.0
8.0
300
8.2
.080
.048
.080
.120
68.0
117.0
68.0
68.0
Name Service Order
DEPT
ROP MWD070
Units Size Nsam Rep Code Offset Channel
FT 4 1 68 0 1
FT/H 4 1 68 4 2
Name Service Unit
DEPT FT
ROP MWD070 FT/H
.
Min
11075.5
20.04
Max
11095
198.61
Mean
11085.3
118.669
First Reading For Entire File......... .11075.5
Last Reading For Entire File.......... .11095
File Trailer
Service name............ .STSLIB.005
Service Sub Level Name...
Version Number.... ...... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record..65535
File Type.............. ..LO
Next File Name......... ..STSLIB.006
Physical EOF
File Header
Service name. ....... .... .STSLIB.006
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type....... ..... ... .LO
Previous File Name...... .STSLIB.005
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
NCNT
FCNT
NPHI
FET
RPX
RPM
RPD
RPS
GR
PEF
RHOB
DRHO
ROP
$
6
Nsam
40
40
.
First
Reading
11075.5
11075.5
Last
Reading
11095
11095
header data for each bit run in separate files.
8
.5000
START DEPTH
11002.5
11002.5
11003.5
11030.0
11030.0
11030.0
11030.0
11030.0
11038.0
11049.5
11049.5
11049.5
11095.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
STOP DEPTH
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
11140.0
10-JAN-05
Insite
66.37
Memory
11140.0
11095.0
11140.0
.
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
SLD
CTN
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
Electromag Resis. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type.. ................0
Data Specification Block Type.....O
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...O
.
85.7
90.3
TOOL NUMBER
64004
112439
113413
59475
6.750
11065.0
Flo-pro
10.10
62.0
9.0
126000
3.0
.060
.037
.070
.080
68.0
114.8
68.0
68.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD080 CNTS 4 1 68 4 2
NCNT MWD080 CNTS 4 1 68 8 3
RHOB MWD080 G/CM 4 1 68 12 4
DRHO MWD080 G/CM 4 1 68 16 5
RPD MWD080 OHMM 4 1 68 20 6
RPM MWD080 OHMM 4 1 68 24 7
RPS MWD080 OHMM 4 1 68 28 8
RPX MWD080 OHMM 4 1 68 32 9
FET MWD080 HOUR 4 1 68 36 10
GR MWD080 API 4 1 68 40 11
PEF MWD080 BARN 4 1 68 44 12
ROP MWD080 FT/H 4 1 68 48 13
NPHI MWD080 PU-S 4 1 68 52 14
. .
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 11002.5 11140 11071.3 276 11002.5 11140
FCNT MWD080 CNTS 116.64 524.3 241.186 276 11002.5 11140
NCNT MWD080 CNTS 12841.8 27389.1 17684.3 276 11002.5 11140
RHOB MWD080 G/CM 1.908 4.97 2.49205 182 11049.5 11140
DRHO MWD080 G/CM -0.598 2.08 0.196725 182 11049.5 11140
RPD MWD080 OHMM 5.37 2000 690.208 221 11030 11140
RPM MWD080 OHMM 4.61 2000 493.823 221 11030 11140
RPS MWD080 OHMM 0.07 1814.88 30.3654 221 11030 11140
RPX MWD080 OHMM 0.07 1112.37 10.3457 221 11030 11140
FET MWD080 HOUR 1. 23 135.54 67.8263 221 11030 11140
GR MWD080 API 45.47 103.34 79.1789 205 11038 11140
PEF MWD080 BARN 2.54 13 .47 5.31242 182 11049.5 11140
ROP MWD080 FT/H 0.69 156.32 69.0521 90 11095.5 11140
NPHI MWD080 PU-S 20.34 52.44 33.2738 274 11003.5 11140
First Reading For Entire File......... .11002.5
Last Reading For Entire File.......... .11140
File Trailer
Service name. ..... ..... ..STSLIB.006
Service Sub Level Name...
Version Number......... ..1.0.0
Date of Generation..... ..05/02/16
Maximum Physical Record. .65535
File Type................ LO
Next File Name.... .......STSLIB.007
Physical EOF
File Header
Service name............ .STSLIB.007
Service Sub Level Name. . .
Version Number.......... .1.0.0
Date of Generation..... ..05/02/16
Maximum Physical Record. .65535
File Type.............. ..LO
Previous File Name...... .STSLIB.006
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
FET
ROP
GR
RPD
RPX
RPM
RPS
$
7
header data for each bit run in separate files.
11
.5000
START DEPTH
11140.5
11140.5
11140.5
11140.5
11140.5
11140.5
11140.5
STOP DEPTH
11161.5
11211.0
11154.0
11161.5
11161.5
11161.5
11161.5
#
LOG HEADER DATA
DATE LOGGED:
13 -JAN-05
.
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
Electromag Resis. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type. .................0
Data Specification Block Type.....O
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
.
Insite
66.37
Memory
11211.0
11140.0
11211.0
85.7
85.7
TOOL NUMBER
64004
59475
6.750
11065.0
Flo-Pro
10.10
55.0
9.0
120000
2.8
.080
.046
.070
.090
74.0
135.1
74.0
74.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD110 OHMM 4 1 68 4 2
RPM MWD 11 0 OHMM 4 1 68 8 3
RPS MWD 11 0 OHMM 4 1 68 12 4
RPX MWD110 OHMM 4 1 68 16 5
FET MWD110 HOUR 4 1 68 20 6
GR MWD110 API 4 1 68 24 7
ROP MWD110 FT/H 4 1 68 28 8
. .
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 11140.5 11211 11175.8 142 11140.5 11211
RPD MWD 11 0 OHMM 5.83 19.53 12.44 43 11140.5 11161.5
RPM MWDII0 OHMM 5.12 22.93 11.8591 43 11140.5 11161. 5
RPS MWD 11 0 OHMM 3.47 17.83 8.76465 43 11140.5 11161. 5
RPX MWD 11 0 OHMM 1.64 7.71 4.25279 43 11140.5 11161. 5
FET MWD 11 0 HOUR 5.29 120.02 15.4065 43 11140.5 11161. 5
GR MWDII0 API 79.15 96.12 84.9861 28 11140.5 11154
ROP MWD 11 0 FT/H 1. 65 76.99 36.5125 142 11140.5 11211
First Reading For Entire File...... ....11140.5
Last Reading For Entire File....... ....11211
File Trailer
Service name. ....... .... .STSLIB.007
Service Sub Level Name...
Version Number... ....... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type.... ........... .LO
Next File Name.. ........ .STSLIB.008
Physical EOF
File Header
Service name............ .STSLIB.008
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type................ LO
Previous File Name.. .... .STSLIB.007
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
FCNT
NPHI
NCNT
DRHO
PEF
RHOB
GR
FET
RPM
RPS
RPD
RPX
ROP
$
8
header data for each bit run in separate files.
12
.5000
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
START DEPTH
11120.0
11120.0
11120.0
11140.5
11140.5
11140.5
11154.5
11162.0
11162.0
11162.0
11162.0
11162.0
11211. 5
STOP DEPTH
12021. 0
12021. 0
12021. 0
12035.5
12036.0
12035.5
12057.0
12064.0
12064.0
12064.0
12064.0
12064.0
12113.0
15-JAN-05
.
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
SLD
CTN
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
Electromag Resis. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type...... ............0
Data Specification Block Type.....O
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...O
Insite
66.37
Memory
12113.0
11211.0
12113.0
.
83.8
91. 9
TOOL NUMBER
64004
112439
113413
59475
6.750
11065.0
Flo-pro
10.10
53.0
9.0
120000
1.6
.090
.056
.080
.100
74.0
122.0
74.0
74.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD12 0 CNTS 4 1 68 4 2
NCNT MWD120 CNTS 4 1 68 8 3
RHOB MWD120 G/CM 4 1 68 12 4
DRHO MWD120 G/CM 4 1 68 16 5
RPD MWD120 OHMM 4 1 68 20 6
RPM MWD12 0 OHMM 4 1 68 24 7
RPS MWD120 OHMM 4 1 68 28 8
. .
RPX MWD120 OHMM 4 1 68 32 9
FET MWD120 HOUR 4 1 68 36 10
GR MWD120 API 4 1 68 40 11
PEF MWD120 BARN 4 1 68 44 12
ROP MWD12 0 FT/H 4 1 68 48 13
NPHI MWD12 0 PU-S 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 11120 12113 11616.5 1987 11120 12113
FCNT MWD120 CNTS 204.27 756.35 432.506 1803 11120 12021
NCNT MWD120 CNTS 15624.5 30211.1 22842.6 1803 11120 12021
RHOB MWD120 G/CM 1.3 3.067 2.38855 1791 11140.5 12035.5
DRHO MWD120 G/CM -0.362 0.695 0.122151 1791 11140.5 12035.5
RPD MWD12 0 OHMM 4.45 19.15 7.41982 1805 11162 12064
RPM MWD120 OHMM 4.07 21. 01 7.42851 1805 11162 12064
RPS MWD120 OHMM 2.7 21.67 6.91924 1805 11162 12064
RPX MWD12 0 OHMM 1. 42 12.84 5.13514 1805 11162 12064
FET MWD12 0 HOUR 0.54 19.43 2.45904 1805 11162 12064
GR MWD12 0 API 66.65 122.95 96.2772 1806 11154.5 12057
PEF MWD120 BARN 1. 26 6.85 2.48179 1792 11140.5 12036
ROP MWD120 FT/H 0.91 199.84 67.5399 1804 11211.5 12113
NPHI MWD120 PU-S 15.77 36.43 23.4486 1803 11120 12021
First Reading For Entire File...... ....11120
Last Reading For Entire File....... ... .12113
File Trailer
Service name............ .STSLIB.008
Service Sub Level Name...
Version Number... ....... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record..65535
File Type.... ........... .LO
Next File Name.......... .STSLIB.009
Physical EOF
File Header
Service name........... ..STSLIB.009
Service Sub Level Name...
Version Number......... ..1.0.0
Date of Generation..... ..05/02/16
Maximum Physical Record. .65535
File Type............... .LO
Previous File Name...... .STSLIB.008
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
NCNT
NPHI
FCNT
RHOB
DRHO
9
header data for each bit run in separate files.
13
.5000
START DEPTH
12021. 5
12021.5
12021.5
12036.0
12036.0
STOP DEPTH
13723.5
13723.5
13723.5
13738.0
13738.0
. .
PEF 12036.5 13738.5
GR 12057.5 13759.5
RPD 12064.5 13767.0
RPM 12064.5 13767.0
FET 12064.5 13766.5
RPS 12064.5 13767.0
RPX 12064.5 13767.0
ROP 12113.5 13816.0
$
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
SLD
CTN
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
Electromag Resis. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type.. ................0
Data Specification Block Type.....O
Logging Direction................ . Down
Optical log depth units. ......... .Feet
Data Reference Point.... ......... . Undefined
Frame Spacing.......... .......... .60 .1IN
Max frames per record... ......... . Undefined
20-JAN-05
Insite
66.37
Memory
13816.0
12113.0
13816.0
86.7
92.2
TOOL NUMBER
64004
112439
113413
59475
6.750
11065.0
Flo-pro
9.60
53.0
8.0
68000
3.4
.110
.070
.090
.120
75.0
122.0
75.0
75.0
. .
Absent value........ ............ ..-999
Depth Units. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
FCNT MWD13 0 CNTS 4 1 68 4 2
NCNT MWD13 0 CNTS 4 1 68 8 3
RHOB MWD 13 0 G/CM 4 1 68 12 4
DRHO MWD 13 0 G/CM 4 1 68 16 5
RPD MWD 13 0 OHMM 4 1 68 20 6
RPM MWD 13 0 OHMM 4 1 68 24 7
RPS MWD 13 0 OHMM 4 1 68 28 8
RPX MWD130 OHMM 4 1 68 32 9
FET MWD 13 0 HOUR 4 1 68 36 10
GR MWD 13 0 API 4 1 68 40 11
PEF MWD 13 0 BARN 4 1 68 44 12
ROP MWD130 FT/H 4 1 68 48 13
NPHI MWD 13 0 PU-S 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 12021. 5 13816 12918.8 3590 12021. 5 13816
FCNT MWD 13 0 CNTS 237.59 706.49 433.8 3405 12021. 5 13723.5
NCNT MWD 13 0 CNTS 16396.8 30894.1 22796.6 3405 12021. 5 13723.5
RHOB MWD 13 0 G/CM 2.002 3.889 2.52423 3405 12036 13738
DRHO MWD13 0 G/CM -0.179 1. 23 0.105414 3405 12036 13738
RPD MWD 13 0 OHMM 1. 33 1031. 68 14.7874 3406 12064.5 13767
RPM MWD130 OHMM 1.14 1027.47 13.84 3406 12064.5 13767
RPS MWD 13 0 OHMM 1. 08 455.93 11.8268 3406 12064.5 13767
RPX MWD 13 0 OHMM 0.86 18.31 7.33887 3406 12064.5 13767
FET MWD 13 0 HOUR 0.58 52.55 3.91058 3405 12064.5 13766.5
GR MWD 13 0 API 60.44 174.18 85.6922 3405 12057.5 13759.5
PEF MWD 13 0 BARN 1.51 8.2 2.91574 3405 12036.5 13738.5
ROP MWD 13 0 FT/H 0.06 235.97 52.9016 3406 12113.5 13816
NPHI MWD 13 0 PU-S 15.38 33.81 23.1583 3405 12021.5 13723.5
First Reading For Entire File...... ... .12021.5
Last Reading For Entire File...... .... .13816
File Trailer
Service name........... ..STSLIB.009
Service Sub Level Name...
Version Number......... ..1.0.0
Date of Generation.... ...05/02/16
Maximum Physical Record..65535
File Type.............. ..LO
Next File Name......... ..STSLIB.010
Physical EOF
File Header
Service name........... ..STSLIB.010
Service Sub Level Name...
Version Number......... ..1.0.0
Date of Generation..... ..05/02/16
Maximum Physical Record..65535
File Type.............. ..LO
Previous File Name..... ..STSLIB.009
Comment Record
FILE HEADER
.
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
FET
RPD
RPX
RPM
RPS
ROP
$
10
.
header data for each bit run in separate files.
14
.5000
START DEPTH
13760.0
13767.0
13767.5
13767.5
13767.5
13767.5
13816.5
STOP DEPTH
14615.5
14622.5
14622.5
14622.5
14622.5
14622.5
14672.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
Electromag Resis. 4
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
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
Data Record Type...... ............0
Data Specification Block Type.....O
23-JAN-05
Insite
66.37
Memory
14672.0
13816.0
14672.0
85.7
93.3
TOOL NUMBER
64004
59475
6.750
11065.0
Pro-Flo
9.60
54.0
8.5
84000
4.4
.120
.070
.100
.130
73.0
129.2
73.0
73.0
.
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...O
.
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
RPD MWD140 OHMM 4 1 68 4 2
RPM MWD140 OHMM 4 1 68 8 3
RPS MWD 14 0 OHMM 4 1 68 12 4
RPX MWD140 OHMM 4 1 68 16 5
FET MWD140 HOUR 4 1 68 20 6
GR MWD140 API 4 1 68 24 7
ROP MWD140 FT/H 4 1 68 28 8
First Last
Name Service Unit Min Max Mean Nsam Reading Reading
DEPT FT 13760 14672 14216 1825 13760 14672
RPD MWD14 0 OHMM 1.8 13.89 5.9789 1711 13767.5 14622.5
RPM MWD140 OHMM 1.49 14.01 5.87932 1711 13767.5 14622.5
RPS MWD 14 0 OHMM 1. 34 12.15 5.17508 1711 13767.5 14622.5
RPX MWD140 OHMM 1. 02 8.45 3.92526 1711 13767.5 14622.5
FET MWD14 0 HOUR 0.26 29.6 4.0686 1712 13767 14622.5
GR MWD14 0 API 63.22 229.1 143.849 1712 13760 14615.5
ROP MWD140 FT/H 0.3 599.62 90.6041 1712 13816.5 14672
First Reading For Entire File.. ... .... .13760
Last Reading For Entire File....... ....14672
File Trailer
Service name.......... ...STSLIB.010
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation...... .05/02/16
Maximum Physical Record. .65535
File Type.... ........... .LO
Next File Name........ ...STSLIB.011
Physical EOF
Tape Trailer
Service name......... ... .LISTPE
Date. . . . . . . . . . . . . . . . . . . . .05/02/16
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. . . . . . . . . . . . . . . . . . . . .05/02/16
Origin. . . . . . . . . . . . . . . . . . . STS
Reel Name............... . UNKNOWN
Continuation Number..... .01
Next Reel Name.......... . UNKNOWN
Comments................ .STS LIS Writing Library. Scientific Technical Services
..
'.
.
Physical EOF
Physical EOF
End Of LIS File
