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Alaska Oil and Gas Conservation Commission
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MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: 07/18/2025
P. I. Supervisor
FROM: Kam StJohn SUBJECT: Site Clearance
Petroleum Inspector KRU 2P-427
Conoco Phillips Alaska LLC.
PTD 2020180; Sundry 324-654
07/15/2025: Went out to KRU 2P Pad for site clearance inspections and met with Roger
Mouser (CPAI). We went over the surface area of KRU 2P-427 which has been P&A and
buried. The area was clean of debris and had a settling mound for soil over the well
location. We verified the well-site with the pad location map and well conductor “as built”.
Marker plate and top of well are at 5 feet 9 inches below original tundra. Overall, the site
clearance was in good condition. The well site still had barriers around due to other work
going on in the area. Only follow up would be a full pad site clearance once CPAI has
completed all pad P&A work.
Attachments: Photo
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.09.16 13:59:10 -08'00'
2025-0715_Location_Clear_KRU_2P-427_ksj
Page 2 of 2
Surface Abandonment Inspection – KRU 2P-427 (PTD 2020180)
Photo by AOGCC Inspector K. StJohn
7/15/2025
2025-0226_Surface_Abandon_KRU_2P-427_bb
Page 1 of 2
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE: February 27, 2025
P. I. Supervisor
FROM: Brian Bixby SUBJECT: Surface Abandonment
Petroleum Inspector KRU 2P-427
ConocoPhillips Alaska Inc.
PTD 2020180; Sundry 324-654
02/26/2025: I arrived at KRU 2P and met with Brennen Green (CPAI) and looked at the
cut off which was more than 4 feet below tundra level. There is good hard cement in all
strings and the marker plate was installed.
Attachments: Photos (2)
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.03.26 12:34:27 -08'00'
2025-0226_Surface_Abandon_KRU_2P-427_bb Page 2 of 2 Surface Abandonment – KRU 2P-427 (PTD 2020180) Photos by AOGCC Inspector B. Bixby 2/26/2025
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: Nordic 3 Rig Elevation: Total Depth: 10402 ft MD Lease No.: ADL 0373112
Operator Rep: Suspend: P&A: X
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7 5/8" O.D. Shoe@ 3030 Feet Csg Cut@ Feet
Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet
Production: 5.5" x 3.5" O.D. Shoe@ 10139 Feet Csg Cut@ Feet
Liner: O.D. Shoe@ Feet Csg Cut@ Feet
Tubing: 3 1/2" O.D. Tail@ 9534 Feet Tbg Cut@ 3300 Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Open Hole Bridge plug 3090 ft 2683 ft 9.8 ppg Drillpipe tag
Initial 15 min 30 min 45 min Result
Tubing 1680 1620 1580 1550
IA
OA
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Chase Erdman
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
Open hole plug set across surface casing shoe to isolate the C80 formation. 5 1/2-inch Production casing cut; bridge plug set in
cut production casing at 3090 ft MD. Cement plug was tagged with drill pipe - top of cement inside 7 5/8-inch surface casing;
10,000 lbs down weight.
February 1, 2025
Bob Noble
Well Bore Plug & Abandonment
KRU 2P-427
ConocoPhillips Alaska, LLC
PTD 2020180; Sundry 324-654
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2025-0201_Plug_Verification_KRU_2P-427_bn
9
9
9 9 9 9
9
9
9
9
9
9
9 9
99 9 9
99999
9
James B. Regg Digitally signed by James B. Regg
Date: 2025.02.07 16:12:19 -09'00'
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other:
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9.Property Designation (Lease Number):10.Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
10402'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. W ell Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. W ell Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
3-1/2"
Packer: Baker GBH-22 Seal Assy
SSSV: Camco DS Nipple NoGo Profile
Perforation Depth MD (ft):
L-80
2999'
9645-9735', 10008-10018'
(below cement plug)
4400'
5510-5554', 5680-5685'
(below cement plug)
3-1/2" x 5-1/2"
Perforation Depth TVD (ft):
120'
3030'
5739'10139'
16"
7-5/8"
90'
9534'
MD
120'
2380'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool-
Abandoned
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112, ADL0389058
202-018
P.O. Box 100360, Anchorage, AK 99510 50-103-20408-00-00
Kuparuk River Field
Meltwater Oil Pool- Suspended
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
9532' MD and 5456' TVD
532' MD and 532' TVD
Shane Germann
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
shane.germann@conocophillips.com
(907) 263-4597
Senior CTD/RWO Engineer
KRU 2P-427
5853' 7690' 4585' 7690',9569', 9624'
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
12/24/2024
MPSP (psi):
831
By Grace Christianson at 8:43 am, Nov 18, 2024
Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane Germann, E=
shane.germann@conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.11.15 15:59:35-09'00'
Foxit PDF Editor Version: 13.0.0
324-654
VTL 12/23/2024
June 30, 2025
SFD 12/2/2024
X
DSR-11/21/24
X
X
X
10-407
BOP test to 2500 psig
Annular preventer test to 2500 psig
See attached "Conditions of Approval"
MEUIRUMOF
Gregory C. Wilson Digitally signed by Gregory C. Wilson
Date: 2024.12.23 13:55:00 -09'00'12/23/24
RBDMS JSB 122424
KRU 2P-4Ϯϳ
Abandonment Conditions of ƉƉƌŽǀĂů͗
ϭ͘ ǀĂriance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100'
below the base of the hydrocarbon-bearing strata.
ʹǤ A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as
the recovery of 50' of production casing below the surface casing shoe and a cement plug
placed across this open hole section and 150' into the surface casing. The plug must pass a
State Witnessed pressure test and tag according to 20 AAC 25.112(g).
͵Ǥ A variance to Order 196 is granted that will eliminate the requirement of logging the cement
placed across the hydrocarbon-bearing strata.
ͶǤ A failed pressure test of the surface casing shoe plug requires the submission of a new
sundry (10-403) to cover the rigless abandonment scope if planned. Completion of
workover operations under the original sundry will be complete and a 10-407 Well
Completion or Recompletion Report and Log must be filed with the Commission within 30
days following the completion of workover operations.
ͷǤ If surface abandonment operations are not initiated within 0 days after the successful
placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407
Well Completion or Recompletion Report and Log must be filed with the Commission
within30 days after the completion of workover operations to date.
Ǥ Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20
AAC 25.120.
Ǥ AOGCC witness is required after the wellhead cutoff and prior to a top job.
Variances granted provide for at least equally effective plugging of the well and prevention of fluid
movement into sources of hydrocarbons or freshwater.
KRU 2P-4Ϯϳ
Abandonment Conditions of ƉƉƌŽǀĂů͗
ϭ͘ ǀĂriance is granted from 20 AAC 25.112(a)(1)(A) which requires a cement plug from 100'
below the base of the hydrocarbon-bearing strata.
ʹǤ A variance is granted under 20 AAC 25.112(i) to allow the alternate plug placement described as
the recovery of 50' of production casing below the surface casing shoe and a cement plug
placed across this open hole section and 150' into the surface casing. The plug must pass a
State Witnessed pressure test and tag according to 20 AAC 25.112(g).
͵Ǥ A variance to Order 196 is granted that will eliminate the requirement of logging the cement
placed across the hydrocarbon-bearing strata.
ͶǤ A failed pressure test of the surface casing shoe plug requires the submission of a new
sundry (10-403) to cover the rigless abandonment scope if planned. Completion of
workover operations under the original sundry will be complete and a 10-407 Well
Completion or Recompletion Report and Log must be filed with the Commission within 30
days following the completion of workover operations.
ͷǤ If surface abandonment operations are not initiated within 0 days after the successful
placement of the surface casing shoe plug (State witnessed pressure test and tag), a 10-407
Well Completion or Recompletion Report and Log must be filed with the Commission
within30 days after the completion of workover operations to date.
Ǥ Plugging of the surface of a well must meet the requirements of 20 AAC 25.112(d) and 20
AAC 25.120.
Ǥ AOGCC witness is required after the wellhead cutoff and prior to a top job.
Variances granted provide for at least equally effective plugging of the well and prevention of fluid
movement into sources of hydrocarbons or freshwater.
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Digitally signed by Shane Germann
DN: O=ConocoPhillips, CN=Shane
Germann, E=shane.germann@
conocophillips.com
Reason: I am the author of this document
Location:
Date: 2024.11.15 16:00:01-09'00'
Foxit PDF Editor Version: 13.0.0
2P-427 Plug and Abandonment
Background & Objective
2P-427 was an injector that has been shut in since mid 2020. This well will be P&A’d as part of the 2P
pad abandonment. 2P pad does not have any facilities or surface line hookups, and the pad is slated
to be used as storage for the Willow development project in 2026. This well was suspended via
reservoir cement plug and intermediate cement plug. The objective of this procedure is to pump the
surface casing shoe cement plug and final abandonment cement plug with Nordic 3 and ultimately
execute final abandonment.
Well Data
Meltwater Formation:
x Reservoir pressure 8/2/2023 = 3001 psi @ 5400’ TVD
x MASP = 2464 psi
C-80 Formation:
x OAP = 252 psi (8/19/23) (fluid packed with diesel)
x MASP = 831 psi
Intermediate plug TOC = 7690’ MD
Tubing cut depth = 3300’ MD
Well Name
Previous plug tag
depth (RKB)PT Result PT/Tag Date
Tubing
Pressure
IA
Pressure
OA
Pressure
Date of
Pressures
2P-427 7690' Pass 9/24/2024 0 psi 0 psi 300 psi 10/19/2024
Production Casing Cement:
50 bbls of 15.8# Class G Cement
Calculated TOC @ 7,481' KB
2P-427 Well Suspension Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
4Production Casing:
5.5" x 3.5" @ 9,541' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 10,139.5’ KB
T-3 Peforations:
@ 9,645' – 10,018' KB (373')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 3,029.6' KB (2380' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 9,534.4' KB
6
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C80 @ 3150' KBC80 @ 3150' KB
Plug #1 – reservoir
TOC ± 9570'
Plug #2 – Intermediate
TOC ±7690' RKB
BOC @ ±9450' RKB
Surface Casing Plugs – Rig
Date: 11-15-2024
Prepared by: Shane Germann
Estimated Start Date: 12-24-2024
MIRU
1. MIRU on 2P-427.
2. Record shut-in pressures on the T & IA. If there is pressure, bleed oƯ IA and/or tubing
pressure and complete 30-minute NFT. Verify well is dead before proceeding.
3. ND Tree and NU BOPE. Test rams and annular to 250/2,500 PSI.
a. Will not set BPV due to two tested cement plugs below providing two barriers to
formation.
b. BOPE ConƱguration: Annular / Variable Bore Rams / Blind Rams / Pipe Rams
4. Circulate tubing and IA to brine.
Retrieve Tubing
5. MU landing joint and BOLDS.
6. Pull tubing from pre-rig cut to surface and LD.
Execute First Surface Casing Abandonment Plug
1. Set bridge plug in production casing ~100’ below surface casing shoe
2. Cut production casing 50’ below surface casing shoe
3. Circulate OA to brine and complete 30-minute NFT.
a. Punch holes in production casing at the surface casing shoe if unable to achieve
circulation from production casing cut.
4. MU landing joint for production casing hanger and conƱrm casing is free from cut.
a. Contingency: If unable to pull production casing from original cut depth
i. Perform second cut inside surface casing shoe
ii. Pull casing down to upper cut and laydown
iii. PU DP and Ʊshing assembly
iv. TIH and engage cut stub of prod casing. Fish stub free.
v. Retrieve to surface. LD DP
5. Pump cement plug through the production casing cut. Utilize 19 BBL of cement, plus
excess, to target a Ʊnal TOC ±150’ TVD inside the surface casing shoe. Slightly under
displace cement and pull 5-1/2” casing slowly to above Ʊnal TOC - allowing cement to Ʊll
the space vacated by the casing displacement. Ensure base of 5-1/2” casing is 150’ – 200’
MD above target TOC and space out with a casing collar at the Ʋoor. Circulate the base of
the prod casing clear of any residual cement. See table below for cement volume
calculations.
a. Contingency: if unable to pull prod casing from original cut depth
i. TIH with tubing to above the casing shoe
ii. Pump cement plug across the shoe through the tubing. PU and circulate the
base of the tubing clear
b. A Variance is requested to 20 AAC 25.112 requiring cement 100’ below hydrocarbon
bearing zones. It is our intention to recover 50’ of production casing from the open
hole section.
c. A Variance is requested to Order 196 requiring the cement to be logged. It is not our
intention, nor recommendation for the integrity of the abandonment, to drill out the
cement plug once pumped.
6. WOC
7. Tag cement and PT to 1,500 PSI with state witness
a. Pressure up to FIT equivalent and hold for 10 min to ensure no leak oƯ prior to
increasing pressure to full 1,500 PSI for 30-min state witness
b. If PT fails, the well will be suspended with KWF and a kill string in preparation for o Ư-
rig remediation.
Production Casing Cement:
50 bbls of 15.8# Class G Cement
Calculated TOC @ 7,481' KB
2P-427 Well Surface Shoe Cement Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
4Production Casing:
5.5" x 3.5" @ 9,541' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 10,139.5’ KB
T-3 Peforations:
@ 9,645' – 10,018' KB (373')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 3,029.6' KB (2380' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 9,534.4' KB
6
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C80 @ 3150' KBC80 @ 3150' KB
Plug #1 – reservoir
TOC ± 9570'
Plug #2 – Intermediate
TOC ±7690' RKB
BOC @ ±9450' RKB
Plug #3 – Surface Shoe
TOC 2709' RKB (2230' TVD)
BOC @ ±3130' RKB
Base of 5.5” Casing
350'-400' MD Inside
Surface Shoe
Execute Final Abandonment Plug
8. Land workstring in casing hanger proƱle.
9. Circulate cement surface to surface until full cement returns observed on surface. See
table below for cement volumes.
RDMO
10. ND BOPE. NU dry hole tree.
a. Note: this step may be performed prior to pumping Ʊnal surface to surface
abandonment plug.
11. RDMO.
Cement Plug TOC BOC Section ID BBL/FT Volume Notes
Surface Shoe
3080 3130 Open Hole 6.75 0.03867 1.9 Displacement of Prod Casing
Stub Included in BBL/FT calc
3030 3080 Open Hole 6.75 0.04426 2.2
2709 3030 Surface Casing 6.87 0.04585 14.7
18.9 Total Volume of Plug
Surface Casing 23 2709 Surface Casing 6.87 0.04026 108.2 Displacement of Prod Casing
Included in BBL/FT calculation
Execute Final Abandonment
Surface Excavation
12. DHD to perform drawdown test on tubing, IA, and OA
13. Remove well house.
14. Bleed oƯ T/I/O to ensure all pressure is bled oƯ the system.
15. Remove tree in preparation for excavation and casing cut.
16. If shallow thaw conditions are found, have shoring box installed during the excavation
activity to prevent loose ground from falling into the excavation.
17. Cut oƯ wellhead and all casing strings at 4 feet below original ground level.
18. Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and
photo document required.
19. Send the casing head with stub to materials shop. Photo document.
20. Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information
bead welded into the top. Photo document. AOGCC witness required.
a. ConocoPhillips
b. KRU 2P-427
c. PTD #: 202-018
d. API #: 50-103-20408-00-00
21. Remove cellar. Back Ʊll cellar with gravel/Ʊll as needed. Back Ʊll remaining hole to ground
level.
22. Obtain site clearance approval from AOGCC. RDMO.
23. Report the Ʊnal P&A has been completed to the AOGCC. Photo document Ʊnal location
condition after work is completed
Plug #4 – Surface
TOC 25' RKB
BOC @ ±2709' RKB
Production Casing Cement:
50 bbls of 15.8# Class G Cement
Calculated TOC @ 7,481' KB
2P-427 Well Final P&A Schematic
Conductor:
16" Conductor 120' KB
1
2
3
5
4Production Casing:
5.5" x 3.5" @ 9,541' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 10,139.5’ KB
T-3 Peforations:
@ 9,645' – 10,018' KB (373')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 3,029.6' KB (2380' TVD)
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 9,534.4' KB
6
/ƚĞŵĞƉƚŚͲƚŽƉƐ
;<Ϳ
ϭ &D,ĂŶŐĞƌ Ϯϱ͘ϳΖ
Ϯ ĂƐƚ/ƌŽŶƌŝĚŐĞWůƵŐ ϯϭϯϬΖ
ϯ ĂŬĞƌDh^ůŝĚŝŶŐ^ůĞĞǀĞ ϵ͕ϰϳϭ͘ϭΖ
ϰ ĂŵĐŽEŝƉƉůĞ ϵ͕ϰϴϳ͘ϭΖ
ϱ ĂŬĞƌ>ŽĐĂƚŽƌ ϵ͕ϱϯϭ͘ϳΖ
ϲ ĂŬĞƌ',ͲϮϮ^ĞĂůƐƐĞŵďůLJ ϵ͕ϱϯϮ͘ϰΖ
C80 @ 3150' KBC80 @ 3150' KB
Plug #1 – reservoir
TOC ± 9570'
Plug #2 – Intermediate
TOC ±7690' RKB
BOC @ ±9450' RKB
Plug #3 – Surface Shoe
TOC 2709' RKB (2230' TVD)
BOC @ ±3130' RKB
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 10,002.0 2P-427 7/7/2024 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: Cut Tbg 2P-427 10/19/2024 bworthi1
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered for water injection only with known TxIA on gas 11/11/2019 jbyrne
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 16 15.05 30.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.6 3,029.6 2,380.0 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 9541'
5 1/2 4.95 27.9 10,139.5 5,739.0 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.7
Set Depth …
9,534.4
Set Depth …
5,456.8
String Max No…
3 1/2
Tubing Description
TUBING
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)
25.7 25.7 0.00 HANGER 8.000 FMC HANGER 3.500
532.4 532.1 5.21 NIPPLE 4.550 CAMCO DS NIPPLE NO GO
PROFILE
CAMCO DS 2.875
2,629.2 2,192.7 62.49 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
6,046.6 3,801.2 61.24 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
8,156.4 4,807.4 61.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,421.6 5,403.9 62.30 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,471.1 5,426.9 62.21 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER 2.813
9,487.1 5,434.4 62.01 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
9,531.7 5,455.4 61.48 LOCATOR 4.500 BAKER LOCATOR BAKER GBH-22 3.000
9,532.4 5,455.8 61.47 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSY 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
2,004.0 1,832.4 43.13 TUBING
PUNCH
TBG PUNCH FROM 2004' TO
2007' RKB W/ 4 SPF
9/22/2024 2.992
3,300.0 2,503.2 62.68 CUT JET CUT @ 3300' RKB 10/19/2024 2.992
9,450.0 5,417.1 62.46 TUBING
PUNCH
TUBING PUNCH (9450' -
9453')
9/9/2024 2.992
9,453.0 5,418.5 62.43 TUBING
PUNCH
TUBING PUNCH (9453' -
9456')
9/18/2024 2.992
9,624.3 5,500.1 60.89 CIBP 2.630" CIBP, OAL = 1.37',
MOE = 9625'
TTS CIBP CPAI
2105-
263-
AC-
001S
R
7/13/2024 0.000
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)
2,629.2 2,192.7 62.49 1 GAS LIFT DMY INT 1 0.0 5/15/2002 Fishin
g
Neck
stripp
ed
0.000
6,046.6 3,801.2 61.24 2 GAS LIFT DMY INT 1 0.0 5/15/2002 0.000
8,156.4 4,807.4 61.38 3 GAS LIFT DMY INT 1 0.0 2/26/2005 0.000
9,421.6 5,403.9 62.30 4 GAS LIFT DMY INT 1 0.0 10/17/2002 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,645.0 9,735.0 5,510.2 5,554.0 T-3, 2P-427 4/23/2007 6.0 APERF 2.5" HSD GUNS w/2506 PJ
Chgs
10,008.0 10,018.0 5,680.1 5,684.7 T-3, 2P-427 10/19/2002 6.0 IPERF 2.5" HSD, JH RDX 2506
Chgs, 60 deg phase, random
orient
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
10,008.0 10,018.0 1 FRAC 10/23/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
9,569.0 9,624.3 5,473.4 5,500.1 Cement Plug Dump Bail cement on CIBP 7/14/2024
7,690.0 9,456.0 4,585.4 5,419.8 Cement Plug PUMPED 31 BBLS OF 15.8 PPG CEMENT &
DISPLACED CEMENT w/ 69 BBLS OF 10.7 PPG
KWF. PLACING TOC IN TBG & IA @ ~7950' MD.
9/20/2024
2P-427, 11/15/2024 3:11:08 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
9541'; 27.9-10,139.5
FLOAT SHOE; 10,138.9-
10,139.5
FLOAT COLLAR; 10,076.1-
10,076.8
FRAC; 10,008.0
IPERF; 10,008.0-10,018.0
APERF; 9,645.0-9,735.0
CIBP; 9,624.3
Cement Plug; 9,569.0 ftKB
SEAL ASSY; 9,532.4
LOCATOR; 9,531.7
CSR; 9,521.6-9,540.7
NIPPLE; 9,487.1
SLEEVE-C; 9,471.1
TUBING PUNCH; 9,453.0
TUBING PUNCH; 9,450.0
GAS LIFT; 9,421.6
GAS LIFT; 8,156.4
Cement Plug; 7,690.0 ftKB
GAS LIFT; 6,046.6
CUT; 3,300.0
SURFACE; 30.6-3,029.6
FLOAT SHOE; 3,028.1-3,029.6
FLOAT COLLAR; 2,939.8-
2,941.1
GAS LIFT; 2,629.2
TUBING PUNCH; 2,004.0
PORT COLLAR; 990.8-993.2
NIPPLE; 532.4
CONDUCTOR; 30.0-120.0
HANGER; 30.6-33.4
HANGER; 27.9-31.0
HANGER; 25.7
Casing 1; 0.0
KUP INJ
KB-Grd (ft)
37.10
RR Date
5/19/2002
Other Elev…
2P-427
...
TD
Act Btm (ftKB)
10,402.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040800
Wellbore Status
INJ
Max Angle & MD
Incl (°)
64.34
MD (ftKB)
10,300.49
WELLNAME WELLBORE2P-427
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: WRDP
ϮWͲϰϮϳϭϭĂůĐƵůĂƚĞĚWdKΛϳϰϴϭ͛Z<^^ŚŽĞΛϯϬϯϬ͛Z</WΛϯϭϯϬ͛Z<^^ŚŽĞĐĞŵĞŶƚƉůƵŐdKΛϮϳϬϵ͛Z<WƵƚΛϯϬϴϬ͛Z<ϴϬdŽƉΛϯϭϱϬ͛Z<ϴϬĂƐĞΛϱϰϬϬ͛Z<
ORIGINATED
TRANSMITTAL
DATE: 10/21/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5130
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5130 2P-427 50103204080000 Tubing Cut Record 19-Oct-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
Richard.E.Elgarico@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-018
T39706
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.10.21 15:22:12 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: N/A Rig Elevation: N/A Total Depth: 10,402 ft MD Lease No.: ADL0373112
Operator Rep: Suspend: X P&A:
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ Feet
Surface: 7 5/8" O.D. Shoe@ 3030 Feet Csg Cut@ Feet
Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet
Production: 5-1/2"x 3-1/2" O.D. Shoe@ 10139 Feet Csg Cut@ Feet
Liner: O.D. Shoe@ Feet Csg Cut@ Feet
Tubing: 3 1/2" O.D. Tail@ 9,534 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Fullbore Balanced 9,450 ft 7,690 ft 9.8 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1720 1690 1690
IA 1820 1770 1750
OA 476 449 437
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Sid Ferguson
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
Traveled to KRU 2P pad for plug tag and MIT-TxIA combo test of the intermediate balanced plug on 2P-427. Wire line tool was
28 ft long with 150lbs of weight bar and a flap bailer on the end. Initial tag was made at 7664 ft MD and eventually beat down to
7,690' for final tag. The bailer returned a good cement sample. 1bbl in and 1 bbl out during the passing MIT
October 5, 2024
Sully Sullivan
Well Bore Plug & Abandonment
KRU 2P-427
ConocoPhillips Alaska Inc.
PTD 2020180; Sundry 324-487
none
Test Data:
P
Casing Removal:
rev. 3-24-2022 2024-1005_Plug_Verification_KRU_2P-427_ss
9
9
9
99
9
9
9
9
9
9
9
9
9999
9 99
9
9
99
9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.11.18 15:58:22 -09'00'
ORIGINATED
TRANSMITTAL
DATE: 9/24/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5079
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5079 2P-427 50103204080000 Tubing Puncher Record 22-Sep-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
tom.osterkamp@conocophillips.com 700 G Street
Anchorage, AK 99503 Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received
By: Received By:
Signature Signature
202-018
T39585
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.09.24 10:04:27 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both: AR@ake-
line.com tom.osterkamp@conocophillips.com
ORIGINATED
TRANSMITTAL
DATE: 9/19/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5067
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5067 2P-427 50103204080000 Tubing Puncher Record 18-Sep-2024
RECIPIENTS
Conoco
DIGITAL FILES PRINTS CD'S
1 FTP Transfer 0 0 USPS
Attn: NSK-69
tom.osterkamp@conocophillips.com 700 G Street
Anchorage, AK 99503
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-018
T39577
Gavin Gluyas
Digitally signed by Gavin
Gluyas
Date: 2024.09.19 10:08:43
-08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com tom.osterkamp@conocophillips.com
ORIGINATED
TRANSMITTAL
DATE: 9/10/2024
ALASKA E-LINE SERVICES
TRANSMITTAL
#: 5044
42260 Kenai Spur Hwy
PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk River
PH: (907) 283-7374 FAX: (907) 283-7378
DELIVERABLE DESCRIPTION
TICKET # WELL # API #
LOG
DESCRIPTION
DATE OF
LOG
5044 2P-427 50103204080000 Tubing Puncher Record 9-Sep-2024
RECIPIENTS
ConocoPhillips Alaska, Inc.
DIGITAL FILES PRINTS CD'S
1 0 0 0 USPS
0
0 0
0
Received
By: Received By:
Signature Signature
AOGCC
DIGITAL FILES PRINTS CD'S
1 ShareFile 0 0 USPS
Attn: Natural Resources Technician II
abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision
aogcc.data@alaska.gov 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501
Received
By: Received By:
Signature Signature
202-018
T39540
Gavin
Gluyas
Digitally signed
by Gavin Gluyas
Date: 2024.09.10
11:32:06 -08'00'
DNR
DIGITAL FILES PRINTS CD'S
1 SharePoint
Link 0 0 USPS
Attn: Natural Resource Tech II
DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501
Delivery Method: USPS
Received
By: Received By:
Signature Signature
Please return via e-mail a copy to both:
AR@ake-
line.com AKGGREDTSupport@ConocoPhillips.onmicrosoft.com
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Suspend-Intermediate Plug
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
10402'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
(907) 263-3718
Senior Well Interventions Engineer
KRU 2P-427
5853' 9569' 5473' 9569', 9624'
N/A
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
katherine.oconnor@conocophillips.com
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
9532' MD and 5456' TVD
532' MD and 532' TVD
Katherine O'Connor
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112, ADL0389058
202-018
P.O. Box 100360, Anchorage, AK 99510 50-103-20408-00-00
Kuparuk River Field
Meltwater Oil Pool- Suspended
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
Meltwater Oil Pool-
Suspended
TVD Burst
9534'
MD
120'
2380'
120'
3030'
5739'10139'
16"
7-5/8"
90'
2999'
9645-9735', 10008-10018'
(below cement plug)
4400'
5510-5554', 5680-5685'
(below cement plug)
3-1/2" x 5-1/2"
Perforation Depth TVD (ft):
9/10/2024
3-1/2"
Packer: Baker GBH-22 Seal Assy
SSSV: Camco DS Nipple NoGo Profile
Perforation Depth MD (ft):
L-80
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 8:14 am, Aug 22, 2024
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=
ConocoPhillips, OU=Wells Group, E=
katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.08.21 16:08:59-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
324-487
SFD 8/28/2024 DSR-8/26/24VTL 9/3/2024
10-407X
X
June 30, 2025
0
*&:
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.09.03 16:31:53
-08'00'09/03/24
RBDMS JSB 090524
Procedure
Wireline & Pumping
1. Punch tubing at ±9450’ RKB
2. Pump the following schedule taking returns up the IA:
a. ±50 bbls surfactant wash
b. ±220 bbls KWF
c. ±31 bbls cement
d. ±69 bbls KWF
3. This should leave TOC in tubing and IA hydrostatically balanced with cement top at 7950’ MD
1. RIH and tag TOC and perform CMIT-TxIA to 1500 psi (AOGCC Witnessed)
Eline/Relay
4. Cut tubing at ±3300’ RKB
notesft/bblvolumebbls/ftIDSizeBottomTopString
calc'd from top of perfs115.083.90.00872.992"3.5" 9.3#964503.5" tubing
calc'd from packer84.0109.50.01194.95" x 3.5"3.5" 9.3# x 5-1/2" 15.5#920003.5" x 5.5" annulus (IA)
60.749.90.01656.87" x 5.5"5-1/2" 26# x 7-5/8" 29.7#302905.5" x 7-5/8" annulus (OA)
2P-427 Intermediate Plug Suspension
Date:8-21-2024
Katherine O’Connor (214-684-7400)
Background & Objecve
2P-427 was an injector was TxIA communica&on while on gas. It has been shut in since Aug 2020. This
well is slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or
surface line hookups, and the objective of this procedure is to suspend the reservoir in preparation for the
well abandonment in 2024.
Well Data
Reservoir pressure 8/2/2023 = 3001 psi @ 5400 TVD = .55 psi/ft = 10.68 KWF
OA Shoe FIT = 17 ppg EW
Suspended 8/9/24 with passing MIT-T
Calculations
2P-427 Well Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
50 bbls of 15.8# Class G Cement
Calculated TOC @ 7,481' KB
1
2
3
5
4
Production Casing:
5.5" x 3.5" @ 9,541' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 10,139.5’ KB
T-3 Peforations:
@ 9,645' – 10,018' KB (373')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 3,029.6' KB
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 9,534.4' KB
6
Item Depth - tops
(KB)
1 FMC Hanger 25.7'
2 Camco DS Nipple No Go Profile 532.4'
3 Baker CMU Sliding Sleeve 9,471.1'
4 Camco D Nipple 9,487.1'
5 Baker Locator 9,531.7'
6 Baker GBH-22 Seal Assembly 9,532.4'
C80 @ 3150' KBC80 @ 3150' KB
Plug #1 – reservoir
TOC ± 9569'
Plug #2 – Intermediate
TOC ±7950' RKB
BOC @ ±9450' RKB
CAUTION: This email originated from outside the State of Alaska mail system. Do not
click links or open attachments unless you recognize the sender and know the content
is safe.
From:O"Connor, Katherine
To:Loepp, Victoria T (OGC)
Subject:RE: [EXTERNAL]RE: DS-2P Intermediate plug sundries
Date:Tuesday, September 3, 2024 2:08:14 PM
Yes - MASPS should all be zero. My perspective for having MASP there was just thinking about KWF
and force of habit for calculating surface pressure. Here is a table of data requested. All witnessed
tests passed.
Prod/Inj Well
Tubing
Size PC Size
Fluid
Weight
Well
Suspended
Tag
Depth
Pressure
Test MASP
Prod 2P-406 3.5 5.5 8.6
6862 1500 0
Prod
2P-
424A 3.5 5.5 8.6
10599 1500 0
inj 2P-427 3.5 5.5
10.7 9569 1500 0
inj 2P-432 3.5 7 10.2
5683 1500 0
Prod 2P-441 3.5 5.5 8.6
6848 1500 0
inj 2P-447 4.5 7 10.9
7509 1500 0
Prod
2P-
448A 3.5 5.5 8.6
7118 1500 0
Thanks,
Katherine O’Connor
CPF2 Interventions Engineer
907-263-3718 (O)
214-684-7400 (C)
-----Original Message-----
From: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>
Sent: Tuesday, September 3, 2024 11:30 AM
To: O'Connor, Katherine <Katherine.OConnor@conocophillips.com>
Subject: [EXTERNAL]RE: DS-2P Intermediate plug sundries
CAUTION:This email originated from outside of the organization. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 10,002.0 2P-427 7/7/2024 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: DB cement on CIBP 2P-427 7/14/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered for water injection only with known TxIA on gas 11/11/2019 jbyrne
NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2010 haggea
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 16 15.05 30.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.6 3,029.6 2,380.0 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 9541'
5 1/2 4.95 27.9 10,139.5 5,739.0 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.7
Set Depth …
9,534.4
Set Depth …
5,456.8
String Max No…
3 1/2
Tubing Description
TUBING
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)
25.7 25.7 0.00 HANGER 8.000 FMC HANGER 3.500
532.4 532.1 5.21 NIPPLE 4.550 CAMCO DS NIPPLE NO GO
PROFILE
CAMCO DS 2.875
2,629.2 2,192.7 62.49 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
6,046.6 3,801.2 61.24 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
8,156.4 4,807.4 61.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,421.6 5,403.9 62.30 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,471.1 5,426.9 62.21 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER 2.813
9,487.1 5,434.4 62.01 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
9,531.7 5,455.4 61.48 LOCATOR 4.500 BAKER LOCATOR BAKER GBH-22 3.000
9,532.4 5,455.8 61.47 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSY 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
9,624.3 5,500.1 60.89 CIBP 2.630" CIBP, OAL = 1.37',
MOE = 9625'
TTS CIBP CPAI
2105-
263-
AC-
001S
R
7/13/2024 0.000
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)
2,629.2 2,192.7 62.49 1 GAS LIFT DMY INT 1 0.0 5/15/2002 0.000
6,046.6 3,801.2 61.24 2 GAS LIFT DMY INT 1 0.0 5/15/2002 0.000
8,156.4 4,807.4 61.38 3 GAS LIFT DMY INT 1 0.0 2/26/2005 0.000
9,421.6 5,403.9 62.30 4 GAS LIFT DMY INT 1 0.0 10/17/2002 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,645.0 9,735.0 5,510.2 5,554.0 T-3, 2P-427 4/23/2007 6.0 APERF 2.5" HSD GUNS w/2506 PJ
Chgs
10,008.0 10,018.0 5,680.1 5,684.7 T-3, 2P-427 10/19/2002 6.0 IPERF 2.5" HSD, JH RDX 2506
Chgs, 60 deg phase, random
orient
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
10,008.0 10,018.0 1 FRAC 10/23/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
9,569.0 9,624.3 5,473.4 5,500.1 Cement Plug Dump Bail cement on CIBP 7/14/2024
2P-427, 8/14/2024 1:08:30 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
9541'; 27.9-10,139.5
FLOAT SHOE; 10,138.9-
10,139.5
FLOAT COLLAR; 10,076.1-
10,076.8
FRAC; 10,008.0
IPERF; 10,008.0-10,018.0
APERF; 9,645.0-9,735.0
CIBP; 9,624.3
Cement Plug; 9,569.0 ftKB
SEAL ASSY; 9,532.4
LOCATOR; 9,531.7
CSR; 9,521.6-9,540.7
NIPPLE; 9,487.1
SLEEVE-C; 9,471.1
GAS LIFT; 9,421.6
GAS LIFT; 8,156.4
GAS LIFT; 6,046.6
SURFACE; 30.6-3,029.6
FLOAT SHOE; 3,028.1-3,029.6
FLOAT COLLAR; 2,939.8-
2,941.1
GAS LIFT; 2,629.2
PORT COLLAR; 990.8-993.2
NIPPLE; 532.4
CONDUCTOR; 30.0-120.0
HANGER; 30.6-33.4
HANGER; 27.9-31.0
HANGER; 25.7
Casing 1; 0.0
KUP INJ
KB-Grd (ft)
37.10
RR Date
5/19/2002
Other Elev…
2P-427
...
TD
Act Btm (ftKB)
10,402.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040800
Wellbore Status
INJ
Max Angle & MD
Incl (°)
64.34
MD (ftKB)
10,300.49
WELLNAME WELLBORE2P-427
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: WRDP
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section: 17 Township: 8N Range: 7E Meridian: Umiat
Drilling Rig: NA Rig Elevation: NA Total Depth: 10402 ft MD Lease No.: ADL 0373112
Operator Rep: Suspend: X P&A: NA
Conductor: 16" O.D. Shoe@ 120 Feet Csg Cut@ NA Feet
Surface: 7-5/8" O.D. Shoe@ 3030 Feet Csg Cut@ NA Feet
Intermediate: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Production: 5-1/2"x3-1/2" O.D. Shoe@ 10139 Feet Csg Cut@ NA Feet
Liner: NA O.D. Shoe@ NA Feet Csg Cut@ NA Feet
Tubing: 3-1/2" O.D. Tail@ 9534 Feet Tbg Cut@ NA Feet
Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified
Tubing Bridge plug 9625 ft MD 9569 ft MD 10.6/6.7 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing 1760 1660 1630
IA 730 730 730
OA 259 263 265
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
I traveled to location to witness the tag and mechanical integrity test (MIT) of the bottom perforation isolating plug inside the wells
production casing. The cement plug on top of the cast iron bridge plug (9625 ft MD) was dumped bailed on 7/14/24. Using a
generic 2-1/4 inch slickline string they tagged the plug at 9569 ft MD (inclination 61°) with multiple hard set downs. A passing MIT
was then done to a target of 1500psi. Top perforation at 9645 ft MD.
August 9, 2024
Austin McLeod
Well Bore Plug & Abandonment
Kuparuk River Unit 2P-427
ConocoPhillips Alaska, Inc
PTD 2020180; Sundry 324-192
none
Test Data: MITT
P
Casing Removal:
Mike Scoles
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
rev. 3-24-2022 2024-0809_Plug_Verification_KRU_2P-427_am
9
9
9
9
9
9
9
9
9
9
9
9 9 9 9 9
9
9 9 9
9 9
9 9
9
James B. Regg Digitally signed by James B. Regg
Date: 2024.10.24 15:03:44 -08'00'
1a. Well Status:Oil SPLUG Other Abandoned Suspended
1b. Well Class:
20AAC 25.105 20AAC 25.110 Development Exploratory
GINJ WINJ WDSPL No. of Completions: __________________ Service Stratigraphic Test
2. Operator Name:14. Permit to Drill Number / Sundry:
3. Address: 7. Date Spudded: 15. API Number:
4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number:
Surface:
Top of Productive Interval:17. Field / Pool(s):
GL: BF:
Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation:
4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth MD/TVD: 19. DNR Approval Number:
Surface: x- y- Zone- 4
TPI: x- y- Zone- 4 12. SSSV Depth MD/TVD: 20. Thickness of Permafrost MD/TVD:
Total Depth: x- y- Zone- 4
5. Directional or Inclination Survey: Yes (attached) No 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD:
Submit electronic information per 20 AAC 25.050 N/A (ft MSL)
22. Logs Obtained:
N/A
23.
BOTTOM
16" B 120'
7-5/8" L-80 2380'
5-1/2" L-80 5460'
3-1/2" L-80 5739'
24. Open to production or injection? Yes No 25.
26.
Was hydraulic fracturing used during completion? Yes No
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
27.
Date First Production: Method of Operation (Flowing, gas lift, etc.):
Hours Tested: Production for Gas-MCF:
Test Period
Casing Press: Calculated Gas-MCF: Oil Gravity - API (corr):
Press. 24-Hour Rate
9532' MD/ 5456' TVD
(seal assembly)
9. Ref Elevations: KB :27'
9541'
SIZE DEPTH SET (MD)
10139'
28'
5460'
62.5#
29.7#
120'
28'
Sr Res EngSr Pet GeoSr Pet Eng
Oil-Bbl: Water-Bbl:
9569-9624' 0.26 bbl Class G cement
Water-Bbl:
PRODUCTION TEST
N/A
Date of Test: Oil-Bbl:
Flow Tubing
SUSPENDED
9645-9735' MD and 5510-5554' TVD (below cement plug)
10008-10018' MD and 5680-5685' TVD (below cement plug)
Gas-Oil Ratio:Choke Size:
Per 20 AAC 25.283 (i)(2) attach electronic information
PACKER SET (MD/TVD)
42"
9.875"
30 bbl AS I
31'380 sx AS IIIL, 220 sx LiteCrete
9.3#
30'
9541'
3030'31'
30'
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date perf'd or liner run):
15.5#
WT. PER
FT.GRADE
5/7/2002
CEMENTING RECORD
5861641
1390' MD/ 1348' TVD
SETTING DEPTH TVD
5861265
TOP HOLE SIZE AMOUNT
PULLED
445964
446077
TOP
SETTING DEPTH MD
suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log,
spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar
locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary.
N/A
BOTTOM
Kuparuk River Field/ Meltwater Oil Pool-
Suspended
N/A
50-103-20408-00-00
KRU 2P-427
ADL0373112, ADL0389058
924' FNL, 1992' FWL, Sec. 17, T8N, R7E, UM
1964' FSL, 1104' FEL, Sec. 20, T8N, R7E, UM
ALK 4998
4/23/2002
10402' MD/ 5853' TVD
9569' MD/ 5473' TVD
P.O. Box 100360, Anchorage, AK 99510-0360
443952 5868953
2338' FSL, 1246' FEL, Sec. 20, T8N, R7E, UM
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
ConocoPhillips Alaska, Inc.
WAG
Gas
202-018/ 324-192
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
CASING, LINER AND CEMENTING RECORD
List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion,
included above6.75"
TUBING RECORD
235 sx Class G6.75"
9534' MD3-1/2"
CASING
Form 10-407 Revised 10/2022 Due within 30 days of Completion, Suspension, or Abandonment
6. Date Comp., Susp., or
Aband.: 08/09/2024
By James Brooks at 2:58 pm, Aug 14, 2024
Suspended
8/9/2024
JSB
RBDMS JSB 081624
xGDSR-8/27/24
Conventional Core(s): Yes No Sidewall Cores:
N/A
30.
MD TVD
Surface Surface
1390' 1348'
Top of Productive Interval
N/A
31. List of Attachments: Schematics, Summary of Operations
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name: Katherine O'Connor
Digital Signature with Date:Contact Email: katherine.oconnor@conocophillips.com
Contact Phone:(907) 263-3718
Senior Well Interventions Engineer
General:
Item 1a:
Item 1b:
Item 4b:
Item 9:
Item 15:
Item 19:
Item 20:
Item 22:
Item 23:
Item 24:
Item 27:
Item 28:
Item 30:
Item 31:
N/A - Suspended
Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and
other tests as required including, but not limited to: core analysis, paleontological report, production or well test results.
Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29.
Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
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).
Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit
detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity,
permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology.
Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain).
Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion,
suspension, or abandonment; or 90 days after log acquisition, whichever occurs first.
Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345),
and/or Easement (ADL 123456) number.
The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements
given in other spaces on this form and in any attachments.
The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic
diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from
a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071.
INSTRUCTIONS
Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other.
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, as-built, core
analysis, paleontological report, production or well test results, per 20 AAC 25.070.
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.
TPI (Top of Producing Interval).
Authorized Name and
Authorized Title:
Formation Name at TD:
If Yes, list formations and intervals cored (MD/TVD, From/To), and briefly summarize lithology and presence of oil, gas or water (submit separate pages if
needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired.
Yes No
Well tested? Yes No
28. CORE DATA
If Yes, list intervals and formations tested, briefly summarizing test results for
each. Attach separate pages if needed and submit detailed test info including
reports and Excel or ASCII tables per 20 AAC 25.071.
NAME
Permafrost - Top
Permafrost - Base
29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered) FORMATION TESTS
N/A- Suspended
Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells Group, E=katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:Date: 2024.08.14 14:15:10-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
Last Tag
Annotation Depth (ftKB) Wellbore End Date Last Mod By
Last Tag: SLM 10,002.0 2P-427 7/7/2024 fergusp
Last Rev Reason
Annotation Wellbore End Date Last Mod By
Rev Reason: DB cement on CIBP 2P-427 7/14/2024 fergusp
Notes: General & Safety
Annotation End Date Last Mod By
NOTE: Waivered for water injection only with known TxIA on gas 11/11/2019 jbyrne
NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 11/22/2010 haggea
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 16 15.05 30.0 120.0 120.0 62.60 WELDED
SURFACE 7 5/8 6.87 30.6 3,029.6 2,380.0 29.70 L-80 BTCMOD
PRODUCTION
5.5"x3.5" @ 9541'
5 1/2 4.95 27.9 10,139.5 5,739.0 15.50 L-80 BTCMOD
Tubing Strings: "String Max Nominal OD" is the OD of the LONGEST segment in string
Top (ftKB)
25.7
Set Depth …
9,534.4
Set Depth …
5,456.8
String Max No…
3 1/2
Tubing Description
TUBING
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)
25.7 25.7 0.00 HANGER 8.000 FMC HANGER 3.500
532.4 532.1 5.21 NIPPLE 4.550 CAMCO DS NIPPLE NO GO
PROFILE
CAMCO DS 2.875
2,629.2 2,192.7 62.49 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
6,046.6 3,801.2 61.24 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
8,156.4 4,807.4 61.38 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,421.6 5,403.9 62.30 GAS LIFT 4.725 CAMCO KBG-2-9 CAMCO KBG-2-9 2.900
9,471.1 5,426.9 62.21 SLEEVE-C 4.500 BAKER CMU SLIDING SLEEVE BAKER 2.813
9,487.1 5,434.4 62.01 NIPPLE 4.550 CAMCO D NIPPLE CAMCO D 2.750
9,531.7 5,455.4 61.48 LOCATOR 4.500 BAKER LOCATOR BAKER GBH-22 3.000
9,532.4 5,455.8 61.47 SEAL ASSY 4.000 BAKER GBH-22 SEAL ASSY 3.000
Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.)
Top (ftKB)
Top (TVD)
(ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in)
9,624.3 5,500.1 60.89 CIBP 2.630" CIBP, OAL = 1.37',
MOE = 9625'
TTS CIBP CPAI
2105-
263-
AC-
001S
R
7/13/2024 0.000
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)
2,629.2 2,192.7 62.49 1 GAS LIFT DMY INT 1 0.0 5/15/2002 0.000
6,046.6 3,801.2 61.24 2 GAS LIFT DMY INT 1 0.0 5/15/2002 0.000
8,156.4 4,807.4 61.38 3 GAS LIFT DMY INT 1 0.0 2/26/2005 0.000
9,421.6 5,403.9 62.30 4 GAS LIFT DMY INT 1 0.0 10/17/2002 0.000
Perforations & Slots
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Linked Zone Date
Shot
Dens
(shots/ft)Type Com
9,645.0 9,735.0 5,510.2 5,554.0 T-3, 2P-427 4/23/2007 6.0 APERF 2.5" HSD GUNS w/2506 PJ
Chgs
10,008.0 10,018.0 5,680.1 5,684.7 T-3, 2P-427 10/19/2002 6.0 IPERF 2.5" HSD, JH RDX 2506
Chgs, 60 deg phase, random
orient
Stimulation Intervals
Top (ftKB) Btm (ftKB)
Inter
val
Num
ber Type Subtype Start Date
Proppant
Designed (lb)
Proppant
Total (lb)
Vol Clean
Total (bbl)
Vol Slurry
Total (bbl)
10,008.0 10,018.0 1 FRAC 10/23/2002 0.0 0.00 0.00
Cement Squeezes
Top (ftKB) Btm (ftKB)
Top (TVD)
(ftKB)
Btm (TVD)
(ftKB) Des Com
Pump Start
Date
9,569.0 9,624.3 5,473.4 5,500.1 Cement Plug Dump Bail cement on CIBP 7/14/2024
2P-427, 8/14/2024 1:08:30 PM
Vertical schematic (actual)
PRODUCTION 5.5"x3.5" @
9541'; 27.9-10,139.5
FLOAT SHOE; 10,138.9-
10,139.5
FLOAT COLLAR; 10,076.1-
10,076.8
FRAC; 10,008.0
IPERF; 10,008.0-10,018.0
APERF; 9,645.0-9,735.0
CIBP; 9,624.3
Cement Plug; 9,569.0 ftKB
SEAL ASSY; 9,532.4
LOCATOR; 9,531.7
CSR; 9,521.6-9,540.7
NIPPLE; 9,487.1
SLEEVE-C; 9,471.1
GAS LIFT; 9,421.6
GAS LIFT; 8,156.4
GAS LIFT; 6,046.6
SURFACE; 30.6-3,029.6
FLOAT SHOE; 3,028.1-3,029.6
FLOAT COLLAR; 2,939.8-
2,941.1
GAS LIFT; 2,629.2
PORT COLLAR; 990.8-993.2
NIPPLE; 532.4
CONDUCTOR; 30.0-120.0
HANGER; 30.6-33.4
HANGER; 27.9-31.0
HANGER; 25.7
Casing 1; 0.0
KUP INJ
KB-Grd (ft)
37.10
RR Date
5/19/2002
Other Elev…
2P-427
...
TD
Act Btm (ftKB)
10,402.0
Well Attributes
Field Name
MELTWATER
Wellbore API/UWI
501032040800
Wellbore Status
INJ
Max Angle & MD
Incl (°)
64.34
MD (ftKB)
10,300.49
WELLNAME WELLBORE2P-427
Annotation
Last WO:
End DateH2S (ppm) DateComment
SSSV: WRDP
DTTMSTART JOBTYP SUMMARYOPS
7/7/2024 CHANGE
WELL TYPE
DRIFT FOR CIBP W/ 2.625" x 10' DWN TO TD @ 10002' SLM, READY
FOR CIBP.
7/13/2024 CHANGE
WELL TYPE
LRS PUMPED 80 BBL 10.6 PPG KWF & 20 BBL DIESEL FREEZE
PROTECT
SET 2.63" QUADCO CIBP (SN: 2105-263-AC-001SR)
LOG CORRELATED TO SLB PERF RECORD DATED 23-APRIL-2007
CCL OFFSET=9.7', ME SET DEPTH=9625', CCL STOP DEPTH=9615.3'
MIT-T TO 1500 PSI (CONFER W/ ENGINEER: PASS)
MIT-IA TO 1500 (PASS)
7/13/2024 CHANGE
WELL TYPE
DRIFT TBG TO CIBP @ 9625' RKB, DUMP 2 GAL OF CEMENT ON TOP
OF CIBP @ 9265' RKB... IN PROGRESS
7/14/2024 CHANGE
WELL TYPE
DUMP BAIL ~42' OF CEMENT ON TOP OF CIBP @ 9625' RKB. READY
FOR SW TOC & MIT IN ~ 72 HOURS.
8/9/2024 CHANGE
WELL TYPE
AOGCC WITNESSED STATE WITNESS (AUSTIN McLEOD) TAG TOC @
9569' RKB. PERFORM PASSING MIT-T TO 1500 PSI. READY FOR NEXT
P&A STEPS.
2P-427 Suspend
Summary of Operations
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
10402'None
Casing Collapse
Structural
Conductor
Surface
Intermediate
Production
Liner
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name:
Contact Email:
Contact Phone:
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
5/1/2024
3-1/2"
Packer: Baker GBH-22 Seal Assy
SSSV: Camco DS Nipple NoGo Profile
Perforation Depth MD (ft):
L-80
2999'
9645-9735', 10008-10018'
4400'
5510-5554', 5680-5685'
3-1/2" x 5-1/2"
Perforation Depth TVD (ft):
120'
3030'
5739'10139'
16"
7-5/8"
90'
9534'
MD
120'
2380'
ConocoPhillips Alaska, Inc.
Length Size
Proposed Pools:
PRESENT WELL CONDITION SUMMARY
N/A-Suspended
TVD Burst
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0373112, ADL0389058
202-018
P.O. Box 100360, Anchorage, AK 99510 50-103-20408-00-00
Kuparuk River Field Meltwater Oil Pool
AOGCC USE ONLY
Tubing Grade: Tubing MD (ft):
9532' MD and 5456' TVD
532' MD and 532' TVD
Katherine O'Connor
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
katherine.oconnor@conocophillips.com
(907) 263-3718
Senior Well Interventions Engineer
KRU 2P-427
5853' 10040' 5694' None
N/A
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 4:26 pm, Apr 01, 2024
Digitally signed by Katherine O'Connor
DN: CN=Katherine O'Connor, O=ConocoPhillips, OU=Wells
Group, E=katherine.oconnor@conocophillips.com, C=US
Reason: I am the author of this document
Location:
Date: 2024.04.01 16:13:36-08'00'
Foxit PDF Editor Version: 13.0.0
Katherine
O'Connor
324-192
DSR-4/12/24
December 31, 2024
SFD 4/10/2024
Suspend
X
VTL 4/19/24
10-407X
JLC 4/19/2024
Brett W. Huber,
Sr.
Digitally signed by Brett W.
Huber, Sr.
Date: 2024.04.19 17:01:14
-04'00'04/19/24
RBDMS JSB 042324
2P-427 P&A
Date: 4-1-2024
Katherine O’Connor (214-684-7400)
Background & Objecve
2P-427 was an injector was TxIA communica&on while on gas. It has been shut in since Aug 2020. This
well is slated to be P&Ad as part of the 2P pad abandonment. 2P pad does not have any facilities or
surface line hookups, and the objective of this procedure is to suspend the reservoir in preparation for the
well abandonment in 2024.
Well Data
Reservoir pressure 9/17/2012 = 3154 psi
MASP = 2603
OA Shoe FIT = 17 ppg EW
Last SL drift down to 9665’ KB (required B&F)
Calculations
Procedure
Wireline & Pumping
1. Tag TD. If unable to get within 50’ of perforations, contact Katherine O’Connor
2. Fluid pack tubing with KWF and freeze protect
3. Set CIBP @ ±9630’ RKB
4. Dump bail at least 30’ of cement on top of the perforations
5. Allow 72 hours for cement to harden, notify AOGCC at least 24 hours in advance
6. RIH and tag TOC (approx. 9600’ KB) (MUST BE AOGCC WITNESSED)
7. RU LRS as necessary. Perform pressure test to 1500 psi (MUST BE AOGCC WITNESSED)
8. Perform DDT-0 psi and record results
String Top Bottom Size ID bbls/ft volume ft/bbl notes
3.5" tubing 0 9645 3.5" 9.3# 2.992" 0.0087 83.9 115.0 calc'd from top of perfs
3.5" x 5.5" annulus (IA) 0 9200 3.5" 9.3# x 5-1/2" 15.5# 4.95" x 3.5" 0.0119 109.5 84.0 calc'd from packer
5.5" x 7-5/8" annulus (OA) 0 3029 5-1/2" 26# x 7-5/8" 29.7# 6.87" x 5.5" 0.0165 49.9 60.7
2P-427 Well Schematic
Conductor:
16" Conductor 120' KB
Production Casing Cement:
50 bbls of 15.8# Class G Cement
Calculated TOC @ 7,481' KB
1
2
3
5
4
Production Casing:
5.5" x 3.5" @ 9,541' KB, 15.5# x 9.3#,
L-80 BTC Mod
Set @ 10,139.5’ KB
T-3 Peforations:
@ 9,645' – 10,018' KB (373')
Surface Casing:
7-5/8", 29.7#, L-80 BTC Mod
Set @ 3,029.6' KB
Production Tubing:
3 ½”, 9.3# L-80 EUE-8rd
Set @ 9,534.4' KB
6
Item Depth - tops
(KB)
1 FMC Hanger 25.7'
2 Camco DS Nipple No Go Profile 532.4'
3 Baker CMU Sliding Sleeve 9,471.1'
4 Camco D Nipple 9,487.1'
5 Baker Locator 9,531.7'
6 Baker GBH-22 Seal Assembly 9,532.4'
C80 @ 3150' KBC80 @ 3150' KB
Plug #1 – reservoir
TOC ± 9600'
1
Regg, James B (OGC)
From:Well Integrity Specialist CPF2 <n2549@conocophillips.com>
Sent:Wednesday, August 17, 2022 10:00 AM
To:Regg, James B (OGC); Wallace, Chris D (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay
Subject:CPAI 2P-Pad shut in tests 08-16-22.xlsx
Attachments:MIT KRU 2P PAD SI TESTS 08-16-22.xlsx
All
Attached is the 10 426 form for the shut in tests performed on 2P pad on the 16
th of Aug 2022. Please let me know if
you have any questions or concerns.
Dusty Freeborn
Well Integrity Specialist
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
Cell phone: (907) 830-9777
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open
attachments unless you recognize the sender and know the content is safe.
Submit to:
OPERATOR:
FIELD /UNIT /PAD:
DATE:
OPERATOR REP:
AOGCC REP:
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2040170 Type Inj N Tubing 2605 2620 2610 2610 Type Test P
Packer TVD 5209 BBL Pump 3.2 IA 470 3590 3500 3480 Interval V
Test psi 2900 BBL Return 3.1 OA 203 360 310 290 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2011820 Type Inj N Tubing 827 827 828 828 Type Test P
Packer TVD 5428 BBL Pump 1.0 IA 460 3210 3145 3130 Interval V
Test psi 2900 BBL Return 0.9 OA 277 363 319 309 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2020180 Type Inj N Tubing 808 1001 980 953 Type Test P
Packer TVD 5456 BBL Pump 2.3 IA 410 3200 3090 3075 Interval V
Test psi 2900 BBL Return 2.0 OA 277 576 515 484 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2011020 Type Inj N Tubing 875 876 876 876 Type Test P
Packer TVD 5219 BBL Pump 2.1 IA 390 3200 3110 3100 Interval V
Test psi 2900 BBL Return 1.8 OA 236 569 539 531 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2020910 Type Inj N Tubing 1091 1091 1091 Type Test P
Packer TVD 5177 BBL Pump 3.2 IA 450 3200 2105 Interval V
Test psi 2900 BBL Return OA 278 405 345 Result F
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2031530 Type Inj N Tubing 886 887 887 887 Type Test P
Packer TVD 5141 BBL Pump 1.6 IA 470 3210 3110 3090 Interval V
Test psi 2900 BBL Return 1.6 OA 254 356 321 312 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2010820 Type Inj N Tubing 112 288 298 294 Type Test P
Packer TVD 5274 BBL Pump 1.7 IA 950 3210 3110 3100 Interval V
Test psi 2900 BBL Return 1,6 OA 211 428 303 253 Result P
Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
PTD 2031540 Type Inj N Tubing 882 882 882 882 Type Test P
Packer TVD 5234 BBL Pump 2.0 IA 210 3210 3110 3110 Interval V
Test psi 2900 BBL Return 1.8 OA 438 444 444 443 Result P
TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes
W = Water P = Pressure Test I = Initial Test P = Pass
G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail
S = Slurry V = Required by Variance I = Inconclusive
I = Industrial Wastewater O = Other (describe in notes)
N = Not Injecting
2P-438
2P-447
MITIA every 2 yr to max anticipated injection pressure per AIO 21C.002
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4
2P-429
2P-432
2P-434
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4
2P-427
Notes:MITIA every 2 yr to max anticipated injection pressure per AIO 21C.001
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4
ConocoPhillips Alaska Inc,
Kuparuk / KRU / 2P Pad
Witness Waived by Guy Cook
Beck / Borge
08/16/22
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4 Tubing plug set at 8110' MD
Notes:
Notes:MITIA every 2 yr to max anticipated surface injection pressure per AIO 21C rule 4
2P-419
2P-420
Form 10-426 (Revised 01/2017)2022-0816_MIT_KRU_2P-pad_8wells
2P-427
Wallace, Chris D (CED)
From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com>
Sent: Saturday, October 19, 2019 5:48 AM
To: Wallace, Chris D (CED)
Cc: CPA Wells Supt
Subject: KRU 2P-427 (PTD 202-018) Update and AA submittal
Attachments: 2P-427 AA application packet 10.18.19.pdf
Chris,
KRU injection well 213-427 (PTD 202-018) water injection monitor period is ending and no TxIA communication was
exhibited throughout the monitor period. CPA[ intends to apply for an Administrative Approval to continue water
injection only with known TxIA communication on gas injection only. The paper application is in the mail and digital
copy of the AA application packet is attached. The well will be left online on water injection while the AA application is
being processed.
Please let us know if you disagree or have any questions with this plan.
Regards,
Jan Byrne / Dusty Freeborn
CPF1 & 2 Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Office phone: (907) 659-7224
WELLS TEAM
Carom IP5
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Abandon Ll Plug Perforations L Fracture Stimulate Ll Pull Tubing Ll Operations shutdown Ll
Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Water Injection startup ❑�
2. Operator ConocoPhillips Alaska, Inc.
4. Well Class Before Work:
5. Permit to Drill Number:
Name:
Development ❑ Exploratory ❑
Stratigraphic ❑ Service ❑✓
202-018
3. Address: P. O. Box 100360, Anchorage, Alaska 99510
6. API Number:
50-103-20408-00-00
7. Property Designation (Lease Number):
8. Well Name and Number:
Surface: ADL 373112/ BH: ADL 389058
KRU 2P-427
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
10. Field/Pool(s):
NA
Ku aruk River Field/Meltwater Oil Pool
11. Present Well Condition Summary:
Total Depth measured 10,402' feet Plugs measured NA feet
true vertical 5,854' feet Junk measured NA feet
Effective Depth measured 10,018' feet Packer measured 9532' feet
true vertical 5,685' feet true vertical 5456' feet
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 90' 16" 120' 120'
Surface 2999' y1=
ConocoPhillips Alaska, Inc.
700 G St.
Anchorage, AK 99501-3448
October 14th, 2019
AOGCC Commissioner
State of Alaska, Oil & Gas Conservation Commission
333 W. 7th Ave., Ste. 100
Anchorage, AK 99501
Dear Commissioner,
ConocoPhillips Alaska, Inc. has completed changing the service of the Kuparuk River Unit
(Meltwater) Well 2P-427 from Gas Injection to Water Alternating Gas Injection.
Enclosed you will find a 10-404 report of Sundry Well Operations for ConocoPhillips
Alaska, Inc. A separate submission for a state witnessed MIT -IA for 2P-427 was also
made.
If you have any questions regarding this matter, please contact me at 907-265-1109.
Sincerely,
Sayeed Abbas
Staff Petroleum Engineer
ConocoPhillips Alaska, Inc.
Attachments:
Report of Sundry Well Operations
Daily report of Well Operations
Well Schematic
2P-427
DAILY REPORT
WELL OPERATIONS
9/19/2019: 213-427 started water injection as part of the process to change the well from Gas Injection
(GINJ) designation to Water -Alternating -Gas (WAG) designation
912512019: 2P-427 passed state witnessed MITIA
/r- ~'\ KUP INJ WELLNAME 2P-427 WELLBORE 2P-427
C. onocONhAIIIpS I El
I peen Annoures Max Angle & AAD - TD
Na3Na.IP.
Flele Hame WellboregPYUWI WeII4ort51atm MII') MU(XKB) geteen (11KB1
MELTWATER 0102 0 4 0 8 0 INJ 1 10.300.49 10.4020
SSSV: nWRDP Hss (PPmI eale MMNm -a- NB4Ye lR1 elg Relgse OeN
Lau WO: 3].10 5119202
Z Pwn, lvlvzaei4v:1aga4
Last Tag
Vellulalunvtic lec4W1
Nmahlbn aeplR(nNB) EM Gee WeWOR LP1Mglay
LaWTag:RKBfEm.W RalhGle) 10,03].011/122018 2P-02] zemba.j
Last Rev Reason
wv4GER L,T ��
Mnahlpn Ene Gak WHlban LaBI MOC By
Rev Reason:Upllove Tag Deem&/nate- lnjeclion Valve 12/12/2018 2P-027 zembael
Casing Strings
eaelne Ges<Npsaa oplln) IG lln) Top(M see Wpnl lnNal sR Gepm (NGL.. WIILen O... G,eee Top Tp -.CONDUCTOR 16 1505 30.0 12OLD 120.0 62.0 WEIDED
Cosing G¢anriptlon p01m1 IGgn) Ta e-, SeLGe l.KB) Se Gepm j'v01... WtlL p... Gnee Tap Tli-so
SURFACE ]SIB 6.8] 30.6 3,029.6 2,380.0 29..70 LA0 BTCMOO
Casing OnMptlon OGOn) 4.95 Tap lnNB) Sel OepM IRKBI -GapM nVD)...NLLen n..GMde Tap Thmae
PRODUCTION 5.513.5. 512 4.95 27.9 10,139.5 5,]39.0 15.50 L-60 BTCMOn
@9S,R
I III Stdngs
TUWn9 GescXpllon Smng Ma.,,IGpn) ToP(RKG) Stl pepflX lfl-SN Gep111 (TVDI1-W111NM Gotle iap ConneCNOn
TUBING 312 1!19 253 9,534.4 5.456.8 930 L-80 EUEAM
COmplation Details
rANDULTOR 39.a,zm
TV, I Top mal Nissan.,top lnxel
MK 1'1 Bam n. Cosm)
25.7 25.7 0.00 HNNGER FMC HANGER 3.50
NnPte plz.4
M'sail
532.4 532.1 5.21 NIPPLE CAMCO 05 NIPPLE NO GO PROFILE 2.875
INJECTIDN
9,6]1.1 5,426.9 62.21 SLEEVE -C BAKER CMD SLIDING SLEEVE 2.813
9,487.1 5,434.4 62.01 NIPPLE CAMGDDNIPPLE 2.750
1
9,531.7 5,455.4 61.48 LOCATOR BAKER LOCATOR 1000
9,532.4 5,455.8 6147 SEAL ASSY BANERG6H-22 SEAL ASSY 3,00
Other In Hole Wtreline MtrIVIable Plugs, valves, Pumps, fish, etc.)
Tap Tell)TOPm.I
G4S UFT;Sp292
Top gUUg
(M e) M Des Co.
Run Gaffe IO (ill)
532.4
5320 521 VALINJECTION 2875 GLOCK w1A-11NJ VALVE (.910 BEAN, OAL=621
VE
12/62018 0.910
erfomgons & Slots
anal
SURFACE;3063,0296-
Tap pINB)
aM (nKBI
Tap(NGI
(Itl(B)
BM
(flKB) KBI
LInFMZme
pate
�re
(assets
1
Type
Cam
9,645.0
9,735.0
5,510.2
5,554.0
TY. 2P-027423120]
60
APERF
2.5" HED GUNS w2506 PJ
-TOMO,.
Olga
10,016.0
S,fi0.1
5,664.]
TA, 2P-02]
10/19202
6.0
IPERF
2.S HSD, JH ROX 250
ChgS, O Men Phase, random
orient
Gaa uPr:4Gea
Frac Summary
Bmrt Dale PnPPmXGealYneelm) PIaPWmmPammm� pb)
1023/202
$qY $mrt Data Tap DaplF (BNa) Bhn(M e) Dnkm FlUW Syae,n VOICINn(bbl) Valgmaylnbl)
i 10232002 10,008.0 10,018.0
c surra s,,ws
Mandrel Inserts
a<
an
N Tap PW)
Top IRN81 Mehe Moeel
Pwl81m 1RORun
O011nl Sery(ml /Peg qun pale1
2,19
26282 2,192.] CPMCO KfiG2-
1 GAS LIFT0.00 0.0 5I1520D29
T:F;��
WSLIFT: 9,1216
26.046.6 3.8012 CAMCO KBG-2-
g
1 GAS LIFT0.00 0.0 5/15202
3 8,1554 4,07.4 CAMCO MG -2-
1 GASLIFT DMV INT 0.00 00 Y26205
9
4 9,421.6 5.403.9 -CO 103G-2-
i GAS LIFT DMY INT 0.00 0.0 10/1]202
9
SIFEVEq Gn„
Notes: General & Safety
Ene Defle Meoepan
11222010 NOTE: VIEW SCHEMATIC wlM ke Schemalic9.0
NIPPLF'9,4a1.Ill
L.RAvv
sFALgssv: Ysu4
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IPERF:,G,M1 10,0160
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PRGWCl1nN5.PG5'®
95e1:P&IO.ta9.5
MEMORANDUM
TO: Jim Regg I< 1015117 q
P.I. Supervisor �(
FROM: Brian Bixby
Petroleum Inspector
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Friday, October 4, 2019
SUBJECT: Mechanical Integrity Tests
ConocoPhillips Alaska, Inc.
2P-027
KUPARUK RIV U MELT 2P-427
Sre: Inspector
Reviewed By:
P.I. Supry JB -
Comm
Well Name KUPARUK RIV U MELT 2P-427 API Well Number 50-103-20408-00-00 Inspector Name: Brian Bixby
Permit Number: 202-018-0 Inspection Date: 10/1/2019
Insp Num: mitBDB191002104334
-
Rel Insp Num:
Packer Depth Pretest Initial
15 Min 30 Min 45 Min 60 Min
2P-427
Type Inj
w 'TVD
5455
Tubing
840
840 ,
840
840 '
[IntervalOTHER
2020180
Type Test
sPT
Test psi
2900
IA
o
3200
3100
3100
Pumped:
2.8
BBL Returned:
2 8 -
OA
788 -
780
P/F P
Notes: MIT -IA as per Sundry #318-454 v
Friday, October 4, 2019 Page I of I
Wallace, Chris D (DOA)
From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com>
Sent: Friday, January 25, 2019 9:41 AM
To: Wallace, Chris D (DOA)
Cc: CPA Wells Supt
Subject: RE: Report of IA pressure anomaly for meltwater gas injector 2P-427 (PTD 202-018)
update 1-25-19
Attachments: 2P-427 90 day TIO 1-25-19.PNG
Chris,
The 30 -day monitor on 2P-427 is nearing its conclusion. While there have been localized thermal fluctuations,
unfortunately signs of TxIA communication continue to be present in the well. Due to the lack of water injection at
Meltwater currently, the well will be shut in as soon as possible and remain shut in until water injection can be restored
to the pad, tentatively scheduled for later this year during the warmer months. At that point, we intend to put the well
on a 30 -day water monitor to confirm that this anomalous behavior is due to a gas -only leak so that we can ultimately
apply for an AA. We were able to pass a witnessed MITIA on 1/8/19. Please let us know if you disagree with the path
forward.
Attached is an updated 90 day TIO trend plot.
Kelly Lyons / Jan Byrne
Well Integrity Supervisor
ConocoPhillips Alaska, Inc.
Desk Phone (907) 659-7224
FK,om: NSK Well Integrity Supv CPF1 and 2
Sen . ursday, December 27, 2018 9:58 AM
To: Walla Chris D (DOA) <chris.wa[lace @alaska.gov>
Cc: Senden, R. r <R.Tyler.Senden@conocophillips.com>
Subject: Report of IA ssure anomaly for meltwater gas injector 2P-427 (PTD 202-018) 12-27-18
Chris,
Meltwater gas injector 2P-427 (PTD -018) is demonstrating possible signs of TxIA communication while on gas
injection. It was recently returned to gas ction on Dec 13, 2018 after having been shut in since July 2018. The IA
pressure build up was originally attributed to a wer than normal thermal response. We did perform a bleed on
12/23/18 and shortly thereafter relatively large injec ' temperature swings have been occurring, so at this point we
will continue to monitor the well under heightened scrutin or 30 days because of possible hysteresis affects. If the
well becomes more strongly suspected of assured communication,,the well will be shut in and freeze protected. Follow-
up diagnostics to include MITs and packoff testing will be pursued. Assuming passing tests and assuming a leak is
confirmed, we intend to put the well on a 30 day water monitor to ensure the leak is a gas -only one. But because there
is no water injection availability to Meltwater at this time, the well will remain shut in till water is restored (currently
anticipated in mid 2019). A follow-up email will be provided at the conclusion of the monitor(s). Please let us know if
you disagree with the plan forward.
Attached are the 90 day and 1 month TIO plot (for closer resolution) and schematic.
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
To: Jim R
�e t�15 11�
DATE: Tuesday, January 15, 2019
P.I. Supervisor (_J
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA, INC.
2P-427
FROM: Guy Cook
KUPARUK RIV U MELT 2P427
Petroleum Inspector
Src: Inspector
Reviewed By:
yy��
P.I. Supry j-V—
NON-CONFIDENTIAL
Comm
Well Name KUPARUK RIV U MELT 2P-427 API Well Number 50-103-20408-00-00 Inspector Name: Guy cook
Permit Number: 202-018-0 Inspection Date: 1/8/2019
Insp Num: mitGDC190109071643
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well ( 2P427 'Type lnj c, TVD 5455 Tubing 2310 2310 2310- 2310
PTD 2020180 ` Type Test s"I Test psi 2500 IA 1190 3210 3140 3120
BBL Pumped: 1.7 BBL Returned: 1.7 - OA 526 533 532 531
Interval REQVAR P/F P ✓
Notes: MIT -IA required every 2 years per A10 21C to maximum anticipated surface pressure. Testing performed with a Little Red Services pump truck
and analog gauges from KRU DHD.
Tuesday, January 15, 2019 Page 1 of I
THE STATE
GOVERNOR BILL WALKER
Adam Childs
Staff Petroleum Engineer
ConocoPhillips Alaska, Inc.
P.O Box 100360
Anchorage, AK 99510-0360
Re: Kuparuk River Field, Meltwater Oil Pool, KRU 2P-427
Permit to Drill Number: 202-018
Sundry Number: 318-454
Dear Mr. Childs:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907 276,7542
www.cogcc.clasko.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
1S
DATED this 14 day of October, 2018.
Sincerely,
Hollis S. French
Chair
;BDMS �G OCT 2 2 2018
Loepp, Victoria T (DOA)
From: Childs, Adam G <Adam.G.Childs@conocophillips.com>
Sent: Thursday, October 11, 2018 9:59 AM
To: Loepp, Victoria T (DOA)
Subject: 2P Injector Sundry Requests
Victoria,
I received your voicemail regarding the 2P sundry requests. The majority of those MITIAs performed last month were
state witnessed, but not all of them. Three of the injectors were shut-in at the time of testing, and were therefore non -
state witnessed tests. A separate 10-426 form was sent to the state with the results of these tests.
Please see table below including which of the wells tested in August were state witnessed, and when the last witnessed
tests were for those that were shut-in.
Well Name
2P-419
August 2018 State
Witnessed Test?
Yes
Status Of Test
Passed
Last State
Witnessed Test
Status of
Last Test
2P-420
Yes
Passed
2P-427
No
Passed
8/20/16
Passed
2P-429
Yes
Passed
2P-432
Yes
Passed
2P-434
No
Passed
11/09/14
Passed
2P-438
No
Passed
9/30/16
Passed
2P-447
Yes
Passed
Let me know if you have any other questions.
Thanks,
Adam Childs
907-263-4690
STATE OF ALASKA OCT Q 8 218
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS A /''� =^
20 AAC 25.280 �''AO G C C
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Convert GINJ to WAG_ ❑�
2. Operator Name:
4. Current Well Class:
5. Permit to Dnll Number:
ConocoPhilli s Alaska Inc.
Exploratory ❑ Development
Lt)
Slratigraphic ElService/'
202-018
3. Address:
6.API Number:
P. O. Box 100360, Anchorage, Alaska 99510
0 `p' 0
50-103-20408-00
7. If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool? N/A
Will planned perforations require a spacing exception? Yes EJ No
No
KRU 2P-427
9. Property Designation (Lease Number):
10. Field/Pool(s):
Surface: ADL 373112/ BH: ADL 389058
1 Kuparuk River Field / Meltwater Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):
Plugs (MD): Junk (MD):
10,402' 5,854' • 10,018' 5,685'
None None
Casing Length Size MD TVD
Burst Collapse
Structural
Conductor 90' 16" 120' 120'
Surface 2,999' 11" 3,030' 2,380'
Intermediate
Production 10,112' 91, 10,140' 5,739'
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
9,645 - 10,018'
5,510 -5,685'
3.5001,
L-80
9,532'
Packers and SSSV Type: Packer- BAKER GBH -22 (SEAL ASSY)
Packers and SSSV MD (ft) and TVD (ft): Seal Assy: MD= 9532', TVD= 5456'
SSSV - 2.875 C -LOCK W/A-1 INJ VALVE (.910 BEAN)
MD= 532 TVD= 532
12. Attachments: Proposal Summary ✓ Wellbore schematic ✓
13. Well Class after proposed work: wa4,lr�
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ DevelopmentOFService
14. Estimated Date for
15. Well Status after proposed work:
Commencing Operations: 10/15/2018
OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑
GAS ❑ WAG Q GSTOR ❑ SPLUG ❑
16. Verbal Approval: Date:
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Authorized Name: Adam Childs Contact Name: Adam Childs
Authorized Title: Staff Petroleum Engineer Contact Email: adam.g.childs@conocphillips.com
Contact Phone: 907-263-4690
Authorized Signature: 11 Date: ID 18
commitsitiN USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number. n ,r — 45
/✓, '%U
q
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑
Other:
fill �lC eo�z�l/times a�Ply
Post Initial Injection MIT Req'd? Yes [�'No ❑
Spacing Exception Required? Yes ❑ No ri� Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
GDf1/ 10l1TI2o1 >? /!$ (� o� (!��/��]tF m and
�/ Submit Form and
Form 10-403 Revised 4/2077 Approved application is al d o 7 t 5 r m sI. (1C 7 2 2 2O(lachments in Duplicate
ConocoPhillips Alaska, Inc.
700 G St.
Anchorage, AK 99501-3448
October 8th, 2018
AOGCC Commissioner
State of Alaska, Oil & Gas Conservation Commission
333 W. 7th Ave., Ste. 100
Anchorage, AK 99501
Dear Commissioner,
ConocoPhillips Alaska, Inc. requests approval to change the service of the Kuparuk River
Unit (Meltwater) Well 2P-427 from Gas Injection to Water Alternating Gas Injection. ✓
Enclosed you will find a 10-403 Application seeking Sundry Approval for ConocoPhillips
Alaska, Inc.
If you have any questions regarding this matter, please contact me at 907-263-4690.
Sincerely,
Adam Childs
Staff Petroleum Engineer
ConocoPhillips Alaska, Inc.
Attachments:
Sundry application
Proposal Summary
Well Schematic
2P-427
DESCRIPTION SUMMARY
OF PROPOSAL
Commensurate with the recently revised and approved AIO 21C. ConocoPhillips Alaska Inc. is in the
process of facility and wellbore modifications to enable water injection in Meltwater.
As part of these changes, ConocoPhillips Alaska Inc. is seeking approval to change the service type of
Meltwater injector 2P-427 from its current Gas Injection (GINJ) designation to Water -Alternating -Gas
(WAG).
The 2P-427 successfully passed an MIT -IA test to 3300 psia on 8/15/18.
fit-"\ KUP INJ 2P-427
l.M NJs.QPhlllips
Well Attributes Maz Angle & MD TD
Alaska. Inc.
weomre PvuuWl WeIIM231am mr1') YD (nxa) A eM 1M3)
MELNJAiER 5010320406W INJ 31 10,9]0.49 10.4020
camm>m xis 1ppml oats AmWIYn Fna Dale xefialn) PJ9ROW-DNe
SSSV: WHDP Last WO: 37.10 MOM
pvm.TrJ.m1e T:4e:4onY
Last Tag
Vwylaaymwclama0
Nmd>Yon Fns Dah OaMetxal YYMWey
LaeT,: SLM 2/10.2015 10.0100 hipshtl
--Last
Rev Reason
FlaxaFA;xST ,��
AYHYbn Be
R 1 DYa ua Yo4 ey
Rev Beeson: Reputed njeteon Valve J24rz018 zembaej
Casing Strings
—wn WWI InY61 mDl...
OOIKKeI 1s�D0>gn
CONouCce T�fl 15 1pD0>gn
1 16 WELDED
6i2
to D—Ml " .M) Tap Braal Sd Oapminxa) Stl Depq llYDI... Yeaae lr_. Onee Topmroe
SURFACE 759 6.87 WS 3.029.6 2,380.0 29.]0 L-80 RTCMOD
CiN�p ON41YIly� DD(ml W(n) Tap0uB1 Sd Degnlnl(al SA Dawn mpt.. —9-4---mpnueaa
PRODUCTION 55Y V Stn 4.95 279 10.139.5 5,)39.0 1550 1-40 STCMOO
9541'
Tubing Strings
TWMp lkeulpllp4 SM�Ip Ya... nl an) Top InRB) Sa+DapM (M1. 9a10>pN (NDI (... W111WR) Gnae Top CO1 Wn
TUBING 3 W 2.99 25.J 9,534.4 6,456.8 930 L-fi0 EUF-8N
Completion Details
Top IWO) Tp Iw xaMllY
mNDunw+'wu+zao
TaPIMInner PI ppea Cyn o
I
257 25.7 0.00 HANGERIMMCI9W
FGER 3.5500 0
MPRE', sn.a
532.4 532.1 1 521 JNIPKE CMICODS NIPPIF NOGOPROFILE 2.875
IxacTrox vAue atx.♦
9,671.1 5.426,91 6221 SLEEVEL BAKER CMU SLIDING SLEEVE 2.813
,187.1 5,4MA 62.01 NIPPLE CAb1C0 D NIPPLE 2.750
1
9,5312 5,455.4 B1 AB LOCATOR BAKERLOCATOR 3.000
9,532.6 5,455.8 61A> SEAL ASSY 6AKER GBH-22SEA SY 1"
Otlter In Note (Whellne rWierabte plugs, vahmrs, pumps, gats, etc.)
We11FT: 3.eie.S
Tap1TVD1
Tw plle)O
Top Nd
19
Du tom aim mY
r0,91
W
532.4 532.0
5211NJECTION
4e
28]5C -LOCK w/A-11NJ VALVE�910 BEAN.OAL=d4'I >rzn91
0910
VALVE
Perforations & Slots
sny
Dw
TWITYD)
enn RYDI
IMaK91
sunrAtE'.wa54a3n�
T°M
a°anseme)
8151)
Mal5,55,
I+P427
Dale
l
9,645.0
9,7350
5510.2
5,554.0
TT-2P<D
4n31'VOJ
6.0
NS
HSD G11NSw125p6 PJ
41KRF
10,008.0
10,018.0
5.660.1
;6842
T-3, 4V
10119/IOOP
6.0ISDRD%,
60 des phast
Frac Summary
Sart DYe RappyResYyK41p) Pmpp>m In Fomxtlon l4)
1O23n002
9S• 81er1 WY Tap Oqq 81N1) am815e1 L1nYrofYtla 6ytlem Vd pbnl>el) Yal Slvryla611
1 10.23•e0D2 10,0084 10.018.0
Des urT: e.14a4
Mandrel Inserts
31
.a
T
R Twi,,sal sea) Y D) 1 WMe Yoad W yM, valla
Weal Type
Led pylaW 1R11Rw
Type W6 tun Dau eyn
1 2W-2 2,192.) CPA1C0 K8G2- 1 GPS LIFT DMY
INT 0 0.000 0.0 6115n002
9
casun: 9.4]1.4
2 .fi 3,801.2 CAMCO 1036-2- 1 CNS DFT DMY
9
INT 0.000 0.0 L152002
8,15fi.4 4,807.4 GAMDD PBG -2- 1 GAS LIFT 3M–Y—
INT 0.000 0.0 iR62005
9
4 9,421.6 5A039 CAMCO KBG72- 1 GAS LIFT DMY
INT 0.000 0.0 1W1](1002
9
a.EEYEc: Dan,
NOEea' General &Safely
Fna DHe
AnpWon
XIDDIE; S,I9)a
11 10
NOTE: VIEW SCHEMATIC w/Alaska SdanNk9.0
InuTon AS>1] _
QFpLn66y: B.SttA
IPERF', 1p.We610.p+ep
fRRD, t0,W90
fWOMKTpH S4Y1.S0_
0511': i)0.10,IR5
• i
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday,August 24,2016
TO:
Jim Regg
P.I.Supervisor 7e g qz5 i!0 SUBJECT: Mechanical Integrity Tests
L CONOCOPHILLIPS ALASKA INC
2P-427
FROM: Brian Bixby KUPARUK RIV U MELT 2P-427
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U MELT 2P-427 API Well Number 50-103-20408-00-00 Inspector Name: Brian Bixby
Permit Number: 202-018-0 Inspection Date: 8/20/2016
Insp Num: mitBDB160824134314
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
Well 2P-427 Type Inj ®TVD 5455 Tubing 2425 1 2425 - 2425 - 2425 -
PTD 2020180 Type Test SPT'Test psi 2900 - IA 2915 3300 - 3270- 3270
Interval REQVAR P/F P ✓ OA 365 365 - 364 365
Notes: AIO-21B.Second test-repressured after valve stem repair.
SCANNED MAY 92017
Wednesday,August 24,2016 Page 1 of 1
• •
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
To Jim Regg z-15 116 DATE: Wednesday,August 24,2016
P.I.Supervisor 1 SUBJECT:Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2P-427
FROM: Brian Bixby KUPARUK RIV U MELT 2P-427
Petroleum Inspector
Src: Inspector
Reviewed By:
P.I.Supry J&2--
NON-CONFIDENTIAL Comm
Well Name KUPARUK RIV U MELT 2P-427 API Well Number 50-103-20408-00-00 Inspector Name: Brian Bixby
Permit Number: 202-018-0 Inspection Date: 8/20/2016
Insp Num: mitBDB160821043651
Rel Insp Num:
Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min
-- — � —: --- - ----
Well 2P-427 ' Type Inj G "TVD 5455 Tubing 2425 2425 • 2425
PTD 2020180 - Type Test SPT Test psi 2900 - IA 1580 3310 3050 -
Interval REQVAR P/F I ✓ OA 361 364 364.
Notes: AIO-21B First test.Noticed a leak on the test equipment on a needle valve.Fixed and pressured back up to 3300 and held for 30 minutes
(see mitBJJ 160824134314).
SCANNED MAY 19 2 0 P ;
Wednesday,August 24,2016 Page 1 of 1
STATE OF ALASKA
AL .(A OIL AND GAS CONSERVATION COMIviISSION
REPORT OF SUNDRY WELL OPERATIONS
1 Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r
Performed Suspend r Perforate
r Other Stimulate r Alter Casing r Change Approved Program r'-
Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Logging
2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development r Exploratory r 202-018
3.Address: 6.API Number:
P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20408-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL 0389058/373112 KRU 2P-427
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s):
TMD3D Water Flow log Kuparuk River Field/Meltwater Oil Pool
11 Present Well Condition Summary:
Total Depth measured 10402 feet Plugs(measured) None
true vertical 5854 feet Junk(measured) None
Effective Depth measured 10045 feet Packer(measured) none
true vertical 5697 feet (true vertical) none
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 90 16 120 120
SURFACE 2999 7.625 3030 2380
PRODUCTION 10112 5.5 10140 5739
RLGEPtikr
JUN 1 9
Perforation depth. Measured depth: 9645-9735, 10008-10018
True Vertical Depth. 5510-5554, 5680-5685 ,(-�
cope
J L. Zl i5
Tubing(size,grade,MD,and TVD) 3.5, L-80, 9534 MD, 5457 TVD "P"' -
Packers&SSSV(type,MD,and TVD) no packer
NIPPLE-CAMCO DS NIPPLE NO GO PROFILE @ 532 MD and 532 TVD
12.Stimulation or cement squeeze summary:
Intervals treated(measured): no stimulation or cement squeeze during this operation
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 640
Subsequent to operation 550
14.Attachments(required per 20 AAC 25 070,25 071,&25 283) 15.Well Class after work:
Daily Report of Well Operations IV Exploratory r Development IF Service r Stratigraphic r
Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r
Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ J7 SUSP r- SPLUG r
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.
314-644
Contact Kasper Kowalewski @ 265-1363 Email Kasper.Kowalewski(a�conocophillips.com
Printed Name Kasper Kowalewski Title Sr. Drillsite Petroleum Engineer
Signature / ' Phone:265-1363 Date G 18 ( 1c
V �/i 4/`� RBDMSA-� JUN 5 1015
a/ice/rs"
Form 10-404 Revised 5/2015 Submit Original Only
y^ ✓ ,� KUP INJ 2P-427
Conoc hiIIips Well Attributes Max Angle&MD TD
Alaska,Inc. Wellbore API/UWI Reid Name Wellbore Statusncl(1 MD(ftKB) Act Btm(ftKB)
f,,,,,I,Mr. 501032040800 MELTWATER INJ 1 64.34 10,300.49 10,402.0
... Comment H2S(ppm) Date -Annotation End Date KB-Grd(ft) Rig Release Date
2P427,5/3/201510.59.02 AM SSSV:WRDP Last WO: 37.10 5/19/2002
Vertical schematic(actual)
Annotation Depth(ftKB) End Date Annotation Last Mod By End Date
Casing 1;0.9 Last Tag:SLM 10,010.0 2/10/2015 Rev Reason:SET INJ VALVE hipshkf 5/3/2015
.....HANGER.25.7 Illi ..
Casing Strings
! Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
CONDUCTOR 16 15.052 30.0 120.0 120.0 62.60 WELDED
li € lj Casing Description OD(in) ID tin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread
SURFACE 75/8 6.875 30.6 3,029.6 2,380.0 29.70 L-80 BTCMOD
Casing Description OD(in) ID(In) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread
YA P OOD41 CTION 5.5"x3.5' 5 12 4.950 27.9 10,139.5 5,739.0 15.50 L-80 BTCMOD
• .,,, ,. ,., •• naa.Tubing Strings
Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection
TUBING 31/2 2.992 25.7 9,534.4 5,456.8 9.30 L-80 EUE-8rd
Completion Details
Nominal ID
Top(11Ke) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in)
•
•
• 25.7 25.7 0.00 HANGER FMC HANGER 3.500
CONDUCTOR-30.0-120.0. A 532.4 532.1 5.21 NIPPLE CAMCO DS NIPPLE NO GO PROFILE 2.875
9,471.1 5,426.9 62.21 SLEEVE-C BAKER CMU SLIDING SLEEVE 2.813
NIPPLE;532.4 9,487.1 5,434.4 62.01 NIPPLE CAMCO D NIPPLE 2.750
VALVE;532.4
iiii I 9,531.7 5,455.4 61.48 LOCATOR BAKER LOCATOR 3.000
9,532.4 5,455 8 61.47 SEAL ASSY BAKER GBH-22 SEAL ASSY 3.000
Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.)
Top(ND) Top Incl
Top(ftKB) (ftKB) (') Des Com Run Date ID(in)
532.4- 532.0 5.21 VALVE 2.875 C-LOCK w/A-1 INJ VALVE(.910 BEAN, 5/2/2015 1.094
OAL=44")
GAS LIFT;2,629.21111
Perforations&Slots
Shot
Dens
Top(TVD) Elm(ND) (shots/f
Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com
9,645.0 9,735.0 5,510.2 5,554.0 T-3,2P-427 4/23/2007 6.0 APERF 2.5"HSD GUNS w/2506
PJ Chgs
10,008.0 10,018.0 5,680.1 5,684.7 1-3,2P-427 10/19/2002 6.0 (PERF 2.5"HSD,JH RDX 2506
SURFACE;30.6.3,0290-- Chgs,60 deg phase,
random orient
�--+ Stimulations&Treatments
GAS LIFT;6.046.6 . 'a Min Top Max Btm
Depth Depth Top(ND) Btm(ND)
(ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn
10,008.0 10,018.0 5,680.1 5,684.7 FRAC 10/23/200
2
Mandrel Inserts
GAS LIFT;8,156.4 St
ati
on Top(ND) Valve Latch Port Size TRO Run
6. N Top(ftKB) (ftKB) Make Model OD(In) Sew Type Type (in) (psi) Run Date Com
1' 2,629.2 2,192.7 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/15/2002
---,,,��s 2 6,046.6 3,801.2 CAMCO KBG-2- 1 GAS UFT DMY INT 0.000 0.0 5/15/2002
GAS LIFT;9,421.6
E. 3 8,156.4 4,807.4 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 2/26/2005
9
4 9,421.6 5,403.9 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 10/17/2002
I 9 I I I
Notes:General&Safety
SLEEVE-C;9,471.1 End Date Annotation
1122/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
NIPPLE;9,487.1
LOCATOR;9,531.7
SEAL ASSY;9,532.4
I
APERF,9.6450-9,735.0 r
FRAC;10,008.0
(PERF;10,1x18.0-10,018.0_ _I
PRODUCTION 55-x3.5'e
9541';27.9.10,139.5
2P-427 WELL WORK SUMMARY
DATE SUMMARY
2/8/2015 Load tubing with 30 bbls 180*f diesel, 290 bbls seawater, 30 bbls 180*f diesel
freeze protect(Job Complete)
2/10/2015 DRIFT W/2.85" G-RING TO A-1 @ 532' RKB; PULLED A-1 INJ. VLV @ SAME.
TAGGED TD @ 10010' SLM (EST. 27' RATHOLE). TAGGED @ SAME W/TMD3D
DMY DRIFT. READY FOR E-LINE
3/27/2015 PERFORM WATER FLOW LOG AT 500 PSI, 0,5 BPM AND 1000 PSI, 3 BPM.
UNABLE TO CONTINUE DUE TO TOOL ISSUES. LAY DOWN FOR NIGHT, WILL
CONTINUE FOLLOWING DAY TO LOG AT 750, 1250 AND 1500 WHIP. LOG
CORRELATED TO SLB CBL DATED MAR. 1, 2005. JOB IN PROGRESS.
3/28/2015 PERFORM IMPULSE TESTS WITH TMD3D TOOLSTRING AT 9640', 9600'AND
9100' INJECTING SEA WATER AT WHIP OF 750 PSI, 1250 PSI AND 1500 PSI.
UP FLOW WAS NOT OBSERVED DURING LOGGING. LOG CORRELATED TO
SLB CBL DATED MAR, 1 2005. JOB COMPLETE.
4/17/2015 PERFORMED A TMD3D WATERFLOW LOG WITH IMPULSE TESTS AT 8100,
8600, 9100, 9600, AND 9640 WITH THE TUBING AT 600 PSI WITH THE PUMPS
OFF. IMPULSE TESTS AT 8100, 9098, 9598, AND 9640 WITH LRS PUMPING
MINIMUM RATE OF .5 BPM AT 750 PSI. IMPULSE TESTS AT 9096, 9596, AND
9636 WITH LRS PUMPING 3.2 BPM AT 1000 PSI. IMPULSE TESTS AT 9094,
9594, AND 9634 WITH LRS PUMPING 4.8 BPM AT 1500 PSI. NO UP FLOW
FOUND DURING ANY OF THE IMPULSE TESTS WHILE PUMPING. UP FLOW
FOUND AT 600 PSI WHIP WHICH IS LIKELY FROM FLUID MIGRATION FROM
HIGH GAS PRESSURE. JOB COMPLETE.
5/2/2015 SET 2.875" C-LOCK W/A-1 INJ VALVE (.913 BEAN) @ 532' RKB (GOOD
CLOSURE TEST), JOB COMPLETE
2.o 2-okb
2-57 Q,5
WELL LOG TRANSMITTAL
DATA LOGGED
M"K
�jBEtotND
To: Alaska Oil and Gas Conservation Comm. April 27, 2015
Attn.: Makana Bender
a
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501 N" i'r 0 ?01';
RE: TMD3D Oxygen Activation Log: 2P-427
Run Date: 4/17/2015
The technical data listed below is being submitted herewith. Please address any problems or
concerns to the attention of:
Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518
FRS_ANC@halliburton.com
2P-427
Digital Data in DLIS format, Digital Log file, Interpretation Report 1 CD Rom
50-103-20408-00
TMD3D Oxygen Activation Log (Processed Log) 1 Color Log
50-103-20408-00
7015
TMD3D Oxygen Activation Log (Field print) CANmvU �1� I 2 '� _ 1 Color Log
50-103-20408-00
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Halliburton
Wireline & Perforating
Attn: Fanny Sari
6900 Arctic Blvd.
Anchorage, Alaska 99518
Office: 907-275-2605
Fax: 907-273-3535
FRS_ANC@halliburton.com
6...eAtat
Date: Signed:
• •
L Or T1,
\ /7,� THE STATE
s Oil Gas
N ALAS 9Iervioo a 1 1IlSSIl
GOVERNOR SEAN PARNELL 333 West Seventh Avenue
OA, Q. Anchorage, Alaska 99501-3572
ALAS Main: 907.279.1433
Fax: 907.276.7542
SCOEV
Thomas Nenahlo
Drillsite Petroleum Engineer
ConocoPhillips Alaska, Inc. Q0)--01S1 D)-_01
P.O. Box 100360
Anchorage, AK 99510
Re: Kuparuk River Field, Meltwater Oil Pool, 2P-427
Sundry Number: 313-566
Dear Mr. Nenahlo:
Enclosed is the approved Application for Sundry Approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the
AOGCC an application for reconsideration. A request for reconsideration is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend.
Sincerely,
Cathy P. oerster
Chair, C mmissioner
DATED this U day of November, 2013.
Encl.
STATE OF ALASKA �,(
•SKA OIL AND GAS CONSERVATION COMM ON 4cL-/ OC1 2 5 2013
APPLICATION FOR SUNDRY APPROVALS �V
20 AAC 25.280 ,a
1.Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell r Change Approved o
Suspend r Rug Perf orations r Perforate r Pull Tubing r Time Extension r
Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Logging W
2.Operator Name: 4.Current Well Class: N..J 5.Permit to Drill Number:
ConocoPhillips Alaska,Inc. Exploratory Vw Development r 202-018
3.Address: 6.API Number:
Stratigraphic r Service
P.O.Box 100360,Anchorage,Alaska 99510 C,bt•••j 50-103-20408-00
7.If perforating, What 8.Well Name and Number:
Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require spacing exception? Yes 1r No r 2P-427
9.Property Designation(Lease Number): 10.Field/Pool(s):
ADL0389058IADL0373112 Kuparuk River Field/Meltwater Oil Pool
11. PRESENT WELL CONDITION SUMMARY
Total depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured):
10402 5854
Casing Length Size MD ND Burst Collapse
CONDUCTOR 90 16 120' 120'
SURFACE 2999 7 5/8 3030' 2380'
PRODUCTION 10112 51/2 10140' 5739'
Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
9645-9735, 10008-10018 5509-5554,5680-5685 3.5 L-80 9534
Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft)
SEAL ASSY-BAKER GBH-22 SEAL ASSY MD=9532 ND=5456
12.Attachments: Description Summary of Proposal Fj 13. Well Class after proposed work:
Detailed Operations Program p BOP Sketch r Exploratory r Stratigraphic r Development r Service F
14.Estimated Date for Commencing Operations: 15. Well Status after proposed work:
2/1/2014 Oil r Gas r WDSPL r Suspended r
16.Verbal Approval: Date: VVINJ r GINJ p WAG r Abandoned r
Commission Representative: GSTOR r SPLUG r
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tommy Nenahlo
Email: Thomas.L.Nenahlo(a�cop.com
Printed Name Thomas Nenahlo Title: Drillsite Petroleum Engineer
Signature ,,�1 Phone:265-6934 Date:10/25/2013
l� Commission Use Only
Sundry Number:
Conditions of approval: Notify Commission so that a representative may witness 3V3"5 A1��
Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RBDMS NOV 1 ¶ZIii
0
Other: Li
14Q,,, i-o o per", Nl at60la44 c2 pv/ri, DLO zi,4. 00 3
Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: / O — / c /(
APPROVED BY (Q `f�
Approved by: COMMISSIONER THE COMMISSION Date: )1y p
Ap rov a
I I tV I J d H 2 months trom the date of approval.
Form 10-403(Revised 10/242)
COI-4 IC/Vito 12 Submit Form and Attachments in Duplicate
• • R E
OCT 17 2013
INV
ConocoPhillips AOGCC
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
October 17th, 2013
Chris Wallace
Alaska Oil and Gas Conservation Commission
333 West 7 th Avenue, Suite 100
Anchorage,AK 99501
SUBJECT: Requests for Administrative and Sundry Approvals for Meltwater
Surveillance Initiatives
Dear Mr. Wallace:
As discussed in the meeting held on September 26th, 2013, between the Alaska Oil and
Gas Conservation Commission(AOGCC) and ConocoPhillips Alaska, Inc. (CPAI), the
Meltwater team is pursuing a number of surveillance initiatives to aid in the
characterization and understanding of the Meltwater shallow gas issue while collecting
further data for the evaluation of development options.
Attached within this communication are the technical justifications for the necessary
administrative and sundry approvals to achieve the objectives of these surveillance
initiatives.
The surveillance initiatives that are currently being pursued are as follows:
• An extended outer annulus bleed at well 2P-431
o Pertaining to this initiative, please find a request for Administrative
Approval via Rule 10, Area Injection Order 21A (Amended), for
Meltwater production well 2P-431 (PTD 202-053) in regard to Rule 3
(annular pressure limits). Also enclosed is an Application for Sundry
Approval (10-403) for authorizing annular flow from 2P-431.
• Video and Spectra-Flow®logging at wells 2P-419, 2P-420, 2P-427, 2P-429, 2P-
434, 2P-447
o Pertaining to this initiative, please find a request for Administrative
Approval via Rule 10, Area Injection Order 21A(Amended), for
Meltwater injection wells 2P-419 (PTD# 204-017), 2P-420 (PTD# 201-
182), 2P-427 (PTD#202-018), 2P-429 (PTD# 201-102), 2P-434 (PTD#
203-153), 2P-447 (PTD# 203-154) in regards to Rule 7 (authorized
injection pressure) and Rule 8 (authorized fluids for injection).
Please call Tommy Nenahlo at 265-6934, or me at 265-1464 if you have any questions.
•
•
ConocoPh i l h s
p
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
Sincerely,
Jerry Dethlefs
ConocoPhillips
Well Integrity Director
e %
Tommy Nenahlo
ConocoPhillips
Meltwater Drill Site Petroleum Engineer
Enclosures:
Technical Justification for Administrative Relief Requests
Application for Sundry Approval
Wellbore Schematic
• •
ConocoPhillips Alaska,Inc.
Kuparuk River Unit
Meltwater Pool Injection Wells
Technical Justification for Administrative Relief Request,AIO 21A,from Rules 7 and 8
Purpose
ConocoPhillips Alaska,Inc. (CPAI)requests that the AOGCC approve this Administrative Relief as per
Area Injection Order(AIO)21A(Amended),Rule 10,for temporary relief from criteria set forth in Rules
7 and 8 that defines the authorized pressure and fluids for injection, respectively. CPAI requests
temporary relief from these rules to conduct video and Spectra Flow®logging on six Meltwater injectors,
2P-419(PTD#204-017),2P-420 (PTD#201-182),2P-427 (PTD#202-018),2P-429(PTD#201-102),2P-
434 (PTD#203-153),and 2P-447(PTD#203-154). By conducting video logging on these injectors,the
Meltwater team is looking to inspect possible collapsed liner, as has been indicated by recent and historic
well work. By conducting Spectra Flow® logging,the Meltwater team is looking to determine if there
is fluid movement around the production casing cement shoe over a range of sand face injection
pressures.
Video Logging Campaign Summary
During recent and historic well work,indications of potentially collapsed liner in injectors 2P-419,2P-
420,2P-429,2P-434, and 2P-447 have arisen. In a number of these injectors it is believed that these
potential collapsed liner locations are limiting our injection into the Bermuda formation. To aid in
characterizing and understanding these potential collapsed liner locations,as well as to formulate a plan
to remediate this issue, it is necessary to run video logs to inspect the locations.
To safely execute a video log on a miscible injectant(MI) injector it is necessary to adequately displace
the near wellbore formation to ensure that MI returns are not taken to surface. Therefore, it is
recommended that the near wellbore formation be displaced with a minimum three tubing volumes of
hot diesel. Upon adequately displacing the near wellbore formation,the video log will be run while
injecting filtered sea water to allow for the optimum video resolution to inspect these potential collapsed
liner locations.
The ability to provide a sufficient injection rate at Meltwater is critical as it is necessary to ensure that
adequate lift gas temperatures are maintained at the Meltwater's Drill Site,2P. Drill Site 2P is located
approximately twelve miles from the nearest drill site,2N. This distance provides a significant amount
of time for cooling of the MI that is used as injection fluid as well as a lift gas for the producers.
During winter months and low injection rate periods,the temperature of the lift gas has historically
become low enough to cause rapid paraffin deposition in the upper wellbore of the producers and can
choke flow to a point at which the well would need to be shut in. If enough production is shut in the
temperature of the Meltwater produced oil line could become low enough to require it to be shut in and
de-inventoried to mitigate the potential for the line to freeze. In 2012,modeling was completed to
determine the minimum MI gas delivery temperature at Meltwater to ensure that this issue can be
mitigated. As anticipated,the variable with the greatest effect on the MI gas delivery temperature at
Meltwater is the MI injection rate. By completing video logs on these potential collapsed liner
locations to aid in developing a remediation strategy it is believed that this risk of low lift gas
temperature and a produced oil line freezing scenario can be reduced.
To successfully complete this video logging campaign,temporary relief from AIO 21A(Amended)
Rules 7 and 8 is requested to adequately displace the formation and conduct these video logs.
CPAI Well Integrity Director 10/17/2013
• •
Spectra Flow° Logging Campaign Summary
To successfully complete this Spectra Flow®logging campaign,temporary relief from AIO 21A
(Amended)Rule 8 is requested to allow for the temporary injection of sea water into the Bermuda
formation. Sea water is not an authorized injection fluid in AIO 21A(Amended).
The Halliburton®Spectra-Flow logging technology is capable of identifying fluid movement around the
production casing shoe by identifying the presence of oxygen. Sea water will provide the oxygen in the
injection fluid to ensure the logging campaign can be completed successfully.
To achieve the most information from the logging campaign,temporary relief from AIO 21A(Amended)
Rule 7 is requested for exceeding the established pressure limit during injection of sea water into the
Bermuda formation while logging. The Meltwater team would like to vary the injection pressures of the
sea water while performing Spectra Flow®logging runs to complete the following objectives:
1. To confirm there is not fluid movement around the production casing shoe when injecting within
the sand face injection pressure limit established by Rule 7 in AIO 21A(Amended).
2. To determine if MI migration is a result of historic sand face injection pressures at Meltwater
prior to the issuance of AIO 21A(Amended).
The second objective stated above is intended to further the Meltwater team's understanding of the MI
migration mechanism. As discussed in the November 2012 hearing with the AOGCC,the Meltwater
team proposed two potential MI migration mechanisms. One of these migration mechanisms includes the
possibility of MI migration around the production casing cement shoe.
By completing the aforementioned objectives,the Meltwater team will be able to make more informed
decisions to ensure the field is operated safely and effectively.
Video and Spectra Flow®w®Logging Procedure Outline
The following is an outline of the procedure for the proposed Spectra Flow®Logging campaign to be
performed on each of the six injectors.
1. Displace the near wellbore formation with a minimum three tubing volumes of hot diesel to
mitigate the risk of taking MI returns at surface during well work operations.
o Injection pressure at surface not to exceed 2,495 psig with diesel(4475 psig
at perf depth assuming 0.36 psi/ft gradient and 5,500 ft TVD to mid-perfs)
2. Rig up E-Line with Spectra-Flow®Logging tools and IPROF string to monitor bottomhole
conditions.
3. Little Red Services(LRS)to pump sea water down on well using a step rate approach as defined
below. During each step,the Spectra-Flow®logging tool will be passed up and down to identify
the possible height of injected fluid above the perforations.
a. Step 1: 500 psi WHIP (2975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD
to mid-perfs)
b. Step 2: 750 psi WHIP (3225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft TVD
to mid-perfs)
c. Step 3: 1,000 psi WHIP (3475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft
TVD to mid-perfs)\
d. Step 4: 1,250 psi WHIP (3725 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft
TVD to mid-perfs)
e. Step 5: 1,500 psi WHIP(3975 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft
TVD to mid-perfs)
CPAI Well Integrity Director 10/17/2013 2
• •
f. Step 6: 1,750 psi WHIP(4225 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft
TVD to mid-perfs)
g. Step 7: 2,000 psi WHIP(4475 psi at perf depth assuming 0.45 psi/ft gradient and 5,500 ft
TVD to mid-perfs)
4. Upon completion of the step rate logging runs,E-Line and LRS will rig down and move off the
well.
5. Injection of seawater will cease on each individual well after the logging runs are completed.
6. The well bores will then be freeze protected with the injection of hot diesel with the injection
pressure at surface not to exceed 2,495 psig(4475 psig at perf depth assuming 0.36 psi/ft gradient
and 5,500 ft TVD to mid-perfs)
Administrative Approval Request:
CPAI requests temporary relief from(AIO)21A(Amended),Rules 7 and 8 to conduct Video and Spectra
Flow®logging on six Meltwater injectors:
2P-419(PTD#204-017),
2P-420(PTD#201-182),
2P-427(PTD#202-018),
2P-429(PTD#201-102),
2P-434(PTD#203-153),
2P-447(PTD#203-154).
1. Temporary relief from AIO 21A(Amended)Rule 7 is requested for exceeding the pressure limit
during injection of sea water into the Bermuda formation during the logging operations only. The
approval is requested for a period of six months from the date of the AOGCC approval.
2. Temporary relief from AIO 21A(Amended)Rule 8 is requested to allow for injection of sea water
into the Bermuda formation for the purposes of performing the logging operations only. The
approval is requested for a period of six months from the date of the AOGCC approval.
CPAI Well Integrity Director 10/17/2013 3
• • •
ConocoPhillips
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
October 25th, 2013
Chris Wallace
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue, Suite 100
Anchorage, AK 99501
RE: Response to Questions Regarding Requests for Administrative and Sundry Approvals for
Meltwater Surveillance Initiatives
Dear Mr. Wallace:
Thank you for your reply regarding our requests for Administrative and Sundry Approvals for the
Meltwater surveillance initiatives. Please find below the responses to your questions in your
emails that were sent October 22nd, 2013.
Injected Volumes and Duration
Per the plan developed by the Meltwater team, it is expected that no more than 6,000 barrels of
Beaufort seawater will be required to be injected at each injector to complete the video and
Spectra-Flow®logging initiatives. This estimate of 6,000 total barrels includes the procedures to
complete the miscible injectant displacement, video logging, and Spectra-Flow® logging
procedures. Below is a high level breakdown of this estimate for clarity:
• Displacement volume estimate: 1,000 BBLs of seawater per well
o This is volume that we may need during the video and/or Spectra-Flow®logging
campaign to mitigate the potential for having miscible injectant present in the
wellbore.
• Video Logging volume estimate: 1,600 BBLs of seawater per well
o To minimize the turbidity of the fluid, and thus increase our video resolution at the
potential collapsed liner locations, filtered seawater will be used to displace the
wellbore and ensure it remains displaced throughout the video logging
procedure.
• Spectra-Flow®Logging volume estimate: 3,400 BBLs of seawater per well
o This estimated volume of 3,400 BBLs is planned to be split evenly amongst the
seven pressure stages outlined in the Technical Justification for Administrative
Relief Request, AIO 21A(Amended), from Rules 7 and 8, that was submitted to
the AOGCC on October 17th, 2013.
o It is preferred that seawater be used for the Spectra-Flow®logging as upright
tanks will be on location at Drill Site 2P to store the seawater that will support the
aforementioned video logging. Operationally, it is preferred that Kuparuk
produced water be kept separated from seawater due to corrosion concerns.
The above logging initiatives may require up to 168 hours(7 days)to complete, per well.
• •
Conoco Phillips
Alaska
P.O. BOX 100360
ANCHORAGE,ALASKA 99510-0360
Beaufort Seawater Compatibility Study
A Meltwater field fluid sensitivity and stimulation study was completed in March of 2001. This
study utilized core samples from the Meltwater North #1 and Meltwater North#2 wells that
included an investigation into the sensitivity of preserved reservoir samples to the proposed flood
waters. These proposed flood waters included a Kuparuk produced water blend and a 75%
Kuparuk produced water/25% Beaufort seawater blend.
The investigation into the sensitivity of the Meltwater North#1 and Meltwater North#2 core
samples to the proposed flood waters concluded that there were no adverse reactions to the75%
Kuparuk produced water/25% Beaufort seawater blend identified.
The Meltwater team plans to inject 100% Beaufort seawater to minimize the turbidity of the fluid
while conducting video logging. Although we do not have fluid sensitivity studies completed with
100% Beaufort seawater, the salinities of the Kuparuk produced water and the Beaufort seawater
are similar, and no appreciable compatibility problems for either the Meltwater formation or its
confining zones are expected. If injectors do incur damage from sea water injection the damage
will be contained within a small radius of the wellbore due to the small volume of fluid required to
complete the logging initiatives. Any damage to the near wellbore formation that may arise can
be reversed by employing remedial treatments.
Sundry Requests
Attached you will find six Application for Sundry Approvals, one for each of the six wells that we
are requesting approval to conduct video and Spectra-Flow logging.
If you require any further information, please do not hesitate, I would be more than happy to
address them for you.
Thanks,
Tommy Nenahlo
Drill Site Petroleum Engineer
2T (Kuparuk&Tabasco)&2P (Meltwater)
North Slope Operations& Development
ConocoPhillips Alaska
Anchorage: (907) 265-6934
Mobile: (720)273-2685
Enclosures:
Applications for Sundry Approval (Quantity 6)
Wellbore Schematics (Quantity 6)
it • •
iii KUP 2P-427
Conoco'Phillips ' 1 \ WeII Attributes Max Angle&MD TD
Alaska,Inc. Wellbore API/UWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB)
501032040800 MELTWATER INJ 64.34 10,300.49 10,402.0
Conoc:oPhdlips
`' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date
"' _SSSV:WRDP Last WO: 37.10 5/19/2002
Well Config:-2P-427,7/18/2013 6:08:42 AM
Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod... End Date
Last Tag:RKB 10,027.0 9/16/2012 Rev Reason:SET INJ VALVE haggea 7/17/2013
Casing 2,4
Casing_Strings
Casing Description String 0... String ID... Top(ftKB) 'Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd
HANGER,26 OM :, /. CONDUCTOR 16 15.052 30.0 120.0 120.0 62.60 WELDED
..t. k Casing Description String 0... String ID... Top(ftKB) Set Depth(f... Set Depth(TVD)... String Wt... String... String Top Thrd
r SURFACE 7 5/8 6.875 305 3529.6 2,3793 29.70 L-80 BTCMOD
Casing Description String 0... String ID... Top(ftKB) Set Depth(t... Set Depth(TVD)... String Wt... String... String Top Thrd
PRODUCTION 512 4.950 27.9 10,139.5 5,738.9 15.50 L-80 BTCMOD
5.5"x3.5"@ 9541' I
• . • Tubing Strings
Tubing Description String 0... String ID... Top(ftKB) Set Depth(L..'Set Depth(TVD)...!String Wt... String...!String Top Thrd
TUBING I 31/2 2.992 25.7 9,534.4 5,456.8 j 9.30 L-80 j EUE-8rd
Completion Details
at Top Depth
(TVD) Top Intl Nomi...
Top(ftKB) (ftKB) (1 Item Description Comment ID(In)
25.7 253 -0.47 HANGER FMC HANGER 3500
532.4 532.1 5.21 NIPPLE CAMCO DS NIPPLE NO GO PROFILE 2575
CONDUCTOR, ,
30-120 9,471.1 5,426.8 61.75 SLEEVE-C BAKER CMU SLIDING SLEEVE 2.813
VALVE,532`
NIPPLE,532 9,487.1 5,434.3 61.66 NIPPLE CAMCO D NIPPLE 2.750
v..�. 9,531.7 5,455.4 61.41 LOCATOR BAKER LOCATOR 3.000
II 9,532.4 5,455.8 61.40 SEAL ASSY BAKER GBH-22 SEAL ASSY 3.000
Other In Hole(Wireline retrievable plugs,valves, pumps,fish,etc.)
Top Depth
(TVD) Top Inc!
GAS LIFT, Top(ftKB) (ftKB) 11 Description Comment Run Date ID(!n)
2,629 532.4 532.0 5.21 VALVE 2.875 C-LOCK w/A1 INJ VALVE(.913 BEAN) 7/7/2013 1.094
a■r Perforations&Slots
Shot
Top(TVD) Btm(TVD) Dens
f' Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh°• Type Comment
9,6455 9,735.0 5508.6 5554.0 T-3,2P-427 4/23/2007 65 APERF 2.5"HSD GUNS w/2506 PJ Chgs
SURFACE, 1 10508.0 10518.0 5580.1 5584.7 T-3,2P-427 10/19/2002 6.0 IPERF 2.5"HSD,JH RDX 2506 Chgs,60
31-3,030 deg phase,random orient
Stimulations&Treatments
III Bottom '
Min Top Max Btm Top Depth Depth
GAS LIFT, Depth Depth (TVD) (TVD)
6,047 (ftKB) (ftKB) (ftKB) (ftKB) Type Date _ Comment
IF 10,008.0, 10,018.0 5,680.1 5,684.7 FRAC 10/23/2002
Notes: General&Safety
End Date Annotation
11/22/2010 (NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0
GAS LIFT,
8,156
hlIL
GAS LIFT,
9,422
■
SLEEVE-C,
9,471
NIPPLE,9,487
■
II
LOCATOR,
9,532
SEAL ASSY, I'
9,532
Mandrel Details
Top Depth Top _ Port
S,.. (TVD) Inc! OD Valve Latch Size TRO Run
N... Top(ftKB) (ftKB) (°) Make Model (in) Set,/ Type Type (in) (psi) Run Date Com...
APERF, r - 1 2,629.2 2,192.7 62.49 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/15/2002
9,645-9,735 - - _
2 6,046.6 3,801.8 61.56 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/15/2002
IPERF,
10,008.1a,ots - -- 3 8,156.4 4,807.1 61.10 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 2/26/2005
FRAC,10,008 =
4 9,421.6 5,403.8 62.30 CAMCO KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 10/17/2002
II
PRODUCTION
5.55(3.5"5
9541',
28-10,140
TD,10,402
Hunt, Jennifer L (DOA)
From: Schwartz, Guy L (DOA)
Sent: Wednesday, June 26, 2013 12:39 PM
To: NSK Fieldwide Operations Supt
Cc: Hunt, Jennifer L (DOA)
Subject: RE: Meltwater SSSV Testing
I missed that one... thanks.Transposed with 2P-419 PTD too. Here is updated corrected wells and PTD's. So a total of
six wells.
Well PTD
2P-447 203-154
2P-419 204-017
2P-434 203-153
2P-427 202-018
7_
2P-420 201-1 2
2P-429 201-102
SCANNED FEB 2 0 2.014 Guy Schwartz
Senior Petroleum Engineer
AOGCC
907-444-3433 cell
907-793-1226 office
From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSupt @conocophillips.com]
Sent: Wednesday, June 26, 2013 12:30 PM
To: Schwartz, Guy L (DOA)
Subject: RE: Meltwater SSSV Testing
Guy,
We also have well 2P-447 as a WAG injector. I don't have the PTD number handy, but I do have the API number—
501032046800.
Thanks,
Larry
Larry Baker/Glynn Jones
NSK Fieldwide Operations Superintendent
N2072(a�ConocoPhillips.com
907-659-7042
Pager 659-7000 x604
From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov]
Sent: Wednesday, June 26, 2013 10:59 AM
To: NSK Fieldwide Operations Supt
Cc: Regg, James B (DOA); Ferguson, Victoria L(DOA); Hunt, Jennifer L (DOA)
Subject: [EXTERNAL]RE: Meltwater SSSV Testing
Larry,
1
After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ
(gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if
water is again available for injection on Meltwater the status can be reverted back to WAGIN.
The wells in our database that need to have status changed from WAGIN to GINJ are:
Well PTD
2P-419 203-154
2P-434 203-153
P-427 202-018
2P-420 201-182
2P-429 201-102
We will change status in our database today...
Guy Schwartz
Senior Petroleum Engineer
AOGCC
907-444-3433 cell
907-793-1226 office
From: NSK Fieldwide Operations Supt [mailto:NSKFieldwideOperationsSuptconocophillips.com]
Sent: Tuesday, June 25, 2013 4:35 PM
To: Schwartz, Guy L (DOA)
Subject: Meltwater SSSV Testing
Guy,
We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they
should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was
your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period.
We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well
classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test
is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or
report SSSV testing for DS-2P during the July pad SVS testing.
I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions.
Thanks,
Larry
Larry Baker/Glynn Jones
NSK Fieldwide Operations Superintendent
N2072 ci ConocoPhillips.com
907-659-7042
Pager 659-7000 x604
2
Hunt, Jennifer L (DOA)
From: Schwartz, Guy L (DOA)
Sent: Wednesday, June 26, 2013 11:26 AM
To: Hunt, Jennifer L (DOA)
Subject: meltwater wells status change WAGIN to GINJ
Put this in comments for 5 Meltwater wells:
Well status change to GINJ: No injection water available on Meltwater pad for foreseeable future. Well needs to have
SSSV tested every 6 months.
Guy Schwartz
Senior Petroleum Engineer
AOGCC
907-444-3433 cell
907-793-1226 office
1
Schwartz, Guy L (DOA)
From: Schwartz, Guy L(DOA)
Sent: Wednesday,June 26, 2013 10:59 AM
To: 'NSK Fieldwide Operations Supt'
Cc: 'Regg,James B (DOA) (jim.regg @alaska.gov)'; Ferguson,Victoria L(DOR); Hunt,Jennifer
L(DOA)
Subject: RE: Meltwater SSSV Testing
Larry,
After further discussion and thought it would be best to reclassify the WAG injection wells on the Meltwater pad to GINJ
(gas injector). The wells should be included in the upcoming SVS testing to be done in July. At some point in future if
water is again available for injection on Meltwater the status can be reverted back to WAGIN.
The wells in our database that need to have status changed from WAGIN to GINJ are:
Well PTD
2P-419 203-154
2P-434 203-153
2P-427 202-018Th
2P-420 201-182
2P-429 201-102
SCANNED FEB 2 0 2014
We will change status in our database today...
Guy Schwartz
Senior Petroleum Engineer
AOGCC
907-444-3433 cell
907-793-1226 office
From NSK Fieldwide Operations Supt [madltr) N-Ki lekiwid eOperat onsSu_pt d Ont a nphillips com]
Sent: Tuesday,June 25, 2013 4:35 PM
To: Schwartz, Guy L(DOA)
Subject: Meltwater SSSV Testing
Guy,
We talked several months ago about the well classification status of the Meltwater(DS-2P) injectors and whether they
should remain as WAG injectors or if we should change the well classification to GINJ. At that time you replied that it was
your preference to leave the well as a WAG well status even though it will stay on MI for an indefinite period.
We are going to perform the SVS testing for DS-2P in July and I just wanted to verify that you still wanted the well
classification to remain as WAG. Please confirm that DS-2P should remain classified as a WAG injector. As a SSSV test
is not required for a WAG injector, we also ask you to please confirm that we are not required to perform a SSSV test or
report SSSV testing for DS-2P during the July pad SVS testing.
I look forward to hearing back from you soon. Please feel free to call me at 659-7042 if you have any questions.
Thanks,
Larry
Larry Baker/Glynn Jones
NSK Fieldwide Operations Superintendent
1
•
MEMORANDUM
To: Jim Regg t~
P.I. Supervisor
FROM: Bob Noble
Petroleum Inspector
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Tuesday, August 10, 2010
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2P-427
KUPARUK RIV U MELT 2P-427
Src: Inspector
NON-CONFIDENTIAL
Reviewed By:
P.I. Suprv .,,.I~~'--
Comm
Well Name: KUPARUK RIV U MELT 2P-427 API Well Number: 50-103-2oao8-oo-0o Inspector Name: Bob Noble
Insp Num: mitRCN100809171812 Permit Number: 202-018-0 Inspection Date: 8/8/2010
Rel Insp Num:
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well ~ zP-az7 ' Type Inj. O ~ TVD 5455 ~ IA 1925 2600 ~ X2520 2520 ~
P.T.D 2020180 " TypeTest SPT Test psi ~ 2600 '~ OA ~ 675 676 676 ~ 676
InteYVa14YRTST p~F P Tubing 3100 3100 3100 3100
Notes: ~ ~~~ 1~Ps
M~ ~ ~ ~b
~, ,~~;~
-,
Tuesday, August 10, 2010 Page 1 of 1
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Mechanical Integrity Test
Email to:jim.regg~alaska.gov; phoebe.braoks~alaska.gov; tom.maurtder~ak~ska.gov; doa.aogcc.prudhce.bay@alaska.gov
OPERATOR:
FIELD /UNIT /PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Kuparuk /KRU / 2P
08/08/10
Colee /Coleman - AES
Robert Noble
Packer Pretest Initial 15 Min. 30 Min.
Well 2P-419 T In'. G ND 5,202' Tu ' 3,700 3,700 3,700 3,700 Interval 4
P.T.D. 2040170 T test P Test 1500 2,716 3,300 3,260 3,260 P/F P
Notes: OA 291 335 338 336
We11 2P-420 T In'. G ND 5,428' Tubi 3,050 3,050 Interval 4
P.T.D. 2011820 T test P Test 1500 Casi 1,850 1,769 P/F F
Notes: Pumped 13bbls. With no pressure increase. ~ OA 291 275
Well 2P-427 T In'. G ND 5,455 Tu " 3,100 3,100 3,100 3,100 Interval 4
P.T.D. 2020180 T test P Test 1500 1,925 2,600 2,520 2,520 P/F P
Notes: OA 675 676 676 676
Well 2P-429 T In . N ND 5,218' T 910 910 910 910 Interval 4
P.T.D. 2011020 T test P Test 1500 Casi 435 1,820 1,770 1,760 P/F P
Notes: OA 310 442 349 339
We11 2P-434 T In'. N ND 5,129` T 1,625 1,625 1,625 1,625 Interval 4
P.T.D. 2031530 T test P Test 1500 Casi 5 2,390 2,290 2,280 P/F P
Notes: OA i00 101 101 101
Well 2P-447 T In'. G ND 5,226' T 3,500 3,500 3,500 3,500 Interval 4
P.T.D. 2031540 T test P Test 1500 240 1,840 1,810 1,810 P/F P
Notes: OA 1175 1176 1195 1201
Well T In". TVD Tu[~i Interval
P.T.D. T test Test Casi P/F
Notes: OA
Well T In'. TVD Tu ' Interval
P.T.D. T test Test P/F
Notes: OA
-~(t~
TYPE INJ Codes TYPE TEST Codes r ' INTERVAL Codes
~~~~ .
D =Drilling Waste M =Annulus Monitoring br= S. ~ ~ ~'~ ~'' ~~~''~ ~'~" '~ I =Initial Test
G =Gas P =Standard Pressure Test 4 =Four Year Cycle
I =Industrial Wastewater R = Internal Radi~cWe Tracer Survey V =Required by Variance
N =Not Injecting A = Temperature l4rarrraly Survey T =Test during Workover
W =Water D =Differential Temperature Test O =Other (describe in notes)
MIT Report Form
BFL 11/27/07 MIT KRU 2P Pad 08-08-10.x1s
[t 2007
SC_._.er.II8P'//i("
NO. 4398
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
ê~
Field:
Well Job# Log Description Date BL
2H-02 11846438 INJECTION PROFILE l )ï:(' "'64-C)T-~ 08/21/07 1
2P·427 11846437 INJECTION PROFILE U I ~ ~(') ';4 - ~-7( 08/20/07 1
1A-07 11850429 INJECTION PROFILE ),(' I~/-137 08/22/07 1
10-08 11850427 SBHP SURVEY I~ -().ç~ 08/20/07 1
3A-09 11850426 GLS NI-ICjq 08/20/07 1
2W-09 11850428 INJECTION PROFILE U Ie. /1f4- Q''1 08/21/07 1
1 L-17 11839642 INJECTION PROFILE UTe' IC\ I-()~ 08/23/07 1
2M-13 11839643 PRODUCTION PROFILE 08/24/07 1
1G-04 11837494 INJECTION PROFILE U/(,~ I~ ~-J~I 08/24/07 1
2N-350 11839644 DDL AÖI - /~.< 08/25/07 1
2N-350 11839645 PMIT ,!J", I - .g ,<; 08/26/07
1A-05 11839646 INJECTION PROFILE (J1'" {'_ / ir I -fA'?! 08/27/07 1
2H-15 11837498 INJECTION PROFILE Ü::rc.. ~-r"SrC. 08/29/07 1
2A-04 11839649 INJECTION PROFILE ():r:C. 11rl.'- 05~~ 08/29/07 1
Kuparuk
Color
CD
1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
08/30107
.
.
1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D Other D
Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D
Change Approved Program D Opera!. ShutdownD Perforate 0. Re-enter Suspended Well D
2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc. Development D Exploratory D 202-018/ /"
3. Address: Stratigraphic D Service 0 6. API Number:
P. O. Box 100360, Anchorage, Alaska 99510 50-103-20408-00 /
7. KB Elevation (ft): 9. Well Name and Number:
RKB 27' / 2P-427 .,--
8. Property Designation: 10. Field/Pool(s):
ADL 37311Z& 389058: ALK 4998 Kuparuk River Field / Meltwater Oil Pool ,I
11. Present Well Condition Summary:
Total Depth measured 10402' ,I feet
true vertical 5854' / feet Plugs (measured)
Effective Depth measured 1 0052' feet Junk (measured)
true vertical 5700' feet
Casing Length Size MD TVD Burst Collapse
Structural
CONDUCTOR 83' 16" 120' 120'
SURFACE 3003' 7-5/8" 3030' 2380'
PRODUCTION 9514' 5-1/2" 9541' 5460'
LINER 599' 3-1/2" 10140' 5739'
Perforation depth: Measured depth: 9645'-9735',10008'-10018' SCANNEDJUN 1 4 2007
true vertical depth: 5510'-5554',5680'-5685' /
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9541' MD.
Packers & SSSV (type & measured depth) no packer
Cameo 'OS' nipple @ 532'
12. Stimulation or cement squeeze summary:
Intervals treated (measured) not applicable
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl Casino Pressure TubinQ Pressure
Prior to well operation na na 905 -- --
Subsequent to operation na na 1248 -- --
14. Attachments 15. Well Class after work:
Copies of Logs and Surveys run _ Exploratory D Development D Service 0 /
Daily Report of Well Operations _X 16. Well Status after proposed work:
OilD GasD WAG 0 / GINJD WINJD WDSPL D
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:
Contact John Peirce @ 265-6471
Printed Name John Peirce Title Wells Group Engineer >/1./01
Signature ~4.-WJ;;?_ Phone Date
- Prenarecl bv '::'haron AlIsu~nrak'" 263-4612
/ '-í-¡'" - ~ S"·2~·07
RECEIVE:U
. STATE OF ALASKA. MAY 0 3 2007
ALASKA OIL AND GAS CONSERVATION COMMISSION . . .
REPORT OF SUNDRY WELL OPERA TION~laska 011 & Gas Cons. CommIssIon
Form 10-404 Revised 04/2006 0 RIG 1 N A L
RBDMS 8Ft ,¡UN! :I. Z~su~in~i67
.
2P-427 Well Events Summary
.
DATE Summary
4/16/07 TAG @ 10,052' RKB, EST. 34' OF RATHOLE. DRIFT TBG w/29' x 2.71" BAR-BELL
DRIFT TO 9877' RKB. JOB COMPLETE.
4/23/07 PERFORATED 9645' - 9735' USING 21/2" HSD GUNS LOADED 6 SPF WITH 2506
POWERJET CHARGES, EH= 0.34", PEN.= 18.7"
~
TUBING
(0-9541,
00:3.500,
10:2.992)
SURFACE
(0-3030,
00:7.625,
Wt:29.70)
'ROOUCTION
(0-9541,
00:5.500,
Wt:15.50)
SLEEVE-C
(9471-9472,
00:4.500)
NIPPLE
(9487-9488,
00:4.500)
SEAL
(9531-9532,
00:4.500)
.
.
LINER -
(9541-10140, --..-.
00:3.500, .......--. .._n.....
Wt:9.30) - -
Perf --- --
(9645-9735) " ~
Perf +- ~
(10008-10018) t
FRAC
(10008-10018)
f-
KRU
2P-427
ConocoPhillips Alaska, Inc.
.
.. ...
Anole@TS: deo@
Anole @TD: 64 dea (!i¡ 10402
Rev Reason: TAG FILL, PERF
Last Undate: 4/25/2007
API: 501032040800 Well TVDe: INJ
SSSVTvoe: Ninnle Orin Comoletion: 5/19/2002
Annular Fluid: Last W/O:
Reference Loa: Ref Loa Date:
LastTaa: 10052' TD: 10402 ftKB
Descriotion Size Too Bottom TVD Wt Grade
CONDUCTOR 16.000 0 120 120 62.60
SURFACE 7.625 0 3030 2380 29.70 L-80 BTCMOD
PRODUCTION . 5.500 0 9541 5460 15.50 L-80 BTCMOD
3.500 9.30 L-80 _
Size Too Bottom TVD Wt Grade 1 Thread
3.500 I 0 I 9541
Interval TVD Zone Status Ft SPF Date Tvoe Comment
9645 - 9735 5510 - 5554 90 6 4/23/2007 APERF 2.5" HSD GUNS w/2506 PJ
Chos
10008 - 10018 5680 - 5685 10 6 10/19/2002 IPERF 2.5" HS~, JH RDX 2506 Chgs,
60deonnase.~andomorient
BillllIl_
I~t;;:;;ã¡~ment
10008 - 1001 I
St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv
Mfr Cmnt
2193 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 5/15/2002
3801 CAMCO KBG-2-9 DMY 1.0 DK-1 0.000 0 5/15/2002
4807 CAMCO KBG-2-9 DMY ~
5404 CAMCO KBG-2-9 DMY ~
TVD Tvoe Descriotion ID
532 NIPPLE CAMCO 'DS' PROFILE 2.875
5427 SLEEVE-C BAKER SLIDING SLEEVE W/DS PROFILE 2.813
5434 NIPPLE CAMCO NO GO 'D' NIPPLE 2.750
5455 SEAL BAKER GBH-22 LOCATED W/SEAL ASSEMBLY 3.000
Thread
1
2
3
4
2629
6046
8156
9421
Deoth
532
9471
9487
9531
Ç)
11/10/06
Sc~loIIIbepgep
NO. 4034
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
1 3 Z006
Company: Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
U3G..9òd-DI15
Field:
Kuparuk
Well
Job#
Log Description
Date
BL
Color
CD
1 R·26 11416225 INJECTION PROFILE 10/23106 1
1 R-22A 11416224 PROD PROFILE WIDEFT 10/22/06 1
2K,28 N/A INJECTION PROFILE 10/19/06 1
3G~09 11415642 PROD PROFILE WIDEFT 10/24/06 1
3G~16 11416226 INJECTION PROFILE 10/24/06 1
2P.427 11415637 INJECTION PROFILE 10/20/06 1
2P-429 11415640 INJECTION PROFILE 10/22/06 1
1J·101 11445123 GLS 11/06/06 1
2~432 11415644 INJECTION PROFILE 10/26/06 1
3G-09 11415645 PROD PROFILE WIDEFT 10/27/06 1
3K-19 11415648 INJECTION PROFILE 10/30/06 1
2W-12 11445122 PROD PROFILE W/DEFT 11/05/06 1
1 R-19A 11416228 INJECTION PROFILE 10/27/06 1
3J·05 1141630 INJECTION PROFILE 10/28/06 1
1 D-04 11445121 PROD PROFILE W/DEFT 11/04/06 1
30-07 11416222 INJECTION PROFILE 10/20/06 1
2N~305 11416223 FLOWING BHP SURVEY 10/31/06 1
3A-12 11445120 GLS 11/03/06 1
2L-311 11415649 FLOWING BHP SURVEY 10/31/06 1
21.:-313 11445119 FLOWING BHP SURVEY 11/02/06 1
2K.27 11416234 FLOWING BHP SURVEY 11/02/06 1
2L-307 11296734 FLOWING BHP SURVEY 11/04/06 1
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
.
.
e
Conoc~illips
Alaska
e
¡, .,. .....", ''''~ .':"",.~..,. ,II U1 0 h
J ;,J L "~' ~ - ..,
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
.;')
,,'"~
June 06, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AK 99501
~{;~i)'\1èD
{i r-
I i
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor by surface casing annulus. The voids that
were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining
volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter,
RG2401, then filled with a viscous hydrocarbon based sealant, Royfi1l404B, 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 cement top-fill operation was completed on May 05,2006. Schlumberger Well Services
mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and
sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call Marie McConnell or myself at 907-659-7224, if you have any questions.
Sincerely,
\(,.st.~6 d~
C:>6/~ 0 /06
Attachment
Ç\I'<'"'- 0 l 0
t)'.../ cI
e
e
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Kuparuk Field
June 6,2006
Well Initial top Vol. of cement Final top of Cement top
Name PTD # of cement um ed cement off date
ft bbls ft
)
ConocJPhillips
Alaska
"Ë' (""~' :'.~"'"""
. '~:b..
'..~ ..:;;71~\"·
JU ¡\Î ¡ .¡.,: 'ì
m~ '& ß¡¡¡S G,iJ¡üH,
Anrch:~r¡]@e
P.O. BOX 100360
ANCHORAGE, ALASKA 99510-0360
(!}D Q, .-() I t3
June 06, 2006
Mr. Tom Maunder
Alaska Oil & Gas Commission
333 West ih Avenue, Suite 100
Anchorage, AI< 99501
SCANN.ED JUN 2 '( 2006
Dear Mr. Maunder:
Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of
these wells was found to have a void in the conductor by surface casing annulus. The voids that
were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining
volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter,
RG2401, then filled with a viscous hydrocarbon based sealant, Royfi1l404B, 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 cement top-fill operation was completed on May 05,2006. Schlumberger Well Services
mixed 15.7 ppg Arcticset I in a blender tub. The cement was pumped into the conductor bottom
and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and
sealant were pumped in a similar manner on May 18th, 19th and 31 st, 2006. The attached
spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on
each conductor.
Please call Marie McConnell or myself at 907-659-7224, if you have any questions.
é
Attachment
)
)
ConocoPhillips Alaska Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Well
Name
: ~. . ','~'!..",
r:,;~¡r.;~~ø~r '
2P-41 5
t:·:·,{iíat,ftt'·, :'.. .
2P-419
~i'?~~P~Ði
2P-422
r:;, :¡2P~A;-'::":;; :":'
2P-427
..·.·.,2~9.:.'::··.'
2P-431
'.::2R~Z:,::,··,
2P-434
" ''':ìP~3f8<.:·! ';.'
2P-441
"'~~(:'>
2P-447
·'.:2ÞM3' .'~:
2P-449
'~2P~'1 .'
Kuparuk Field
June 6,2006
I nitial top
of cement
ft
. ,·,~f"..· ,
5.5
'7~5'
1
. ',. "3;'5:' "', :; :
13.5
"'4.5"·. '
10
"2:··.··
13
,8'.5.',: ~.', ~. .
14
5:···:',··;' .
15
. '.3.5'::
2.5
..... tS'
3
, 40
Vol. of cement Final top of Cement top
pumped cement off date
bbls ft
. .():.:O, " ".:4.aa.'
0.0 5.5 na
"ö~'1'< . >'2'.5 >'. :.·;:5J112006.·..
0.0 1 na
':'.0;0'" ':':'."3.5..'" '<ßå,:'
2.3 2.5 5/1/2006
.¡,' ,ø~,o·.:":,<' o;.:.4~5., '.'. . ',ne:":,"· .'
1.6 2.5 5/1/2006
. .....'1,... ,,' 'I. . .
, .,., .()~:Q:. . . " . ".:~2:\·::; ".' ".:oa;.... ',:. ,: : . ..'
1.9 2.5 5/1/2006
'O~9, ,. ,_ >2:'5':: .'~ :511/2(1Q6::: ~"
2.0 2.5 5/1/2006
·:oi.à:· , ,,: :"':':;5' . . ,:'nå':',,:.,
2.0 2.5 5/1/2006
. ,
. .. " '. G.O-: . , ·..E3~5.. .hä;::,',· :'J
0.0 2.5 na
. . '...O~O· ". ;:1·~:s'. .... "na ," ~
0.0 3 na
, 2~'1" . 2.5. ,·51.112006 .
RG2041 va; I
gal
- . ~.···5~:7 .
7.1
.,.;5".,7 .
6.7
" "·,·.::7~·t.·,· .
7.1
5~'7,,·, . "
7.1
3:.::8~ .
7.1
'.··.5~·7..:·,··,·
5.7
',::.5]>:- .
7.1
,··..,,8:.7:,
9.5
···9.5;'"
5.7
.:i1·
Royfill4048
vol.
Qal
~
. ". . t7.'1.· .
30.9
, ·,·9,;,··'
o
. . "1:,7:.3·,.: .
10.7
··t7~6: .
13.7
. ,5~:7 .
10.1
1:3.'8:' ,
6.2
"2t9',
13.1
:'1'1.4 .
o
0' '
11.5
'6~5 .
Corrosion
inhibitor/
sealant date
5/19/2006
'. .·,..·~5J1:S~0f16'
5/19/2006
': :',~8i2_':(
5/18/2006
.' ':. ...... .\5Þ1~~6::·;',::
5/18/2006
.' :,;5þf.8J2Ø06:: '.
5/18/2006
'.: r .,...:51:1812QUß.;".::;
5/18/2006
. .:$11__,;,:'",:
5/18/2006
. . .··.'5rt812Q06:.': .,;::
5/18/2006
, t. .',511812006' .-
5/18/2006
, '. r . .,51í~8I2006"'.·':'.
5/31/2006
:" 5r1;a¡2006 . ".
.
.
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc
MEMORANDUM
State of Alaska
TO:
)
Jim Regg 1?~Jt1 4/1-i/CÇ'
P.I. Supervisor (t
Alaska Oil and Gas Conservation Commis~' )
DATE: Monday, April 18, 2005
J,ðô--o~i
FROM:
Lou Grimaldi
Petroleum Inspector
SUBJECT: Mechanical Integrity Tests
CONOCOPHILLIPS ALASKA INC
2P-427
KUPARUK RIV U MELT 2P-427
Src: Inspector
Reviewed By:
P.I. Suprv Jß¡2-
Comm
Well Name: KUPARUK RIV U MELT 2P-427
Insp Num: mitLG050418073624
Rei Insp Num:
NON-CONFIDENTIAL
API Well Number: 50-103-20408-00-00
Permit Number: 202-018-0
Inspector Name: Lou Grimaldi
Inspection Date: 4/17/2005
Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min.
Well i 2P-427 Type Inj. G TVD 5455 IA 1940 1500 1520 1520 1520
P.T. I 2020180 TypeTest SPT Test psi 1363.75 OA 510 505 505 500 500
Interval INIT AL P/F P Tubing! 3000 3000 3010 3010 3010
Notes: IA left pressured up from previous test. Observed for thirty minutes in pretest condition. Bled IA down 440 psi (No gas present). Well tested
for additional 45 minutes.
'S'CANNED JUN <) 2 .2005
Monday, April 18, 2005
Page I of 1
) STATE OF ALASKA ')
ALASKA OIL AND GAS CONSERVATION COMMISSION /I)
Mechanical Integrity Test , . ~-' '{)t~
Email to:Tom_Maunder@admin.state.ak.us;BobJleckenstein@admin.state.ak.us;andJim_Regg@ad~te.ak.us
OPERATOR:
FIELD / UNIT / PAD:
DATE:
OPERATOR REP:
AOGCC REP:
ConocoPhillips Alaska Inc.
Meltwater / KRU/2P
04/17/05
Arend - ASRC
Lou Grimaldi
Packer Depth Pretest Initial 15 Min. 30 Min.
Well 2P-427 Type Inj G TV.D. 5455 Tubing 3000 3000 3000 3000 Interval
P.T.D. 2020180 Type Test P Test psi 1500 Casing 1940 1500 1520 1520 P/F P
Notes: Initial State Witnessed MIT - Completed a draw down test instead of a positive pressure test due to tubing
pressure.
Well Type Inj TV.D. Tubing Interval
P.T.D. Type Test T est psi 1500 Casing P/F
Notes:
Well Type Inj TV.D. Tubing Interval
P.TD. Type Test T est psi 1500 Casing P/F
Notes:
Well Type Inj TV.D. Tubing Interval
P.T.D. Type Test T est psi 1500 Casing P/F
Notes:
Well Type Inj T.V.D. Tubing Interval
P.T.D. Type Test T est psi 1500 Casing P/F
Notes:
Test Details:
SCANNE.D ¡~PH :rt 8 lO05
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
o = Other (describe in notes)
MIT Report Form
Revised: 05/19/02
MIT KRU 2P-427 04-17-05.xls
4/18/2005
) STATE OF ALASKA -)' ·RECEIVED
ALASKA OIL AND GAS CONSERVATION COMMISSI~I APR 11 2005
1 ,000mtiO.. P~rto~od:A~~dòn'gEPO~~~~~UN~~J¥~Z~L. O~:~~ 610~~Sk.o9A~~ ::C~ ~:;£~w~gøion
.. ;Alt~rq~sil;lgD BuIlTubin,gDPe1ora~~'Nev{Pool D· . Waiver D Time Extension ~I
·Çh~~9.~,~ppr()Y~9P.rdgrÇt~:D .... .·pþ~t,ät..$hlJtdoWnO<p~~o~WtJ· Re-enter Suspended Well D
2. Operator Name: 4, :CÙrtéút.\lVØIl:~tãtl.ls: . 5. Permit to Drill Number:
ConocoPhillips Alaska, Inc.[)evêI6prn~nt;;..'[]. 202-018
3. Address:.~ttäti~~áphiC .;.·IJ . 6. API Number:
P. O. Box 100360 50-103-20408-00
7. KB Elevation (ft): 9. Well Name and Number:
RKB 254' 2P-427
8. Property Designation:
Kuparuk River Unit
11. Present Well Condition Summary:
Total Depth
Effective Depth
Casing
Structural
CONDUCTOR
SURFACE
PRODUCTION
LINER
Perforation depth:
10. Field/Pool(s):
Kuparuk River Field 1 Meltwater Oil Pool
, .
measured 10402' feet
. true vertical 5854' feet
measured feet
true vertical 6276' feet
Length Size MD
120' 16" 120'
2776' 7-5/8" 3030'
9287' 5-1/2" 9541'
599' 3-1/2" 10140'
Plugs (measured)
Junk (measured)
TVD
Burst
Collapse
120'
2380'
5460'
5739'
Measured depth: 10008'-10018'
true vertical depth: 5680'-5685'
Tubing (size, grade, and measured depth) 3-1/2" , L-80, 9541' MD.
S(··{~~~H..i¡L.:~·'~ 1\'!)I:~ ~,')), "i: ')OU'lÇ
",h~"n\H:::::,tl,..1 H I> i' J.. too ,J
Packers & SSSV (type & measured depth) no packer
SSSV= NIPPLE SSSV= 532'
12.'Stimulatiohor, cèmèntsquéeze sumrnary:
I ntervalstreated(measured)
N/A
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production' or Injection Data
Oil-Bbl Gas-Met Water~Bbl Casinç¡Pressure Tubinç¡ Pressure
Prior to well operation 189 133 158 865 254
Subsequent to operation 13825 497 2529
14. Attachments 15. Well Class after proposed work:
Copies of Logs and Surveys run _ Exploratory D Development D Service 0
Daily Report of Well Operations _X 16. Well Status after proposed work:
oilD GasD WAG 0 GINJD WINJ D WDSPLD
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:
Contact
Form 10-404 Revised 04/2004
Signature
59-7535
Title
Phone
Production Engineering Technician
659-7535 Date f~S-
:\ I f1 ,
;\1.d
¡dJ-\L_
rl C¡
RBDMS 8Ft APR -rr ;t'2UUS\
(...... ~
:~.:'") j
Submit Original Only
-) . 2P-427 )
.' DESCRIPTION OF WORK COMPLETED
SUMMARY
Date Event Summary
4/1/200sICommenced WAG EOR Injection
Schlumberger
Schlumberger -DCS
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
A TTN: Beth
Well
Job #
/gJ:C4¡ 2U-12
ß:¡" /22. 2B-02
/"7'3 -ú 7730-07
rii-tJJ¿ 2V-15
2·c¥ -CC;"¡ 1 E-112
1.ú"J. ... fJ,t;' 2P-427
10942844
10922542
10922549
10922543
10922552
10922545
SIGNED:
Log Description
Date
¿;<D 2- - Ol<g'
03/15/05
NO. 3365
Company: Alaska Oil & Gas Cons Comm
Attn: Helen Warman
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Kuparuk
'_/
BL
Color
CD
PROD PROFILE/DEFT
PROD PROFILE/DEFT
INJECTION PROFILE
PROD PROFILE/DEFT
INJECTION PROFILE
SCMT
02/15/05
02/26/05
03/05/05
02/27/05
03/08/05
03/01105
1
1
1
1
1
1
'-
(______ /¡< í
Qð!~~- /'í /LÞ1Ar~
Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you.
3)~fo."
srAN- ~iEF' f\ pF,. < pc-, è'\no¡~
- '<de"- C \1 r.J!.cd ,d h" ". ~./ I 0 !<oJ, ,
--- ",. .. ..k U'- J'0
.
~(ëF, ír!Æi( ¡r rt'
tl ß I ¡ r
" i 1 ~ i ,t ¡ l
~, I >oJ ~
)
[ill} ~" 1"""11 ffi"~ r;;~1I 1\1' lã~
¡' r1 ~ ¡ I 11'\ \ ! f lA '¡ ~i\~ 'Y, f, ;1',/ i.u\ \
II, 1 U r HI 'I', ðU
r U, ! 'l-; ¡ ¡ ¡ , i; l <, \ ff iü ~
\ i.' ~ t......::J ' u L! u
)
h~ -tJ(l
AIfASIiA. OIL AlVD GAS
CONSERVATION COMMISSION
,/
/
/
I
/
FRANK H. MURKOWSKI, GOVERNOR
333 W. ]TH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Robert Christensen
Production Engineering Technician
ConocoPhillips Alaska, Inc.
P.O. Box 100360
Anchorage, Alaska
Re: Kuparuk 2P-427
Sundry Number: 305-057
Dear Mr. Christensen:
Enclosed is the approved Application for Sundry Approval relating to the above
referenced well. Please note the conditions of approval set out in the enclosed form.
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).
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such
further time as the Commission grants for good cause shown, a person affected by it may
file with the Commission an application for rehearing. A request for rehearing is
considered timely if it is received by 4:30 PM on the 23rd day following the date of this
letter, or the next working day if the 23rd day falls on a liday or weekend. A person
may not appeal a Commission decision to Superior ou1: unless rehearing has been
requested.
{ Si
DATED this 't'" day of March, 2005
Encl.
~f' f.;.i"'ii\.ijE.¡r-l~" ¡H1 i1 D 1 G" 2nl O~~
~,JI"",~,n~~~ ~ .' ~Î!-'.Ii ",'. } !.d
,I
075 3/4-15
RECt;.IVED) STATE OF ALASKA ) j~
. MAr< 0''1 Z005 ALASKA OIL AND GAS CONSERVATION COMMISSION ¡¿r'1 '='
Alaska Oil & Gas ~OIl~~C¡¡~TION F?o~~~.~?RY APPROVAL.. "~OO~,.,,., '"m1 >
11.
Total depth MD (ft):
10402'
Casing
CONDUCTOR
SURFACE
Total Depth TVD (ft):
5854'
Length
120'
202-018
6. API Number:
50-1 03-20408-00
9. Well Name and Number:
2P-427
10. FieldlPool(s):
Kuparuk River Field I Meltwater Oil Pool
PRESENT WELL CONDITION SUMMARY
Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
. i' ;":':/,;i;:¡,:::;¡::;;¡,':;,i<:: >';:::: ::":::::::-::'.": ..:.' 'i':::::::; '¡ C;::::;::::.:':::::';;;¡::;::::::¡::;. :,:/::j¡,:::::'):¡:Hi:::~;¡~;) ':~>r:i:::j~;;.::-::¡;~:;::i!;:X~:::'::::\:¡:~:;'::::':: .:::::?::::',::;:~:;:;:;:;!Ii:::::.:::;;':; :::: ::/ .<//", '
: :,,1
,. .
P. O. Box 100360
7. KB Elevation (ft):
RKB 254'
8. Property Designation:
. . ..:: K~P~rYk:'~¡yèr::YD't
16"
MD
120'
TVD
. ;:: '1~~~;::!,:::,:':,:/:'<r::'
::':;:\:::::,;:::;:':23"ßÓ:'::":'::':':::> ' .
':!:::::,::::/:,,: ;?§~~Þ.:/ .¡:.:.:-.,
:¡;:',::;::':;::;,:j:,::':;:;§i~,~;,::::;:;:;""::
Burst
Collapse
Size
PRODUCTION
LINER
2776'
9287'
7-5/8"
5-1/2"
3030'
9541'
599'
3-1/2"
1 0140'
Perforation Depth MD (ft):
l' Ô.ÖQ8(1ÓPj 6'.'.: :::.:. ,',. ;' .::
Packers and SSSV Type:
no packer
SSSV= NIPPLE
12~~~i~þ~i~~1~~~~U~ð~;~(~~ÞH~~;b,
. .. ,:,c1.Ao'~,'m',;'Ë,mste''.,m,'n::.:'c:~¡~n"~g: ':',:o'.'Þ''',':p'~et.'''~r::a',':...JtÒ":.'o'.',rn' ~i., ..:.:' " .. . , 'f '." ,'" .
. ". 'Ma~Çt,l'.i5,. 200q',
. .f6.:,Ver1;>al :Â.pprç)val: :.' .' Däté: . .'
Qc:>mmjs~jÓn Repres~!1tati.vå: :
17. I. heJreby certifytÌ1~t.,thè,.foregoing:is true. and correct to the. best of my knowledg~,
:~::u:~Il:¡
Perforation Depth TVD (ft):
5ßao',;s6äs" ',:' : ..'.1. ' : "
Tubing Size:
3-1/2"
Tubing Grade:
L-80
Tubing MD (ft):
95411
Packers and SSSV MD (ft)
SSSV= 532'
i1~::W~~~~¿~6Ÿ~:~~!~~;h1;'d. '~e~~eø.
_1~Ötl'~Q$ãïï¥'P¡~Ò~~<_:' '~;~gèøD'
WAG 0. dINJ: D" . -'wiNJD'
'.' ..
.Aba~~on~d' :'0
WDSPL"O'
t Commission Use Only
. .. .'
. có~tåct: . .: Roþert :Chris~ënseh.@ 6!:)9-7535
Title: Prodliction Engineering Technician
Phonel:&f~Date o/~ør
Conditions of approval: Notify Commission so that a representative may witness
Sundry Number:
30~-lb-?
Plug Integrity 0 BOP Test 0
Mechanicalln~~grity Test ~
Location Clearance 0
Other:
RBDMS BFL MAR 0 8 2005
ORIGINj\L
COMMISSIONER
BY ORDER OF
THE COMMISSION
Date: 1~/ of
INSTRUCTIONS ON REVERSE
Submit in Duplicate
)
)
~
2P-427
DESCRIPTION
SUMMARY OF PROPSAL
ConocoPhillips Alaska Inc. requests approval to change the approved program for Meltwater
we1l2P-427 from Oil production to Water Alternating Gas (MI) injection service. This
conversion to injection service is required to provide support to the offset producers.
2P-427 was completed as a 5-1/2" x 3-1/2" Oil producer on May 18, 2002. The targeted
Meltwater T3 and T2 zones were encountered between 9632' - 10290' md (55041-5805' tvd).
The 5-1/2" production casing Inner Annulus is isolated utilizing a Baker GBH-22 Locator with
Seal Assembly at 9531' md (5455' tvd).
A Cement Bond log is scheduled to be ran after a Fill Clean Out is performed. A copy of the
CBL will be submitted when logging is completed on or around March 2, 2005.
, ;
II'
TUBING
(0-9541 ,
OD:3.500,
ID:2.992)
SURFACE
(0-3030,
OD:7.625,
Wt:29.70)
::>RODUCTlON
(0-9541 ,
OD:5.500,
Wt:15.50)
Gas Lift
:lndrel/Dummy
Valve 2
(604~047,
OD:4,725)
Gas Lift
MandrelNalve
3
(8156-8157,
Gas Lift
:lndrel/Dum my
Valve 4
(9421-9422,
OD:4.725)
SLEEVE-C
(9471-9472,
OD:4.500)
NIPPLE
(9487-9488,
OD:4.500)
SEAL
(9531-9532,
OD:4.500)
FRAC
:10008-10018)
Peñ
:10008-10018)
LINER
(9541-10140,
OD:3.500,
Wt:9.30)
)
Çøì1qij~Pl1in~p$,~I@E;Jt~"~."I:qp~
2R+427 :',' ' ,
I ~;,
"'",,11 ,r"", "'~.\"
1\
I I'Ó'
I,!i II,I! 1,1 'i
A
~
)
KRU
2P-427
API: 501032040800
SSSV Type: Nipple
Angle (éi) TS: deg (éi)
Angle @ TD: 64 deg @ 10402
Well Type: PROD
Orlg 5/19/2002
Completion:
Last W/O:
Rev Reason: Post paraffin
cutting Tag
Last Update: 1/27/2005
Annular Fluid:
Reference Log:
Last Tag: 9886
Last Tag Date: 1/26/2005
Casina Strina - ALL STRINGS
Description Size
CONDUCTOR 16.000
SURFACE 7.625
PRODUCTION 5.500
LINER 3.500
Tubing String - TUBING
Size I Top
3.500 0
Pêrforations Summary
Interval TVD
10008 - 10018 5680 - 5685
Ref Log Date:
TD: 10402 ftKB
Max Hole' 64 deg @ 10402
Angle:
Bottom
9541
Top Bottom TVD Wt Grade Thread
0 120 120 62.60
0 3030 2380 29.70 L-80 BTCMOD
0 9541 5460 15.50 L-80 BTCMOD
9541 10140 5739 9.30 L-80 BTCMOD
TVD Wt I Grade I Thread
5460 9.30 L-80 EUE8RD
Status Ft SPF Date Type Comment
10 6 10/19/2002 IPERF 2.5" HSD, JH RDX 2506
Chgs, 60 deg phase,
random orient
Zone
Stimulations & Treatments
Interval I Date I Type
10008 -10018 10/23/2002 FRAC
Gas Lift MandrelsNalves
St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO
Mfr
1 2629 2193 CAMCO KBG-2-9
2 6046 3801 CAMCO KBG-2-9
3 8156 4807 CAMCO KBG-2-9
4 9421 5404 CAMCO KBG-2-9
Qther!Plúg$¡::êqUiì>i:~:êto;r~JEWELR~" ,"
Depth TVD Type
532 532 NIPPLE CAMCO 'DS' PROFILE
9471 5427 SLEEVE-C BAKER SLIDING SLEEVE W/DS PROFILE
9487 5434 NIPPLE CAMCO NO GO 'D' NIPPLE
9531 5455 SEAL BAKER GBH-22 LOCATED W/SEAL ASSEMBLY
Comment
DMY
DMY
OV
DMY
1.0 DK-1 0.000
1.0 DK-1 0.000
1.0 DK-1 0.313
1.0 DK-1 0.000
Date
Run
0 5/15/2002
0 5/15/2002
0 3/28/2003
0 I 0/17/200~
Vlv
Cmnt
"':.,,' .
: ,,' .'
'"
',.""':".. "
"
,'" ,
Description
ID
2.875
2.813
2.750
3.000
--------.-
)
)
JOd-O \ %:
MECHANICAL INTEGRITY REPORT'
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OPER & FIELD
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:.I G RSLE.J._S =:: . WELL NUMBER
T O-?~'à Co-c:;\ 1-'> "'-J I SE.ú. \ «rc.e {>-\\ <:. \ E
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Annulus Press Test:
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COrm::lents:
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HECH..ANICÞ~ INTEGRITY - PART /2
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Theoretical TOe ccrl'Ni:,,"~r-.~(')~ro.%": ~<;. ~ \ ~"( m~~J
<i.'tvCt\\Ct.i'c&J ~~ 'o~NS '''' 2O~ê . ~
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Cement Bond Log (Yes or No) Nb ; ~n AOGCt' F~le '1{.~ ('\t.C~\¡'~<-
CBL ;O:valuation, ::.one above perfs '>fè~ ~T) bo~ "Th ~ ~<;~'1D
So'> ~~ -{ \,""\\è;~\c.,.~ \«cÁo' Q G'St:.t ~ '
Cement Volumes:' .Amt. Liner
Proåuc.tion Log: Type
¡Evaluation
CONCLUSIONS:
? art if 1 :
V\'"\ \~ l:?)~n~~CJ /nØ7'VÍ'..'. .,'" . '
",- A::J7:-. II' ( 3/(k\'-OC;-
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DATA SUBMITTAL COMPLIANCE REPORT
10/29/2004
Permit to Drill 2020180
MD 10402 ,/
Well Name/No. KUPARUK RIV U MELT 2P-427
Operator CONOCOPHILLlPS ALASKA INC
API No. 50-103-20408-00-00
TVD 5853 '"
Completion Date 1 0/19/2002 ../
Completion Status 1-01L
Current Status 1-01L
UIC N
REQUIRED INFORMATION
Mud Log No
Samples No Directional Surv~~,,- ~-~,~
(data taken from Logs Portion of Master Well Data Maint)
ß
Log Log Interval '\-._~'
Run OH/
Scale Media No Start Stop CH Received Comments
1 Blu 1 9370 1 0040 Case 11/8/2002
Blu 9370 10040 Case 11/8/2002
0 1 0402 Open 5/30/2002
Blu 9370 10040 Case 11/8/2002
Blu 9370 1 0040 Case 11/8/2002
1-3 120 10402 Open 11/12/2003
1-3 120 1 0402 Open 11/12/2003
25 120 1 0402 Open 11/12/2003 Multiple Propagation
Resistivity, Gamma Ray -
RWD
25 Blu 120 10402 Open 11/12/2003 Multiple Propagation
Resistivity, Gamma Ray -
RWD
25 120 10402 Open 11/12/2003 Caliper Corrected Neutron, ~
Optimized Rotational
Density - RWD
25 Blu 120 10402 Open 11/12/2003 Caliper Corrected Neutron,
Optimized Rotational
Density - RWD
25 120 10402 Open 11/12/2003 Caliper Corrected Neutron,
Optimized Rotational
Density - RWD
25 Blu 120 10402 Open 11/12/2003 Caliper Corrected Neutron,
Optimized Rotational
Density - RWD
DATA INFORMATION
Types Electric or Other Logs Run:
Well Log Information:
Log/
Data Digital
Type Med/Frmt
I,.Dg
Lðg>
CRf>t
éog
tOg
ED C Tf
4'
ED C Pdf
~~r
ED C Pdf
Lo.Q/
~'
ED C Pdf
~/
Electr
Dataset
Number Name
~emperature
vPressure
I"'""ÖTrectional Survey
.,...' Casing collar locator
-Gamma Ray
~260~.
~60 Induction/Resistivity
.-fnduction/Resistivity
..Mso Neutron
J':Iøutron
~o Density
Æéñsity
Permit to Crill 2020180
MD 10402
Well Cores/Samples Information:
TVD 5853
Name
Well Cored?
ADDITIONAL INFORMATION
Y~'
Chips Received? - Y / N "
Analysis
Received?
Comments:
'Y/N .-
Compliance Reviewed By:
DATA SUBMITTAL COMPLIANCE REPORT
10/29/2004
Well Name/No. KUPARUK RIV U MELT 2P-427
Operator CONOCOPHILLlPS ALASKA INC
Completion Date 10/19/2002
Completion Status 1-01L
Interval
Start Stop
Sent
Received
Daily History Received?
Formation Tops
1 f
~
Current Status 1-01L
Sample
Set
Number Comments
~N
è})N
Date:
API No. 50-103-20408-00-00
UIC N
~
~ ~. ~"-\J 'i
-
g)Oé9 -0 I g
Transmittal Form
'&1.
BAKER
HUGHES
INTEQ
Anchorage GEOScience Center
To:
AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention:
Lisa Weepie
Reference:
2P-427
~~~ r_--~___-~ ~~~~,,---~~-~~~-..~- --..-.,.- ..,~-~,._.~~-~"~- _.~~-.' "_'8', -_..~., .,,"'~..-r-."'- -_~__'~n-..-_~.---
.----,--~,",-------~-~---~--~----~-~-~--------_._-,----
Contains the following:
1 LDWG Compact Disc ) d¡~ tcð
(Includes Graphic Image files)
:1 1 LDWG lister summary
1 blueline - MPR Measured Depth Log
1 blueline - MPR TVD Log
1 blueline - CCN-ORD Measured Depth Log
1 blueline - CCN-ORD TVD Log
LAC Job#: 291862
Date: RËè2ËÎVED
Date:
NOV 12 2003
PLEASE ACKNOWLEDGE RECEIPT BY SIGNIl~~&Q :ð~n
OR FAXING YOUR COPY
FAX: (907) 267-6623
Sent By: Glen Borel
Received BY~~~\ ~ j~~"ÇJ O~^^'
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska
99518
Direct: (907) 267-6612
FAX: (907) 267-6623
~~~N\~
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, . .
,,~'" ,"'.C', .,.,...
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--.... -...... .. -
---,-_.,--~.- -
l:iò~J : -.=.-
-
----------------.--
FRAC
(10008-10018)
Perf
(10008-10018)
LINER
(9541-10140,
00:3.500,
Wt:9,30)
OønocøPtillllj:)s :AI..k~,',ln~.
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2P-427
KRU
2P427
API: 501032040800
SSSV Type: Nipple
Angle @ TS: deg @
Angle@ TD: 64 deg @ 10402
Well Type: PROD
Orlg 5/19/2002
Completion:
Annular Fluid: Last W/O:
Reference Log: Ref Log Date:
Last Tag: 10008 TD: 10402 ftKB
Last Ta9 £?ate: ?/27(2003 , .' , Max Hole Angle: ~.4 de9 ,~ 10402. ,
Caslng'Stririg~A:LL>STRINGS:;"' , . ";;"":"'" ," "" , . "'",
Description Size Top Bottom TVD
CONDUCTOR 16.000 0 120 120
SURFACE 7.625 0 3030 2380
PRODUCTION 5.500 0 9541 5460
LINER 3.500 9541 10140 5739
Túbing:Stnng"..TUBING " " " . '; :
Size I Top I Bottom TVD Wt I Grade I
3.500 0 9541 5460 9.30 L-80
Petforätiöns Summary , ,
Interval TVD Zone Status Ft SPF Date Type
10008 -10018 5680 - 5685 10 6 10/19/2002 IPERF
Rev Reason: Tag fill, cut paraffin
Last Update: 7/30/2003
Wt Grade Thread
62.60
29.70 L-80 BTCMOD
15.50 L-80 BTCMOD
9.30 L-80 BTCMOD
Thread
EUE8RD
Interval Date
10008 - 10018 10/23/2002
Gas Lift MåndrelslValves
St MD TVD Man Man
Mfr Type
1 2629 2193 CAMCO KBG-2-9
2 6046 3801 CAMCO KBG-2-9
3 8156 4807 CAMCO KBG-2-9
4 9421 5404 CAMCO KBG-2-9
Other t )Iugs, equip., "eic.' ~ "JEWELRY
Depth TVD Type
532 532 NIPPLE CAMCO 'DS' PROFILE
9471 5427 SLEEVE-C BAKER SLIDING SLEEVE W/DS PROFILE
9487 5434 NIPPLE CAMCO NO GO 'D' NIPPLE
9531 5455 SEAL BAKER GBH-22 LOCATED W/SEAL ASSEMBLY
Comment
Type
V Mfr V Type VOD Latch Port TRO
DMY 1.0 DK-1 0.000 0
DMY 1.0 DK-1 0.000 0
OV 1.0 DK-1 0.313 0
DMY 1.0 DK-1 0.000 0
"
Description
Date Vlv
Run Cmnt
5/15/2002
5/15/2002
3/28/2003
10/17/200:;
ID
2.875
2.813
2.750
3.000
Integral Casing Detail
Size ' Weight Grade Drift Threads JTS Length Top MU Torq. THD Manufacturer
(in.) (Ib/ft) (in) (ft) (ft) (ft-Ibf)
7625 6.875 BTC-ABMOD 1 2.78 30.57
7.625 29.70 L-80 6.750 BTC 22 957.31 33.35
7.625 6.750 BTC-ABMOD 1 2.44 990.66
7.625 29.70 L-BO 6.750 BTC-ABMOD 45 1.946.61 993.10
7.625 6.750 BTC.ABMOD 1 1.34 2.939.71
7.625 29.70 L-80 6.750 BTC-A8MOD 2 86.93 2.941.05
6.625 6.750 8TC-A8MOD 1 1.50 3.027.98
Non-Integral Casing Accessories
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
String Type: Surface Casing
Hole TVD: 2.385.0 (ft)
Ground Level: 224.00 (ft)
Circ Hours: 5.00 (hr)
Manufacturer: FMC
Hanger Model: 7.625 fluted
Actual TMD Set: 3,029.48 (ft)
,Item"
Casing Hanger
Casing
Tam Port Collar
Casing
Float Collar
Casing
Float Shoe
Accessory
Bowspnng Centralizer
Permanent Datum:
KB-Datum:
CF Elevation:
Mud Lost:
, Manufacturer
WEATHERFORD
.-'. . . '. . \.' .' "
,ConoCoPhiUips,Alaska
,Casing R,eport
Report #:
Start:
1
4/22/2002
9.875 (in)
(ft)
(ft)
30.57 (ft)
. c"5~;;~~?i
-',... ~ -~~!~~-- -~
Spud Date: 4/24/2002
Report Date: 4/26/2002
End:
" " '
. . -~." '.: ¡-" -
- -,-- -.'. .".. . .,-,..
-or ,- .
Hole TMD:
Str Wt on Slips:
Max Hole Angle:
Days From Spud:
3.040.0 (ft)
74,000 (Ibs)
62.00 (°)
4.00 (days)
'~
General Information
Rotary Table
254.00 (ft)
(ft)
(bbl)
Hole Size:
Water TMD:
Liner Overlap:
KB to Cutoff:
.,:~,sÞ~¡{f
Casing Flange I Wellhead
Model:
Packoff Model:
GenV
Top Hub/Flange: 10.750 (in) /5,000 (psi)
BTM Hub/Range: (in) / (psi)
..; "
""" - "':. "i":,"::'~¥~f:r.
'. -~ - ~-~~ ~-~~~~'~ ~-
"COnd> MaxOp...-Mm ID '.'::~~~e'
" ' " . ~Î'i)", (In) '. :'~;'":"::-.:
Number
Spacing
(ft)
Moder.
\lEW
\lEW
6.875 Casing Hanger
6.875 7 Sl8" 29.7# L-8
6.875 Tam Port Collar
Remarks
new
\JEW
\JEW
\lEW
'JEW
6.875 7 Sl8" 29.7# L-8
6.875 Float Collar
I
6.875 7 Sl8" 29.7# L-8 .~
6.875 Float Shoe
- ~.:_~~:!:--
Interval
. . '. - -. :-"'::~ . :.;J.-"; -
Hooi~h
Top (ft)
3,019.0
S-ottom (ft)
3.022.0 Stop colla
Thread lock shoe track & pin inot float collar. Wt uo 105k, dwn 73k Ibs. Used API artic Grade csg lub. Drifted w/6.75" rabbit. No rejects. Ran 69 jts /6 out.
--. «<~1~~~'"
Printed: 9/212003 3:40:53 PM
')
)
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
. ,
-: ,-..:,
'... . -
."
,.'t'. "
" > :'" ,:Piimsrv', .
Hole Size:
TMD Set:
Date Set:
Csg Type:
Csg Size:
3,030 (ft)
4/26/2002
Surface Casing
Cmtd. Csg:
Cement Co: Dowell Schlumberger
Report #:
Start:
Spud Date: 4/24/2002
1 Report Date: 4/26/2002
4/22/2002 End:
, - .
,Cement JoÞJYpe~
I":. .,:
, ,',SQueèzs'Cashig
Hole Size:
TMD Set:
Date Set:
Csg Type:
sa TMD:
sa Date:
Cmtd. Csg:
Cementer: Don Zierke
... .
~. , .
Squeeze Open Hole
Hole Size:
sa TMD: (ft)
sa Date:
sa Type:
Cmtd. Csg:
, , '
'. ,
~.; ~< l,~
, i,
.' ,
", 4 ,"
!, :,',
.., ,', :Plug',
Hole Size:
Top Set:
BTM set:
Plug Date:
Plug Type:
Drilled Out:
Cmtd. Csg:
Pipe Movement: Reciprocating
(ft)
(ft)
. ..-r-',. ',' .'. :: -'. ','" .'". .. .
~'.':;:::'\ .'~~~~ø~,'~:ÞJye.:n.:erit ." .:
Init Torque: (ft-Ibf)
Stroke Length: 20.0 (ft)
~.-' :"/,1:
. -
Rot Time Start:: Time End:: RPM:
Rec Time Start:18:00 Time End: 22:26 SPM: 5
Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf)
Drag Up: 28,000 (Ibs) Drag Down: 10,000 (Ibs)
Type: Cement Casing
Volume Excess %: 400.00
Meas. From: 175
Time Circ Prior
To Cementing: 3.00
Mud Circ Rate: 242 (gpm)
Mud Circ Press: 400 (psi)
Start Mix Cmt: 21 :50
Start Slurry Displ: 21 :50
Start Displ: 22:59
End Pumping: 23:30
End Pump Date: 4/26/2002
Top Plug:
Bottom Plug:
Disp Avg Rate: 5.80 (bbl/min)
Disp Max Rate: 6.00 (bbl/min)
Bump Plug:
Press Prior: (psi)
Press Bumped: (psi)
Press Held: (min)
Float Held:
Returns: 100
Total Mud Lost: (bbl)
Cmt Vol to Surf: (bbl)
Ann Flow After:
Mixing Method: displaceme
Density Meas By: Scale/D.Me
Type: Density: (ppg) Visc: (s/qt)
Bottom Hole Circulating Temperature: (OF)
Displacement Fluid Type:
PVNP: (cp)1 (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2)
Bottom Hole Static Temperature: (OF)
Density: (ppg) Volume: (bbl)
Slurry Data
Fluid Type: LEAD
Slurry Interval: (ft)
Water Source: fw lake
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
(OF)
. . -. .
....j;:¡~~~~;~~::.#;~í~rY:'~~:.:~1gt~; ..,.
. .~" ~ ¡"v,.:;,", ~ :.
~-\.~. ~I ".5'<~,..
" ",. ,. . . .. -.
Description: ASLite
To: 1,416.00 (ft) Cmt Vol: 290.0 (bbl)
Slurry Vol280 (sk)
Temperature: eF)
Temperature: (OF)
Temperature: (OF)
. ,~. .
':,;..,.\ .:
Class: G
Density: 10.70 (ppg) Yield: 4.28 (ft3/sk)
Water Vol: 187.0 (bbl) Other Vol: 0
Time
Compressive Strength 1:
Compressive Strength 2:
Purpose: PRIMARY
Mix Water: 20.70 (gal)
Foam Job: N
Temp
(OF)
eF)
Pressure
(psi)
(psi)
Printed: 9/2/2003 3:40:32 PM
~~i~l~il~';':: Y~!1:'~Wi~.:...',
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)
~~0;5f~~
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Report #:
Start:
Spud Date: 4/24/2002
1 Report Date: 4/26/2002
4/22/2002 End:
, .
Stage. No::1:.$JtJi"ry;N'~: 2:of 2.
I ~ .' ,
, .
Slurry Data
Fluid Type: TAIL Description: LiteCRETE
Slurry Interval: 1,416.00 (ft¡To: 3,040.00 (ft) Cmt Vol: 94.0 (bbl)
Water Source: fw lake Slurry Vol:220 (sk)
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
(OF)
~ . . .
. . '"
,:;\';Ä:.(:,: '.':~<Ç~s,.,gTest' .:
Test Press: (psi)
For: (min)
Cement Found between
Shoe and Collar:
. . .
. - .-
.,' .. :..' :.:
, '.';'~;-~ø~~lIrvey :Evàiu~tÎön
CBL Run:
Under Pressure: (psi)
Bond Quality:
Cet Run:
Bond Quality:
Temp Survey:
Hrs Prior to Log:
t, '~",.' " ,~. ,:
Class: G
Density: 12.00 (ppg) Yield: 2.40 (ft3/sk)
Water Vol: 46.0 (bbl) Other Vol: ()
Purpose: PRIMARY
Mix Water: 8.84 (gal)
Foam Job: N
Temperature: eF)
Temperature: (OF)
Temperature: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Pressure
(psi)
(psi)
Temp
(OF)
(DF)
" .
"
:,:,~h~Te$t .
. ,
, lin,C!t,T9þ:t~.$t .
Pressure: (ppge)
Tool:
Open Hole: (ft)
Hrs Before Test:
Liner Lap:
Pos Test: (ppge)
Neg Test: (ppge)
Hrs Before Test:
Cement Found on Tool:
Tool:
Tool:
. ",
. - ~ " r.,
. . .. ..
:~~~I~t~tprêtåUoh '~¿,fuiÍ1åry:":; .'
Cement Top:
How Determined:
TOC Sufficient:
Job Rating:
If Unsuccessful Detection Indicator:
Remedial Cementing Required:
Number of Remedial Squeezes:
(ft)
Dowell cmted 7.625" csg as follows: Pumped 40 bbl of CW 100 @ 8.34 ppg, 360 psi - 6 bpm press testing pump & lines to 3500 psi.
Drop bottom plug. Pump 40 bbl1 0.5 ppg Mud Push @ 5.5 bpm - 400 psi. Follow wI 290 bbl [380 sx] Lead slurry [AS Lite] 10.7 ppg CI G
{adds = 50% D124, 9% D44, .4% d46, 30% D53, 1.5 % S1 & 1.5% D79], f water @ 19.39 gal/ sx, yield 4.28 tt31 sx. Press I rates
max - min - avg= 570 I 6 - 36016 - 480 psi - 6 bpm. Follow wI Tail slurry of 94 bbl [219 sx] LiteCRETE @ 12.0 ppg. F wtr 8.122 gall sx,
yeal 2.4 ft31 sx. Adds = D079 .5%, D046 .6%, D065 1.0 %. Press / rates max - min - avg = 650 I 5 - 600 I 5 - 625psi- 5 bpm. {all add
%BWOC}. Drop top plug & disp wI 10 bbl f wtr + 134 bb19.8 ppg mud, plug hit on calculated displaced value total of 144bbl. Bumped
plug from 650 psi to 1500 psi & held for 5 minutes, bleed back ?5 bbl- plug I floats held.
175 bbl [229 sx] cmt to surface, full returns throughout ops.
Reciprocate pipe 20' I 1 min until string became "sticky. when tail hitt on back side of 7.625" csg. CIP @ 2325 psi.
Printed: 9/2/2003 3:40:32 PM
)
('
')
WE~ N';'.' .. . 2P-427. .. . 'IJOs NUMB'R I ~;~D' 1.4 H~ ~ T~~040~IT~~385,O IDFS4,OO . I R~~~' I ~~~
SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANGO
R W Bowie n1433@ppco.co Nordic 3 Meltwater 10,500.0 0
CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INT ANG WI MUD
ND diverter. 0 0
DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD
4/22/2002 212,036 676,940
I LEAKOFF AFE AUTH.
AK0230 2,985,046
I NEXT CASING LAST BOP PRES TEST
5.500 (in) @ 15.5 (ft) 4/19/2002
0 I CUM COST I 0
PflMf CI ' Ca H2S LIME ES'
I
." ','- ';';:,'~ ': '-;'i'<}~::~>:<,: ~:':;' ': ):.:;:,'~,~_....~.-,.~-~,:..,-'~",-"~,',:,,,;>,"'~.'B.'.:,',:a.'~, 2,:'.L';:,~'ElG' . ,TH' .2.
' "TØRQU~/li~~: :,:~<: - ". nft. n
1,109.80
"cØN~:$~zE':'}ÇQN~ ,:l:'t'P~'
24 HR FORECAST
complete nd - nu bope Itest I rih I drtg out FIT.
LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP
LAST SURVEY: DATE TMD INC AZIM I LAST CASING
4/25/2002 2,987.00 62.050 163.770 7.625 (in) @ 3,030.0 (ft)
OENSITY(ppg) I I PI' I IECol IMUD DATA 'DAILVCOST I
FV PVIVI' GELS WUHTHP FClT.SOL ' OIUWAT %SandlMBT Ph/pM
I / / / / I
~Íif~9~~! - " ..2. .." ,..1:: ",<''':/U;''::;c:;'i'>, '/';';;/'sl~:miBI'HN",'G'A,',."WT'.~"t:H."'OO,N' ,~LÊ/CÔ:',Ns, ."TR', b,,}TI'N. :'G1O,:,.',WT,-~.'S':R':'P-:T;i,::'','",."":,::::,,,
~HÂ,VfT. BE~O\\,JARS ;~:,:'::-; Sm!f-i(ÜVT~UP , "
, :'IT:eM DESCRIPTION' NOJTS LENG1;t1 ,:q.D~ ,:' ,:tD.:J':,":'
Hole Opener 1 5.74 9.875
Bit Sub 1 2.00 8.000 3.000
Drill Pipe - Non-Mag 4 Comp Serv 1 29.04 5.000 2.810
Drill Pipe - Non-Mag 4 Comp Serv 1 29.44 5.000 2.810
Drill Pipe - Non-Mag 4 Comp Serv 1 30.15 5.000 2.810
Crossover 1 2.25 6.750 2.250
Drill Pipe - Heavy W gt 18 552.46 4.000 2.250
Jars 1 32.04 6.250 2.250
Drill Pipe - Heavy W gt 14 426.68 3.500 2.250
, ,BITS,
':::BIT/RÛN"',:~ ::,;:~~,SIZ~.:, '~MANÜì:> ,: 'i,: TYPE\':'.SE~IÅLNO;", "
2/ 9.875 SMITH HOLE OP6Nœ4
, .
..,
:: ,'.' ...
, DI;PÙÙN ':D.ATffIN '''::~~~L~è,-G~Ó1~. ,
3,040.0 4/26/20020-0-NO-A-E-I-NO-TD
...:¡;~~4~J~:/;',i'!!~!~:!~~.~~:!.!.¡ ;.....;~~~)j.I'!!;4Þ~" "I;;i'íí~~~~:rfrt~~~It:~~~I!;:;~4~:~~)'I;~~i!~gii);~~'~:;it~~~~;:.~t~;~~,
OPERATIONS SUMMARY
FROM TO HOURS COOE TROUBLE SUB PHASE DESCRIPTION
00:00 01 :00 1.00 DRILL P DRLG SURFAC Continue to mu hole opener bha.
01 :00 03:30 2.50 DRILL P
03:30 08:00 4.50 DRILL P
08:00 11:30 3.50 DRILL P
TRIP
SURFAC Rih w/ hole opener assmby. No problems.
CIRC
SURFAC Cir & cond, run Solids cont van & reduce mw from 9.9+ to 9.7+ ppg. Adjust yp
to 18.
TRIP
SURFAC Pooh for csg, pulled 20k Ibs over @ 1380', rih 50' & work through, repeat
second time w. no restriction. 5k Ibs over pull @ 1200', worked though w/ no
problem, checked open - continued trip out.
11 :30 13:00 1.50 DRILL P
PULD SURFAC Ld tools.
13:00 14:00 1.00 CASE P
SFTY
SURFAC PJSM & ops briefing.
Printed: 9/2/2003 3:39:38 PM
')
)
~ N";E ... . 2P-427 .1';'. ~~II~E~ I ~~D~DE I'¡~RS"";;; . 1~~040.0 1';,385.0 '1~4.00 I AEPT ~;;'I :"61200~
¡'
FROM. TO HOURS
14:00 18:00 4.00
" I'
, ,
, ' . ",OPERATIONS 'SUMMARY.:,' ,,~:, ",
C,ÒDE "tROUBLE,' SUB ~HASE ' " ", . "" ,', DESCRIPTfON , "
CASE P RUNC SURFAC Ran 69 jts 7.625- x 29.7 ppf x L-80 x Bt&c ab mod csg as per program.
Located Tam Port Collar @ 991'.
Utilized Wx-Lamb float shoe & float collar & two shoe jts. Ldg out @ 3030'
md.
Brk cir @ 1700 & 2300 ' [cir @ 5.5 bpm 1300 & 475 psi.
Work pipe 70k up 55 k Ibs down.
18:00 21 :00 3.00 CASE P
CIRC
SURFAC Cir I cond mud to cmting properties. Mu cmt head. Continue to cir & adjust
mud properties t09.7 ppg I yp 14. Reciprocate pipe 20' stroke, weights up I
down = 90k I 73k Ibs.
21 :00 21 :30 0.50 CASE P
SFTY
SURFAC PJSM lOps briefing
21 :30 23:30 2.00 CASE
SURFAC Dowell cmted 7.625- csg as follows: Pumped 40 bbl of CW 100 @ 8.34 ppg,
360 psi - 6 bpm press testing pump & lines to 3500 psi. Drop bottom plug.
Pump 40 bbl1 0.5 ppg Mud Push @ 5.5 bpm - 400 psi. Follow wI 290 bbl [380
sx] Lead slurry [AS Lite] 10.7 ppg CI G {adds = 50% D124, 9% D44, .4% d46,
30% D53, 1.5 % S1 & 1.5% D79], f water @ 19.39 gall sx, yield 4.28 ft31 sx.
Press I rates max - min - avg= 570 I 6 - 360 I 6 - 480 psi - 6 bpm. Follow wI
Tail slurry of 94 bbl [219 sx] LiteCRETE @ 12.0 ppg. F wtr 8.122 gal I sx, yeal
2.4 ft3 I sx. Adds = D079 .5%, D046 .6%, D065 1.0 %. Press I rates max -
min - avg = 650 I 5 - 600 I 5 - 625psi- 5 bpm. {all add %BWOC}. Drop top
plug & disp wi 10 bbl 1 wtr + 134 bbl 9.8 ppg mud, plug hit on calculated
displaced value total of 144bbl. Bumped plug from 650 psi to 1500 psi & held
for 5 minutes, bleed back ?5 bbl - plug I floats held.
175 bbl [229 sx] cmt to surface, full returns throughout ops.
Reciprocate pipe 20' 11 min until string became -sticky" when tail hitt on back
side 017.625" csg. CIP @ 2325 psi.
23:30 00:00 0.50 CEMENT P
PULD SURFAC Wash Cmt equip & rig equip. Rd cmt equip. [incomplete @ rpt time].
24 HR SUMMARY: Complete H. opener run I run & cmt surface csg I nd diverterl
~"";,
Rig Fuel
Rig Water
:',UN,ITS
gals
BBI
.,:;::~¿:~~E~~ú~~,~,?t¡i~:~~A~Y .
2 Bariod
2 APC
1 GBR
3
',. ":, G~~G~.:~~!,~~~~:(,Ø~~,S:~~~~;<?N'< ~/;~...: ,'. 'iJ~~:"',:;;.{fc~',::h.,;$)1~~",':"':,i ' ':" ,'.-';'.: :'~ :,.,'~':
476 4,642 Camp Fuel gals 200
194 186 Camp Water bbls 41
J:~Þ:~'«~~' ,,~; .'. - .~: ~~'~~ ~""~"r~"~,,i.':_¿: : ",::: ~""~':' ~.:,~ ~ . '... < "": :.;'~:.~'~'~:.:< ',';:' ,- ~:,--
, ,
';ëÒMPANY, :. ,>.".:",: ''''''', :¡;~-':, $E~V,ïC,Ê':'('~,:"
Nordic
Catering
ConocoPhillips Company
Baker Hughes Inteq
3
1
,:QN{H~p
2,175
41
TYPE
2P-415
2P-415
NO.
290 Heavenly
206 2P-427
REMARKS
SUPPORT CRAFT .
TYPE .
2P-420
2P-420
NO.
290 Heavenly
500 2P-427
REMARKS
Printed: 9/212003 3:39:38 PM
')
)
2P-427
~ , -.~, ~ -, -" .. ,,,.,,,, " -'''.~, .."~-..'''''',
TMD ITVD IDFS REPTNO. I DATE
3,040.0 2,385.0 4.00 5 4/26/2002
WELL NAME
Heavenly
2P-427
Heavenly
2P-427
, '" ;.';<¡~ '" RESERVOIÁAND,INtE'R\I AL', DATA,'
'2:0NE ,', ,," ' "TOP':':: 'B,ASE ¡. :><:: "
290 2 1000
206 2 1000
290 3 400
500 2 350
'". .
. : . ' " ~ "; \:. ~ :::1. -.' : ~ i. '
, :' RE'SERVQI¡""NAME
2P-415
2P-415
2P-420
2P-420
~ . I' I
i 'j: . . 1 .'. '!- ~... ~. ". ,
:' C()MM,~'
.: \'
Printed: 9/2/2003 3:39:38 PM
Casing I est
Hole Depth Pumping Shut-in
3,060 Ft-MD I 2,420 Ft-TVD Gals psi Min psi
I. 0 0 0 2550
2.25 150 1 2525
5 290 2 2525
6.75 450 3 2520
9 560 4 2515
11.15 680 5 2512
13.5 810 6 2512
0.4bbl 15.75 940 7 2512
I... 18 1075 8 2512
'20.25 1212 9 2512
22.5 1349 10 2500
24.75 1414 11 2500
27 1619 12 2500
29.25 1759 13 2500
31.5 1894 14 2500
33.75 2029 15 2500
36 2169 16 2500
38.25 2304 17 2500
40.5 2439 18 2500
42.75 2550 19 2500
~ 20 2495
21 2495
22 2495
23 2495
24 2495
25 2496
26 2496
27 2496
28 2496
30 2495
~/olum~ Volume
Pumped Bled Back
0.0 l'ials _--l'ials
Well Name:
Drilling Supervisor:
2P-427
CASING AND FORMATION INTEGRITY TEST
PHilliPS Alaska, Inc.
Nordic 3 I Date: 4/28/2002 I Volume Input
Ipump used: I BOP Test Pump I... Gallons ~
Pumping down drillpipe. .
I Rig:
Ralph Bowie
Type of Test:
Hole Size: 18-3/4"
RKB-CHF: I Ft
CasinQ Size and Description:
CasinQ Test
Mud Weight: 9.6 ppg
Mud 10 min Gel: 11.0 Lb/100 Ft¿
Test Pressure: 2550 psi
Rotating Weight (Pumps off): 71000 Lbs
Blocksrrop Drive Weight: 23000 Lbs
Estimates for Test: 1.1 bbl
.
Casing Shoe Leak Off Test
I... -
Casing Shoe Depth
3,030 Ft-MDI 2,394 Ft-TVD
17-5/8" 29.7#/R L-80 BTC-MOD
Formation InteQritvTest
Mud Weight: 9.6 ppg
Mud 10 min Gel: 11.0 Lb/100 Ft¿
Rotating Weight (Pumps off): 71000 Lbs
Blocksrrop Drive Weight: 23000 Lbs
Desired FIT EMW: 17.0 ppg
Estimates for Test: 921 psi
I...
EMW = Leak-off Pressure + Mud Weight =
0.052 x TVD
FIT 15 Second
Shut-in Pressure, psi
900
921
0.052 x 2394 + 9.6
EMW at 3030 Ft-MD = 17.0 ppg
3000 .
Lost 50 psi during test,
98% of test pressure.
,¥.,~_.>:-"-', ','v.:i....1 . , " I. .' . , J. . . . . 1.. '.. J
.'-'«"'~~~~'~~:*~~~:*:*:~W~~~:~~~:~ii::*:*:~~~~.
2500.
..0\.
2000-
~JOr
~
~'C
~
/'
w
a:
::J
~ 1500-
W
a:
0.
--
..,t"
,:::~ -y/
071 ,
:;:11;::::::;:::;:
~.:.:
-----.:::::. .
:':1:¡;:::;:;:::""".'_."'::j:~¡:::::::::::::;:::¡:::::::
"1'"
5
20 25
Gallons
30
35
10
15
30
40
45 0
----CASING TEST
---LEAK-OFF TEST
5 10 15 20 25
Shut-In time, Minutes
. FIT Point
Comments:
750
~
i
680
Philllps Alaska, hie.
Dàily, Drn'ling ,R~PQrt
I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS I REPT NO. I DATE
ODR 355.0 3,395.0 2,547.0 6.00 7 4/28/2002
I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANGO
Nordic 3 Meltwater 10t500.0 0
ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD
0 0
DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD
Dir Drlg ahd I Survey 4/22/2002 116,339 961,713
LITHOLOGY SHALE I JAR HRS OF SERVICE I BHA HRS SINCE INSP LEAKOFF AFE AK0230 AUTH. 2,985,046
LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
4/28/2002 3,860.56 60.910 164.480 7.625 (in) @ 3,030.0 (ft) 5.500 (in) @ 15.5 (ft) 4/27/2002
',D$NSITY(ÞPØ> I 10.00 I PP,, IEeD ¡MUD DATAl DAILY COST I 0 I, CUMC;OST I 0
FÝ:, PVNP' G'ELS.', WL..(HTHP FCIT.SOL OIL/WAT %san~BT, Ph/pM PflMf : ',CI .,':éa, H2S, , 'UME ES
46 14/24 8119 5.41 1 I n.5 10.01 I
')
WELL NAME
SUPERVISOR
R W Bowie
CURRENT STATUS
2P-427
I RIG NAME & NO.
n1433@ppco.co
Drlg ahd @ 14265'
24 HR FORECAST
'~HANO. I 3 I'
aHA Wr. BELOW JARS . STRiNG vir. UP :'
18 70
ITEM 'DESCRIPTION
. BHA1'HOLE,CONDiTiONS .
.. . .
STRING WT. ON 'STRING WT. ROT'
60 65
NO JTS LENGTH
1 0.75
1 0.85
1 30.78
1 5.31
1 3.92
1 17.04
1 16.69
1 23.04
1 30.83
1 30.28
1 30.94
1 2.54
18 552.46
1 29.54
14 426.68
Bit
Turbo-Back Stab
Mud Motor
Stabilizer - NonMag
LWD/MAP
LWD/MPR
LWD/SDN
MWD
Drill Pipe - Non-Mag 4 Comp Serv
Drill Pipe - Non-Mag 4 Camp Serv
Drill Pipe - Non-Mag 4 Camp Serv
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy Wgt
,.' ::.:,BrT / ßlJN
3/
:- Si2:E . ' MANUF.
6.750 SMITH
,', . BiTS. .
, "TYPE SERIAL NO~ 'JETS ÓR ~A
M93VYPX JS6688 13/13/13/13/1
O.D. .
6.750
6.719
6.625
6.625
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.750
4.000
4.750
4.000
)
, Page::1.:of;2
. TORQUE I UNITS
4,000 ft-Ibf
I.D:
,>'-:: : I'B 'r~.9.1 3
. ,BHA LENGTH '
1,201.65
CONN SIZE CONN, TYPE
1.500
2.250
2.812
2.812
2.812
2.812
2.690
2.690
2.690
2.250
2.250
2.250
2.250
,DEPTH IN,i:>~iE IN' :, 1-:0~(j.:L"B~G~O-Ø:'
3,040.0 4/27/20020-0------
BIT/RUN'
3/
:'RPM" . .~PM
75 I 85 300
. : BITOPERATlqN~ :
,PRESS' PSIT,',' HRS~:, '.24HrDIST' 24HrROP":CUMHRS:,Cl!MDEPTH èUMROP:
2,100 285 13.00 957.0 73.62 13.00 957.0 73.62
'WOB,
5/15
.. M:D.
3,103.50
3,197.88
3,293.14
3,387.53
3,482.67
" . .$URV'EYDATA
. .
. AZIMUTH,' ....T.V.D. .NI$ CUM ElWCUM' SECTlÖN . M.p.
163.070 2,414.10 -1,483.4 426.16 1,543.38 3,577.77
162.720 2,456.86 -1,563.8 450.90 1,627.49 3,672.26
162.370 2,500.08 -1,644.7 476.37 1,712.35 3,767.07
162.720 2,543.35 -1,724.8 501.53 1,796.20 3,860.56
163.770 2,586.65 -1,805.9 525.95 1,880.90
'. INCL.
62.750
63.370
62.670
62.750
63.11 0
." ' . OPERATIONS'SUMMARY
fRþ~ '" T~ -: ,"~OORS. ~o~e:'. TRQUBL.E SVi~" . ..p~~$~ . :. .: .
00:00 01 :00 1.00 CASE P CIRC SURFAC Cir bottoms up for csg test.
INCL. .
61.700
61.350
61.880
60.910
.' . - . .
. . .
'ÄZlMUTH T.VJ). WSCUM EfW.<::UJ.rS¡:CTION
163.770 2,630.70 ~1 ,886.8 549.51 1,965.18
164.830 2,675.75 ~1,966.8 571.98 2,048.23
164.480 2,720.83 -2,047.2 594.06 2,131.64
164.480 2,765.59 -2,126.3 616.02 2,213.72
. D.E$CRIPl1d~j
Printed: 10/1/2003 2:44:08 PM
)
)
2P-427
Þhillips Alaska, Inc.
, ' ,
Dáilý Dr.illing, Report
TMD
3,395.0
Page 2 'of 2
WELL NAME
I JOB NUMBER I EVENT CODE 124 HRS PROG
ODR 355.0
TVD DFS REPTN70. I DATE
2,547.0 6.00 4/28/2002
OPERATIONS SUMMARY ,
FROM TO HOURS CODE mOUBLE SUB' PHASE' DESCRIPTION
01 :00 02:30 1.50 CASE P DEaT SURFAC Test surface csg to 2500 psi, initial pressure 2550 final [31 minutesJ2495 psi.
02:30 04:30 2.00 WELCTL P OTHR SURFAC Drlg shoe track, 10' of cmt to new formation @ 3040' & 20' of new formation to
3060'.
04:30 05:00 0.50 WELCTL P CIRC SURFAC Cir till shakers clean. Pull into 7.625" csg.
05:00 06:30 1.50 WELCTL P OTHR SURFAC Conduct F. I.T. to 17 ppg EMW.
Cal. = 9.6 ppg mw + {920 psi imposed? [.052 x 2394' tvd]} = 16.99 ppg emw
06:30 00:00 17.50 DRILL P
DRLG PROD Dir Drlg 3060' [2394' tvdJ - 3997" [2837' tvd].
Parameters: P. Press 2100 spi 1300 gpm, Bit wts 5 - 8k Ibs, Torque @ RPMs
= 4k Ibs @ 85, pu I so / rot wts = 80/60171 k Ibs. Maintaining drilling rop
100 -120 fph.
Bit #2 hrs = 13 = art 11.7 + ast 1.3 hrs
ECDs in the 11.6 ? .3ppg range.
Back reaming hole x2 on each connection @ high rpm, hi vis I {occasional hi
wt) sweep each 2 -3rd connection.
24 HR SUMMARY: Complete rih w/ bit #2 / csg test I Drlg out I FIT I drg & survey
PERSONNEL DATA
NO. 'HOURS COMPANY
2 Bariod
2 APC
1 GBR
3
, COMPANY
Nordic
Catering
ConocoPhillips Company
Baker Hughes Inteq
SERVICE
, SERVICE
NO. ' HOURS' ,
3
1
ITEM
Rig Fuel
Rig Water
, UNITS'
gals
BBI
USAGE
310
201
MÄTERIAlS ¡CONSUMPTION
, , ON HAND ITEM '
7,618 Camp Fuel
210 Camp Water
::, .
,t...,
UNITS
gals
bbls
USAGE
, ,ON ,HAND
2,175
46
54
, TYPE,
2P-420
, NO.
120 Heavenly
'SUPPORT :êFiAFT
: REMARKS" ' , ", TyPE,
2P-420
NO. ,
1 ,116 2P-427
REMARKS,
RESERVOIR NAME
2P-420
2P-420
RESERVOIR AND ',IN"tERV AL DATA"
ZONË 'TÓpSA$E'
120 2 700
1116 2 500
,COM~NTS
Heavenly
2P-427
Printed: 10/1/2003 2:44:08 PM
- ,
-:~-~~i
, "I. .. . :' tl ", ~'" ! .
ConocoPhillips Alaska
Casing Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
String Type: Production Casing
Hole TVD: 5,853.0 (ft)
Ground Level: 224.00 (ft)
Circ Hours: 6.00 (hr)
Permanent Datum:
KB-Datum:
CF Elevation:
Mud Lost:
Manufacturer: FMC
Hanger Model: FMC
Actual TMD Set: 10,139.53 (ft)
-Item
Hanger
Casing
Casing - Pup Jt
Casing
Casing - Pup Jt
Cross Over(Locator sub)
Baker CSR Assy
Cross Over
Pup
Casing - Pup Jt
Casing - Pup Jt
Casing
Marker Jt
Casing
Casing w/plug catcher
Float Collar
Casing
Float Shoe
Size Weight Grade Drift Threads JTS
(in.) (Iblft) (in)
10.750 1
5.500 15.50 L-80 4.825 BTC 1
5.500 15.50 L-80 4.825 BTC 1
5.500 15.50 L-80 4.825 BTC 221
5.500 15.50 L-80 4.825 BTC 149
3.500 1
3.500 9.30 L-80 2.867 BTC 1
3.500 9.30 L-80 2.867 BTC 1
3.500 9.30 L-80 2.867 BTC 2
EUE-8RD 1
3.500 9.30 L-80 2.867 BTC 13
1
2.867 EUE.8RD 1
3.500 9.30 L-80 2.867 BTC 2
3.500 2.867 EUE-8RD 1
~ ."'. .
Report #:
Start:
Spud Date: 4/24/2002
Report Date: 5/16/2002
End:
2
4/22/2002
-.
èX~ê~
General Information
(in)
(ft)
(ft)
27.89 (ft)
Hole TMD:
Str Wt on Slips:
Max Hole Angle:
Days From Spud:
10,402.0 (ft)
165,000 (Ibs)
61.00 (°)
24.00 (days)
\-...-'
Rotary Table Hole Size:
254.00 (ft) Water TMD:
(ft) Liner Overlap:
(bbl) KB to Cutoff:
'Sà~,ih~~¡å~~~~'~~lih~~~+ .
Model: Gen V
Packoff Model: FMC
Top HublFlange: 11.000 (in) / 5,000 (psi)
BTM Hub/Aange:11.ooo (in) / 5,000 (psi)
..~. - - -- --... -
. ~._- -' ,....""" ". . -
-. --'.' ,-. -
. :.~¡.~ -'.' ~"~:'..~';~:...2~~.- -.
Integral Casing Detail
Length
(ft)
3.10
42.59
19.40
9,417.47
9.99
1.18
19.12
0.51
10.05
10.02
8.02
61.55
8.10
406.29
30.82
0.67
62.16
0.60
Top
(ft)
MU Torq. THD Manufacturer
(ft-Ibf)
. . ~ ':~ ~.~.-~;~-~.~:~-~ --.~:.~~~~~~~~~.:--:~'
- CoOd. Max ab --,~ ID::~~9oñ~p¡:N~8'-
(in) {inf" . - ,';
Model
27.89
30.99
73.58
92.98
9,510.45
9,520.44
9,521.62
9,540.74
9,541.25
9,551.30
9,561.32
9,569.34
9,630.89
9,638.99
10,045.28
10,076.10
10,076.77
10,138.93
N
N
N
N
4.950 51/2" 15.5# L-8
4.950 51/2"15.5# L-8
4.950 51/2" 15.5# l-B
4.950 51/2"15.5# L-8
5-1/2" BTC x 4.7 ~
N
4.75 Acme x 3-1/
3 1/2" 9.3# L-80
2.992 3 1/2" 9.3# L-80
2.992 3 1/2" 9.3# L-80
2.992 3 1/2" 9.3# L-80
3 1/2" 9.3# L-80
2.992 3 1/2" 9.3# L-80
3 1/2" 9.3# L-80
2.992 3 1/2" 9.3# L-80
Printed: 9/2/2003 3:41:02 PM
.: 0"
..
ConocoPhillips Alaska
Casing Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Report #:
Start:
2
4/22/2002
Integral Casing Detail'
Item
Size
(In.)
Weight Grade
(Ib/ft)
Drift
(In)
Threads JTS
Top
(ft)
MU Torq. THO Manufacturer
(ft-Ibf)
Length
(ft)
10,139.53
. I <' , " ' . , ,.' .',
, ~ön~ÙitêgråIC,à~~h9,::;~èc~ssÓ~ies', ,
, Number
Bowspring Centralizer
Bowspring Centralizer
Centering Guides
WEATHERFORD
WEATHERFORD
WEATHERFORD
18
18
23
Remarks
I .:~ ~
. ..... --<;:!'I~1~'
.,
,.
Spud Date: 4/24/2002
Report Date: 5/16/2002
End:
..Condo MaXbéM~~:~i!
. . On)" ""(10):"-:----:""
Model:
.~
" :ròj:{(ftf
9,500.0
8,750.0
200.0
10,140.0 3.5" X 6.5
9,500.0 5.5" X 6.7
3,000.0 5.5" X 6.5
Batch mixed cement. Pumped 40 bbls CW 100, 30 bbls Mud push @ 11 ppg, and 50 bbls "G" with gas blok at 15.8. Displaced cement with 10.6 brine at 3 bpm. Pressure increased from
80 psi-380 psi as the cement started coming up annulus after pumping 3795 strokes(calculted 3897 strokes) When the plug entered the 3-1/2" casing the psi increased from 380 psi to 490
psi. Pumped cement per Schlumberger job design. Calculated plug to bump-3972 strokes. Actual strokes to bump-3867. Plug bumped on calculated volume after entering the 3-1/2.
casing. Bump plug to 850 psi. Floats held CIP @ 1700. Full returns entire job. Reciprocated casing with a 12 ft stroke the entire job.
~
Printed: 91212003 3:41:02 PM
')
)
~t;,J~;n';~~;t~;~~ri::~~~;~¡~;t;;i;r~.;,~:;:;-."j!l~,'[;f~~~~~~!Í:!I~f:~~;;;;.'1;1:~~!;:,~Pf~f~~~;t'{,::';.'f,~.:Y;;?¡;~~1~1~~~'
~~~j:t~'~:,:;¡~r\ ;::;: ::;',.< 1'Mil?: ;~;;:I.!;::?~~~~~t~'~';Ft~þ~í;t:'.:.;:. .' ; ~.... . 'iX' ... ':.' .. ,;?;;'/,:~:i~:';~\:::'
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
I,' I ~ ','..
, 1-,
.' ~ " ' '~:~. :"pri~£ry 'i":'
Hole Size: 6.750 (in)
TMD Set: 10,140 (ft)
Date Set: 5/16/2002
Csg Type: Production Casing
Csg Size: 5.500 (in.)
Cmtd. Csg: OPEN HOLE
Cement Co: Dowell Schlumberger
Report #:
Start:
Spud Date: 4/24/2002
2 Report Date: 5/16/2002
4/22/2002 End:
. ,
.:C,ement, Jo~ Type~,.:,~~~m'~~
, f . \ '",:', . I
, Squeeze Open, Hole"
Hole Size:
sa TMD: (ft)
sa Date:
sa Type:
Cmtd. Csg:
-, 'SqÙeeze Casing
Hole Size:
TMD Set:
Date Set:
Csg Type:
sa TMD:
sa Date:
Cmtd. Csg:
',~ .
Plug
Hole Size:
Top Set:
BTM set:
Plug Date:
Plug Type:
Drilled Out:
Cmtd. Csg:
Pipe Movement: Reciprocating
Cementer: Dean Waters
(ft)
(ft)
. .,
. .. . ...
, .' . .
. '. "~iPe::Mov~m'~nt '
Rot Time Start: : Time End:: RPM: Init Torque: (ft-Ibf)
Rec Time Start:00:30 Time End: 15:00 SPM: 50 Stroke Length: 12.0 (ft)
Type: Cement Casing
Volume Excess %: 75.00
Meas. From:
Time Circ Prior
To Cementing: 12.00
Mud Circ Rate: 3 (gpm)
Mud Circ Press: 500 (psi)
Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf)
Drag Up: 175,000 (Ibs) Drag Down: 55,000 (Ibs)
. . . . .
. ',;:Støg~:'~~:;:1:Þt.1;'
Start Mix Cmt: 14:00
Start Slurry Displ: 15:00
Start Displ: 15:00
End Pumping: 16:00
End Pump Date: 5/16/2002
Top Plug: N
Bottom Plug: N
Disp Avg Rate:
Disp Max Rate:
Bump Plug:
Press Prior:
Press Bumped:
Press Held:
Float Held:
3.00 (bbl/min)
3.00 (bbl/min)
Y
380 (psi)
850 (psi)
5 (min)
Y
Returns: 100
Total Mud Lost: (bbl)
Cmt Vol to Surf: (bbl)
Ann Flow After: N
Mixing Method: Batch
Density Meas By: Densometer
Type: Non-Disp. LS Density: 10.5 (ppg) Visc: 36 (s/qt) PVNP: 13 (cp)/9 (lb/100ft2) Gels 10 sec: 2 (lb/100ft2) Gels 10 min: 4 (lb/100ft2)
Bottom Hole Circulating Temperature:90 (OF) Bottom Hole Static Temperature: 120 (OF)
Displacement Fluid Type:Brine Density: 10.6 (ppg) Volume: (bbl)
Slurry Data
Fluid Type: FLUSH
Slurry Interval: (ft)
Water Source:
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
(OF)
. . . .., ~,,'. . . : . t, '.
.'.. ~tå~:~:,:~QH1::#i~:~~',~:():,:~::~(~:; ;:.. ..., ..
To: (ft)
Description: CW100
Cmt Vol: (bbl)
Slurry Vol: (sk)
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
Density: (ppg)
Water Vol: (bbl)
Class:
Yield: (ft3/sk)
Other Vol: 0
Time
Compressive Strength 1:
Compressive Strength 2:
. .I~ .
Purpose:
Mix Water: (gal)
Foam Job: N
Temp
(OF)
(OF)
Pressure
(psi)
(psi)
Printed: 9/2/2003 3:40:42 PM
)
)
~'C 'j~¡:l~~:,rl~~~~~2~i~'d;s;:1~';~.~:~:J'~¡~i~f.~fii~~~¡~~~':1i,~fEtì;i~~,~.;i:,;::r;.. ,;)i~¡i\~~¡:,t_1~f~:!
¡~:.:::t;-i';f.I>""¿1 ~f~~t::: '. : : :~,::,.,)"'~ ';: :'!:'{':~F~~,~~~, :::.\.;<:', <i:;~{;.~" ~~Y!jt:~'::)Jj:;;1:j~:f;~'~~jtITr:r ;:;~!;~;,~i'::~'t r;') ;i:\ ~;': " ':...'~ :,:': ,:: ': ~ ',"" "":,:;, ,:'r:".' . I:,: :';'~:i":'}~ : ", ,:," ,', .. :'\'~t:J~~~; :~:J(~ f; '~L;í:'
(~;?:~~~:~;::::~L: '::~;;': . ,. . .. ".. .. ::11~B;:,~~!':n9.~i~c:.~~"':I,:, C:', :'.' "'.:' :': .... .:,';': :/:l:3;::
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Slurry Data
Fluid Type: FLUSH
Slurry Interval: (ft)
Water Source:
Test Data
Thickening Time:
Free Water: (%)
Fluid Loss: (cc)
Fluid Loss Pressure:
(OF)
Report #:
Start:
Spud Date: 4/24/2002
2 Report Date: 5/16/2002
4/22/2002 End:
, Stage No: 1, Slurry No:,2 of 3 :
To: (ft)
Description: MUDPUSH XL Class:
Cmt Vol: (bbl) Density: 12.00 (ppg) Yield: (ft3/sk)
Slurry Vol: (sk) Water Vol: (bbl) Other Vol: ()
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
Slurry Data
Fluid Type: PRIMARY
Slurry Interval: 10,140.00 (ftP:
Water Source:
Test Data
Thickening Time: 4.50
Free Water: (%)
Fluid Loss: 12.0 (cc)
Fluid Loss Pressure: (OF)
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
(OF)
(OF)
:st~ge N,c?::1:, ~Jutry~ô: 301;3 "
Description:
9,000.00 (ft) Cmt Vol: 50.0 (bbl)
Slurry Vol235 (sk)
Temperature: (OF)
Temperature: (OF)
Temperature: (OF)
D-65
D-53
D-800
Class: G
Density: 15.80 (ppg) Yield: 1.20 (fP/sk)
Water Vol: 30.0 (bbl) Other Vol: 0
Time
Compressive Strength 1:
Compressive Strength 2:
Temp
(OF)
(OF)
Purpose:
Mix Water: (gal)
Foam Job: N
Pressure
(psi)
(psi)
Purpose:
Mix Water: 5.30 (gal)
Foam Job: N
Pressure
(psi)
(psi)
','
"",' '" . .
..,~ ,;:~.~~~~N~,:, ~::.~,I~,rry':~Ó~,3.. ~f:3,~, Åd~:i~!y~~:...
~~:::--~(:":~~"~?TYPe '.",~,
DISPERSANT
GYPSUM
RETARDR MID-T
.. Concen'tTåti6rí',:
0.30
3.0C
0.02
, ~"::"\Jh¡ts/
Printed: 9/212003 3:40:42 PM
)
)
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Report #:
Start:
Spud Date: 4/24/2002
2 Report Date: 5/16/2002
4/22/2002 End:
.-, .
: ::;f"~~~,~~ie$. ,.
"'r,',::., ;,.;",,:;,-:"S'~4:;Test ,
Pressure: (ppge)
Tool:
Open Hole: (ft)
Hrs Before Test:
. ",. I "
, c.,
,I !
, ,Lln~r Top Test, . - '
-, -
.,1, "
"
Test Press: (psi)
For: (min)
Cement Found between
Shoe and Collar:
.~~~J!,,:r~~~~~~~.:~Få¡~~i\~~':;M;>,k':.:.
',.'1'.
Liner Lap:
Pos Test: (ppge)
Neg Test: (ppge)
Hrs Before Test:
Cement Found on Tool:
.: .:.. .i'}l~~~i~~~~~:~~:~~~frt~~
Tool:
Tool:
" .,H'
. '.lJ:'
,-
" ,'.; I,
, . ~ .:.
, , -
CBL Run:
Under Pressure: (psi)
Bond Quality:
Cet Run:
Bond Quality:
Temp Survey:
Hrs Prior to Log:
Cement Top: (ft)
How Determined:
TOC Sufficient:
Job Rating:
If Unsuccessful Detection Indicator:
Remedial Cementing Required:
Number of Remedial Squeezes:
Printed: 9/2/2003 3:40:42 PM
)
)
~~~~:~,
W~~~E ..2P-427.. ... IJOBNUIIB~~ I~~~D~DE 12~HRSPAOG . ~;'402.0 1~:853.o1~~4.00 I~EPT;. 1~~O02
SUPERVISOR I RIG NAME & NO. I FIELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANG
Dear! W. Gladden n1433@ppco.co Nordic 3 Meltwater 10,500.0 0 0
CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD
TIH W 13.5. Completion Tbg Assy ( @ Jt 186) (Temp 52?) 0 0
24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD
Finish running csg. - Cir & Cond mud. - Cement. 5/16/2002 187,172 3,215,944
UTHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH.
AK0230 2,985,046
LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
51712002 10,402.00 64.340 161.660 7.625 (in) @ 3,030.0 (ft) 5.500 (in) @ 15.5 (ft) 5/4/2002
DENSITY(pþg) 1 10.50 I PP I ¡ECD IMUD DATAl DAILY COST I 0 I CUM COST .j 0
FV . PVIYP GELS WLlHTHP FCIT.SOL OILIWAT %Sand/MBT Ph/pM PflMf CI Ca H2S LIME ES
36 13/9 2/4 2.8/ I I /15.0 9.9/ /
:::t~~;~ELÒW'J~1. ~.'\~,~:'.~~iNG Wt.u,p>,: / . .':)::S:I~~b~~7i:C.~;~~~J~~~~òt:.
. ,,:ITEN! DESCRiPTiON
Hole Opener
Bit Sub
Drill Pipe - Non-Mag 4 Comp Serv
3-Pt Roller Reamer
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy W gt
\~>'j~,~.lÁ,ÛN ,,'
I
SIZE',
-' ,:MANUF.
¡;~p'M' :. ;;iõ :',/.
00:00 00:30
00:30 03:30
03:30 12:30
»~.OÜR,'S', ' :<~copË .
0.50 CASE
3.00 CASE P
9.00 CASE P
12:30 13:00 0.50 CASE P
13:00 14:00 1.00 CASE P
14:00 15:00 1.00 CEMENT P
15:00 17:00 2.00 CEMENT P
17:00 18:00 1.00 CEMENT P
.'.. "NÖ ..ITS.:
1
1
1
1
1
18
1
14
LENGTH :.
5.14
2.00
30.83
4.54
2.54
552.46
29.54
426.68
, , . BITS
. ~:1YPE,:,: ,SERIÀL,~Q(: '. ,~È~ 9.R,ÌFA
16/116/16/1
. '. <;J~D~ : .
6.750
4.750
4.750
6.750
6.750
4.000
4.750
3.500
I BIT N~. J .. .
, BHAiENGTH {.
1,053.73
tD/''c': :~ONN,SIZE'-,CONN .TYPE'.
'~~'Í~ùN;:I;.. .. Wô~;.¡'.I. .~P,~:'I..~~~';I':~~~~~~~'ir~~tI~~~~r:;~~r~ls+¡I;~~i~~¿;:~'~~~~~~$'I~~p~~jku"~~Q~
..'::::1H.!,f:.', ;:;;':'::;:'.',':-:',',",'/.f/,',:--.i:.,->,',,:.', ;iY',;::::::;~,!.:;':,::,::,':i;,::;<:.:,~:,\/ 'Ci^';:C;,:<' 'i,:,": """"":OPER:ATIONS SUMMARY'::,"" :::::");('~.'J¡,f,:,':.,'-,;;!,,:,H':'1::r.:::..~,;,.::,:.:~~,:',;F:c' . ">": <";".,,, ,
. . " '. iRoUB~E';~i:~~~:,""~pij~~.;"'~:':c -." ,',":: ::..~:':,:':. :',:.. .::/":, ,:"::'r¡~Sqijl~:~(~';:U:l'l,,,:::..'Ji:'::::è'::':~::';'::~~\ ':. ::;':',
CIRC PROD Finish circulating bottoms up at 9775' at 40 spm with 600 psi.
RUNC PROD Wash the last 22jts to bottom.
CIRC PROD Make up landing jt and break circulation slowly. Stat at 20 spm(1.2 bpm) and
increase to 50 spm(3.0 bpm) with no losses and 500 psi.
SFTY PROD Pre job safety meeting with all personnel.
RURD PROD UD Frank's fill up tool and make up Dowell cement head. Transfer mud from
pits to ball mill to make room for cement job.
CIRC PROD Continue circulating while Dowell batch mixed cement.
PUMP PROD Test lines 4000 psi. Pump 40 bbls CW100 and 30 bbls 11 ppg mud push.
Pump 50 bbls(230 sxs) "G" @ 15.8 ppg with gas blok. Drop wiper dart and
displace 10.6 ppg brine with rig pumps at 3 bpm. Slowed rate to 2 bpm when
cement came around shoe. Psi increased from 80 psi-380 psi. Plug bumped
early(3972/ 3867) but bumped right on the calculated volume inside the 3-1/2"
casing. Bumped plug to 850 psi. Floats held. Reciprocate casing with full
returns the entire job.
RURD PROD Rig down Dowell
~: tOF(auEt UN(f$:,
1.500
2.678
1.812
2.250
2.250
2.250
2.250
. , .
" ,
,;DI;PTIiiN':D~TI: ÎN. . +~.D-L~B-G-o-~.
10,402.0 5/11/20020-0------
Printed: 9/212003 3:40:00 PM
)
)
~LL HAMEL... .2~-4~7 .. . IJ~ N...~È~ i ÈY~D~E 124';" PHOG 1~~402.0 ITY;'S53.<r ID~4.oo .1 ~~Pr ;;. 1 ~;;~2002
'.. ,
'OPE~ATIÓNS ,SUMMARY' ,
, 'PH~SE' , : " ': , ,DESCRIPTION,
PROD Finish loading pipe shed with 3-1/2" tubing.
PROD Lay down landing jt. Install 5-1/2" packoff and test same to 5000 psi for 10
minutes.
NUND PROD Set test plug. Change top rams to 2-7/8" x 5" and bottom rams to 4" Test
same to 250/3000 psi
"
FROM: TO ",ÌioÚns ,uCODE ',TROUBLE'" SUB
18:00 19:30 1.50 CASE P OTHR
19:30 22:00 2.50 CASE P RURD
22:00 00:00 2.00 WELCTL P
24 HR SUMMARY: Cir last 22 jts in well. Cir and cond mud. Batch mix cement per well plan. Dispalce and bump plug. Ld landing jt. Set
packoff. Change rams.
: ~ '.'.:i:~ ~.f':" :~. .
, ::PEASONNECDATÄ":>, :
<,NO;' : ,HQÜRS':'ëo,M~ANY
3 APC
2 GBR
2 MI
Schlumberger
, ,
, cØ~p~'{
Nordic
Catering
ConocoPhillips Company
Baker Hughes Inteq
Bariod
';:.-
:J, 9~,:{ :J:¡O~~$ ','
2
4
" ~ '-" ..: ,r ,~ .
'-, ,,:M'ATERIÄLSICONSUMPTION
USA~É : ~ONtJA~D ,.' , )"tEM"
1,160 3,820 Camp Fuel
209 195 Camp Water
SUPPORTlCRAFi"
" , ':. ':"TYPE::
46
:"" frË'-' ~\t.'
,Rig Fuel
Rig Water
UNITS .
gals
BBI
,NO~'
, .
2P-420
2P-427
: :~" '.
. " ,,' RESERVOIR AND]NTERVALDATA",
:ZÖNE' , . TOP' . . BASE' "
1070
. ., .. .
''I', ':,:::;:RE~~RVÓlli~I\ME :'
2P-420
2P-427
Printed: 9/2/2003 3:40:00 PM
CASING TEST and FORMATION INTEGRITY TEST
Weff Name:
Date:
5/18/2002
Supervisor: Dearl W. Gladden
2P-427
0 Initial Casing Shoe Test
Reason(s) for test: 0 Formation Adequacy for Annular Injection
0 Deep Test: Open Hole Adequacy for Higher Mud Weight
Casing Size and Description: 75/8" 29.7# L80 X 5.511 15.5# L80 Ann
Casing Setting Depth: 3,030' TMD Hole Depth: 3,060' TMD
2,380' TVD 2,394' TVD
Mud Weight: 10.5 ppg Length of Open Hole Section: 30'
EMW= Leak-off Press. + Mud Weight = 682 psi + 10.5 ppg
0.052 x rvD 0.052 x 2,394'
EMW for open hole section = 16.0 ppg
Pump output = 0.0583 bps
Fluid Pumped = 8.7 bbl
2,000 psi
1,900 psi
1,800 psi
1,700 psi
1,600 psi
1,500 psi
1,400 psi
1,300 psi
W 1,200 psi
§ 1,100 psi
~ 1,000 psi
~ 900 psi
D. 800 psi
700 psi
I I I I I I I I
-+- LEAK-OFF TEST
---CASING TEST
-$- LOT SHUT IN TIME
-.-CASING TEST SHUT IN -
TIME
.
~
600 psi
500 psi
400 psi - ~ '
300 psi /
200 PSi"
100 psi,
0 psi ~ ~ I') '"
- - -
, ~ .
~ 01 en -..J
.. ..... -'> .....
Q> '" -
- - 0
...... ...... -" .....
..... I\) c-:r .....
.... ..... ..... ...
..... ...... - .....
en 0) ...., CD
..... ...... ..... .....
~ g ~ ~ ~ ~
STROKES
NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above
LEAK-OFF DATA
CASING TEST DATA
MINUTES
FOR
LOT STROKES PRESSURE
,----------------,--- -T- ~ -, ,-
,---------------~_st~!_ul_m~O_psi i I
L______--______1 4 s~.!<~ --1--- ~~O psi j 1
j--------------- 1 m~ ~!~s --t. 31 0 ps~ j l
1---------------1 1 ~_st~~_-L-_~5~p~i J l
1--------------- ! - 1.6 s!~~--!--- 380 psi -- .' i
I-----------~- - I ~~-~t!<s_-!---~ 10 psi ~ ~
1-------------- ¡ ~~- st~~-.---~!O p~i..: l
I I 40 stks I 520 psi ~ !
I._-------------+-------------t - - ---- of ~
L______-----_...L_~~ s!k~ -l-__~~5 'p'si i !
L___---_m- __1- !O ~!~!..L- ~~~ .esi ; l
L-------------l--~~-!!~~--L-- 5~~.esi 1 i an
L------------L!~..Q-~t~~-.! 625 psi 1 ~--
! I 130 stks! 665 nsi I I
,----------------.,..-------------".... h -... - .. r'"
I I 150 stks I 682 psi I I
1----------------+------------ J-. - -- I f--
il::::=:==:::::t::::::=:::::~t::--:::_- a:: j t -. - --
, , , , I
I-------------_J._-----------t- .------. ~-~ 1 1-- - t
I ! I I I I
¡-----------r------------ - t- Uu -1 tu . I
, I I , I I
1----------------:--------------:-- -- --1 t t
I I I I I I
1---------------1--------------""'."'''' .
! ¡ ¡ I i SHUTINTlME !
,---------------.,..-------------.,- ... 'i .... ..
1---------------- i - -. ---- u i - .J ~ 0:0 min ~
I : : I I 1.0min ,
1-------------- I I I ~ .-1
I I I I I 2.0 mln I
I . . . ~ +
I SHUT IN TIME ¡ SHUT IN PRESSURE' 3.0 min I
'---------------1 .- -.. --..--. - 1 l - -t -
I 0.0 min I I 682 psi, ! 4.0 min I
1----------------'-------------. &_....... ....--- .- .. - -.
1 0 . I I 590 . I , 5 0 . I
L--:---~!~---L--. -- - t pSI i:. . mln l -
'---~:Q.-~!~---L--- --- L ~70 psi i I - 6.0 min l -
r---~:Q.-~!~ ! ----------___-J...5~~ p~i j I 7.0 min !
---~:Q.-~!~---J - ---------_.J-- 5~0 'psi J ~ 8.:0 min i. .
I---~:Q._~~n -- i ----------- -i - ~?O esi_-_.' ~ 9.0 min ¡
I---~:Q. m!~___¡--------------t-- 540 .esi . I 10.0 }),in i
L_!.~_~!~---+-----_. uU -i 540 psi I ! 15.0 ~il'! ~
L_~:Q._~!~-- ! -. ---- ---- 1 5~0 p~i: ! 20.0 min L-
I 9.0 min I I 530 psi! ! 25.0 min I
I----------------î------------.----~ - ... ~
L_!Q:9_~!~__1______--__--___L_.!.~~si J t .30.0 min l
MINUTES
FOR
CSG TEST
STROKES
, -0 stks ~,
t
__l
. ~
r-
!
~
I
~ -
I
t
f
I
PRESSURE
0 psi
I
.
'"
. j
i
!
..
iI
I
i
,
ì
1
;\,-,'
!
1
I
i
I
I
i
of
I
~
I
I
,
I
,
i
,
i
SHUT IN PRESSURE
0 psi
.
+-.
I~
,
I
,
;
- i
!
i
1
,
j
I
!
NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY
. . .
: 'PhnJlPs'A~~.~I<.~~ I,nc.
.: " ", '.,øÍ1íly'~~llíHj,g~R~þQn'
I JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS I REPT NO. I DATE
2P-427 ODR 10',402.0 5,853.0 26.00 27 5/18/2002
SUPERVISOR I RIG NAME & NO. I AELD NAME I OCS NO. AUTH MD I DAILY TANG I CUM. TANGO
Dear! W. Gladden n1433@ppco.co Nordic 3 Meltwater 10,500.0 0
CURRENT STATUS ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD CUM INTANG WI MUD
Rig Released @ 0600 hrs 5/19/02 0 0
24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL CUM COST WI MUD
Put Rig on Matts and move off well 5/17/2002 448,713 4,113,370
LITHOLOGY JARHRSOFSERVICE BHAHRSSINCEINSP LEAKOFF AFE AK0230 AUTH. 2,985,046
LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING LAST BOP PRES TEST
5(7/2002 10,402.00 64.340 161.660 7.625 (in) @ 3,030.0 (ft) 5.500 (in) @ 15.5 (ft) 5/4/2002
"D~Nsnj(ppøLI 10.50 Ip~l. .' leêD .' IMÜb.DAfAlDAILVCOsT I 0 I :cUM'èoST 0
,i=v, :'pv"rf.P: ,GELS', WLlH1:HP FCrr.SOL' OIUWAT" ::~ndIMBT' 'Ph/pM', 'PflMf CI ,'Ca," ;', H~S 'LIME' ES ,
36 13/9 2/4 2.8/ I / /15.0 9.9/ I
)
WELL NAME
BHA.NO~, , I
BHA WT.' BELOW JARS
')
Page 1 of 2
STRING WT. UÞ,
. BHA1,HoLe:CONDITIONS,
, STRING wr." DN ' '.StR~NG wr. RÒi-
. TORQUE/UNITS
,f BITN.o.I, ,
, BHA LENGTH
1,053.73
"'CONN SiZe, CONN lYPE '
ITEM' DESCRIPTÍON .
Nom
1
1
1
1
1
18
1
14
Hole Opener
Bit Sub
Drill Pipe - Non-Mag 4 Comp Serv
3-Pt Roller Reamer
Crossover
Drill Pipe - Heavy Wgt
Jars
Drill Pipe - Heavy Wgt
. LENGTH
5.14
2.00
30.83
4.54
2.54
552.46
29.54
426.68
,ò.~. .
6.750
4.750
4.750
6.750
6.750
4.000
4.750
3.500
, I.D.' ,
1.500
2.678
1.812
2.250
2.250
2.250
2.250
,BI:THmN ,
/
MANUF. '.
. ,BITS"
TY~E . S~RIAL NO. " ,JETS .oR TFA,
16//16/16//
" DEPTH IN DATE IN :. . I-O-t:rL-B-G-o-R
10,402.0 5/11/20020-0------
::. ' . BIT, OPERATiONs,., . '. .
: ~rr ¡'R~N.' ~,I" ,WaB I,' RPM: .~'~~~" 'I ~RE:s~fJ,:Þ~IT;:;':I>:ÏiRS:" I :2~HI'DIST . 241;frROP I CUM Hijs.1 CUMb~PTH:I,cOM~()~
. ". ' '. .. ,:"OPE~ATiONS"~UMMARV.
FRQ.~ TO',' ,H~U,R~' 'CODe' TR'OUBLÊ c:sùe 'PH~SE' . .' ",. , "DES:~RIP1ioN
00:00 01 :00 1.00 CMPL TN P FRZP PROD Con't to RlU to 7.625' X 5.5" Ann
Preform LOT per program - Original 2394' TVD - with 10.5ppg mud in ann =
Pressure at surface 682 psi = Held 16ppg EMW . After 10 min shut in psi was
520psi.
Bring pump on line - Formation broke dn @ 900psi (17.7 EMW) - Con't to
pump @ .25 bpm = 630psi injection rate - Freeze protect 7.625" X 5.5" Ann
with 35 bbls diesel (2121' MD) - RID holes
Dress Tree with all blinds & guages - Clean cellar area - SI tgb 0 psi, SI IA 0
psi, SI OA 650 psi
Clean all extra equip from pipe shed - PJSM - RlU to UD drill pipe
UD drill pipe from derrick using mouse hole
S~E
01 :00 05:30 4.50 CMPL TN P
FRZP PROD
05:30 06:00 0.50 CMPL TN P
RURD PROD
06:00 08:00 2.00 CMPL TN P
08:00 00:00 16.00 CMPL TN P
PROD
PROD
24 HR SUMMARY: Preform LOT - Freeze protest Ann - RlU & UD drill pipe out of derrick
Printed: 10/1/2003 2:43:24 PM
",
WELL NAME
, COMPANY
Nordic
Catering
" ,
, " ,ITE,'"
Rig Fuel
Rig Water
TYPE
2P-420
. ' ;'RESERVOIR NAME:
2P-420
"
2P-427
'UNITS '
gals
BBI
NO.
2P-427
. :'¡ '. . . .
: ':\i1pHullþsAláS:ka '" ::InC.
;i"?~I\~l)tilll~9~~P~rt . <'... .
I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD I TVD
ODR 10,402.0 5,853.0
, . :ÞÈRS'ONNELDATA
NO., HOURS, ' COMPANY
3 ConocoPhillips Company
1 APC
)
SERVICE
:MATERIALS100NSÜMPTION
USAGE" ,:' OthiAND' ":.' iTEM' .
610 4,850 Camp Fuel
444 391 Camp Water
, ":,,SOPPORTCRAFT ,
,REMAÄKS' " , , 'TYPE
2P-427
, "RESERVOIRAN'D:INTEFiVALDATA'
'ZO~E' ", :TOÞ" BASE'.'
0
')
"Ur:<IlTS
gals
bbls
'NO.",
! ..t
, ,
'Þåg~2 of:2
DFS REPT NO. DATE
26.00 27 5/18/2002
,SÈRVICE "
NO. HOURS
1
1
USAGE'
"\ , "
, ON'HANi>'
2,645
89
11
REMARKS
COMMENTS
Printed: 10/1/2003 2:43:24 PM
RE: 2P-422A Annular Disposal Application
)
Subject: RE: 2P-422A Annular Disposal Application
Date: Wed, 22 Oct 2003 09:11:28 -0800
From: "Hayden, Philip" <Philip.Hayden@conocophillips.com>
To: "Tom Maunder" <tom_maunder@admin.state.ak.us>
Tom,
Here are the recalculated pump in pressures with some comments for the
wells in question. (Did you want them in an excel spreadsheet?)
2P-417: 14.3 ppg
2P-422: 15.2 ppg (unchanged as the difference between the correct and
incorrect TVDs was so small)
?P-44~: 17.2 ppg. This "new calculated" pump in pressure is greater than
the original FIT of 16.2 ppg. This is attributed to the fact that an
intermediate casing string was run on this well due to a "{ell con~rol
problem. This resulted in a shoe (and cement) approximately 1500 ft TVD
higher than any of the other wells drilled on Meltwater. We conclude
that the formations exposed on the other wells, including our candidate
well 2P-422, are isolated in the case of 2P-441.
Regards
Philip
-----Origina I Message-----
From: Tom Maunder rmailto:tom maunder@admin.state.ak.usl
Sent: Wednesday, October 22, 2003 8:11 AM
To: Hayden, Philip
Subject: Re: 2P-422A Annular Disposal Application
Philip,
With regard to the "new calculated" pump in pressures for 2P-417, 2P-422
and
2P-441, would you please provide them??
Thanks,
Tom Maunder
"Hayden, Philip" wrote:
> Tom,
>
> In response to your comments:
> ./
> For the pump in test for well 2P-420 I must apologise for not having
> made sure that the sheet had been correctly filled in. Your
calculation
> of 14.2 ppg EMW had been previously confirmed by us but the sheet had
> not been corrected. /
> v/ J v
> For wells 2P-417, 2P-422 and 2P-441 the incorrect TVD was used for
> calculating the EMW for injection at the shoe. This had been noted by
us
> and the corrected EMW for injection at the shoe had been determined
and
> found to be, in all cases, lower than the original injection pressure
at
> the initial leak off or formation integrity test. We did not amend
these
> files before sending them on to you as they are part of the official
1 of 3
r t' )~ po~-\. C)~ \- ~ '\ ~ 1\ \)
c...V ~U~\..\t::>C'\ c::.... \> þ., ~~'o~, ~~'
\4tc.c~,:> O\:- -\ "t: ~\~'>.J\~ ~\\
Ç)?-\,\,-\\, ~Ç>-,--\~\ d~_LI
JP '\ ð~
- ~~d~'~?~dÙ\~~_~\\
\ "<l \<1 ~\ ~ ~<i: , \ ~ ~~ tx-r;.---: -I
L r ......\,,)\~~~
Df<.~ '"' c. p\>D:) \;)~ ~ -\.0 f:\
r~.....c... ~ "\",, ~ \,,~ C- ~. 1~
~ 'v\-. -\-0 -\. h ~ \t(: <; ~ o.~ \ ~ '" \)..J Co ~
\ C\"--') ~ú.'( c.~'f Pc:c-\.\ \,)c- ~<è~
ç\\~~
,
1r2~
t t)/. ~
1,Ji)-t;.
10/22/2003 9:59 A~
RE: 2P-422A Annular Disposal Application
)
> files. This would have lead to two different sets of data for these
> wells and we felt this could be potentially more confusing. On the
other
> hand we recognise now that we should have brought this to your
attention
> in our initial correspondence. We will be sure to do so in the future.
>
> For well 2P-431 we have been unable to locate any record of a pump in
> test after the initial leak off test was performed. We do know that
this
> annulus has been freeze protected and also that methanol has been
pumped
> down it to remove a hydrate plug but accurate pressure information is
> lacking. However, due to its location, between wells 429 and 441. we
are
> confident that its behaviour with respect to a pump in test is similar
> to these wells.
>
> I hope this note adequately addresses your comments and questions. If
> there is anything else please let me know.
>
> Regards
>
> Philip
>
> -----Original Message-----
> From: Tom Maunder {mailto:tom maunder@admin.state.ak.us}
> Sent: Monday, October 20, 2003 9:07 AM .
> To: Hayden, Philip
> Subject: Re: 2P-422A Annular Disposal Application
>
> Phil,
> Here are my further comments/questions on the 2P-422A application. I
> look
> forward to your reply.
> Thanks.
> Tom Maunder, PE
>AOGCC
>
> On the 2P-420 pump in test, the calculation has not been done. TVDs
> have
> not been entered. Using the 550 psi maximum pressure and the shoe
tvd,
>1
> calculate 14.2 EMW. The EMW of the sustained pump in pressure would
be
> slightly lower.
>
> On the pump in test of 2P-417, the calculation does not use the tvd of
> the
> rathole at the surface casing shoe. Using 2430' tvd, the EMW
calculates
> to
> 14.2 which is in agreement with the calculation for 2P-420.
>
> Tom Maunder wrote:
>
> > Hi Phil,
> > Welcome back. I was looking at the application and I have a couple
of
> > questions. Please note that I am not finished with my review of the
> > packet. This first note wíll allow you to capture my eddress.
')
2of3
10/22/2003 9:59 A~
~E: 2P-422A Annular Disposal Application
)
)
»
> > My questions/comments are:
»
> > On the pump in plot for 2P-422ST dated 4/22/02, the TVD used in the
> > calculation is not the same as done on the initialleakoff dated
> > 2/20/02. Why the difference??
»
> > The TVDs on 2P-441 also are different. In particular the pump in
TVD
> is
> > listed as the mid point between the top of cement and surface shoe.
> All
> > EMWs should be referenced to the surface shoe.
»
> > There is no pump in test for 2P-431.
»
> > You have made the appropriate tvd change on 2P-429.
»
> > Tom Maunder, PE
> > AOGCC
3of3
10/22/20039:59 AI
)
)
Randy Thomas
Greater Kuparuk Team Leader
Drilling & Wells
ConocJPhillips
P. O. Box 100360
Anchorage, AK 99510-0360
Phone: 907-265-6830
RL Thomas@ppco.com
November 26, 2002
Commissioner Cammy Oechsli Taylor
State of Alaska
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, Alaska 99501
Subject: Completion Report for 2P-427 (202-018/302-165)
Dear Commissioner:
Phillips Alaska, Inc. submits the attached Completion Report for the drilling
operations on the Meltwater weIl2P-427.
If you have any questions regarding this matter, please contact Pat Reilly at 265-
6048.
Sincerely,
~~
R~ Thomas 1
Greater Kuparuk Team Leader
CPAI Drilling
RL T /skad
RECE\VED
NOV 2. 6 2002
Alaska on & Gas Cons. Commission
Anchorage
) STATE 'oF ALASKA ')
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Oil 0 Gas 0
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
924' FNL, 1992' FWL, Sec. 17, T8N, R7E, UMr"'¿r;J(:¡¡~T.¡ST5f.tl
At Top Producing Interval ~ lð ~~~ oot'
2338' FSL, 1246' FEL, Sec. 20, T8N, R7E, UM1 '-'~~~:-;;I~:~;- "
At Total Depthì¡¡bK:ç/J ,
1964' FSL, 1104' FEL, Sec. 20, T8N, R7E, UM ì':::~-:J (ASP: 446077, 5861265)
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
RKB 27' ADL 373112 & 389058, ALK 4998
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore
April 23, 2002 May 7,2002 Dc.t ;)AaV1'"9, 2002 ¿!1> NIA feet MSL
17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set
10402' MD 15853' TVD 10045' MD 15697' TVD YES 0 No 0 NIA
1. Status of well
Suspended
0
Service 0
~, II" ",'IIf', \:,-,. " t.:, '''*J'iII''J.t, t
Jl<X'A~r!
i~~~
1i. Æ~~~~Jt
~:~"."~~:)~",,~~n~
(ASP: 443952, 5868953)
Abandoned 0
(ASP: 445964, 5861641)
22. Type Electric or Other Logs Run
23.
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
TOP BOTTOM
Su'rlace 120'
Surface 3030'
,. Surface 9541'
9541' 10140'
CASING SIZE
GRADË
B
! L-80
'S--, L-BO
L-80'
included above
WT. PER FT.
62.5#
29.7#
15.5#
9.3#
HOLE SIZE
Classification of Service Well
7. Permit Number
202-018/302-165
8. API Number
50-103-20408-00
9. Unit or Lease Name
Kuparuk River Unit
10. Well Number
2P-427
11. Field and Pool
Kuparuk River Field
Meltwater Pool
16. No. of Completions
feetMD
21. Thickness of Permafrost
1390' (approx)
AMOUNT PULLED
16"
42"
CEMENTING RECORD
30 bbl AS 1
380 sx AS IIIL, 220 sx LiteCrete
235 sx Class G
7.625"
9.875"
6.75"
5.5"
3.5"
6.75"
24. Perforations open to Production (MD + TVD of Top and Bottom and
interval, size and number)
3.5"
TUBING RECORD
DEPTH SET (MD)
9541'
PACKER SET (MD)
None
25.
SIZE
10008' - 10018' MD 5680' - 5685' TVD 6 spf
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
10008' - 10018' 282,500# of 16/20 proppant, placed 262500#
behind pipe
26.
27.
Date First Production
November 7,2002
Date of Test Hours Tested
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Gas Lift Oil
Production for OIL-BBL GAS-MCF
2987 2557
OIL-BBL GAS-MCF
3584 3068
CORE DATA
W A TER-BBL
336
W A TER-BBL
403
11/11/2002 20 hours
Flow Tubing Casing Pressure
press. 300 psi not available
28.
Test Period>
Calculated
24-Hour Rate>
Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips.
NIA
Form 10-407 Rev. 7-1-80
CONTINUED ON REVERSE SIDE
RBDMS 8Fl
CHOKE SIZE
100 bean
OIL GRAVITY - API (corr)
GAS-OIL RATIO
856
Not available
RECEIVED
NOY 2 6 2002
A1aska Oil & Gas Cons. Commission
Anchorage
NOV 2 7
Submit in duplicate ,.-.:
G\./
29.
)
30.
')
GEOLOGIC MARKERS
FORMATION TESTS
MEAS.DEPTH
TRUE VERT. DEPTH
Include interval tested, pressure data, all fluids recovered and gravity.
GOR, and time of each phase.
NAME
T3
T2
9632'
1 0290'
5504'
5805'
RECEIVED
NOV 26'2002
Nasb Oil & Gas Cons. Commission
Anchorage
Annulus left open - freeze protected with diesel.
31. LIST OF ATTACHMENTS
Summary of Daily Operations, Directional Survey
32. I hereby certify that the following is true and correct to the best of my knowledge.
Questions? Pat Reilly 265-6048
~ .- \~
Signed \ ~ ...
R. Thomas
Title
Kuparuk Drilling Team Leader
Date
\( (~6ID ~
Prepared by Sharon AI/sup-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 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other
spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in
item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each
additional interval to be separately produced, showing the data pertinent to such interval.
Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location
of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection,
Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407
)
~~
~'Ir~ ."~
: I Îjl
~
)
Page 1 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
4/22/2002 12:00 - 13:00 1.00 MOVE MOVE MOVE
13:00 - 19:00 6.00 MOVE RURD MOVE
19:00 - 20:00 1.00 MOVE POSN MOVE
20:00 - 00:00 4.00 MOVE RURD RIGUP
4/23/2002 00:00 - 04:30 4.50 WELCTL NUND RIGUP
04:30 - 05:30 1.00 RIGMNT RSRV RIGUP
05:30 - 06:00 0.50 WELCTL BOPE RIGUP
06:00 - 07:30 1.50 RIGMNT RSRV RIGUP
07:30 - 10:00 2.50 DRILL PULD COND1
10:00 - 10:30 0.50 DRILL CIRC COND1
10:30 - 19:00 8.50 DRILL DRLG COND1
19:00 - 00:00
5.00 DRILL DRLG COND1
4/24/2002
00:00 - 06:30
6.50 DRILL DRLG SURFAC
06:30 - 07:30
07:30 - 09:00
1.00 DRILL CIRC SURFAC
1.50 DRILL TRIP SURFAC
09:00 - 09:30
0.50 RIGMNT RSRV SURFAC
09:30 - 10:00
10:00 - 10:30
0.50 DRILL TRIP SURFAC
0.50 DRILL CIRC SURFAC
10:30 - 00:00
13.50 DRILL DRLG SURFAC
4/25/2002
00:00 - 09:00
9.00 DRILL DRLG SURFAC
09:00 - 10:30
10:30 - 13:00
1.50 DRILL CIRC SURFAC
2.50 DRILL TRIP SURFAC
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
Move rig from 2P-422 to 2P-427. Set diverto
r
Changing bop's per PAl request.
pted 1300 hrs.
Spot and level rig over well
Secure rig, spot tanks and berm location. C
hange out floor equipment.
CompleteNu diverter, load in spud mud.
Cut & s lip d rig I i n e.
Test diverter; witness waved by AOGCC [C.
Sheave].
Ser rig I Tds & set torque limits on tds.
PU I mu Bha, orient - scribe tools, up load
mwd, Rih to tag cmt in conductor @ 114' RF
Rig acce
Load hole wI mud, ck for leaks in riser syst
em & pits.
Spud well in @ 1030 hrs. Drlg to 720'. Init
ial pump rate 340 gpm 1750 psi, stage up t
0 420 gpm 11000 psi @ 300' & to 480 gpm /
1400 psi @ 500'. Pick up & reposition jars
On Highline Power @ 1100 hrs.
Drlg 720 ' - 1060' [1050' tvd]. 480 gpm 120
00 psi, rpm 60 - 85, bit weights all to 10k Ib
s. Sweeping hole as necessary. 24 hr ad
t = 10.0 hrs = 4.6 ast + art 5.4
Dir drlg 1060' - 1546' [1478' tvd]. Rpm 85,
bit wts 8 - 12k Ibs, 2200 psi 1465 gpm. sw
eeping hole? 500'. Ecds in the 10.5 range.
Permafrost faces @ 1415-1430'.
Sweep / cir hole I monitor for short trip.
Pull to 190'. Pulled 10k @ 1530' & 5 - 7k
bs ?300'.
Rot work pipe. Rig service. Brk cir, sd & s
ervice tds.
Rih 1455', no tight spots.
Break cir slowly, precationary wash real to t
d I no fill.
Dir drlg 1546 - 2492' [2127' tvd] P. press
2100 psi - 480 gpm I bit wts 8 -12 k Ibs I rp
m 80 I torque on - off bot 3200 I 2600 ft-Ibs
I Pu - so - rot weight 60 - 54 - 56k Ibs. Sw
eeping hole prior to each 2 - 3 connections,
maintaining ecds in the 10.7 ?4 ppg. 24
hrs adt = 15.5 hrs = 6.4 ast + art 9.1 Bit #
1 adt = 25.5 hrs = 11 ast =+ art 14.5
Dir Drlg Ahd 2492' [2127' tvd] - 3040' [2385
I tvd], 7.625" csg pt.
Cir I cond pump I sweep hole.
Short trip out to conductor shoe. Pulled tig
ht [12k Ibs over] starting @ 1680. RIH 50'
to normal wt, mu trs & back real cir wI mo
derate resistance to 1380' where free, pump
""
Printed: 5/29/2002 1 :49:31 PM
~,
u
)
")
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
4/25/2002 10:30 - 13:00 2.50 DRILL TRIP SURFAC
13:00 - 15:00 2.00 DRILL TRIP SURFAC
15:00 - 19:00 4.00 DRILL CIRC SURFAC
19:00 - 22:30 3.50 DRILL TRIP SURFAC
22:30 - 00:00
1.50 DRILL PULD SURFAC
4/26/2002 00:00 - 01 :00 1.00 DRILL DRLG SURFAC
01 :00 - 03:30 2.50 DRILL TRIP SURFAC
03:30 - 08:00 4.50 DRILL CIRC SURFAC
08:00 - 11 :30 3.50 DRILL TRIP SURFAC
11 :30 - 13:00
13:00 - 14:00
14:00 - 18:00
1.50 DRILL PULD SURFAC
1.00 CASE SFTY SURFAC
4.00 CASE RUNC SURFAC
18:00 - 21 :00
3.00 CASE CIRC SURFAC
21 :00 - 21 :30
21 :30 - 23:30
0.50 CASE SFTY SURFAC
2.00 CASE SURFAC
Page 2 of 14
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
sweep @ beginning of rearing, small amt of
material to surface. Rih to 1740' & wash r
eam [precautionary] back to 1300'. Continu
e to pooh wI no further over pulls.
Rih, string took minor wt @ 300' [kick off pt
], good trip below 300' to td, mu tds & preca
utionary wash ream to td, no fill.
Cir I cond I sweep hole. Bu gas 20 units.
Mw 9.7 ppg +, no seepage. YP = 19.
Pooh for 7.625" csg. Tight area @ 1100', w
orked through wI up to 20k Ibs over. Did n
ot clear up completely. Continue to tooh, m
inor 5-7k Ibs over pulls @ 600' & 300'.
Down load Lwd I Mwd tools & Id down same.
Pu hole opener & mu same. Wx rpt for 06
00 hrs 04 26 2002: temp 31?F, wI v 270? @ 5
knots
Continue to mu hole opener bha.
Rih wI hole opener assmby. No problems.
Cir & cond, run Solids cont van & reduce mw
from 9.9+ to 9.7+ ppg. Adjust yp to 18.
Pooh for csg, pulled 20k Ibs over @ 1380', r
ih 50' & work through, repeat second time w
. no restriction. 5k Ibs over pull @ 1200', w
orked though wI no problem, checked open -
continued trip out.
Ld tools.
PJSM & ops briefing.
Ran 69 jts 7.625" x 29.7 ppf x L-80 x Bt&c
ab mod csg as per program. Located Tam
Port Collar @ 991'. Utilized Wx-Lamb float
shoe & float collar & two shoe jts. Ldg out
@ 3030' md. Brk cir @ 1700 & 2300 I [cir @
5.5 bpm 1300 & 475 psi. Work pipe 70k up
55 k Ibs down.
Cir I cond mud to cmting properties. Mu cm
t head. Continue to cir & adjust mud proper
ties to9.7 ppg I yp 14. Reciprocate pipe 20
I stroke, weights up I down = 90k I 73k Ibs.
PJSM lOps briefing
Dowell cmted 7.625" csg as follows: Pumpe
d 40 bbl of CW 100 @ 8.34 ppg, 360 psi - 6
bpm press testing pump & lines to 3500 psi
Drop bottom plug. Pump 40 bbl 10.5 ppg
Mud Push @ 5.5 bpm - 400 psi. Follow wI 2
90 bbl [380 sx] Lead slurry [AS Lite] 10.7 pp
g CI G { adds = 50% D124, 9% D44, .4% d46
, 30% D53, 1.5 % S1 & 1.5% D79], f water
@ 19.39 gal I sx, yield 4.28 ft3 I sx. Pres
s I rates max - min - avg= 570 I 6 - 360 / 6
- 480 psi - 6 bpm. Follow wI Tail slurry of
94 bbl [219 sx] LiteCRETE @ 12.0 ppg. F w
Printed: 5/29/2002 1 :49:31 PM
.)
~~
~¡
~
')
Page 3 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Date
From - To Hours Code Sub Phase
Code
4/26/2002
2.00 CASE
SURFAC
21 :30 - 23:30
23:30 - 00:00 0.50 CEMENT PULD SURFAC
4/27/2002 00:00 - 01 :00 1.00 CEMENTOTHR SURFAC
01 :00 - 03:30 2.50 WELCTL NUND SURFAC
03:30 - 06:00 2.50 WELCTL NUND SURFAC
06:00 - 10:00 4.00 WELCTL NUND SURFAC
10:00 - 11 :00 1.00 WELCTL NUND SURFAC
11 :00 - 17:00 6.00 WELCTL BOPE SURFAC
17:00 - 18:00 1.00 WELCTL BOPE SURFAC
18:00 - 21 :30 3.50 WELCTL NUND SURFAC
21 :30 - 00:00 2.50 WELCTL TRIP SURFAC
4/28/2002 00:00 - 01 :00 1.00 CASE CIRC SURFAC
01 :00 - 02:30 1.50 CASE DEQT SURFAC
02:30 - 04:30 2.00 WELCTL OTHR SURFAC
04:30 - 05:00 0.50 WELCTL CIRC SURFAC
05:00 - 06:30 1.50 WELCTL OTHR SURFAC
06:30 - 00:00 17.50 DRILL DRLG PROD
Start:
Rig Release:
Rig Number:
4/22/2002
Spud Date: 4/24/2002
End:
Group:
Description of Operations
tr 8.122 gal / sx, yea I 2.4 ft3 I sx. Adds =
D079 .5%, Do46 .6%, Do65 1.0 %. Press I
rates max - min - avg = 650 / 5 - 600 I 5 - 6
25psi- 5 bpm. {all add %BWOC}. Drop top
plug & disp wI 10 bbl f wtr + 134 bbl 9.8 P
p g mud, pi u g hit on calculated displaced val
ue total of 144bbl. Bumped plug from 650 p
si to 1500 psi & held for 5 minutes, bleed b
ack ?5 bbl - plug / floats held. 175 bbl [22
9 sx] cmt to surface, full returns throughout
ops. Reciprocate pipe 20' I 1 min until stri
ng became "sticky" when tail hitt on back si
de of 7.625" csg. CIP @ 2325 psi.
Wash Cmt equip & rig equip. Rd cmt equip.
[incomplete @ rpt time].
Continue to rd / clean up after 7.625" cmt jo
b.
ND Diverter
Load well wd equip into celler, install csg
hd [pt void to 1000 psi I 15 min] & tbg spoo
I.
Nu bope, remove diverter riser & cont. line
s.
function test bops, set test plug.
Test bope 250 I 3500 psi, annular 3000 psi.
Floor equip, choke manifold 250 I 3500 ps
i. X-out upper kelly valve & test.
PJSM on moving Hi line power cable to facil
itate mi of coil tbg unit on adjacent well. S
et wear bushing
PU 6.75" bha & Tih bha #2, rotate through
Tam collar @ 992", shallow test mwd - Iwd e
qui p.
Cont to rih wI drill pipe to float collar to 29
38', preforming stripping drill as trip in.
Cir bottoms up for csg test.
Test surface csg to 2500 psi, initial pressur
e 2550 final [31 minutes]2495 psi.
Drlg shoe track, 10' of cmt to new formation
@ 3040' & 20' of new formation to 3060'.
Cir till shakers clean. Pull into 7.625" csg.
Conduct F. I.T. to 17 ppg EMW. Cal. = 9.
6 ppg mw + {920 psi imposed? [.052 x 239
4' tvd]} = 16.99 ppg emw
Dir Drlg 3060' [2394' tvd] - 3997" [2837' tv
d]. Parameters: P. Press 2100 spi I 300 gp
m, Bit wts 5 - 8k Ibs, Torque @ RPMs = 4k I
bs @ 85, pu I so I rot wts = 80 160 I 71k I
bs. Maintaining drilling rop 100 -120 fph.
Bit #2 hrs = 13 = art 11.7 + ast 1.3 hrs
ECDs in the 11.6 ? .3ppg range. Back rea
ming hole x2 on each connection @ high rpm
Printed: 5/29/2002 1 :49:31 PM
~~
!.......~,
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
)
')
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Date From - To Hours Code Sub Phase
Code
4/28/2002 06:30 - 00:00 17.50 DRILL DRLG PROD
4/29/2002 00:00 - 00:00 24.00 DRILL DRLG PROD
4/30/2002
00:00 - 11 :30
11 :30 - 13:30
13:30 - 15:30
15:30 - 00:00
11.50 DRILL DRLG PROD
2.00 DRILL CIRC PROD
2.00 DRILL WIPR PROD
8.50 WAlTON WOW PROD
Page 4 of 14
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
, hi vis / {occasional hi wt) sweep each 2 -3
rd connection.
Dir Drlg 3997' - 5270" [3393' tvd]. Parame
ters: P. Press 2500 spi 1300 gpm, Bit wts
4 - 10k Ibs, Torque @ RPMs = 4.5k Ibs @ 85
, pu I so I rot wts = 87 I 75 I 73k Ibs. Mai
ntaining drilling rop 100 -120 fph. Bit #2
totals = 29.7 = art 27.9 + ast 1.8 hrs Bit #2
last 24 hrs = 16.7 = art 16.2+ ast .5 hrs
ECDs in the 11.4 ? .2 ppg range. Back re
aming hole x2 on each connection @ high rp
m, hi vis I {occasional hi wt) sweep each 2 -
3rd connection. ECD respond to above actio
n well. Lwd-Neutron I Density tool: Yieldi
ng intermitten info this report period. Requ
ires numerous pump recycling [hinders drilli
ng operations], very pronounced between no
on & 1700 hrs. Tool preforming well since
1800 hrs. Back up tool is on location 0500
hrs 4 30 2002 after repair trip to Deadhorse
Dir Drlg 5270' - 6026 [3790' tvd]. Paramet
ers: P. Press 2550 spi I 304 gpm, Bit wts 6
- 12k Ibs, Torque @ RPMs = 4.5k Ibs @ 85,
pu I so / rot wts = 86 / 75 / 70k Ibs. Main
taining drilling rop 100 -120 fph. Bit #2 t
otals = 37.6 = art 35.8 + ast 1.8 hrs Bit #2
last 24 hrs = 7.9 art 6.6 + ast 1.3 hrs
ECDs in the 11.4 ? .2 ppg range. Back r
eaming hole x2 on each connection @ high r
pm, hi vis / {occasional hi wt) sweep each 2
-3rd connection. ECD respond to above act
ion well. Lwd-Neutron I Density tool: Yiel
ding good data throughout.
Cir cond for short trip, shakers clean.
Pooh to 2963', no over pull off bottom. Som
e random over pulls to 6K Ibs over string wt
s. Good trip out. Wx deteriorating toward
end of trip due to winds approaching 35k f
or 170?
Shut down due to high wI v to 37k 1165 - 18
O? {local weather Phase III, rig team call}.
Cir well @ 2 bpm / moving pipe randomly [ti
me]. Security declares Phase III wx in the
meltwater area @ ? 1630hrs. Winds continu
e to increase to "average" of 40knots {170?}
w/ gust to 45 knots. Visibility <10'. Temp
15 to 20?F wind chill minus 40 or so. Cr
ew activities: Clean, lubricate, well watch,
review procedures, rewrite ESP running / pu
Iling procedures wI imphasis on cutting esp
cable & si techniques. @ 0600 05 01 2002
wind remains very high {no decrease} from
Printed: 5/29/2002 1 :49:31 PM
t;HI;LlP8.~
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
4/30/2002
5/112002
5/2/2002
/)
)
Page 5 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Start:
Rig Release:
Rig Number:
4/22/2002
Spud Date: 4/24/2002
End:
Group:
From - To Hours Code Sub Phase
Code
15:30 - 00:00
00:00 - 17:00
8.50 WAlTON WOW PROD
17.00 WAlTON WOW PROD
17:00 - 20:00 3.00 DRILL TRIP PROD
20:00 - 20:30 0.50 DRILL CIRC PROD
20:30 - 00:00 3.50 DRILL DRLG PROD
00:00 - 10:00
10:00 - 21 :00
21 :00 - 00:00
10.00 DRILL DRLG PROD
11.00 DRILL DRLG PROD
3.00 DRILL
PROD
Description of Operations
the SE to S. Highest sustained velocity [ov
er 1 minute] 65 Knots / 160?, general "Avg"
45Knots. from the SE. Sec imposes Phase I
II over entire Kuparuk area @ 0447 hrs.
Wind abating from 1200 hrs to ? 25 knots 11
65? by 1600 hrs. Main rds in field Phase I
or II by 1700 hrs & rd from 2M into 2P phase
III. Scout rd to 2m [convoy] no drifts or
problems.
PJSM Rih picking ul 24 jts 4" dp then runni
ng stands in to 5970'.
Stage pumps up slowly to 300 gpm. Precaut
ionary wash ream to td [ no fill].
Dir Drlg 6026' - 6295' [3924' tvd]. Paramet
ers: P. Press 2550 spi I 304 gpm, Bit wts 4
- 7k Ibs, Torque @ RPMs = 6.5k Ibs @ 85,
pu I so I rot wts = 105 I 65 I 81k Ibs. Maint
aining drilling rop 100 -120 fph. Bit #2 to
tals = 40.9 = art 38.7 + ast 2.1 hrs Bit #
2 last 24 hrs = 3.2 art 2.9 + ast .3 hrs
ECDs in the 11.1 ? .2 ppg range. Back r
eaming hole x2 on each connection @ high r
pm, hi vis I {occasional hi wt) sweep each 3
- 4rd connection. ECD respond to above ac
tion well. Lwd-Neutron I Density tool: Vie
Iding good data throughout.
Dir Drlg 6295' [3924' tvd] - 6957 Parameter
s: P. Press 2500 spi 1304 gpm, Bit wts 5 -
10k Ibs, Torque @ RPMs = 8k Ibs @ 85, pu
I so I rot wts = 95 I 80 I 84k Ibs. Maintaini
ng drilling rop 100 -120 fph. ECDs in the
11.0 ? .2 ppg range. Back reaming hole x
2 on each connection @ high rpm, hi vis I {o
ccasional hi wt) sweep each 3 - 4rd connecti
on. ECD respond to above action well.
Dir Drlg 6957 - 7488'. Drill ahead wI one p
ump, 260 gpm. Decreased rop to 80fph to m
aintain an ecd of < 11.3 ppg. No hole probl
ems. Pump #2: developed a small fluid I
eak on pressure side one pod. Possible hai
r line crack. Located spair pod, wrong bolt
pattern [non standard pod], located 2 more
pods, one wI correct standard bolt pattern.
Returning 2 non-standard pods to Supplier
- pods are off location. Estimate pods pro
blems required 6.5 hrs to un-ravel.
Dir Drlg 7488 - 7625 [4553' tvd]. Parameter
s: P Press - Q = 2520psi - 300 gpm I torqu
e - rpm = 7800 ft-Ibs - 85 I Bit wts 4 - 7k Ib
s I Pu - so - rot wts = 115 - 75 - 88k Ibs. D
elta P ? 250 psi. @ 7554' survey: track is
4' high & 14' right. ECD in the 10.7 rang
e wI static mw 9.6+ [adjusted down from 10
Printed: 5/29/2002 1:49:31 PM
)
)
Page 6 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
5/2/2002 21 :00 - 00:00 3.00 DRILL PROD
5/3/2002 00:00 - 22:30 22.50
22:30 - 00:00 1.50 DRILL CIRC PROD
5/4/2002 00:00 - 02:00 2.00 DRILL CIRC PROD
02:00 - 07:00 5.00 DRILL TRIP PROD
07:00 - 09:30 2.50 DRILL PULD PROD
09:30 - 10:30 1.00 DRILL PULD PROD
10:30 - 11 :30 1.00 WELCTL OTHR PROD
11 :30 - 17:00 5.50 WELCTL BOPE PROD
17:00 - 17:30 0.50 PROD
17:30 - 19:30 2.00 DRILL TRIP PROD
19:30 - 00:00 4.50 DRILL TRIP PROD
5/5/2002 00:00 - 01 :00 1.00 DRILL TRIP PROD
01 :00 - 02:30 1.50 DRILL CIRC PROD
02:30 - 00:00 21.50 DRILL DRLG PROD
5/6/2002
00:00 - 09:00
9.00 WELCTL KILL PROD
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
ppg over last 24 hrs] Bit #2 totals = 58.6
= art 50.8 + ast 7.8 24 hrs drlg = 9.4 = art
7.1 = ast 2.3
Dir Drlg 7625' [4553'] - 8963' [5188'] Para
meters: P. Press 2500 spi 1300 gpm, Bit wt
s 6 - 10k Ibs, Torque @ RPMs = 8k ftlbs @ 8
5, pu I so / rot wts = 97 / 86 I 94k Ibs. Ma
intaining drilling rop 100 -120 fph. Well b
ore track 3.5' high x 4' right of proposed.
Bit #1 totals = 75.1 = art 57.5 + ast 9.2 hrs
24 hr drlg = 8.1 = art 6.7 + ast 1.4 hrs
ECDs in the 11.2 ? .2 ppg range. Back re
aming hole x2 on each connection @ high rp
m, hi vis [stop hi wt sweeps] sweep each 3 -
4rd connection. ECD respond to above acti
on well.
Cir & cond for trip. Incomplete rpt time.
Complete cir & cond hole I mud
Pooh for bha ck {Iwd stabs & bit} & bop test
PJSM Recover radioactive material from Ne
utron Tool, download LWD - MWD.
Ld LWD tool, motor & stabvlizer. Inspect b
it, 3 small chips on 3 cutters, < 1/32 under
gage. Re-run same.
Pull wear bushing, install test plug & fill st
ack wI water, ru test lines for BOP test.
Test bope 250 low 3500 psi high, annular 30
00 psi.
Recover test plug & set wear bushing.
Mu I pu bha replacing mud motor, Iwd [neutr
on density], orient tool faces, up load mwd
& load source [pjsm].
Rih to 5931', breaking circulation @ 3900',
& 5931' [ wlcir bu. ]
Rih to 8875', brk cir slowly & rih to 8963', n
0 fill. Good trip in.
Cir bu, no gas.
Dir Drlg 8963' [5188'tvd] -- 9754' [5564' tv
d] Parameters: Pump press - Q = 2600 - 29
6 gpm I bit wts 3 - 5k Ibs I torque-rpm on
-off bot. 8300 - 7800 ftlbs @ 80rpm I pu - s
0 - rot wts = 103 - 90 - 98k Ibs. ECD = 10
.5 ppg ? .2. Totals bit #2 = 12.8 = art 9.8
+ ast 3.0 24 hrs drlg time = art 9.8 + ast 3
.0 = 12.8 hrs. Well bore track is 4' high
& 4.5' right of proposed.
Drlg Ahd @ 9754' [5564'] when small gas bu
bble came to surface. 3 bbl pit gain was n
oted from the scheduled? hr pit check. SID
PP = 100 psi, SICP = 150 psi. Mud wt incre
ase of .4 ppg , 10 ppg kill wt mud. Mw was
increased to 9.8 ppg in one circulation & we
Printed: 5/29/2002 1 :49:31 PM
I)HI;LlP8.~
~~., .,~
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/6/2002
5/712002
)
)
Page 7 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Sub
From - To Hours Code Code Phase
00:00 - 09:00
09:00 - 00:00
00:00 - 04:00
04:00 - 10:30
9.00 WELCTL KILL PROD
15.00 WELCTL
PROD
4.00 DRILL DRLG PROD
6.50 DRILL CIRC PROD
10:30 - 12:00 1.50 DRILL CIRC PROD
12:00 - 13:00 1.00 DRILL CIRC PROD
13:00 - 13:30 0.50 DRILL TRIP PROD
Start:
Rig Release:
Rig Number:
4/22/2002
Spud Date: 4/24/2002
End:
Group:
Description of Operations
II was checked static & preventer opened.
Circulation was continued & mw raised to 10
ppg & static. Ecd @ 10 ppg, 300 gpm = 10
.9 ppg +, @ 250 gpm ecd ?10.75 ppg. False
conection made wI small increase in gas cu
t mud in shakers. Small additions of Barafi
ber started [five 25 Ib sx I hr).
Dir Drlg 9754' [5564' tvd) -- 10288' [5804' t
vd) Parameters: Pump press - Q = 2200 - 2
40 gpm I bit wts 3 - 5k Ibs I torque-rpm 0
n-off bot. 10800 - 9000 ftlbs @ 80rpm / pu
- so - rot wts = 115 - 105 - 105k Ibs. ECD
= 10.8 ppg ? .2. Static mw = 10.0 ppg Q d
ecreased to 240 gpm & discontinued the use
of Barafiber to assist control of ECD. Swe
eping hole each stand & back reaming twice
@ high rpms. Totals bit #2 = 26.1 = art 2
1.1 + ast 5.0 24 hrs drlg time = art 11.3 +
ast 0.0 = 11.3 hrs. Entered target @ 551
5'tvd, 4.8' high & .8' left, exited target @ 5
751' tvd, 10.9' high & 2.8' left.
Dir Drlg 10288' [5804 tvd) -- 10402' [5853'
tvd) Parameters: Pump press - Q = 22300 -
240 gpm I bit wts 3 - 5k Ibs I torque-rpm
on-off bot. 10900 - 9000 ftlbs @ 80rpm I p
u - so - rot wts = 115 - 105 - 105k Ibs. E
CD = 10.8 ppg ? .2. Static mw = 10.0 ppg
Q decreased to 240 gpm & discontinued the
use of Barafiber to assist control of ECD. S
weeping hole each stand & back reaming twi
ce @ high rpms. Totals bit #2 = 26.1 = art
21.1 + ast 5.0 24 hrs drlg time = art 11.3
+ ast 0.0 = 11.3 hrs. Entered target @ 55
15'tvd, 4.8' high & .8' left, exited target @
5751' tvd, 10.9' high & 2.8' left.
Lost 40 bbl mud over 10 minutes. Pu off bo
ttom, Sd monitor well for 10 minutes gained
11 bbl. Spot 30 bbl Barafiber pill on bot to
m, Pull 2 standstl 10,290 (Spot pill @ 85 g
pm to avoid mud losses.)Circu @ 6 bpm to p
ush pill into formation @ 30 bbl loss slow p
umps to 4 bpm & monitor fl GIL - Gas to sur
face on BU - Adjust pump rate to find rate 0
f NO G/L = 4.7 bpm - Circu and add LCM to
system
Shut dn pump and monitor GIL -Gain 1.5 bp
m - TIH to Bttm (Gained 7 bbls w/TIH w/std
Spot LCM Pill on Bttm (30 bbl @ 12.5 ppb b
arofiber & 12.5 ppb baroseal fine) pumped
@ 3 bpm 800psi NO loss
POOH 6 stds tI 9817' to get above LCM Pill
- Gained 13 bbl while pulling stds - 150K u
P wt , 78k dn wt
Printed: 5/29/2002 1 :49:31 PM
t;H I;U P8'~
~.~14r,~h.
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/7/2002
5/8/2002
5/9/2002
)
Page 8 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Start:
Rig Release:
Rig Number:
4/22/2002
Spud Date: 4/24/2002
End:
Group:
Sub
From - To Hours Code Code Phase
13:30 - 17:30
17:30 - 23:30
23:30 - 00:00
00:00 - 01 :00
01 :00 - 04:00
04:00 - 08:30
08:30 - 09:30
09:30 - 12:00
12:00 - 13:00
13:00 - 16:00
16:00 - 18:30
18:30 - 21 :00
21 :00 - 00:00
00:00 - 05:30
05:30 - 07:00
07:00 - 08:00
08:00 - 09:30
4.00 DRILL CIRC PROD
6.00 DRILL CIRC PROD
0.50 DRILL CIRC PROD
1.00 DRILL CIRC PROD
3.00 DRILL CIRC PROD
4.50 DRILL TRIP PROD
1.00 DRILL TRIP PROD
2.50 DRILL CIRC PROD
1.00 DRILL CIRC PROD
3.00 DRILL CIRC PROD
2.50 DRILL TRIP PROD
2.50 DRILL TRIP PROD
3.00 DRILL CIRC PROD
5.50 DRILL CIRC PROD
1.50 DRILL RIRD PROD
1.00 DRILL OTHR PROD
1.50 DRILL OTHR PROD
Description of Operations
Monitor well for GIL - Well flowing @ .2 tent
hs BPM -- WT up to 10.2 ppg - Circu @ 4.7
bpm - Lossing 8 bph - Reduce rate to 4 bpm
- No GIL
Shut dn pump - Monitor well 30 min - Gain 7
bbls - Appears to be flowing @ .2 tents bp
m - CBU - Gas to surface - Mud cut to 9.3pp
g for 1500 stks
Monitor well for GIL - Well flowing @ .2 tent
hs BPM -- Will WT up to 10.4 ppg -
Con't Monitor well wI Trip Tank - Recip pipe
slowly - Gain 3.2 bbls in 1 hr.
CBU -Work circu rate up to 2 bpm @ 750 psi
wI no GIL - Gas cut to surface t/ 9.3 ppg fo
r 950 stks (51 bbls)
Slowly TIH wI 3 stds Dp out of derrick - Circ
u in slowly to minimize ECDs from LCM pill I
eft on Bttm - @ 10,101 retuns decreasing -
CBU - Small Gas show cantam mud @ BU
Con't TIH slowly with stds out of derrick to
10,402' ( TD )- Circu dn slowly to minimize
ECDs from LCM pill - Static Mud wt 10.4ppg
CBU - Circu @ 3.3 bpm @ 800 psi NolGIL -
Small gas show on BU
Monitor well to trip tank - Gain 5.6 bbl after
1 hr (at end of hr well appeared to be clos
e to static. Next to NO gain last 10 min of c
heck) Static Mud wt 10.4+ppg
CBU @ 3.5 bpm @ 1000 psi - 5 bbl gas cut 0
n B U
Pump Out off Hole 20 stds - Pump @ 1.45 bp
m - Hole fill very close - Stop @ 20 stds a
nd monitor well - Gained 1.6 bbls in 8 min
TIH slowly - Fill DP on fly - Returns appear
near correct @ 15.4bbls (2 bbJ over calcu)
CBU - Stage up pump rate - Saw 10.7 to 10.
9ppg mud while circu BU -Very small amount
of Gas cut mud on BU - Due to high ECDs f
rom heavy mud worked pump rate up slowly
while recip string very slowly- @ Midnight r
ate 1.2 bpm , 420 psi No GIL
Con't Circu & Condition - Rate 2 bpm - 40 R
PMs - Static Mud wt 10.4+ - Waiting on Dow
ell Batch mixer to navigate bad road to pad
(Dowell on Loc @ 0530 hrs)
R/U Dowell - Load MI Plug material in Dowel
I unit - Hold PJSM with Nordic crew and all
contractors
Mix 16 bbls of Hi Vis Pill for spacer @ 10.6
ppg - Pump 10 bbls for spacer - Turn over t
0 Dowell
Dowell & MI reps Mix harder with plug produ
ct - Dowell pump 25 bbls FormaPlug fluid @
Printed: 5/29/2002 1:49:31 PM
~I
,..... D'
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/9/2002
5/1 0/2002
5/11/2002
)
')
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Page 9 of 14
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Sub
From - To Hours Code Code Phase
08:00 - 09:30
09:30 - 10:00
10:00 - 10:30
10:30 - 11 :30
11 :30 - 16:30
16:30 - 17:00
17:00 - 00:00
00:00 - 01 :00
01 :00 - 05:00
05:00 - 06:30
06:30 - 08:00
08:00 - 10:30
10:30 - 16:00
16:00 - 17:30
17:30 - 00:00
00:00 - 02:00
1.50 DRILL OTHR PROD
0.50 DRILL TRIP PROD
0.50 DRILL CIRC PROD
1.00 DRILL TRIP PROD
5.00 DRILL CIRC PROD
0.50 DRILL CIRC PROD
7.00 DRILL REAM PROD
1.00 DRILL REAM PROD
4.00 DRILL CIRC PROD
1.50 DRILL CIRC PROD
1.50 DRILL CIRC PROD
2.50 DRILL CIRC PROD
5.50 DRILL TRIP PROD
1.50 DRILL CIRC PROD
6.50 DRILL TRIP PROD
2.00 DRILL TRIP PROD
Description of Operations
3 bpm - Produce wt ran 11.1 to 11.3 ppg aft
er mixing excellirator and pumping ??? MI c
ould not explain why?? I ask them to investi
gate and give us a written report on posiabl
e reasons.Turn over to Rig - Rig pump 2.1 b
bls Hi Vis spacer to balance plug and displ
ace with 99.7 bbls mud (1710 stka)
Slowly pull out of MI FormaPlug 6 stds to 98
17' (slowly stroke 17 stks to displace ea. st
d as pulled) per MI rep instructions
Rot & Recip string @ 9817' - Start pumping
@ 2.5 bpm and increase rate to where fluid I
oss occured (per plug procedure) = 4 bpm
After lossing 10 bbls to formation pumps we
re shut down - Plug in place @ 10:30 hrs
Con't per procedure and pumped 10 stds out
of hole - rate w/ pumping out 2 bpm
Rot & Recip string - Pump @ 2 bpm (615 psi
) to maintain ECD pressure on PermaPlug un
til cured per recomended plug procedure
@ end of cure period stage pumps up to 5 b
pm in 1/2 bbl increments- NO GIL
Wash & Ream 8870' to 10210' per MI reps i
nstructions & plug procedure - Rot 40 RPMs
- Pump rate 3 BPM (680 psi) Appeared to ta
g top of plug @ 9895' - Plug appeared to be
firmer in spots @ 10196'
Wash & Ream MI PermaPlug from 10210' to
10265' - @ 10250' started seeing eradic tor
que @ 10250' - Cleaned out to 10265' - Hole
taking fluid if pumping above 3 bpm.
Circu @ reduced rate 2 BPM - Mix & pump 0
n Bttm LCM 22 bbl pill wI 12.5 ppb barofibe
r, 12.5 baroseal fine - Slowly TOH wI 5 stds
DP to 9817' - Circu DP clean
Circu BU @ 4 BPM /1176 psi - Recip DP at
all times
Shut down pumps - Monitor well to asure hol
e is Static - Gained 1.1 bbls over 1:15 min
Circu & Condition - Wt up complete mud sys
tem to 10.6 - 10.6+ ppg
Pump Out of hole - TOH pump 2 bpm and mo
nitor displacement while pulling - Tight spot
s 15 to 20K 8700',8630',8267',8190',7190',7
050',6930'- Had to back ream @ 6589',6235'
& 6210' - Worked all tight hole until clear -
Hole fill 1.7 bbls over
Circu hole clean - Rotate & recip to clean u
p cuttings bed - 75 RPMs Pump rate 5 bpm
Con't pumping out of hole - Hole fill 3.8 bbl
s over
Con't TOH - Monitor well @ shoe - Static-No
GIL
Printed: 5/29/2002 1 :49:31 PM
)
I'~~
- Ij~
~
)
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
5/11/2002 02:00 - 03:30 1.50 DRILL PULD PROD
03:30 - 07:00 3.50 DRILL PULD PROD
07:00 - 07:30 0.50 RIGMNT RSRV PROD
07:30 - 10:30 3.00 DRILL PULD PROD
10:30 - 11 :30 1.00 DRILL CIRC PROD
11 :30 - 12:30 1.00 DRILL TRIP PROD
12:30 - 13:30 1.00 DRILL CIRC PROD
13:30 - 14:30 1.00 DRILL TRIP PROD
14:30 - 15:30 1.00 DRILL CIRC PROD
15:30 - 17:00 1.50 DRILL TRIP PROD
17:00 - 18:00 1.00 DRILL CIRC PROD
18:00 - 20:30 2.50 DRILL TRIP PROD
20:30 - 00:00 3.50 DRILL CIRC PROD
5/12/2002 00:00 - 01 :00 1.00 DRILL CIRC PROD
01 :00 - 02:00 1.00 DRILL TRIP PROD
02:00 - 03:30 1.50 DRILL CIRC PROD
03:30 - 04:30 1.00 DRILL TRIP PROD
04:30 - 09:00 4.50 DRILL CIRC PROD
09:00 - 09:30 0.50 DRILL OTHR PROD
09:30 - 10:00
0.50 DRILL CIRC PROD
Page 10 of 14
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
PJSM - Remove RA sources - LID flex colla
rs
Dn Load MWD info - L/D all BHA - Clean all
equip off rig floor and out of Pipe Shed
Grease Crown - Service Rig
P/U HO Assy - TIH to 2945' (TIH slowly to m
inimize ECDs )
CBU - Stage rate up slowly to 4 BPM (400 P
si) I Slip and cut drill line while circu
TIH slowly to 4556' (TIH slowly to minimize
ECDs)
CBU - (Stage rate up slowly)Rate 4 BPM 15
OOpsi - @ BU mud wt 10.9ppg - Circu until w
t dn to 10.6/10.6+ppg
TIH slowly to 6071' (TIH slowly to minimize
ECDs)
CBU - (Stage rate up slowly)Rate 4 BPM / 5
10psi - @ BU mud wt 11.0+ppg - Circu until
wt dn to 10.6/10.6+ppg
T I H s I owl Y to 7 5 8 6' (T I H s I owl Y to m i n i m iz e
ECDs)
CBU - (Stage rate up slowly)Rate 4 BPM I 6
40psi - @ BU mud wt 10.9+ppg - Circu until
wt dn to 10.6/10.6+ppg
TIH slowly to 8249' (TIH slowly to minimize
ECDs)
CBU - (Stage rate up slowly)Rate 4 BPM I 6
40psi - @ BU mud wt 10.9+ppg - Circu until
wt dn to 10.6/10.6+ppg Up Wt 100K / Dn Wt
95K ( Pumping 4 BPM & Rotate 60 RPMs) *
* NOTE** Used a lot of extra care RIH to ma
ke sure formation was not broke down by sur
ge for assy.
Con't to circu @ 8249' - Rot ( 65 rpm) & Rec
ip - up wt 98k , dn wt 90k - 10.8+ ppg Out
TIH slowly to 9006' (fill ever 5 stds)
Circu @ 9006' - Rate 4 bpm = 640 psi - Rot
(65 rpm )& Recip-10.8+ to 10.9 ppg Out- Tre
ating all returns
TIH slowly to 9764' (Top of LCM pill) (fill ev
er 5 stds)
Circu Hole Clean - Slowly stage up pump rat
e to 4 bpm = 750 psi ( 13 PV & 15 YP ) - up
wt 105k ,dn wt 98k
Run ECD / Loss Rate Test - Stage up pump
rate slowly @ 1/2 bbls increments: @ 7 bpm
started lossing very slowly. Increase rate
to 7.5 bpm( 2020 psi). Pumped for 11 min an
d lost 8 bbls. slowing a small regular loss.
Mud wt out and in 10.6+ , PV 13 , YP 15
Note** The 7.5 bpm rate equaled a simulate
d ECD of 11.61ppg
Reduce pump rate back to 4 bpm - Con't to
Printed: 5/29/2002 1 :49:31 PM
)
~HI;LlPS'Þ
~1~/tj~
~
)
Page 11 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name: 2P-427
Common Well Name: 2P-427
Event Name: ROT - DRILLING
Contractor Name: n1433@ppco.com
Rig Name: Nordic 3
Date From - To Hours Code Sub Phase
Code
5/12/2002 09:30 - 10:00 0.50 DRILL CIRC PROD
10:00 - 11 :30 1.50 DRILL REAM PROD
11 :30 - 15:00 3.50 DRILL CIRC PROD
15:00 - 15:30 0.50 DRILL OTHR PROD
15:30 - 18:00
2.50 DRILL CIRC PROD
18:00 - 19:00
1.00 DRILL TRIP PROD
19:00 - 00:00
5.00 DRILL TRIP PROD
5/13/2002 00:00 - 04:00 4.00 DRILL TRIP PROD
04:00 - 04:30 0.50 DRILL TRIP PROD
04:30 - 07:00 2.50 DRILL TRIP PROD
07:00 - 08:30 1.50 DRILL PULD PROD
08:30 - 11 :30 3.00 WELCTL EQRP PROD
11 :30 - 12:00 0.50 CASE RURD PROD
12:00 - 15:00 3.00 CASE RUNC PROD
15:00 - 17:00 2.00 CASE RUNC PROD
17:00 - 00:00 7.00 CASE RUNC PROD
5/14/2002 00:00 - 02:30 2.50 CASE RUNC PROD
02:30 - 04:30 2.00 CASE RUNC PROD
04:30 - 13:00 8.50 CASE CIRC PROD
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
Rot (60rpms & Recip)- Evaluate test (Rig Su
pv ,Well Eng & Team Leader confer on Plan
forward)
Wash & Ream to 10,110' (Circu @ 4 bpm , ro
tate 40 rpms
Circu hole clean - Pump rate 4 bpm = 750 ps
i-Rot (60 rpms) & Recip
Run ECD I Loss Rate Test - Stage up pump
rate slowly @ 1/2 bbls increments to 6.5 BP
M - Pumped 10 min @ 6.5 BPM = lost 2 bbls
- Static mud wt 10.6+ppg , PV 12 , YP 15
Reduce pump rate back to 4 bpm - Con't to
Rot (60rpms & Recip) to clean & condition
hole - Evaluate test- Rig Supv ,Well Eng , T
eam Leader & Kevin Tanner -It was agreed t
hat the CMT job could be pumped at a reduc
ed rate (3 to 3.25 BPM) and be successful -
Decision made NOT to pump PermaSeal plu
g ( will be returned, but will have some cos
t but reduced )- ** Note** Conditioned mud t
010.6 ppg , PV12 , YP 11 @ trip time.
Monitor Well for flow ( Static)- Fill trip tank
- Blow down
TOH slowly - Pump out first 20
r at 8249' (.8 bbl gain after 40
Iing String slowly - Fill shows
( Calcu 27.6 bbl , Accual 29.1
poi n t
Con't TOH to Shoe
Monitor well @ shoe (2945') per procedure
Con't TOH - SIB SWDP - LID HO assy
Drain stack - M/U combo tool - Pull wear bu
shing - Install test blug
Change out rams - Install 5.5" rams in TPRs
and 3.5" rams in LPRs - Test body breaks 2
50psi 10 & 3500 psi High "OK"
RID test equip - R/U Csg tools - PJSM
TIH wI Slim Hole Csg system (Run 18 jts 3.
5" 9.3# L80 EUE 8rd)
R/U 5.5" Csg Tools - Change out to long bai
Is - P/U Franks fill up tool
M/U Baker 80-40 CSR - TIH wI 5.5" 15.5# L
80 BTCM - Monitor Returns closely
CBU x 2 @ the Shoe (40 spm(2.33 bpm) =
420spi
TIH wI 5.5" 15.5# L80 BTCM to 4454' ( 90
jts run)
CBU - Work pump rate up slowly - Rate @ 4
0 SPM (2.33 bpm) and started to slowly loss
partial returns. Brought rate back to 1.0 BP
M - Loses stabilized- Slowly worked the pum
p rate up several times and loses would occ
ure @ 1.9 to 2.0 BPM. Mud Wt 10.6 ppg , FI
stds - Monito
min) TOH pu
to be correct
bbl ) to this
Printed: 5/29/2002 1 :49:31 PM
~HI;LlP8..
~
)
)
Page 12 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/14/2002
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Sub
From - To Hours Code Code Phase
04:30 - 13:00
8.50 CASE CI RC PROD
13:00 - 16:30 3.50 RIGMNT OTHR PROD
16:30 - 17:00 0.50 CASE CIRC PROD
17:00 - 20:00 3.00 CASE RUNC PROD
20:00 - 00:00 4.00 CASE RUNC PROD
5/15/2002 00:00 - 00:00 24.00 CASE RUNC PROD
5/16/2002
5/17/2002
00:00 - 00:30
0.50 CASE CIRC PROD
00:30 - 03:30
03:30 - 12:30
3.00 CASE RUNC PROD
9.00 CASE CIRC PROD
12:30 - 13:00
13:00 - 14:00
0.50 CASE SFTY PROD
1.00 CASE RURD PROD
14:00 - 15:00
1.00 CEMENTCIRC PROD
15:00 - 17:00
2.00 CEMENT PUMP PROD
17:00 - 18:00
18:00 - 19:30
19:30 - 22:00
1.00 CEMENT RURD PROD
1.50 CASE OTHR PROD
2.50 CASE RURD PROD
22:00 - 00:00
2.00 WELCTL NUND PROD
00:00 - 00:30
0.50 CMPL TN SEaT PROD
00:30 - 01 :00
0.50 CMPL TN RURD PROD
Start:
Rig Release:
Rig Number:
4/22/2002
Spud Date: 4/24/2002
End:
Group:
Description of Operations
ow Line Temp 60?,PV 23 I YP 19 - API @ 1
20? PV 14 I YP 13 R/U steam hose coil in
pits to warm up mud. Warming pits seem to
help circulation rates.
Lost high line power and locked out breaker
on SCR's. Rig up Dowell and circulate hole
at 1.5 bpm with 400 psi.
Back on rig power. Break circulation slowly
and increase rate to 2.3 bpm with 430 psi.
Run three jts. Circulate b/u 1-1/2 times. Sta
ge pumps to 2 bpm.
Continue rih with 5-1/2" casing to 5185. Cir
cui ate bu on # 97 and #110. Stage pumps up
slowly to 2.5 bpm with 600 psi.
Continue running 5-1/2" casing. Circulate 50
0 strokes after every 5 jts and 10 jts run.
Circulate bottoms up after running every 15
jts. Total jts in hole at midnight=215 of 22
2 jts. Circulate at 40 spm with 600 psi.
Finish circulating bottoms up at 9775' at 40
spm with 600 psi.
Wash the last 22jts to bottom.
Make up landing jt and break circulation slo
wly. Stat at 20 spm(1.2 bpm) and increase t
0 50 spm(3.0 bpm) with no losses and 500 p
s i.
Pre job safety meeting with all personnel.
LID Frank's fill up tool and make up Dowell
cement head. Transfer mud from pits to ball
mill to make room for cement job.
Continue circulating while Dowell batch mix
ed cement.
Test lines 4000 psi. Pump 40 bbls CW100 an
d 30 bbls 11 ppg mud push. Pump 50 bbls(23
0 sxs) "G" @15.8 ppg with gas blok. Drop wi
per dart and displace 10.6 ppg brine with ri
g pumps at 3 bpm. Slowed rate to 2 bpm whe
n cement came around shoe. Psi increased f
rom 80 psi-380 psi. Plug bumped early(3972
13867) but bumped right on the calculated v
olume inside the 3-1/2" casing. Bumped plug
to 850 psi. Floats held. Reciprocate casing
with full returns the entire job.
Rig down Dowell
Finish loading pipe shed with 3-1/2" tubing.
Lay down landing jt. Install 5-1/2" packoff a
nd test same to 5000 psi for 10 minutes.
Set test plug. Change top rams to 2-7/8" x 5
" and bottom rams to 4" Test same to 250/30
00 psi
Fill Stack - R/U Test equip - Test door brea
ks 250 10 I 3000 psi - Pull test plug
R/U floor equip to run 3 1/2" Tbg
Printed: 5/29/2002 1:49:31 PM
~~.
~~ ~~~~
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/17/2002
5/18/2002
From - To
01 :00 - 12:00
12:00 - 13:00
13:00 - 14:30
14:30 - 19:30
19:30 - 21 :00
21 :00 - 23:30
23:30 - 00:00
00:00 - 01 :00
01 :00 - 05:30
)
)
Page 13 of 14
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Sub
Hours Code Code
Phase
11.00 CMPL TN RUNT PROD
1.00 CMPL TN RUNT PROD
1.50 CMPL TN RURD PROD
5.00 CMPL TN RURD PROD
1.50 CMPL TN NUND PROD
2.50 CMPL TN RUNT PROD
0.50 CMPL TN RUNT PROD
1.00 CMPL TN FRZP PROD
4.50 CMPL TN FRZP PROD
05:30 - 06:00 0.50 CMPL TN RURD PROD
06:00 - 08:00 2.00 DRILL PULD PROD
08:00 - 00:00 16.00 DRILL PULD PROD
5/19/2002 00:00 - 03:30 3.50 DRILL PULD PROD
03:30 - 06:00 2.50 DRILL PULD PROD
Start:
Rig Release:
Rig Number:
Spud Date: 4/24/2002
End:
Group:
4/22/2002
Description of Operations
PJSM - Run Completion Assy - Run 301 jts 3
.5" 9.3# L80 8rd EUE tbg . Run perl Tbg d
etail . Space out wI 1 pup (6.04) (I full jt
under tbg hanger) - Land Tbg - FMC RILDS a
nd torque - FMC Test hanger (String up wt
85K , Dn wt 45K **NOTE** Seals in CSR top
at 9521.62' I Bttm of 3 1/2" @ Plug catch
er @ 10045' PBTD == 10045'
Pressue up Tbg to 500 psi - Pressure test 5.
5" X 3.5" Ann to 3000psi and chart for 30 mi
n. - Lost 40 psi over 30 min test -
Bleed psi off Tbg - Shear out shear vavle @
9408' - Confirm Valve sheared - RID surfac
e Ii n e
Clean all equip from Rig floor - Run Wash 0
ut tool in BOPs - NID BOPs
N/U Tree - DSO (Dana) approved Tree orient
ation- Test tree 5000psi 10 min "OK"
R/U to freeze protest - Pump 60 bbls diesel
dn 5.5" X 3.5" Ann taking reurns from tbg -
Put Tbg and Ann in comminication - Let U T
ube
RID surface lines - Install BPV - R/U Surfac
e lines to 7 5/8" X 5.5" Ann
Con't to R/U to 7.625' X 5.5" Ann
Preform LOT per program - Original 2394' T
VD - with 10.5ppg mud in ann = Pressure at
surface 682 psi = Held 16ppg EMW - After 1
0 min shut in psi was 520psi. Bring pump 0
n line - Formation broke dn @ 900psi (17.7
EMW) - Con't to pump @ .25 bpm = 630psi i
njection rate - Freeze protect 7.625" X 5.5"
Ann with 35 bbls diesel (2121' MD) - RID hol
es
Dress Tree with all blinds & guages - Clean
cellar area - SI tgb 0 psi, SI IA 0 psi, SI
OA 650 psi
Clean all extra equip from pipe shed - PJSM
- R/U to LID drill pipe
LID drill pipe from derrick using mouse hole
Con't to LID 4" DP out of derrick using mous
e h 0 Ie.
RID Eckel power tongs - Clear all equip fro
m rig floor - Remove all equip & unload from
pipe shed. Rig released @ 0600 hrs 5/19/0
2 **Note** Well cellar box had some subsid
ence around the edges. 1 foot or so and may
be 3' deep. A well guard was placed around
well. **Note** Matting boards were place
d under Rig and the rig was rolled straight 0
ff well and set back down. This leaves a tra
vel space of 24' between the well guard an
d cellar wall and 40' from the motor room st
Printed: 5/29/2002 1 :49:31 PM
~HI~LlPS.~
~~{jr
~
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
5/19/2002
)
)
PHILLIPS ALASKA INC.
Operations Summary Report
2P-427
2P-427
ROT - DRILLING
n1433@ppco.com
Nordic 3
Sub
From - To Hours Code Code Phase
03:30 - 06:00
2.50 DRILL PULD PROD
Start: 4/22/2002
Rig Release:
Rig Number:
Page 14 of 14
Spud Date: 4/24/2002
End:
Group:
Description of Operations
airs to the edge of pad. The loader will atte
mpt to back drag and level all ruts that he c
an. We will minimize loader traffic afterward
to let pad set and dry out.
Printed: 5/29/2002 1 :49:31 PM
Date
07/28/02
10/16/02
10/17/02
10/18/02
10/19/02
10/23/02
10/25/02
10/26/02
10/27/02
10/28/02
10/29/02
1 0/31/02
11/01/02
11/02/02
11/03/02
11/04/02
11/06/02
)
2P-427 Event History
')
Comment
2.8111 CAMCO CS LOCKS (FOR JET PUMPS) CHARGES
DRIFTED TBG TO 9710' WLM W/ 10' X 2.56511 DUMMY GUN. ENCOUNTERED OBSTRUCTION @ THAT
PT. OBTAINED SAMPLE OF SAME. [TAG]
INSTALLED DV @ 9421' RKB. PT TBG & CSG TO 3500#. GOOD TESTS [GLV, PT TBG-CSG]
CLEANED TO 10,030 FT CTM WITH MILL. WASHED WELL TO SURFACE WITH DIESEL. [FCO]
DRIFTED TBGW/ 11' X 2.565I1DUMMY GUN TO 10016' WLM. [TAG] RAN JEWELRY LOG FROM TD (10042'
MD) TO 9350'. PERFORATED INTERVAL 10008' - 10018' WITH 2.511 HSD GUNS. USED HYPERJET 2506
CHARGES, RDX. 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. API PENETRATION 13.111,
ENTRANCE HOLE 0.4311. AFTER PERFORATING PERFORMED SBHPS. STOP COUNTS TAKEN @ 10013'
& 9813'.
PUMP FRACTURE TREATMENT USING 30# X-LINKED GEL. PUMP 282,500 LBS OF 16/20 CERAMIC
PROPPANT. PLACED 262,500 LBS OF PROPPANT BEHIND PIPE WITH 10 PPA ON PERFS. BUILT 600
PSI OF NET PRESSURE AT END OF JOB. SCREENED OUT WITH 16 BBLS OF DIESEL FLUSHED.
RECOVERED ALL TREE SAVER CUPS.
CLEANED OUT SURFACE ICE PLUG TO 120' - POST FRAC FILL CLEANOUT FROM TOP OF SAND @
2600' TO HARD BOTTOM @ 10026' CTM - SWEPT THROUGH PERF ZONE NUMEROUS TIMES USING
SLICK WATER / SLICK DIESEL AND DIESEL GEL SWEEPS - ADDED 700 PSI BACKPRESSURE TO WELL
TO POOH @ ONE FOR ONE RETURNS ATTEMPTING TO KEEP PROP IN THE FORMATION - CLEANED
ALL GLM'S WHILE POOH - READY FOR SLlCKLlNE.
TAGGED FRAC SAND BRIDGE @ 9520' WLM. HUNG UP @ 2370' WLM. SUSPECT FRAC SAND BRIDGE.
CUTTER BAR & TOOLSTRING IN HOLE. [TAG]
BAILED FRAC SAND & RECOVERED CUTTER BAR @ -9467' WLM. IN PROGRESS. [FISH]
BAILED FRAC SAND FROM -9463' WLM TO -9470' WLM. IN PROGRESS.
BAILED FRAC SAND FROM -9470' WLM TO -9473' WLM. IN PROGRESS.
BAILED SAND 9474' TO 9477' SLM, ATTEMPT TO LATCH FISH. ATTEMPT TO PULL DV FROM GLM'S #1
THRU #4, FRAC SAND. IN PROGRESS. [FISH]
RIH W/ SWIRL JET NOZZLE, CIRC TO TOP OF FISH. SD PUMPS, ATTEMPT TO TAG TOP OF FISH WITH
DRY TAG. RIH TO 9500' CTM, DID NOT SEE FISH. WELL EXTREMELY TIGHT, PRESSURE CHANGING
WITH COIL IN/OUT. PUH RECIP WI BIOZAN PILLS ACROSS ALL MANDRELS, FREEZE PROTECT.
RIH W/ HYDRAULIC JD LATCHING TOOL & JARS IN ATTEMPT TO FISH TOOLS. LOCATED TOP OF FISH
AT 9509' CTM. CIRCULATED 10 BBL BIOZAN PILL TO SURFACE TO WASH TOP OF TOOL, LAID IN 5 BBL
OF BIOZAN AT TOP OF FISH. ATTEMPT TO LATCH, TOOL MOVED DH 9515' CTM, 2ND ATTEMPT
APPEARS SUCCESSFUL. PUH TO 9450', SET DN TO ENSURE LATCHED, STACKED WT AT 9414'
APPEAR TO HAVE FISH. POOH W/WELL SI, LOSING PRESSURE. AT SURF, CLOSE SWAB & MASTER,
STAB OFF WELL, NO FISH.
STANDING BY FOR RESULTS OF LIB RUN BY WIRELlNE. UNABLE TO REACH FISH DUE TO BIOZAN
LEFT AT TOP OF FISH. PE WANTS OV RUN WHILE HALIBURTON WIRELlNE IS ON THE WELL.
CONTINUE FISHING TOMMOROW. [FISH] TAGGED IN TBG @ 9461' RKB, FRAC SAND. PULLED DV @
8156' RKB, UNABLE TO SET OV DUE TO THICK FLUIDS IN TBG. TOOL STRING HUNG UP @ 7800' SLM
DUE TO OV BESIDE TRAY. IN PROGRESS.
DISPLACED TBG & IA WI DIESEL TO 8156' RKB. RECOVERED DROPED OV. SET 5/1611 OV @ 8156' RKB,
TESTED GOOD. [FISH] RIH TO CLEAN DN TO FISH. RAN 2 VENTURI BASKET RUNS, MADE HOLE
EQUIVALENT TO BASKET SECTION EACH RUN. RU W/BALL DROP NOZZLE, RIH REVERSING, BROKE
THRU SEVERAL HARD BRIDGES. PUSH FISH TO 9980' CTM, BTM OF FISH AT BTM PERF @ 10,018'
RKB. POOH FREEZE PROTECT WELL TO 2500'.
RIH WI HYDRAULIC JD LATCHING TOOL TO TOP OF FISH. PARK TOOL AT TOP OF FISH. CIRCULATE
BIOZAN PILL BTMS UP. RIH LATCH FISH, POOH. IMMEDIATELY AFTER LATCHING FISH WHP JUMPED
FROM 700 TO 1000 PSI, AT 9800' BRING WELL ON AT 700 PSI WHP. WELL FLOWING APPROX 1.25
BPM WHILE POOH. AT SURFACE, FLANGE DN, ALL OF FISH RECOVERED WITH LARGE METAL PIECE
ABOVE FISHING NECK IN JD TOOL.
Page 1 of 1
11/11/2002
)
)
Phillips Alaska, Inc.
Drill Site 2P
427
slot it427
Meltwater
North Slope, Alaska
SUR V E Y LIS TIN G
by
Baker Hughes INTEQ
Your ref: MWD <0-10402'>
Our ref: svy6747
License:
Date printed: 20-May-2002
Date created: 24-Apr-2002
Last revised: 8-May-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000,N
Slot location is n70 3 9.434,w150 26 54.701
Slot Grid coordinates are N 5868952.768, E 443952.044
Slot local coordinates are 923.61 S 1995.10 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
)
Phillips Alaska, Inc.
Drill 8ite 2P,427
Meltwater,North 8lope, Alaska
Measured Inclin Azimuth True Vert
Depth Degrees Degrees Depth
0.00
114.00
197.51
287.97
380.96
473.86
565.20
659.41
751.63
842.26
933.40
1024.43
1116.63
1210.72
1305.46
1399.57
1495.80
1589.94
1685.02
1779.27
1874.35
1969.35
2061.01
2156.48
2250.84
2345.32
2439.83
2535.17
2629.61
2724.10
2819.24
2914.54
2987.00
3103.50
3197.88
3293.14
3387.54
3482.67
3577.77
3672.26
3767.07
3860.56
3954.79
4049.88
4144.04
4238.83
4333.77
4428.11
4523.49
4619.56
12.48
16.35
22.15
25.58
28.30
31. 11
34.54
36.04
39.02
40.25
39.64
41.84
45.26
48.25
52.38
57.30
59.94
61. 88
62.49
62.05
62.05
62.05
62.05
62.75
63.37
62.67
62.75
63.11
61. 70
61.35
61. 88
60.91
60.56
61. 61
62.49
62.93
62.23
61. 2 6
61.08
60.82
0.00
0.00
0.44
0.09
2.02
0.00
0.00
349.40
24.90
165.18
0.00
114.00
197.51
287.97
380.94
473.69
564.68
658.29
749.68
839.34
928.92
1017.07
1104.08
1190.11
1274.57
1356.30
1437.15
1513.99
1589.39
1661.97
1734.86
1806.84
1873.26
1938.66
1998.91
2053.31
2102.51
2148.87
2192.93
2236.90
2281. 49
2326.16
2360.13
2414.10
2456.86
2500.08
2543.36
2586.65
2630.70
2675.75
2720.83
2765.59
2811. 65
2857.63
2901.76
2945.22
2988.94
3033.60
3079.60
3126.25
)
5URVEY LI8TING Page 1
Your ref: MWD <0-10402'>
Last revised: 8-May-2002
R E C TAN G U L A R Dogleg Vert
COO R DIN ATE 8 Deg/100ft 8ect
O.OON
O.OON
0.32N
O.72N
0.808
5.828
13.728
24.218
36.438
49.498
65.828
87.728
116.938
153.508
194.678
239.288
288.925
340.608
395.858
453.528
512.348
572.225
633.378
700.918
771.008
845.018
922.478
1002.248
1081.928
1161. 868
1242.488
1323.168
1384.455
1483.408
1563.818
1644.798
1724.828
1805.938
1886.868
1966.818
2047.258
2126.348
2205.748
2286.408
2366.808
2447.978
2529.378
2609.708
2690.218
2771.268
O.OOE
O.OOE
0.06W
0.09W
0.36E
1.38E
2.47E
3.94E
5.67E
7.67E
11.06E
16.80E
25.19E
35.73E
47.85E
61.44E
77.42E
94.37E
111.73E
128.70E
145.04E
161. 08E
176.84E
193.38E
212.23E
234.26E
256.81E
280.83E
305.89E
330.49E
354.22E
378.24E
396.69E
426.16E
450.90E
476.37E
501.53E
525.95E
549.51E
571.98E
594.06E
616.02E
637.29E
657.84E
679.12E
701. 66E
723.46E
744.72E
767.08E
789.06E
0.00
0.00
0.53
0.41
2.25
0.00
0.00
-0.32
-0.72
0.86
G RID COO R D 8
Easting Northing
443952.04
443952.04
443951.99
443951.96
443952.40
443953.38
443954.41
443955.80
443957.44
443959.34
443962.60
443968.18
443976.34
443986.60
443998.41
444011.66
444027.25
444043.81
444060.74
444077.27
444093.16
444108.74
444124.04
444140.06
444158.37
444179.84
444201. 79
444225.20
444249.65
444273.64
444296.75
444320.16
444338.14
444366.84
444390.98
444415.82
444440.37
444464.17
444487.10
444508.97
444530.43
444551.78
444572.44
444592.38
444613.04
444634.96
444656.14
444676.78
444698.53
444719.89
5868952.77
5868952.77
5868953.08
5868953.49
5868951.97
5868946.94
5868939.03
5868928.53
5868916.30
5868903.22
5868886.87
5868864.93
5868835.66
5868799.01
5868757.76
5868713.05
5868663.29
5868611.49
5868556.12
5868498.32
5868439.39
5868379.39
5868318.13
5868250.48
5868180.25
5868106.08
5868028.45
5867948.52
5867868.65
5867788.54
5867707.75
5867626.89
5867565.47
5867466.31
5867385.72
5867304.55
5867224.34
5867143.05
5867061. 96
5866981.84
5866901.25
5866822.00
5866742.45
5866661.65
5866581.09
5866499.76
5866418.20
5866337.72
5866257.05
5866175.84
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #427 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level).
Bottom hole distance is 7977.06 on azimuth 164.11 degrees from wellhead.
Vertical section is from.wellhead on azimuth 164.24 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
4.31
5.71
7.21
8.17
8.61
170.10
173.62
170.80
172.91
169.75
167.29
163.77
164.12
163.77
163.42
162 . 72
161. 66
162.01
163.07
164.12
164.83
165.18
165. 88
166.58
163.42
163.42
164.12
162.37
162.72
163.07
164.12
162 . 72
163.77
163.07
162 . 72
162.37
162 . 72
163. 77
163.77
164.83
164 .48
164.48
165.53
165.88
164.48
164.48
165.53
164.83
164 . 12
165.53
2.48
1. 57
1. 63
1. 08
0.70
5.97
13 .87
24.37
36.60
49.72
4.27
4.36
6.29
3.65
2.88
66.35
88.99
119.37
157.44
200.35
3.01
3.61
1. 61
3.21
1. 49
246.97
299.09
353.43
411.31
471.43
0.80
2.33
3.77
3.18
5.08
532.47
594.46
657.59
727.08
799.66
5.21
2.86
2.59
0.72
0.57
876.87
957.55
1040.84
1124.33
1207.94
0.97
1. 30
1.28
0.80
0.74
1291.98
1376.15
1440.15
1543.38
1627.49
0.80
0.34
1. 05
1. 48
1. 05
1712.35
1796.20
1880.90
1965.18
2048.23
0.65
1. 04
1. 04
1.15
1. 61
2131.64
2213.72
2295.91
2379.12
2462.28
0.46
1.23
1.22
0.68
1.31
2546.52
2630.78
2713.87
2797.43
2881.40
)
Phillips Alaska, Inc.
Drill 8ite 2P,427
Meltwater,North 81ope, Alaska
Measured Inclin Azimuth True Vert
Depth Degrees Degrees Depth
4714.88
4808.43
4903.61
4995.31
5091. 09
5185.10
5280.59
5374.77
5469.60
5564.38
5660.25
5755.21
5849.66
5943.20
6037.71
6132.57
6228.23
6322.08
6416.90
6511.79
6607.73
6702.12
6797.07
6891.63
6986.62
7081.43
7176.05
7269.24
7363.60
7458.90
7553.63
7647.71
7742.27
7838.61
7933.08
8027 .50
8122.58
8217.55
8312.10
8406.84
8500.60
8595.72
8688.66
8784.08
8880.75
8973.17
9069.07
9164.08
9258.51
9353.71
60.38
60.82
61. 52
62.23
63.63
63.19
63.28
62.67
61.79
60.73
60.29
61.17
62.05
61.79
61.26
61. 00
60.38
60.29
58.71
58.36
59.24
60.03
60.91
61.70
62.58
63.63
63.54
62.40
63.63
63.72
63.19
62.23
61.61
61. 08
61.44
62.23
61. 35
61.44
61. 96
60.91
60.73
61. 2 6
62.31
63.02
62.31
63.02
62.31
61.44
61. 70
61. 79
165.53
165.53
165.53
164.48
165.18
164.48
164.83
163.42
163.42
163.42
162.72
162.37
161.66
162.37
163.42
163.77
164.83
164.48
167 . 64
167.29
166.94
167.29
166.23
166.58
166.23
166.58
165.88
164.12
1 63 . 77
163.07
163.77
162.72
163.77
164.48
163. 77
163.07
163.42
164.12
163.77
163.77
163.77
163.07
163.77
163.77
163.77
165.88
164.12
164.48
164.48
163.07
3173.04
3218.97
3264.86
3308.09
3351.68
3393.76
3436.76
3479.55
3523.74
3569.31
3616.50
3662.93
3707.84
3751. 87
3796.93
3842.73
3889.56
3936.01
3984.14
4033.67
4083.37
4131. 09
4177.89
4223.29
4267.68
4310.57
4352.66
4395.01
4437.83
4480.09
4522.43
4565.56
4610.07
4656.27
4701.70
4746.26
4791. 21
4836.68
4881. 50
4926.80
4972.51
5018.64
5062.58
5106.39
5150.78
5193.22
5237.26
5282.05
5327 . 01
5372.08
)
8URVEY LI8TING Page 2
Your ref: MWD <0-10402'>
Last revised: 8-May-2002
R E C TAN G U L A R Dogleg Vert
COO R DIN ATE 8 Deg/100ft 8ect
2851.678
2930.598
3011. 338
3089.448
3171.768
3252.898
3335.118
3415.818
3496.238
3575.878
3655.718
3734.738
3813.768
3892.258
3971. 658
4051. 348
4131. 648
4210.288
4289.558
4368.568
4448.568
4527 .958
4608.368
4688.988
4770.618
4852.808
4935.108
5015.288
5096.088
5177.958
5259.178
5339.228
5419.118
5500.428
5580.108
5659.878
5740.108
5820.168
5900.168
5980.058
6058.658
6138.388
6216.878
6298.258
6380.718
6459.948
6542.228
6622.898
6702.908
6783.418
809.81E
830.18E
851.02E
871.94E
894.26E
916.25E
938.82E
961. 76E
985.70E
1009.42E
1033.72E
1058.57E
1084.22E
1109.71E
1134.14E
1I57.60E
1I80.18E
1201.76E
1221. 45E
1239.02E
1257.32E
1275.48E
1294.40E
1313.90E
1333.64E
1353.51E
1373.68E
13 95. 16E
1418.42E
1442.79E
1466.97E
1491.07E
1515.12E
1538.25E
1560.91E
1584.66E
1608.82E
1632.12E
1655.14E
1678.40E
1701.28E
1725.02E
1748.39E
1772.08E
1796.08E
1817.56E
1839.61E
1862.28E
1884.50E
1907.93E
0.46
0.47
0.74
1.27
1. 60
2964.43
3045.91
3129.27
3210.13
3295.41
G RID COO R D S
Easting Northing
444740.03
444759.79
444780.01
444800.34
444822.02
444843.40
444865.33
444887.66
444910.98
444934.09
444957.78
444982.02
445007.07
445031.95
445055.78
445078.63
445100.59
445121.57
445140.66
445157.62
445175.31
445192.86
445211.17
445230.05
445249.17
445268.41
445287.95
445308.81
445331. 45
445355.20
445378.76
445402.25
445425.69
445448.19
445470.24
445493.38
445516.92
445539.61
445562.02
445584.67
445606.95
445630.07
445652.84
445675.91
445699.28
445720.16
445741.57
445763.63
445785.24
445808.05
5866095.28
5866016.22
5865935.33
5865857.07
5865774.59
5865693.30
5865610.92
5865530.06
5865449.47
5865369.65
5865289.64
5865210.44
5865131.23
5865052.55
5864972 . 97
5864893.12
5864812.65
5864733.86
5864654.45
5864575.31
5864495.19
5864415.67
5864335.12
5864254.36
5864172.59
5864090.27
5864007.82
5863927.49
5863846.51
5863764.47
5863683.08
5863602.85
5863522.79
5863441.31
5863361. 48
5863281.53
5863201.13
5863120.90
5863040.74
5862960.68
5862881.92
5862802.02
5862723.36
5862641.80
5862559.18
5862479.79
5862397.35
5862316.52
5862236.35
5862155.67
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #427 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level).
Bottom hole distance is 7977.06 on azimuth 164.11 degrees from wellhead.
Vertical section is from wellhead on azimuth 164.24 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
0.81
0.34
1. 48
0.93
1.12
3379.47
3464.73
3548.62
3632.52
3715.62
0.78
0.98
1.14
0.73
1.13
3799.05
3881.85
3964.87
4047.34
4130.39
0.42
1.16
0.34
3.32
0.48
4213.45
4296.87
4378.41
4460.05
4540.86
0.97
0.90
1. 34
0.90
0.98
4622.82
4704.16
4786.69
4869.58
4953.50
1.16
0.67
2.08
1. 34
0.67
5037.99
5122.68
5205.68
5289.76
5375.17
0.87
1. 42
1.18
0.85
0.76
5459.91
5543.50
5626.91
5711. 45
5794.28
1.06
0.98
0.65
0.64
1.11
5877.51
5961.29
6044.66
6127.91
6211.11
0.19
0.85
1. 31
0.74
0.73
6292.97
6376.15
6458.04
6542.80
6628.67
2.17
1. 79
0.97
0.28
1.31
6710.76
6795.94
6879.73
6962.77
7046.62
)
)
Phillips Alaska, Inc. SURVEY LISTING Page 3
Drill Site 2P,427 Your ref : MWD <0-10402'>
Meltwater,North Slope, Alaska Last revised : 8-May-2002
Measured Inclin Azimuth True Vert R E C TAN G U L A R Dogleg Vert G RID COO R D S
Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing
9447.69 62.49 163.42 5415.99 6862.97S 1931.88E 0.81 7129.70 445831.39 5862075.93
9542.09 61. 35 163.07 5460.43 6942. 72S 1955.89E 1.25 7212.97 445854.79 5861996.01
9636.58 60.82 164.12 5506.12 7022.07S 1979.25E 1.12 7295.67 445877.54 5861916.50
9732.30 60.91 161.66 5552.72 7101. 96S 2003.85E 2.25 7379.25 445901.53 5861836.42
9826.59 62.31 163.07 5597.56 7181.01S 2028.97E 1. 98 7462.15 445926.04 5861757.19
9921.27 63.11 164.47 5640.97 7261.80S 2052.48E 1. 56 7546.29 445948.94 5861676.24
10015.93 63.19 164.12 5683.72 7343.10S 2075.34E 0.34 7630.74 445971.18 5861594.77
10111. 56 63.63 160.26 5726.54 7424.50S 2101. 50E 3.64 7716.18 445996.71 5861513.19
10206.07 63.81 162.01 5768.39 7504.68S 2128.90E 1. 67 7800.79 446023.49 5861432.80
10300.49 64.34 161.66 5809.67 7585.37S 2155.37E 0.65 7885.63 446049.35 5861351.93
10402.00 64.34 161.66 5853.62 7672.22S 2184.16E 0.00 7977.04 446077.47 5861264.87
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #427 and TVD from RKB (Nordic 3) (254.00 Ft above mean sea level).
Bottom hole distance is 7977.06 on azimuth 164.11 degrees from wellhead.
Vertical section is from wellhead on azimuth 164.24 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
)
')
Phillips Alaska, Inc.
Drill Site 2P,427
Meltwater,North Slope, Alaska
SURVEY LISTING Page 4
Your ref: MWD <0-10402'>
Last revised: 8-May-2002
Comments in wellpath
--------------------
--------------------
MD
TVD
Rectangular Coords.
Comment
-----------------------------------------------------------------------------------------------------------
10402.00 5853.62
7672.22S
2184.16E Projected Data - NO SURVEY
Casing positions in string 'A'
------------------------------
------------------------------
Top MD Top TVD
Rectangular Coords.
Bot MD Bot TVD
Rectangular Coords.
Casing
-----------------------------------------------------------------------------------------------------------
0.00
0.00
O.OON
O.OOE 3030.00 2380.19
1420.94S
407.41E 7 5/8 CSG
Targets associated with this wellpath
-------------------------------------
-------------------------------------
Target name
Geographic Location
T.V.D.
Rectangular Coordinates
Revised
-----------------------------------------------------------------------------------------------------------
MW(O) Midpt TGT RVSD 445938.000,5861705.000,999.00 5630.00
7233.12S
2041.33E 22-Feb-2001
Sc~l.bepg8P
Schlumberger Technology Corporation, by and through is Geoquest Division
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TTN: Beth
Well
Job#
Log Description
Date
1R-07
2P-427
J~f5 n 1~ PRODUCTION PROFILE
~-Ol W' SBHP SURVEY
10/17/02
10/19/02
Sl~r
DATE:
NO. 2543
11/07/02
Company: Alaska Oil & Gas Cons Comm
AUn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field:
BL
Sepia
Kuparuk
CD
Color
~
1
1
~
RECEIVED
NOV 08 2002
Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Alaska Od & Gas Cons. CommiStion
Anchorage
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
Description summary of proposal - Detailed operations program - Schematic -
I Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic -
14. Estimated date for commencing operation 15. Status of well classification as:
May 13, 2002
16. If proposal was verbally approved 10-May-02
Name of approver Winton Aubert Date approved Service-
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed T~~~ ~ - - Title: Kuparuk Drilling Team Leader
R. Thomas ... - 1
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity - BOP Test - Location clearance - Li.
Mechanical Integrity Test- Subsequentform required 10- ì 0'1
Onglnal SIgned By
Cammy Oechlli f§y @\'
. () R , GIN Ålmissioner
.
. ':J
)
1. Type of request:
Abandon - Suspend -
Alter casing - Repair well -
Change approved program _XX
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P. O. Box 100360
Anchorage, AK 99510-0360
4. Location of well at surface
924' FNL, 1992' FWL, Sec. 17, T8N, R7E, UM
At top of productive interval
2539'FSL, 1341'FEL,Sec.20,T8N, R7E,UM
At effective depth
At total depth
1926' FSL, 1173'FEL,Sec.20,T8N, R7E,UM
12. Present well condition summary
Total depth: measured
true vertical
Effective depth:
10402
5853
10140
5739
measured
true vertical
Length
80'
2996'
Casing
Conductor
Surface
Size
16"
7.625"
Production
Liner
Perforation depth:
measured None
true vertical None
Tubing (size, grade, and measured depth
None
Packers & SSSV (type & measured depth) No packer, No SSSV
13. Attachments
Approved by order of the Commission
Form 10-403 Rev 06/15/88 .
Operational shutdown -
Plugging -
Pull tubing -
5. Type of Well:
Development _X
Exploratory -
Stratigraphic -
Service -
(ASP's: 443952, 5868953)
(as proposed)
(as proposed)
feet
feet
feet
feet
Plugs (measured)
Junk (measured)
Cemented
30 bbl AS 1
380 sx AS Lite, 220 sx LiteCrete
Oil-
)
lL-lGA- S/IS/OL
¥I ( ~
l)C(:f S'/~
Re-enter suspended well -
Time extension - Stimulate -
Variance - Perforate -
6. Datum elevation (DF or KB feet)
RKB 34 feet
7. Unit or Property name
Other -
Kuparuk River Unit
8. Well number
2P-427
9. Permit number / approval number
202-018
10. API number
50-103-20408-00
11. Field I Pool
Kuparuk River Field / Meltwater Pool
Measured Depth
114'
3030'
True vertical Depth
114'
2380'
f.) E. ""
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Alaska OH & Gas Cons, Commission
Anchorage
Gas-
Suspended -
Questions? Pat Reilly 265-6048
oj-If )-/0<-
Date
Prepared by Sharon Allsup-Drake
I Approval nO'3D;) - / &S-
Date
I
'5/J((fO?-
SUBMIT IN TRIPLICATE
.Meltwater 2P-4¿,.)
Proposed Completion Schematic
Slimhole Base Case - 3-1/2" Completion String
30" x 16" 62.6#
(Insulated)
@ +1-114' MD
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Depths are
based on
Nabors 19E
RKB
Surface csg.
7-5/8" 29.7# L-80 BTCM
+1- 3030' MD /2380' TVD
Intermediate csg.
5-1/2" 15.5# L-80 BTCM
run CSR to surface
+1- 9541' MD I 5460' TVD
Future Perforations
Production csg
3-1/2" 9.3# L-80 EUE8RD
TO to CSR
+1- 10140' MD / 5739' TVD
MI Forma Plug
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)
~ PHI.LLIPS AI k
as a, Inc.
\~ A Subsidiary of PHILLIPS PETROLEUM COMPANY
Top Bermuda
9630' MD I 5503' TVD
;
;
;
;
;
;
;
;
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,
;
;
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,
,
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!
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,
y Landing Collar/Plug Catcher (Catcher, Insert Type, Tapered Plug) 10067'
OIL
! WATER
...::::::::<~. LCM Pill /'
+/- 10100' MD ~/
TD 10402' MD
.----
----
10265' MD
Base Bermuda
10285' MD I 5803'
TVD
PJR 5/15/02
)
~~IÆ~! :"F IÆllÆ~~~1Æ
)
AlASKA OIL AND GAS
CONSERVATION COMMISSION
TONY KNOWLES, GOVERNOR
333 w. -¡rn AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Chuck Mallary
Drilling Engineering Supervisor
Phillips Alaska, Inc.
. PO Box 100360
Anchorage AK 99510
Re:
Kuparuk River Unit 2P-427
Phillips Alaska, Inc.
Permit No: 202-018
SurLoc:924'F~, 1992'FVVL,Sec. l7,T8N,R7E,~
Btmhole Loc. 1926' FSL, 1173' FEL, Sec. 20, T8N, R7E, ~
Dear Mr. Mallary:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from other
governmental agencies, and does not authorize conducting drilling operations until all other required
permitting determinations are made.
Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to
ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be
contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test
(FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on
form 10-403 prior to the start of disposal operations.
Please note that any disposal of fluids generated from this drilling operation which are pumped down the
surface/production casing annulus of a well approved for annular disposal on 2P must comply with the
requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize
disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single
well or to use that well for disposal purposes for a period longer than one year.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25035. Sufficient
notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a
test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission
petroleum field inspector on the North Slope pager at 659-3607.
Sincerely,
(J M. - . ,~,-<-U'!»-f-i
C';~;~hsli Taylor
Chair
BY ORDER QF THE COMMISSION
DATED this.J...L day of February, 2002
cc:
Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
, ,~
(J.JGA 1.'/</(0 '-
, .
~')
PHilliPS Alaska, Inc.
A Subsidiary of PHILLIPS PETROLEUM COMPANY
)
Post Office Box 100360
Anchorage, Alaska 99510-0360
Chuck Mallary
Phone (907) 265-6434
Fax: (907) 265-1535
Email: crmalla@ppco.com
January 24, 2002
Cammy Oechsli Taylor, Chair
Alaska Oil and Gas Conservation Commission
333 West ih Avenue
Suite 100
Anchorage, Alaska 99501
(907) 279-1433
Re: Application for Permit to Drill, producer 2P-427
, Dear Commissioner Taylor:
Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore producer well, KRU 2P-427, a
development well.
Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c).
If you have any questions or require any further information, please contact Scott Lowry at 265-6869.
Sincerely,
~u~~é
Drilling Engineering Supervisor
REC I'V 0
J r~ t,! 9: ¡;;: ¡PO,?
f-,I.. ",,; ~^' LU 1-
Alaska Oil & Gas Cons. Commission
Anchorage
0 R I Cl i r~ /~ L
) STATE OF ALASKA ')
ALASKA Oil AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
Þ;R/~
~ W-Z-j!5/0z,
1b. Type of well. Exploratory D Stratigraphic Test D
Service D Development Gas D Single Zone 0
5. Datum elevation (DF or KB)
RKB 34 feet
6. Property Designation 3~1~B ))c
ADL 373112 ALK 4998 ~A
7. Unit or property Name
Kuparuk River Unit
8. Well number
2P-427
20. Attachments Filing fee 0 Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0
Drilling fluid program 0Time vs depth plot Qefraction analysis DSeabed report D 20 MC 25.050 requirements 0
21. I hereby certaify that 7YregOing is true and rect to the best of my knowledge Questions? ~C:I. tt t¡;~~5-~6;
Signed f< . Title: Drilling Engineering Supervisor ~'!te ~vor, - e?-
C. Mallary PrRnArRrl hv ShAmn AII.cwn-nrAkR
Commission Use Only
Permit Number . . <3 I API nu er. / I ,C2 ./Y"" I Approval date~\ . ~(>~see cover letter
/,-(:./'2- - Ú I ð 50- /D3 - 2L)yG}O ~L<-J . \. r) U. for other requiryments
Conditions of approval Samples required D Yes ~ No Mud log requited S Yes ~ No
Hydrogen sulfide measures DYes .s: No Directional survey required lXl Yes D No
Required working pressure for BOPE D2M; D 3M; D 5M; D 10M; D D
Other: T e c;, t ß? P E 4v ~ 5 D 0 ~ ç ¿. tAl6Æ-
Original Signed By
Gammy Oechsli
1 a. Type of work: Drill 0 Redrill D
Re-entry DDeepen D
2. Name of Operator
Phillips Alaska, Inc.
3. Address
P.O. Box 100360 Anchorage, AK 99510-0360
4. location of well at surface
924' FNL, 1992' FWL, Sec. 17, T8N, R7E, UM
At top of productive interval
2539' FSL, 1341' FEL, Sec. 20, T8N, R7E, UM
At total depth
1926'FSL,1173'FEL,Sec.20,T8N,R7E,UM
12. Distance to nearest property line 13. Distance to nearest well
1173' @ TD feet 2P-429 , 35.9' @ 700'
16. To be completed for deviated wells
Kickoff depth: 300 MD
18. Casing program
size
Maximum hole angle
61°
Hole Casing Weight
42" 16" 62.5#
9.875" 7.625" 29.7#
6.75" 5.5" 15.5#
6.75" 3.5" 9.3#
Specifications
Grade Coupling
H-40 welded
L-80 BTCmod
L-80 BTCmod
L-80 =UE 8rd Moc
Length
80'
3003'
8950'
1514'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total Depth:
measured
true vertical
feet
feet
Effective Depth:
feet
feet
measured
true vertical
Casing
Conductor
Surface
Production
Size Cemented
Length
Liner
Perforation depth:
measured
true vertical
Approved by
Form 10-401 Rev. 12/1/85.
Development Oil 0
Multiple Zone D
10. Field and Pool
Kuparuk River Field
Meltwater Pool
11. Type Bond (see 20 AAC 25.0251)
Statewide
Number
#59-52-180
9. Approximate spud date Amount
February 11,2002 $200,000
14. Number of acres in property 15. Proposed depth (MD and TVD)
~ ~7 ..i~ 10498' MD 16002 ' TVD
17. Anticipated pressure (see 20 AAC 25.035 (e)(2»
Maximum surface 1940 psig At total depth (TVD) 2550 psig
Setting Depth
Top Bottom Quantity of Cement
MD TVD MD TVD (include stage data)
34' 34' 114' 114' 9 cy High Early
34' 34' 3037' 2396' 310 sx AS III & 220 sx Litecrete
34' 34' 8984' 5270' 470 sx Class G
8984' 5270' 1 0498' 6002' included above
Plugs (measured)
Junk (measured)
Measured depth
True Vertical depth
Alaska Oil & Gas COrlS, Commission
Anchorage
Commissioner
by order of
the commission
Date
c« find--
0 fl. \v. j ~ n L
Submit in triplicate
)
Apr""tion for Permit to Drill, Well 2P-427
Saved: 24-Jan-02
Permit It -Meltwater 2P- 427
Application for Permit to Drill Document
Ml)ximizE
We-II ValUE;
Table of Contents
1. Well Name ...... ... .... ...... ......... ..... .......... ... ........ ... ..... ... ..... ....... ........ ...... ..Ii.... ..... .......... 3
Requirements of 20 AAC 25.005 (f)................. ......... ....... ............. ........... ............... ............ .................... 3
2. Location Sum mary .. ........... ....... ........ ............ ..... ................. ...... .......... ............ ..~...... 3
Requirements of 20 AAC 25.005(c)(2) ....... ......... ....... ............. ..... ..........................'........ ......... ............... 3
Requirements of 20 AAC 25. 050(b ).... ....... ....... ........ .......... .............. ....... ....... ......... .... ........... ................ 3
3. Blowout Prevention Equipment Information ...............................~..................~...... 4
Requirements of 20 AAC 25.005(c)(3) ......... ....... ..... ........... ...................... ......... ...... ......... ............ ......... 4
4. Dri II i ng Hazards Information. .......... .... ....... ...... ..... ....... ... ... ..... ........... ..... ......... ....... 4
Requirements of 20 AAC 25.005 (c)(4) ..................................................................................................4
5. Procedure for Conducting Formation Integrity Tests ........................................... 4
Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4
6. Casi ng and Cementi ng Program ..... ........ ...... ....... .......... ......... ..... ....... ........ .... ........ 4
Requirements of 20 AAC 25.005(c)(6) ...... ............ ............ ........ ....... ................. ..................... ....... ......... 4
7. Diverter System Information .. ..... ............ ..... ... ..... ..... ........... .... ....... ..... ...... .... ..,; ...... 5
Requirements of 20 AAC 25.005(c)(7) ...... ...................... ................. ......... .............. ......................... ...... 5
8. Dri II i ng FI uid Program .... ... ....... .......... ..... .......... ............ ..... ..... ... .......... ... ..... ........... 5
Requirements of 20 AAC 25.005(c)(B) .... ......... .......................... ............. ......... .......................... ............ 5
9. Abnormally Pressured Formation Information...................................................... 6
Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6
10. Seism ic 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
12. Evidence of Bondi ng .. .... ........ ..... ....... ..... ...... .......... ........ ...... ........ ... ....... ... ......... .... 6
Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6
2P-427 PERMIT IT. doc
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13. Proposed Dri II i ng 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. Attachments ... ... ...... ..... ............... ..... ........ ..... ......... .... ........ ...... ..... ..... ..... ........... ...... 7
Attachment 1 Directional Plan..... .... ................................ ..... ................. ....... ........ ........... ...................... 7
Attachment 2 Drilling Hazards Summary.. ....................... ..... .............. ............ ............ ....................... .... 7
Attachment 3 Well Schematic ........... ........ .............. ......... .......... ......... ..... ..... ......... ..... ........................... 7
2P-427 PERMIT IT. doc
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Apr "rion for Permit to Drill, Well 2P-427
. Saved: 24-Jan-02
1. Well Name
Requirements of 20 AAC 25.005 (f)
Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commi:."Sion
under 20 MC 25.040(b). For a well with multiple well branche:.~ each branch must similarly be identified by a unique name and API
number by adding a suffix to the name designated for the well by tbe operator and to the number a:."Signed to the well by the
commission.
The well for which this Application is submitted will be designated as 2P-427.
2. Location Summary
Requirements of 20 AAC 25.005(c)(2)
An applícation for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the
commission and identitied in the application:
(2) a plat identifying the property and the property's owners and showing
(A)the coordinates ot the proposed location ot tbe well at the surface, at the top of eac.;f¡ objective formation and at total depth
referenced to governmental section lines.
(B) the coordinates of the proposed location of the well at the slJIface/ referenced to the state plane coordinate system for this
state as maintained by the National Geodetic Survey in tbe National Oceanic and Atmospheric Administration"
(C) the proposed depth of the well at the top of each object1've formation and at total depth,.
Location at Surface
NGS Coordinates
Northings: 5,868,952.36 Eastings: 443,952.08
924' FNL, 1992' FWL, Sec 17, T8N, R7E, UM
RKB Elevation: 259.0 ft AMSL
Pad Elevation: 224.0 ft AMSL
Location at Mid Point of
Productive Interval
(Bermuda Formation)
NGS Coordinates
Northings: 5,861,843 Eastings: 445,869
2539' FSL, 1341' FEL, Sec 20, T8N, R7E, UM
Measured Depth (RKB feet):
True Vertical Depth (55 feet):
True Vertical Depth (RKB feet):
9771'
5391'
5650'
Location at Total Depth
NGS Coordinates
Northings: 5,861,228.12 Eastings: 446,034.79
1926' FSL, 1173' FEL, Sec 20, T8N, R7E, UM
Measured Depth (RKB feet): 10498'
True Vertical Depth (55 feet): 5743'
True Vertical Depth (RKB feet): 6002'
and
(D) other 1'nformation requ1'red by 20 AAC 25.050{b);
Requirements of 20 AAC 25. 050 (b)
If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) mllst
(1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores wIthin 200
feet of any portion of tbe proposed wel¿~
Please see Attachment 2: Directional Plan
and
(2) for a/I wells wIthin 200 feet of the proposed wellbore
(A) list the names of the operators of those viells¡ to the extent that those names are known or discoverable 1'17 public records¡
and show that each named operator has been furnished a copy of the application by certified mail;" or
(8) state that the applicant is the only affected owner.
The Applicant is the only affected owner.
2P-427 PERMIT IT. doc
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AP"~'}tion for Permit to Drill, Well 2P-427
. Saved: 24-Jan-02
3. Blowout Prevention Equipment Information
Requirements of 20 AAC 25.005(c)(3)
An applicatIon for a PermIt to Drill must be accompanied by ea(:tJ of the following jtem~ except for an item already on file with the
commissIon and Identified in the application:
(3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20
AAC 25.03;~ as applicable/ I
Please refer to Nabors 19E BOP Schematic currently on file with the Commission.
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 dnlling hazard~ including
(A) the maximum downhole pressure that may be encounterect criteria used to deterrmì7e It, and maximum potential surface
pressure based on a methane gradient/
The expected. reservoir pressures in the Bermuda sands. in the 2P pad area vary from 0.44 to 0.46 psi/ft,
or 8.5 to 8.9 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing
operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2j2A.
The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a
methane gradient (0.11) and the vertical depth of the expected top of the Bermuda formation is:
MPSP =(5543 ft)(~ - 0.11 psi/ft)
=1940 psi
Assuming a leak off of 15.9 ppg (0.83 psi/ft) based on open hole LOT results from offset Meltwater
exploration wells, formation breakdown at the surface casing shoe (2396' TVD) can be expected to
occur at 1981 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated
above.
(B) data on potential gas zones/
No potential gas zones have been identified along the planned well path.
and
(C) data concernIng potential causes of hole problems silch as abnormally geo-pressìJred strata/ lost circulation zones~ and zones
that have a propensIty for dIfferential stìcking:
Please see Attachment 3: 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 accvmpanied by each of the following item~ except for an item already on tìle wIth the
commission and identified in the appllc.;¡tion:
(5) a description of the procedure for £.:vnducting formation integríty tests, as required under 20 AAC 25. 030{!);
A formation integrity test will be performed after drilling out below surface in accordance with the Phillips
Alaska LOT j FIT procedure, currently on file with the Commission.
6. Casing and Cementing Program
Requirements of 20 AAC 25.005(c)(6)
An applIcation for a PermIt to Drill must be accompanied by each of the following Item~ except for an item already on file with the
commission and Identified in the applìcat:jon:
(6) a complete proposed casing and cementing program as required by 20 AAC 25.030/ and a description of any slotted linefr pre-
perforated linefr or screen to be instal/eel"
2P-427 PERMIT IT. doc
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Ap. """}tion for Permit to Drill, Well 2P-427
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Casing and Cementing Program
Hole Top Btm
Csg/Tbg Size Weight Length MD/TVD MD/TVD
00 (in) (in) (Ibltt) Grade Connection (tt) (tt) (tt) Cement Program
30 X 16 42 62.5 H-40 Welded 80 34 / 34 114/ 114 9 cy High
Insulated Early
7-5/8 9-7/8 29.7 L-80 STCM 3003 34 / 34 3037 / 2396 310 sx 10.7/
ppg AS3 Lead,
220 sx 12.0/
ppg LiteCrete
Tail
Planned Top of
Cement:
Surface
5 1/2 6-3/4 15.5 L-80 STCM 8950 34 / 34 8984 / 5270 470 sx 15.8 I
ppg Class 'G'
3-1/2 6-3/4 9.3 L-BO EUE, 8rd 1514 8984 / 5270 10498/ 6002 Planned Top of
Mod Cement:
8484' MD
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 item~ except for an Item already on file with the
commission and identified in tile application:
(l) a diagram and description of the diverter ::.ystem as requíred by 20 MC 25 035; unless this requirement is waived by the
commis..tjion under 20 MC 25.035(11)(2);
Please refer to Nabors 19E Diverter Schematic currently on file with the Commission.
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 item~ except for an Item already on fife with the
commis!:>ion and identified in the application:
(8) a drilling fluid prograrn including a diagram and description of the drilling fluid systern as required by 20 MC 25.033;
Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be
built and maintained to the following specifications:
Spud to 7-5/8" Drill Out to Top Bermuda
Surface Casing Top Bermuda To Well TD
Initia/ Value Final Value Initial Value Final Valu~ Initia/ Value Final Va~
Density (ppg) 9.6 9.8 9.4 9.8./ 9.8 9.8
Funnel Viscosity 80 100 50 65 50 65
(seconds)
Yield Point 35 45 10 25 20 30
(cP)
Plastic Viscostiy 13 21 6 14 6 14
(lb1100 sf)
10 second Ge/ 10 15 2 6 4 7
Strength (lb1100 sf)
10 minute Ge/ 15 40 4 8 4 8
Strength (lb1100 sf)
pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5
API Filtrate(cc) <15 <15 <6 <6 8-10 8-10
2P-427 PERMIT IT. doc
Page 5 of 7
C .F. ".' .h.~.,t~ ;~.' ..~, 'V h" ~rinted: 24-Jan-02
r ' ¡ ~ ~'d
;~liUlr ~-
)
APr"ltion for Permit to Drill, Well 2P-427
~ Saved: 24-Jan-02
Please refer to Nabors 19E Fluid System Components currently on file with the Commission.
9. Abnormally Pressured Formation Information
Requirements of 20 AAC 25.005 (c)(9)
An applícation for a Permit to Drill must be accompanied by ea(:17 of the following Items, except for an Item already on file with the
commission and identifled in the application:
(9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as
required by 20 MC 25.033{f)/ /
Not applicable: Application is not for an exploratory øf 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 identifled in the application:
(10) for an exploratory or stratigraphic test well a seismic refraction or reflection analysis as required by 20 MC 25.061(a)/'
Not applicable: Application is not for an exploratory .øf 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 tollowlng Items, except for an ìtem already on file ~1/ith the
commission and identified in the application:
(11) for a well drilled from an off..çhore platform/ mobile bottom-founded structure/ jack-up lig/ or floatìng drilling vessel, an analysIs
of seabed mndJtions as required by 20 MC 25.061(b)/
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 must be accompanied by each of the following Item5~ except for an item already on file with the
commis..çion and identifìed in the applìcation:
(12) evidence showing that the requirements of 20 MC 25.025 {BondJ'ng}have been met'
Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission.
13. Proposed Drilling Program
Requirements of 20 AAC 25.005 (c)(13)
An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the
commission and identífied in the application:
The proposed drilling program is listed below. Please refer as well to Attachment 3: Well
Schematic:
1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +/- 114' RKB.
Weld landing ring on conductor. /'
2. Move in / rig up Nabors 19E. Install diverter & function test same.
3. Spud and directionally drill 9-7/8" hole to 7-5/8" surface casing point (+/- 3037' MD) according to
directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation
data gathering. LWD logs: GR only.
4. Run and cement 7-5/8" 29.7# L-80 STCM casing to surface using ArcticSet 3 lead slurry and
LiteCrete tail to assure cemSAt returns to the surface. Adequate tail cement will be pumped to
ensure cement reaches the surface. Displace cement with mud. /'
5. Nipple down diverter and install wellhead. Nipple up BOPE and test to 3500 psi. Record results.
'"
6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results.
2P-427 PERMIT /T.doc
C rf,~ ,r¡, * fl.J f Page 6 of 7
Ii 11111 \. I- :.rinted: 24-Jan-02
)
Apr"jtion for Permit to Drill, Well 2P-427
Saved: 24-Jan-02
7. Drill out cement anjf"20' minimum to 50' maximum of new hole. Perform formation integrity test not
to exceed 16.0 ppg EMW.
8. Directionally drill 6-3/4" hole to well total depth (+/- 10498' MD) according to directional plan. Run
MWD / LWD logging tools in drill string for directional monitoring and formation data gathering.
Circulate and condition hole. POOH. LWD logs: GR/Res w/ density-neutron through Cairn and
Bermuda intervals
9. Run open hole e-line or 'ill pipe conveyed logs as needed (none planned).
10. Run and cement 5-1/2" 15.5# L-80 BTCM x 3-1/2 9.3# L-80 EUE 8RD tapered production casing
string with Baker casing seal receptacle crossover (CSR). Place CSR +/- 100' above the planned top
perforation.
11. Run and land 3-1/2" tubing with gas-lift mandrels.
12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV.
Install test plug. Pressure test production tree. Pull test plug. Secure well.
13. Freeze protect well. Set BPV. Release rig and turn well over to production.
14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating.
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 mU!:.7C be accompanied by each of the following item~ except for an item already Of} file with the
commls:.c,ion and Identified in the application:
(14) a general descríption 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 AAC 25.080 for an annular disposal operation I'¡)he ~"¡le/!.;
Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P
pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down
the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for
disposal down an approved disposal well.
At the end of drilling operations, a request will be submitted for this well to be permitted for annular
pumping of fluids occurring as a result of future drilling operations on 2P pad.
15. Attachments
Attachment 1 Directional Plan
Attachment 2 Drilling Hazards Summary
Attachment 3 Well Schematic
2P-427 PERMIT IT. doc
Page 7 of 7
0 b..... ... ...:~r¡~;, 'A. F:rinted: 24-Jan-02
i~'U'.ij ...
,--., 1500 -
Q;
<D
-
'--" 2000 -
..c
Ïi
<D 2500 -
0
0 3000 -
0
-+-
L
<D
> 3500 -
<D
:J
L 4000 -
f-
I
V 4500 -
5000 -
5500 -
6000 -
6500
INTv'Q
500 -
0 - ~, RKB Elevatian: 259'
')
Phillips Alaska, Inc.
Structure: Drill Site 2P
Well: 427
Field: Meltwater
Location: North Slope,
164.47 AZIMUTH
7364' (TO TARGET)
...Plane of Proposal'"
1000 -
'" KOP
'" 2.00
'" 6.00
12.0Bouild 3/100
18.00 DLS: 3.00 deg per 100 ft
24.00
Base Permafrost
30.00
36.00
42.00
48'~~.00Base West Sak
60.00
EOC
'1 5/8 CSG
C80
500 -
500
1000
C50
C40
C37
TANGENT ANGLE
61.10 DEG
~
5 1/2 X 3 1/2 Crossaver
1500 2000 2500 3000 3500 4000
4500
T4.1 (Top Cairn)
n.1 (Base Cairn)
n (Tap Bermuda)
T2 (Base B~~r';,gueJa)
C35 (Tap Albion)
TO - Csg pt
::x,
~
5000
5500
6000
6500
7000
7500
8000
8500
Vertical Section (feet) - >
Azimuth 164.47 with reference 0.00 N, 0.00 E from slot #427
0¡ II V\jj"rd..
Creot.d by bmichoel For: S Lowry
Dote plotted: 23-Jon-2002
Plot Reference is 2P-427 Version #1.8.
Coordinates ore in feet reference slot #427.
Vertical Depths ore reference RK8 (Nabors
fi¡miii
BAKER
-
IN'n:!)
1600 -
2000 -
2400 -
2800 -
3200 -
,,--....
-+-
Q)
Q)
'+- 3600 -
'--'
.£:
-+-
:J 4000 -
0
If)
I 4400 -
V
4800 -
')
Phillips Alaska, Inc.
Structure: Drill Site 2P
Well: 427
Field: Meltwater
Location: North Slope, Alaska
East (feet) ->
0
400
800
1200
1600
2000
2400
2800
3200
0 -
SURFACE LOCATION:
924' FNL, 1992' FWL
SEC. 17, T8N, R7E
5200 -
TRUE
400 -
164.47 AZIMUTH
7364' (TO TARGET)
***Plone of Proposal***
800 -
1200 -
~
g
~~~
5600 -
6000 -
6400 -
5 1/2 X 3 1/2 Crossover
14.1 (Top Cairn)
13.1 (Base Cairn)
6800 -
TARGET LOCATION:
2539' FSL, 1341' FEL
SEC. 20, T8N, R7E
7200 -
T2 (Base Bermuda)
7600 -
I TO LOCATION:
1926' FSL, 1173' FEL
SEC. 20, T8N, R7E
C35 (Top Albian)
1 \. TO - CS9 pt
8000 -
3600
)
.r~~
4000
0: 'G NA-
¡Phillips Alaska, Ince /~HI~LI~.
For S Lowry Structure: Drill Site 2P Well: 427
Dote plotted; 23-Jan-2DD2
Plot Reference is 2P-427 Version #1.B. Field: Meltwater Location: North Slope.
Coordinates are in feet reference slot #427.
Vertical Depths ore reference RKB (Nabors 19E).
e¡¡1I
IIflAø
INTF.Q
==== PROF~LE COMMENT DATA ====
Point MO Inc Oir TVO N 0 rt h East V. Sect Oeg/100 ~
----- -----
KOP 300.00 0.00 164.47 300.00 0.00 0.00 0.00 0.00
Build 3/100 800.00 10.00 1 64.4 7 797.4 7 -41.93 11.65 43.52 2.00
Base Permafrost 1 396.1 0 27.88 1 64.4 7 1359.00 -227.61 63.24 236.23 3.00
Base West Sak 2180.94 51.43 1 64.4 7 1959.00 - 706.81 196.37 733.58 3.00
EOC 2503.38 61.10 1 64.4 7 2137.86 -964.86 268.06 1001.40 3.00
5/8 CSG 3036.87 61.10 1 64.4 7 2395.67 ~1414.87 393.09 1468.46 0.00
C80 3136.87 61.10 164.47 2444.00 -1499.22 41 6.52 1556.01 0.00
C50 4277.03 61.10 164.47 2995.00 -2460.98 683.72 2554.20 0.00
C40 4943.34 61.10 164.47 3317.00 -3023.03 839.87 3137.53 0.00
C37 5322.01 61.10 1 64.4 7 3500.00 -3342.45 928.62 3469.05 0.00
5 1/2 X 3 1/2 Crosso 8983.94 61.10 164.47 5269.67 -6431.38 1786.80 6674.98 0.00 '-t'
C) 1 (Top Cairn) 9083.94 61.10 1 64.4 7 5318.00 -6515.73 1810.24 6762.52 0.00
::xJ 1 (Base Cairn) 9222.58 61.10 1 64.4 7 5385.00 -6632.68 1842.73 6883.90 0.00
-
{;:) (Top Bermuda) 9549.52 61.10 1 64.47 5543.00 - 6908.46 1919.35 7170.13 0.00
-- rget 9770.91 61.10 1 64.4 7 5649.99 - 7095.21 1971.23 7363.95 0.00
~
:t:=- (Base Bermuda) 10013.04 61.10 1 64.4 7 5767.00 -7299.45 2027.97 7575.93 0.00
r- C35 (Top Albian) 10323.43 61.10 1 64.47 5917.00 -7561.27 2100.71 7847.66 0.00
"
)
)
Structure: Drill Site 2P
Well: 427
Phillips Alaska, Inc.
Plot Reference is 2P-427 Version #1.8.
Field: Meltwater
Location: North Slope, Alaska
Coordinates ore in feet reference slot '427.
Vertical Depths ore reference RKB (Nabors
I NTI~()
340
TRUE NORTH
~
@O
* 1100
1 0 ~ 1300 œ ~
\?O
, \
30 \
~~.?~, 1300
~ \\
""'J. . ".
*, '. ,
190O.' '.. 320
350
330
210
280
* 2300
~o
'~ 1100
\
50
31
300
60
80
270
90
100
250
.~ 110
24-8.-
8?
120
230
, 130
, '" 1900
220
140
210
150
~
200
160
190
180
170
Normal Plane Travelling Cylinder - Feet
All depths shown ore Measured depths on Reference Well
C : G ~ Þ '.
160 120 80 40
80 - %
40 - '.900
~
- v.fI:,
. '
For: S Lowry
Dote plotted: 2.3-Jan-2002
Plot Reference is 2P-427 Version #1.8.
Coordinates ore in feet reference slot Jj427.
Depths ore reference RKB (Nabors
II
INT~;Q
0 -
, '~.17ee
R:\ ' ',"" 11 00
~ ' 3003o~300
.. 3ü1!J 300 '1'500
.,; 700
40 -
80 -
.. 900
120 - * 1100
160 -
.1300
-::::- 200 -
Q)
Q)
'+-
'--/ 240 - @J
.r::
+-
:J
0 280 -
U1
I
V 320-
360 -
400 -
440 -
480 -
520 -
560 -
600 -
')
)
Phillips Alaska,
~
Inc.
Structure: Drill Site 2P
Well: 427
Field: Meltwater
Location: North Slope,
East (feet) ->
0
80
120
40
160
200
240
280
320
360
400
440
'@
1iJ' ~ '
. 900 .' ""
'3 300 300 .,; ,300 ~,500
. 30. 3ot,3og,3~ 'ÐQpoIWO ..,j;jðò ,
t 700 300 3""-3",," 2900 >. šIJ'[.-.._~._,".,:-~_._~,._.....'Em" 700
300 300 ;300,30<1\ 30'1( 300. . 500 .,.so!;,700 . 0.200 . 900- 11 00 .
\ . ,500 ',500' 500700.,700, ., '\" 3100" -',900 ' ""
\.,. ,700 , '{JOO 700 --. 700 ~
. .. . 70~ ' ""
70&"'00'700 .,700,,900..900 . "', 33"0 """ *1100 '.,1300
, ' .' 100. '.. 0 '., ' .. '
\ ' . , . ..900 ,'" . 90'0".,,900 '" 1100
'700 \ ' ," -., . .. "'-
11011\ '900 -. 1100'''-. 900 ~' '0J
, ,900 ' 11 00'. ,.." \\, '
. \ ,. ' 11 00 ' 900 35"'\" 13oð",110Q
, ' . 900 . . "..," -, . k-.
*900 \ \ ' '," 9,00 '.1100 ., '-..'- 37 \.. .',,"~
, ' ' ",-00 .~
130d' '. \"00 ' ' . 1300 .. , '..----'''.--...". '~
, \1100 ' .' .', .,.,-~
,,, . 1300 ,1306, -. 1100 IJ1g)
\ "
, ..' 11 00
\ '* 11 00 ' '~'" 1 300
\
, 1300
\
\
\
\
\
\
\
\
\
\
\
~ 1500
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\
. 1700
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\
~
+ 1100
,;. 1 500 \
,¡\ 1500
~
.. 1100
\ 1300
;0 1500 '.
'* 1500',
~ 1 ~0f700
\
\
1500
, "" 1300 ~
' "'"
, ó'
"
\
.. 1300',
';0 1300
.1900
\
\
\ 1500
~
.1700
'JIt, 1700
'JIt 1700
* 1500
~
\'¿)
.;. 2100
i
i
\
~ 1700
~. 150~ 1900
~
'" 1500
it 2300
~ 1700
'" 2500
~
œ
00
\ID
~%
) 1:G,,~,-.~
")
For: S Lowry
: 23-Jon-2002
Phillips Alaska,
Depths ore reference RK8 (Nabors
_iiilii
¡wi';i¡--
iiiiikHiiiiS
INT~:Q
Structure: Drill Site 2P
300 200 100 0
400 I @J I
moo
500 - 2300*
600 - 1900'1' 2500t
--....
-+-
Q)
Q)
'+-
'--"
..c
-+-
:::J
0
U1
I
V
1400 -
. 4700
1500 - t 4900
~ 5100
1600 -
.;. 5300
1700 -
'" 5500
1800 - ~ 5700
1900 - ~ 5900
~
2000 -
2100 -
2200 -
2300 -
Field: Meltwater
Location: North Slope, Alaska
Well: 427
East (feet) ->
100
200
300
Inc.
400
500
600
~\ I
~
\
\
\
\
\
\
\
, 1900
\
\
\
\
\
\
\
\
\
\
\
.2100
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\
~ 2300
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\
\ 2500
\
\
\
\
\
\
\
\
\
\
\
\
\
\
~ 2700
\
\
\
\
\
\
\
\
\
\
\
\
\
'~\\) I ~~~'~~
\. '. 1900 ',* 15e019'QO '
1500'
'.2100
+ 2300
* 2500
00
\ 190o"
,
'.21 ÒO
\. ~\ 74:X9 0
, '~ 2500
'. 2700
'.\1900
,'. 2900
, ,
700
I
~,
~
,
,
'.2100
2700.
700 -
2900~
800 - t2100 31 O~ .;. 1900
900 - 330~
. 3500
1000 - ~ 2300
@1 ,). 3700
1100 - . 3900 '* 2100
1200- ~ 4100
'" 4300
1300 -
.;. 4500
" '~
, ~
, 1700'""
\*210~
'*, 1700,
\\230~
\. 31 00
-'
,.3300
~\2100
'. 3500
~
800
~
~
\%
JRIG~^t~
.'
For: S Lowry
: 23-Jcn-2002
ore reference RKB (Nabors
:NTI':Q
\§
~
2100 - \
- 3100,
i
2400 - i
3300+
i
2700 - 3500~
3000 -
3300 -
3600 -
3900 -
4200 -
4500 -
,-....
-+-
Q)
Q)
'+- 4800 -
"--/
...c
-+-
:J 5100-
0
c.n
I 5400 -
V
5700 -
6000 -
6300 -
6600 -
6900 -
7200 -
7500 -
7800 -
8100 -
)
')
Inc.
.I""""----~""'"
{PHILLIPS}
. - .
. .
.
f
~
Phillips Alaska,
Well: 427
Structure: Drill Site 2P
I~ I I I ~~~~~I
~ f>4100
\ ~4300
~2900 '.;
\ 4500Ì'i~500
\ 470d~,
.3100 .
\ 4900*,\ 2700
\ 510~\
\ '
,3300 5300":
\
\ 550d\~, 2900
\ 5700\'
\
\ .,:900
\ ~\. 3100
, 3700
\
\
\
~ 3900
\
\
\
\
.4100
\
\
\
\
~ 4300
\
\
\
\
. 4500
\
\
\
\
,4700
\
\
\
\
. 4900
\
\
\
\
,5100
\
\
\
\
. 5300
\
\
\
\
, 5500
\
\
\
~ 5700
\
,
\
\
, 5900
\
1illJ
600
3700\
\
3900,
4100\
4300~
\
\
00
4500 ~
\
47°°\
4900~
\
i
\
,;. 3900
5100~
t 4100
~ 4300
,:. 4500
.. 4700
.. 4900
~ 5100
.. 5300
* 5500
00
Field: Meltwater
900
\
5300~
\
\
5500~
i
\
\
5700t
i
5900t
Location: North Slope,
East (feet) ->
1200
1500
1800
2100
2400
2700
3000
3300
3600
I I I I I I
~~
'--* ~900', ". '''' 5500
\\ 3500 2900 * 3300 270u' '" ", 41 òO!,5-'QJ(pO
230d" , ",\ '" 2::JQO ' '*" 61 Q~ ~
" '* 37ÒO " *, 3500 2;0~* :~30~
" '3100' , ~
' \~ 3900,* 2700 ,Ý7J
,\ ' , ';1\ 3700 Ý76'
2500.'
'* 41 0'0
, ',* 3300. ,
, "43ÒO ' \I< 290{{ 3900
'. "" .
, \
2700\ '* 4500' '* 350b, ;1\ 4100
'" ';1\ 31ÒO,
'", 4700',
... 3300
'* 4300
\', '. 490~., 370Ò" ~
2900"', . " '\I< 33'(;d
\.. ' "
, ';1\ 5100'
..390~
... ,5300 '\,
3100~.
'.. 3500
'. ,5500~
'. 5700
.. 3700
* 3300
" ~
,~
. 3900
~
~ 4100
j¡,4300
fill]
'.. 4500
~ 4700
'" 4900
'~ 5100
%
0: G NA-
.'
)
Phillips Alaska, Inc.
Drill Site 2P
427
slot #427
Meltwater
North Slope, Alaska
PRO P 0 S ALL 1ST I N G
by
Baker Hughes INTEQ
Your ref: 2P-427 Version #l.B
Our ref: prop4942
License:
Date printed: 23-Jan-2002
Date created: 25-0ct-200l
Last revised: 23-Jan-2002
Field is centred on 441964.235,5869891. 466,999.00000 ,N
Structure is centred on 441964.235,5869891.466,999.00000, N
Slot location is n70 3 9.430,w150 26 54.700
Slot Grid coordinates are N 5868952.362, E 443952.076
Slot local coordinates are 924.02 S 1995.13 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
')
JRIG'NAL
.'
)
')
Phillips Alaska, Inc. PROPOSAL LISTING Page 1
Drill Site 2P, 427 Your ref: 2P-427 Version #1.B
Meltwater,North Slope, Alaska Last revised: 23-Jan-2002
Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert
Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect
0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00
100.00 0.00 164.47 100.00 0.00 N 0.00 E 0.00 0.00
200.00 0.00 164.47 200.00 0.00 N 0.00 E 0.00 0.00
300.00 0.00 164.47 300.00 0.00 N 0.00 E 0.00 0.00 KOP
400.00 2.00 164.47 399.98 1. 68 S 0.47 E 2.00 1. 75
500.00 4.00 164.47 499.84 6.72 S 1.87 E 2.00 6.98
600.00 6.00 164.47 599.45 15.12 S 4.20 E 2.00 15.69
700.00 8.00 164.47 698.70 26.86 S 7.46 E 2.00 27.88
800.00 10.00 164.47 797.47 41. 93 S 11.65 E 2.00 43.52 Build 3/100
866.67 12.00 164.47 862.90 54.19 S 15.06 E 3.00 56.24
966.67 15.00 164.47 960.13 76.68 S 21.30 E 3.00 79.58
1066.67 18.00 164.47 1056.00 104.04 S 28.91 E 3.00 107.98
1166.67 21. 00 164.47 1150.25 136.20 S 37.84 E 3.00 141.36
1266.67 24.00 164.47 1242.63 173.07 S 48.08 E 3.00 179.62
1366.67 27.00 164.47 1332.88 214.54 S 59.61 E 3.00 222.67
1396.10 27.88 164.47 1359.00 227.61 S 63.24 E 3.00 236.23 Base Permafrost
1466.67 30.00 164.47 1420.75 260.51 S 72 .38 E 3.00 270.38
1566.67 33.00 164.47 1506.01 310.85 S 86.36 E 3.00 322.62
1666.67 36.00 164.47 1588.41 365.42 S 101. 52 E 3.00 379.26
1766.67 39.00 164.47 1667.74 424.07 S 11 7 . 82 E 3.00 440.13
1866.67 42.00 164.47 1743.77 486.63 S 135.20 E 3.00 505.06
1966.67 45.00 164.47 1816.30 552.95 S 153 .62 E 3.00 573.89
2066.67 48.00 164.47 1885.12 622.83 S 173.04 E 3.00 646.42
2166.67 51.00 164.47 1950.06 696.09 S 193.39 E 3.00 722.45
2180.94 51. 43 164.47 1959.00 706.81 S 196.37 E 3.00 733.58 Base West Sak
2266.67 54.00 164.47 2010.93 772 .52 S 214.63 E 3.00 801. 78
2366.67 57.00 164.47 2067.56 851. 92 S 236.68 E 3.00 884.18
2466.67 60.00 164.47 2119.81 934.06 S 259.51 E 3.00 969.44
2503.38 61.10 164.47 2137.86 964.86 S 268.06 E 3.00 1001. 40 EOC
3000.00 61.10 164.47 2377.86 1383.77 S 384.45 E 0.00 1436.18
3036.87 61.10 164.47 2395.67 1414.87 S 393.09 E 0.00 1468.46" 5/8 CSG
3136.87 61.10 164.47 2444.00 1499.22 S 416.52 E 0.00 1556.01 C80
3500.00 61.10 164.47 2619.49 1805.54 S 501. 62 E 0.00 1873.92
4000.00 61.10 164.47 2861.12 2227.30 S 618.80 E 0.00 2311.66
4277.03 61.10 164.47 2995.00 2460.98 S 683.72 E 0.00 2554.20 C50
4500.00 61.10 164.47 3102.75 2649.06 S 735.98 E 0.00 2749.40
4943.34 61.10 164.47 3317.00 3023.03 S 839.87 E 0.00 3137.53 C40
5000.00 61.10 164.47 3344.38 3070.82 S 853.15 E 0.00 3187.14
5322.01 61.10 164.47 3500.00 3342.45 S 928.62 E 0.00 3469.05 C37
5500.00 61.10 164.47 3586.01 3492.59 S 970.33 E 0.00 3624.87
6000.00 61.10 164.47 3827.65 3914.35 S 1087.51 E 0.00 4062.61
6500.00 61.10 164.47 4069.28 4336.11 S 1204.68 E 0.00 4500.35
7000.00 61.10 164.47 4310.91 4757.88 S 1321. 86 E 0.00 4938.09
7500.00 61.10 164.47 4552.54 5179.64 S 1439.04 E 0.00 5375.82
8000.00 61.10 164.47 4794.17 5601.40 S 1556.21 E 0.00 5813.56
8500.00 61.10 164.47 5035.80 6023.16 S 1673.39 E 0.00 6251.30
8983.94 61.10 164.47 5269.67 6431.38 S 1786.80 E 0.00 6674.98 5 1/2 X 3 1/2 Crossover
9000.00 61.10 164.47 5277 . 44 6444.93 S 1790.56 E 0.00 6689.04
9083.94 61.10 164.47 5318.00 6515.73 S 1810.24 E 0.00 6762.52 T4.1 (Top Cairn)
9222.58 61.10 164.47 5385.00 6632.68 S 1842.73 E 0.00 6883.90 T3.1 (Base Cairn)
All data is in feet unless otherwise stated.
Coordinates from slot #427 and TVD from RKB (Nabors 19E) (259.00 Ft above mean sea
Bottom hole distance is 8000.87 on azimuth 164.47 degrees from wellhead.
Total Dogleg for wellpath is 61.10 degrees.
Vertical section is from wellhead on azimuth 164.47 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
level) .
J r ~ A ~ " fA L
L,i ... l} I¡ :~ ~
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")
)
Phillips Alaska, Inc.
Drill Site 2P,427
Mel twa ter ,North Slope, Alaska
PROPOSAL LISTING Page 2
Your ref: 2P-427 Version #l.B
Last revised: 23-Jan-2002
Measured Inclin. Azimuth True Vert
Depth Degrees Degrees Depth
RECTANGULAR
COO R DIN ATE S
Dogleg
Deg/lOOft
Vert
Sect
9500.00 61.10 164.47 5519.07 6866.69 S 1907.74 E
9549.52 61.10 164.47 5543 .00 6908.46 S 1919.35 E
9770.91 61.10 164.47 5649.99 7095.21 S 1971.23 E
9770.93 61.10 164.47 5650.00 7095.23 S 1971.24 E
10000.00 61.10 164.47 5760.70 7288.45 S 2024.92 E
10013.04 61.10 164.47 5767.00 7299.45 S 2027.97 E
10323.43 61.10 164.47 5917.00 7561.27 S 2100.71 E
10498.43 61.10 164.47 6001.57 7708.89 S 2141.73 E
0.00
0.00
0.00
0.00
0.00
7126.77
7170.13 T3 (Top Bermuda)
7363.95 Target
7363.97 MW(O) Midpt Tgt Rvsd 12Dec01
7564.51
0.00 7575.93 T2 (Base Bermuda)
0.00 7847.66 C35 (Top Albian)
0.00 8000.87 TD - Csg pt
All data is in feet unless otherwise stated.
Coordinates from slot #427 and TVD from RKB (Nabors 19E) (259.00 Ft above mean sea
Bottom hole distance is 8000.87 on azimuth 164.47 degrees from wellhead.
Total Dogleg for wellpath is 61.10 degrees.
Vertical section is from wellhead on azimuth 164.47 degrees.
Calculation uses the minimum curvature method.
Presented by Baker Hughes INTEQ
level) .
C 1IG,'~AL.
"
')
Phillips Alaska, Inc.
Drill Site 2P
427
slot jl427
Meltwater
North Slope, Alaska
PRO P 0 S ALL I S TIN G
by
Baker Hughes INTEQ
Your ref: 2P-427 Version jll.B
Our ref: prop4942
License:
Date printed: 23-Jan-2002
Date created: 25-0ct-2001
Last revised: 23-Jan-2002
Field is centred on 441964.235,5869891. 466,999.00000, N
Structure is centred on 441964.235,5869891.466,999.00000, N
Slot location is n70 3 9.430, w150 26 54.700
Slot Grid coordinates are N 5868952.362, E 443952.076
Slot local coordinates are 924.02 S 1995.13 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
)
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)
)
Phillips Alaska, Inc. PROP05AL LI5TING Page 1
Drill 5ite 2P, 427 Your ref: 2P-427 Version #l.B
Mel twa ter ,North 5lope, Alaska Last revised: 23-Jan-2002
Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D 5 G E 0 G RAP H I C
Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5
0.00 0.00 0.00 0.00 O.OON O.OOE 443952.08 5868952.36 n70 3 09.43 w150 26 54.70
100.00 0.00 164.47 100.00 O.OON O.OOE 443952.08 5868952.36 n70 3 09.43 w150 26 54.70
200.00 0.00 164.47 200.00 O.OON O.OOE 443952.08 5868952.36 n70 3 09.43 w150 26 54.70
300.00 0.00 164.47 300.00 O.OON O.OOE 443952.08 5868952.36 n70 3 09.43 w150 26 54.70
400.00 2.00 164.47 399.98 1. 685 0.47E 443952.53 5868950.68 n70 3 09.41 w150 26 54.69
500.00 4.00 164.47 499.84 6.725 1.87E 443953.89 5868945.62 n70 3 09.36 w150 26 54.65
600.00 6.00 164.47 599.45 15.125 4.20E 443956.16 5868937.21 n70 3 09.28 w150 26 54,58
700.00 8.00 164.47 698.70 26.865 7.46E 443959.33 5868925.45 n70 3 09.17 w150 26 54.49
800.00 10.00 164.47 797.47 41. 935 11. 65E 443963.41 5868910.34 n70 3 09.02 w150 26 54.36
866.67 12.00 164.47 862.90 54.195 15. 06E 443966.72 5868898.06 n70 3 08.90 w150 26 54.27
966.67 15.00 164.47 960.13 76.685 21.30E 443972.79 5868875.53 n70 3 08.68 w150 26 54.09
1066.67 18.00 164.47 1056.00 104.045 28. 91E 443980.19 5868848.11 n70 3 08.41 w150 26 53.87
1166.67 21. 00 164.47 1150.25 136.205 37. 84E 443988.87 5868815.89 n70 3 08.09 w150 26 53.61
1266.67 24.00 164.47 1242.63 173.075 48. 08E 443998.83 5868778.95 n70 3 07.73 w150 26 53.32
1366.67 27.00 164.47 1332.88 214.545 59. 61E 444010.04 5868737.39 n70 3 07.32 w150 26 52.98
1396.10 27.88 164.47 1359.00 227.615 63.24E 444013 .57 5868724.30 n70 3 07.19 w150 26 52.88
1466.67 30.00 164.47 1420.75 260.515 72 .3 8E 444022.46 5868691.33 n70 3 06.87 w150 26 52.62
1566.67 33.00 164.47 1506.01 310.855 86.36E 444036.06 5868640.89 n70 3 06.37 w150 26 52.21
1666.67 36.00 164.47 1588.41 365.425 101. 52E 444050.80 5868586.22 n70 3 05.84 w150 26 51.78
1766.67 39.00 164.47 1667.74 424.075 117 .82E 444066.65 5868527.45 n70 3 05.26 w150 26 51.31
1866.67 42.00 164.47 1743.77 486.635 135.20E 444083.55 5868464.76 n70 3 04.64 w150 26 50.81
1966.67 45.00 164.47 1816.30 552.955 153.62E 444101. 47 5868398.31 n70 3 03.99 w150 26 50.28
2066.67 48.00 164.47 1885.12 622.835 173 .04E 444120.35 5868328.29 n70 3 03.30 w150 26 49.72
2166.67 51. 00 164.47 1950.06 696.095 193.39E 444140.14 5868254.89 n70 3 02.58 w150 26 49.13
2180.94 51.43 164.47 1959.00 706.815 196.37E 444143.04 5868244.15 n70 3 02.48 w150 26 49.05
2266.67 54.00 164.47 2010.93 772.525 214. 63E 444160.79 5868178.30 n70 3 01. 83 w150 26 48.52
2366.67 57.00 164.47 2067.56 851. 925 236.68E 444182.24 5868098.75 n70 3 01. 05 w150 26 47.89
2466.67 60.00 164.47 2119.81 934.065 259.51E 444204.43 5868016.44 n70 3 00.24 w150 26 47.23
2503.38 61.10 164.47 2137.86 964.865 268.06E 444212.75 5867985.58 n70 2 59.94 w150 26 46.99
3000.00 61.10 164.47 2377.86 1383.775 384.45E 444325.93 5867565.83 n70 2 55.82 w150 26 43.64
3036.87 61.10 164.47 2395.67 1414.875 393.09E 444334.33 5867534.67 n70 2 55.51 w150 26 43.39
3136.87 61.10 164.47 2444.00 1499.225 416.52E 444357.12 5867450.15 n70 2 54.68 w150 26 42.72
3500.00 61.10 164.47 2619.49 1805.545 501.62E 444439.88 5867143.23 n70 2 51. 67 w150 26 40.27
4000.00 61.10 164.47 2861.12 2227.305 618.80E 444553.83 5866720.63 n70 2 47.52 w150 26 36.90
4277.03 61.10 164.47 2995.00 2460.985 683. 72E 444616.96 5866486.48 n70 2 45.22 w150 26 35.03
4500.00 61.10 164.47 3102.75 2649.065 735.98E 444667.78 5866298.02 n70 2 43.37 w150 26 33.53
4943.34 61.10 164.47 3317.00 3023.035 839.87E 444768.81 5865923.31 n70 2 39.70 w150 26 30.54
5000.00 61.10 164.47 3344.38 3070.825 853.15E 444781. 72 5865875.42 n70 2 39.23 w150 26 30.16
5322.01 61.10 164.47 3500.00 3342.455 928. 62E 444855.11 5865603.25 n70 2 36.55 w150 26 27.99
5500.00 61.10 164.47 3586.01 3492.595 970. 33E 444895.67 5865452.82 n70 2 35.08 w150 26 26.79
6000.00 61.10 164.47 3827.65 3914.355 1087. 51E 445009.62 5865030.22 n70 2 30.93 w150 26 23.42
6500.00 61.10 164.47 4069.28 4336.115 1204. 68E 445123.57 5864607.61 n70 2 26.78 w150 26 20.05
7000.00 61.10 164.47 4310.91 4757.885 1321.86E 445237.52 5864185.01 n70 2 22.63 w150 26 16.68
7500.00 61.10 164.47 4552.54 5179.645 1439.04E 445351. 46 5863762.41 n70 2 18.48 w150 26 13 .31
8000.00 61.10 164.47 4794.17 5601.405 1556. 21E 445465.41 5863339.80 n70 2 14.33 w150 26 09.95
8500.00 61.10 164.47 5035.80 6023.168 1673.39E 445579.36 5862917.20 n70 2 10.18 w150 26 06.58
8983.94 61.10 164.47 5269.67 6431.385 1786.80E 445689.65 5862508.17 n70 2 06.17 w150 26 03.32
9000.00 61.10 164.47 5277.44 6444.935 1790.56E 445693.31 5862494.60 n70 2 06.04 w150 26 03.21
9083.94 61.10 164.47 5318.00 6515.735 1810. 24E 445712.44 5862423.65 n70 2 05.34 w150 26 02.65
9222.58 61.10 164.47 5385.00 6632.688 1842. 73E 445744.03 5862306.47 n70 2 04.19 w150 26 01.71
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #427 and TVD from RKB (Nabors 19E) (259.00 Ft above mean sea level).
Bottom hole distance is 8000.87 on azimuth 164.47 degrees from wellhead.
Total Dogleg for wellpath is 61.10 degrees.
Vertical section is from wellhead on azimuth 164.47 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ORIG \A~
)
)
Phillips Alaska, Inc. PROP05AL LI5TING Page 2
Drill 5ite 2P,427 Your ref: 2P-427 Version #1.B
Meltwater ,North 51ope, Alaska Last revised: 23-Jan-2002
Measured Inclin Azimuth True Vert RECTANGULAR G RID COO R D 5 G E 0 G RAP H I C
Depth Degrees Degrees Depth COO R DIN ATE 5 Easting Northing COO R DIN ATE 5
9500.00 61.10 164.47 5519.07 6866.695 1907. 74E 445807.26 5862072.00 n70 2 01. 89 w150 25 59.85
9549.52 61.10 164.47 5543.00 6908.465 1919. 35E 445818.54 5862030.14 n70 2 01. 48 w150 25 59.51
9770.91 61.10 164.47 5649.99 7095.215 1971.23E 445868.99 5861843.02 n70 1 59.64 w150 25 58.02
9770.93 61.10 164.47 5650.00 7095.235 1971. 24E 445869.00 5861843.00 n70 1 59.64 w150 25 58.02
10000.00 61.10 164.47 5760.70 7288.455 2024. 92E 445921.20 5861649.39 n70 1 57.74 w150 25 56.48
10013.04 61.10 164.47 5767.00 7299.455 2027.97E 445924.17 5861638.37 n70 1 57.63 w150 25 56.39
10323.43 61.10 164.47 5917.00 7561.275 2100. 71E 445994.91 5861376.03 n70 1 55.05 w150 25 54.30
10498.43 61.10 164.47 6001. 57 7708.895 2141.73E 446034.79 5861228.12 n70 1 53.60 w150 25 53.13
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from slot #427 and TVD from RKB (Nabors 19E) (259.00 Ft above mean sea level).
Bottom hole distance is 8000.87 on azimuth 164.47 degrees from wellhead.
Total Dogleg for wellpath is 61.10 degrees.
Vertical section is from wellhead on azimuth 164.47 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
],qJG,AAL
')
)
Phillips Alaska, Inc.
Drill Site 2P
427
slot Jl427
Meltwater
North Slope, Alaska
SUMMARY CLEARANCE REPORT
by
Baker Hughes INTEQ
Your ref: 2P-427 Version #l.B
Our ref: prop4942
License:
Date printed: 23-Jan-2002
Date created: 25-0ct-2001
Last revised: 23-Jan-2002
Field is centred on 441964.235,5869891.466,999.00000,N
Structure is centred on 441964.235,5869891.466,999.00000, N
Slot location is n70 3 9.430,w150 26 54.700
Slot Grid coordinates are N 5868952.362, E 443952.076
Slot local coordinates are 924.02 S 1995.13 E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Object wellpath
MWD <0-9224 '>, ,438,Drill Site 2P
MWD <3660 - 1l075'>,,415,Drill Site 2P
MWD <5552 - 9038'>, ,415A,Drill Site 2P
MWD <0-8974' >, ,429, Drill Site 2P
MWD <0 - 6008'>,,417,Drill Site 2P
MWD <0-2040' >, ,448, Drill Site 2P
MWD <754 - 8663'>,,448A,Drill Site 2P
MWD <4000 - 7593'>,,448B,Drill Site 2P
MWD <0-6860' >, ,420, Drill Site 2P
PMSS <0-6122' >, ,MWN#l,Meltwater North #1
PMSS <0-8935' >, ,MWSouth1, Meltwater South #1
PMSS <0-6300 '>, ,MWN#2,Meltwater North #2
PMSS <2212-7349' >, ,MWN#2A, Meltwater North #2
Reference North is True North
Closest approach with 3-D Minimum Distance method
Last revised Distance M.D. Diverging from M.D.
4-Jun-2001 220.1 100.0 100.0
2-Dec-2001 239.8 200.0 200.0
17-Dec-2001 239.8 200.0 200.0
18-Dec-2001 35.9 700.0 700.0
25-May-2001 200.0 0.0 0.0
28-Dec-2001 419.9 0.0 0.0
10-Jan-2002 419.9 0.0 0.0
14-Jan-2002 419.9 0.0 0.0
14-Jan-2002 140.1 100.0 100.0
26-Feb-2001 1923.2 8660.0 8660.0
6-Mar-2001 39231.8 10498.4 10498.4
26-Feb-2001 3030.8 4020.0 4020.0
26-Feb-2001 2961.6 3580.0 3580.0
,
:IGI"\A~
.~
')
)
2p.427 Drillio2 Hazards Summary
(to be posted in Rig Floor Doghouse Prior to Spud)
(See Well Plan for further discussion of these risks)
Surface Casine Interval
Event
Conductor Broach
Well Collision
Risk Level
Low
Low
Gravel and sand sloughing
Low
Stuck Pipe
Low
Permafrost Hydrates
Low
Shoe Fracture/Lost
Returns during cement job
Low
Production Interval
Event
Lost Circulation in
Bermuda interval
High ECD and swabbing
if higher MW is required
Risk Level
High
Low
I Mitigation Strategy
Monitor cellar continuously during interval.
Careful well planning and surveying, adherence
to anti-collision policy
Elevated mud viscosity from spud; Hi dens
sweeps.
Monitor drilling parameters for early signs of a
problem. Use PWD tool to evaluate hole
cleaning efficiency.
Controlled drilling, reduced pump rates, higher
mud weights, cold mix water and mud, lower
viscosities, and lecithin additions as needed
Reduced pump rates, and lightweight tail
cement
Mitigation Strategy
Good drilling practices. LCM as needed. Stay within
ECD Hardline.
Pumping and rotating out on all trips to reduce swab
and barite sag potential.
2P-427 Drilling Hazards Summary. doc
prepared by Scott Lowry
I 01/24/02
J û â G. .. .\. Page 1 of 1
" f ~,i..
Meltwater 2P-427^~)
Proposed Completion Schematic
Slimhole Base Case - 3-1/2" Completion String
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Surface csg. ~
7-5/8" 29.7# L-80 BTCM .tIIIII.
+/- 3037' MD /2396' TVD
30" x 16" 62.6#
(Insulated)
@+1-114'MD
Depths are
based on
Nabors 19E
RKB
12' Pup (Critical)
Intermediate csg.
5-1/2" 15.5# L-80 BTCM
run CSR to surface
+1- 8984' MD / 5270' TVD
Future Peñorations
Production csg
3-1/2" 9.3# L-80 EUE8RD
TD to CSR
+1- 10498' MD 16002' TVD
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PHILLIPS Alaska, Inc.
'~ A Subsidiary of PHILLIPS PETROLEUM COMPANY
3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down
3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required
3-1/2" 9.3# L-80 EUE8RD Tubing to Surface
3-1/2" Camco 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling
pups installed above and below, EUE8RD set at +1- 500' MD
3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple
3-1/2" x 1" Camco 'KBG-2-9' Mandrels wI DV's and RK latch's (Max. OD 4.725", ID
2.90"), IBT box x box, 3-1/2" X 6' L-80 EUE8RD box x IBT pin handling pup installed
above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced
out w/3-1/2" 9.3# L-80 EUE8RD tubing as follows:
GLM # TVD-RKB
MD-RKB
GLM Numbers and Spacing To Be Determined
3-1/2" x 1" Camco 'KBG-2-9' mandrel wI STS-2 shear valve and bottom latch
(Max. aD 4.725", ID 2.90"), IBT box x box, pinned for 3000 psi shear (casing to
tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed
above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below
1 jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Cameo No-Go profile, EUE8RD
box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above
3-1/2" Camco 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RD
handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below
1 jt 3-1/2" 9.3# L-80 EUE8RD tubing
3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80
EUE8RD box up, 3-1/2" X 6' L-80 EUE8RD handling pup installed on top
Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD
Baker 5" aD x 4" ID 17' Seal Bore Extension
CSR set at +/- 100' MD above top perforation
0.:: 'G ^A - SLL 1/21/02
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/22/2002
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
Pre\10US Csg.
< 75/8",29.7#, L-80 grade
BTC, AB Modified
at 3,037 ft. MD
)
Schlumberger
CemL., E Preliminary Job Design
5 1/2" x 3 1/2" Production
Preliminary Job Design based on limited Input data. For estimate purposes only.
Volume Calculations and Cement Systems
(Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above
casing X-over.
Tail Slurrv (minimum thickening time 156 min.)
GasBLOK wf Class G + 053,0600,0135,0800,0047,0065, per lab testing
@ 15.8 ppg, 1.2 fefsk
0.0835 fefft x 500' x 1.75 (75% excess) =
0.1817 ft3fft x (10498' - 8984') x 1.75 (75% excess) =
0.0488 ft3fft x 80' (Shoe Joint) =
73.1 ft3 + 481.4 ft3 + 3.9 ft3 =
558.4 ft3f1.2 ft3fsk =
Round up to 470 sks
73.1 ft3
481.4 ft3
3.9 fe
558.4 ft3
465.3 sks
BHST = 134°F, Estimated BHCT = 115°F.
(BHST calculated using a gradient of 2.2°Ff1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
< 51/2", 15.5#, L-80 grade Stage (bpm) Volume (min) Time
BTC, AB Modified (bbl) (min)
in 6 3/4" OH CW100 6 60 10.0 10.0
MudPUSH XL 6 40 6.7 16.7
Tail Slurry 6 100 16.7 33.4
Drop Top Plug 3.0 36.4
Displacement 6 137 22.8 59.2
Slow Rate 4 80 20.0 79.2
< Top of Tail at Bump Plug 3 9 3.0 82.2
8,484 ft. MD
< X-o\er at 8,984 ft. MD
< Top of Bermuda Fm.
at 9,550 ft. MD
< 3 1/2", 9.3#, L-80 grade
EUE, 8re1 Modified
in 6 3/4" OH
TO at 10,498 ft. MD
(6,002 ft. lVD)
* Mark of Schlumberger
MUD REMOVAL
Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 12.0 ppg MudPUSH* XL, Pv ~ 19-22, Ty ~ 22-29
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
Rig: Doyon 141
Location: Kuparuk (Meltwater)
Client: Phillips Alaska, Inc.
Revision Date: 1/22/2002
Prepared by: Kevin Tanner
Location: Anchorage, AK
Phone: (907) 265-6205
Mobile: (907) 230-6628
email: ktanner@slb.com
< TOC at Surface
Pre\tious Csg.
< 16", 62.6#, H-40 grade
Welded Connection
at 120 ft. MD
< Base of Permafrost
at 1,396 ft. MD
(1,359 ft. TVD)
< Top of Tail at
1,416 ft. MD
< 75/8",29.7#, L-80 grade
BTC, AB Modified
in 9 7/8" OH
lD at 3,037 ft. MD
(2,396 ft. TVD)
* Mark of Schlumberger
E Preliminary Job Design
7 5/8" Surface
Preliminary Job Design based on limited input data. For estimate purposes only.
)
SchluDlbepgep
Volume Calculations and Cement Systems
(Volumes are based on 350% excess in the permafrost and 45% excess below the
permafrost. Top of tail slurry is designed to be 20' below base of permafrost.)
Lead Slurrv (minimum pump time 176 min.)
ASLite @ 10.7 PPg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1,
1.5%D79 - 4.44 ft fsk
0.9513 fefft x (120') x 1.00 (no excess) =
0.2148 ft3fft x (1396' -120') x 4.50 (350% excess) =
0.2148 ft3fft x (1416' -1396') x 1.45 (45% excess) =
114.2 fe + 1233.4 ft3+ 6.2 ft3 =
1353.8 ft3f4.44 ft3fsk =
Round up to 310 sks
114.2 fe
1233.4 ft3
6.2 ft3
1353.8 ft3
304.9 sks
Have 220 sks of additional Lead on location for Top Out stage, if necessary.
Tail Slurrv (minimum pump time 135 min.)
LiteCRETE @ 12.0 ppg - 2.40 fefsk
0.2148 ft3fft x (3037'.... 1416') x 1.45 (45% excess) =
0.2578 ft3fft x 80' (Shoe Joint) =
504.9 ft3 + 20.6 ft3 =
525.5 ft3f2.40 ft3fsk =
Round up to 220 sks
504.9 ft3
20.6 ft3
525.5 ft3
219 sks
BHST = 55°F, Estimated BHCT = 73°F.
(BHST calculated using a gradient of 2.2°Ff1 00 ft. below the permafrost)
PUMP SCHEDULE
Pump Rate Stage Stage Time Cumulative
Stage (bpm) Volume (min) Time
(bbl) (min)
CW100 6 40 6.7 6.7
Drop Bottom Plug 3.0 9.7
MudPUSH XL 6 40 6.7 16.4
Lead Slurry 6 245 40.8 57.2
Tail Slurry 6 94 15.7 72.9
Drop Top Plug 3.0 75.9
Displacement 6 116 19.3 95.2
Bump Plug 3 20 6.7 101.9
MUD REMOVAL
Recommended Mud Properties: 9.6 ppg, Pv < 15, T y < 15. As thin and light as possible
to aid in mud removal during cementing.
Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ~ 17-20, Ty ~ 20-25
Centralizers: Recommend 1 per joint across zones of interest for proper cement
placement.
)
i'
;ffll~Î~I~!~~'
. . ".,' " .. .
. . . ~ . . . "
PAY>'ŠTATËÖF>ALASKA
TO THIB AQGCC >.
:..Qf»D6R}:PF~:».... ..~33::W>'7TH
:".:')'~.:" >.:.
IIANK= ø1/~ :
. --
BANK ONE, NA - 0710
'qH{Q~~?!1 L . ..' .. >. .
.. Paya6fè'lhrough.. .
Republic Bank &'TruslCom'Pany
..' TRACE NUMBER:
.' ;< Pi~¿rrJ
. 111.20.5...0 7"'81111
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO
BEINCLUDEDINTRANSNßTTALLETTER
WELL NAME K£d zf2-yZ 7
CHECK 1
STANDARD LETTER
DEVELOPMENT
.1"'"""/
/'
~
DEVELOPMENT
REDRILL
EXPLORATION
INJECTION WELL
INJECTION WELL
REDRILL
CHECK WHAT APPLIES
ADD-ONS (OPTIONS)
MULTI LATERAL
(If api number last two (2)
digits are between 60-(9)
PILOT HOLE (PH)
ANNULAR DISPOSAL
L-)NO
ANNULAR DISPOSAL
L-.) YES
ANNULAR DISPOSAL
THIS WELL
DISPOSAL IZTO . .THER
ANNULUS
~YFß+
SP ACING EXCEPTION
Templates are located m drive\jody\templates
"CLUE"
The permit is for a new well bore segment of existing well
-----' Permit No, . API No. - '.
Production should continue to be reported as a function of
the original API number stated above. .
In accordance with 20 AAC 25.005(t), all records, data and
logs acquired for' the pilot bole mu'st be clearly
, differentiated in both name (name on permit plus PH)
and API number (50 -70/80) from
records, data and logs acquired for well (na,me on permit).
Annular disposal has not been requested. . .
Annular Disposal of drilling wastes will not be approved. . .
Annular Disposal of drilling wastes will not be approved. . .
Please note that an disposal of fluids generated. '. .
Enclosed is the approved application for permit to drill the
above referenced well. The permit is approved, subject to
full compliance with 20 AAC 25.055. Approval to peñorate
and produce is contingent upon issuance of a conservation
order approving a spacing exception.
(Company Name) will assume tbe liability of any protest to
the spacing exception that may occur.
, ~,e¿¿,
WELL PERMIT CHECKLIST COMPANY ~/~ 5. WELL NAME .2P- <127 PROGRAM: exp - dev ~edr1l- serv - wellbore seg _ann. disposal para req -
FIELD & POOL V90/4Ø INIT CLASS ":l;?EV I CJ/L GEOL AREA GC¡O UNIT# D /1/00 ON/OFF SHORE -D n
ADMI NISTRA TION 1. Permit fee attached. . . . . . . . . . . --. / "/'" ¿ ~. . . . . . J"/' Y N '
2. Lease numberappropriate.~. fi~ ~/n~././t?-. ;:'01 .$v.-('~(:.c-:-IO~,q¡'ê;""YI ~ /lZ>L.373/1Z-; 7'ðP Prød ~vd..ll4-r: þ~
3. Unique well name and number. .. . . . . . . . . . . . . . . . LÁv Ap~ ~=1K"9¿;sl?
4. Well located in a defined pool.. . . . . . . . . . . . . . . . .
5. Well located proper distance from drilling unit boundary. . . .
6. Well located proper distance from other wells.. . . . . . . . .
7. Sufficient acreage available' in drilling unit.. . . . . . . . . . .
8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . .
9. Operator only affected party.. . . . . . . . . . . . . . . . . .
10. Operator has appropriate bond in force. . . . . . . . . . . ..
11. Permit can be issued without conservation order. . . . . . . .
AP~ DAT~ r- __12. Permit ca~.be issued without administrativ~ approval.. . . . .
/~J? 2.. { .D z.-. 13. Can permit be approved before 15-day walt.. . . . . . . . . . Y
, EN~INEERING 14. Conductor string provided .. . . . . . . . ,. . . . . .. . .. ", (ÿ) N ~i (j) 1¡~ . T'" D / " ( .
15. Surface casing proteds all known USDWs. . .. . . . . . . . ;yf4 ~ N . A~ P.sDw~ ,Æ:::.-.>-u,-,>-.o 1À'-/!~/.:h,u4.4Ii~O ~(#ID .zl ) ;'.~6
16. CMT vol adequate to circulate on conductor & surf csg. . . . . N ' '
17. CMT v~1 àdequate to.tie-in long s~ng t~ surf csg. . . . . . .. . ~N ÆdP, ,c¡;,~,' L.1=e '~ut;s ~t p!arL/t..e d , .
18. CMT Will cover all known productive honzons. . . . .'. . . . . N (/
19. Casing designs adequate for C. T. B & permafrost. . . . . . . . N
20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N ¡J.c\'b t1 r' ~ I q E.
21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N All It
22. Adequate well bore separation proposed.. . . . . . . . . . . . &2 N ..
23. If diverter required. does it meet regulations. . . . . . . . . . iN Ai tq ¡¿
24. Drilling .fluid program schematic & equip list adequate. . ~ . . N
25. BOPEs. do they meet regulation. . . . . . . . . . . . . . . . ' N ...¡.~ t t
APP,R. DA)"F 26. BOPE press rating appropriate; test to 35'00 psig. ~ N }Æ PSP :: I c,£/.O rs:(\ ßV PE 'f-€"~ ' f ~SS, fb4' 'e~'t'l¡r;;t,u.. '
VJGfJ< 2../'1(0 z.. '27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N
t(ð9J~I1;;"1 J',,~ 28. Work will occur without operation shutdown. . . . . . . . . . . ~
,tt):: if l tit -U 29. Is presence of H28 gas probable.. . . . . . . . . . . . . . . . Y ~
GEOLOGY, 30. Pennit can be issued w/o hydrogen sulfide measures. .. . -. rY) N.
31. Data presented on potential overpressure zones. . . . . .. . ,tl'--<f ~
, 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . ~fVl \/Ý N
AP.1?R þATE 33. Seabed condition survey ("If off-shore). . . . . . . . . . ~ Y N
.:,J.b z., {, Ö2--.---34. Contact name/phone for weekly progress reports [egl6iatory only] Y N
(,,--
ANNULAR DISPOSAL35. With proper cementing records. this plan.
(A) will contain waste in a suitable receiving zone; . . . . . . .
(B) will not contaminate fréshwater; or cause drilling waste. ..
to surface;" '
(C) will not impair mechanical integrity 9f the well used for disposal; Y N
(D) will not damage producing fonnation or impair recovery from a Y N
pool; and
(E) will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N
GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION:
~Þ8 / ' .- ~6k- WM '8~s ~ (: /02-
r ¿p t~n ~~~ JMH ~tt ::J/5Jcø-
APPR DATE
c:\msoffice\wordian\diana\checklist (rev. 11/01/100)
c
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~~Çcru.L<uf OtIÆ/Iu,<.lav LtsjÎDSt<) W]ílLSf.
Commentsllnstructions:
')
Well H ¡story File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Pennitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simpHty finding information, information of this
nature is accumulated at the end of the file under APPEN,DIX.
No special. effort has been made to chronologically
organize this category of information.
')
)
REC IV D
aOd -0 l <g
'~¿,
**** REEL HEADER ****
LDWG
03/11/03
AWS
01
NOV 122003
Ala8kloa&GaaCoRi.~n
."'...
**** TAPE HEADER ****
LDWG
03/11/05
01
*** LIS COMMENT RECORD ***
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
TAPE HEADER
MELTWATER UNIT
MWD/MADLOGS
#
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
JOB DATA
LDWG File Version 1.000
Extract File: LISTAPE.HED
2P-427
501032040800
Phillips Alaska, Inc.
BAKER HUGHES INTEQ
05-NOV-03
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 1
1
F. WENDLER
R. BOWIE
MWD RUN 2
2
E. AGUIRRE
R. BOWIE
MWD RUN 3
3
S. TUFTON
D. GLADDEN
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
17
8N
7E
254.00
224.00
#
WELL CASING RECORD
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
9.875
6.750
16.000
7.625
120.0
3030.0
10402.0
#
REMARKS:
PER PHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY
CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS
WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED.
INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR
TO DELIVERY FROM THE WELL SITE.
SURFACE LOCATION:
LAT: N 70 DEG 3' 9.434"
LONG: W150 DEG 26' 54.701"
LOG MEASURED FROM D.F. AT 254.0 FT. ABOVE PERM. DATUM
~~~I"'~
. .
(h )L.). )
Per PAI Geoscience request, the fixed depth of invest-
igation resistivity results from INTEQ's post process-
ing routine, MPRTEQ, are included in this LDWG output.
Four fixed depth resistivity curves from MPRTEQ are
presented, RS10 (10" fixed depth), RS20 (20" fixed
depth), RS35 (35" fixed depth), & RS60 (60" fixed
depth resistivity) .
COMMENTS:
(1) Baker Hughes INTEQ run 1 utilized a Gamma Ray with
MAP (Modular Annular Pressure) services from 120 -
3040 feet MD (120 - 2385 TVD).
(2) Baker Hughes INTEQ runs 2 & 3 utilized the slimhole
Advantage Porosity Logging Service (APLS) which
includes the Optimized Rotational Density (ORD),
Caliper Corrected Neutron (CCN), along with AP
(Annular Pressure) and MPRResistivity services from
3040 - 10402 feet MD (2385 - 5854 TVD).
REMARKS:
(1) Depth of 16" Casing Shoe - Driller: 120 feet MD
(120 TVD)
(2) Depth of 7 5/8" Casing Shoe - Logger: 3030 feet MD
(2380 TVD)
Depth of 7 5/8" Casing Shoe - Driller: 3030feet MD
(2380 TVD)
(3) The Neutron Porosity sensor had an intermittent
transmission error. The following intervals are missing
Neutron data:
3861 - 3871 feet MD (2766 - 2771 feet TVD)
4723 - 4820 feet MD (3177 - 3225 feet TVD)
4831 - 4912 feet MD (3230 - 3269 feet TVD)
4974 - 5005 feet MD (3298 - 3313 feet TVD)
5732 - 5800 feet MD (3652 - 3684 feet TVD)
5860 - 5889 feet MD (3713 - 3726 feet TVD)
5939 - 5953 feet MD (3750 - 3756 feet TVD)
6334 - 6351 feet MD (3942 - 3950 feet TVD)
6502 - 6520 feet MD (4029 - 4038 feet TVD)
6745 - 6806 feet MD (4152 - 4182 feet TVD)
7495 - 7565 feet MD (4496 - 4528 feet TVD)
7660 - 7680 feet MD (4571 - 4581 feet TVD)
7683 - 7711 feet MD (4582 - 4595 feet TVD)
7979 - 8044 feet MD (4723 - 4754 feet TVD)
8307 - 8324 feet MD (4879 - 4887 feet TVD)
(4) No formation evaluation data, either real time or
memory, was recorded due to tool system lock-up from
5838 to 5859 feet MD (3702 - 3712 TVD).
(5) Downhole tool memory reached capacity prior to
stopping drilling at 8963 feet MD (5189 TVD) for a BOP
test. Only real time data is available over this
interval. Not all of the presented memory curves are
pulsed to the surface and recorded as real time data.
The following list documents which curves are available
real time and where this real time data was spliced
into the memory data to fill the aforementioned gap:
Gamma Ray (GRAM): 8350 - 8828 feet MD
(4900 - 5127' TVD)
8206 - 8828 feet MD
(4831 - 5127' TVD)
7268 - 8810 feet MD
(4395 - 5118' TVD)
7260 - 8812 feet MD
(4391 - 5119' TVD)
7647 - 8801 feet MD
(4565 - 5114' TVD)
Formation Exposure Time (RPTHM): 8200 - 8965 feet MD
(4828 - 5190' TVD)
(6) The interval from 10350 to 10402 feet MD (5831 -
5854 TVD) was not logged due to sensor-bit offset at
TD.
$
Shallow Resistivity (RPS):
Caliper (CALM):
Bulk Density (BDCM):
Neutron Porosity (NPCKSM):
Tape Subfile: 1
120 records...
Minimum record length:
Maximum record length:
8 bytes
132 bytes
""
)
**** FILE HEADER ****
LDWG .001
1024
*** LIS COMMENT RECORD ***
! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILE001.HED
1
clipped curves; all bit runs merged.
.5000
START DEPTH
120.0
STOP DEPTH
10402.0
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
$
#
MERGED
PBU
MWD
MWD
MWD
$
DATA SOURCE
TOOL CODE
BIT RUN NO MERGE TOP
1 120.0
2 2996.0
2R 8912.0
MERGE BASE
2996.0
8912.0
10402.0
#
REMARKS:
MERGED PASS.
NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH
REFERENCE FOR THIS WELL.
Four fixed depth resistivity curves from MPRTEQ are
presented, RS10 (10" fixed depth), RS20 (20" fixed
depth), RS35 (35" fixed depth), & RS60 (60" fixed
depth resistivity) .
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p427_5.xtf
150
Phillips Alaska, Inc.
2P-427
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GR GR GRAM 0.0
RPD RPD RPD 0.0
RPM RPM RPCSLM 0.0
RPS RPS RPS 0.0
RPX RPX RPCSHM: 0.0
RS10 RSIO RS10 0.0
RS20 RS20 RS20 0.0
RS35 RS35 )RS35 0.0 ')
RS60 RS60 RS60 0.0
RHOB RHOB BDCM 0.0
DRHO DRHO DRHM 0.0
PEF PEF DPEM 0.0
NPHI NPHI NPCKSM 0.0
ROP ROP ROPS 0.0
FET FET RPTH 0.0
MTEM MTEM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 68 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 14
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
16 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 GAP I 4 4
2 RPD MWD 68 1 OHMM 4 4
3 RPM MWD 68 1 OHMM 4 4
4 RPS MWD 68 1 OHMM 4 4
5 RPX MWD 68 1 OHMM 4 4
6 RSI0 TEQ 68 1 OHMM 4 4
7 RS20 TEQ 68 1 OHMM 4 4
8 RS35 TEQ 68 1 OHMM 4 4
9 RS60 TEQ 68 1 OHMM 4 4
10 RHOB MWD 68 1 G/C3 4 4
11 DRHO MWD 68 1 G/C3 4 4
12 PEF MWD 68 1 BN/E 4 4
13 NPHI MWD 68 1 PU-S 4 4
14 ROP MWD 68 1 FPHR 4 4
15 FET MWD 68 1 HR 4 4
16 MTEM MWD 68 1 DEGF 4 4
-------
64
Total Data Records: 1469
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing =
Tape File Depth Units = feet
120.000000
10402.000000
0.500000
**** FILE TRAILER ****
Tape Subfile: 2
1526 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .002
1024
-.
*** LIS COMMENT RECORD ***
! ! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! !
!!!!!!!!!!!!!!!!!!!
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILEOll.HED
2
)
log header data for each bit run in separate files.
1
.2500
START DEPTH
116.0
STOP DEPTH
2996.0
#
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
DIR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
GAMMA RAY
#
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 TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
BIT RUN 1 (MWD Run 1) .
GR-Directional services only.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
ROPS - RATE OF PENETRATION (FPHR)
$
#
*** INFORMATION TABLE: CONS
MNEM VALU
25-APR-02
MSB 18704
6.75 GAM
MEMORY
3040.0
116.0
2996.0
0
0.0
62.0
TOOL NUMBER
DAS 7071
1211
9.875
120.0
Spud Mud
9.60
.0
.0
550
.0
.000
.000
.000
.000
107.0
.0
.0
.0
0.00
.000
.0
0
.
I
---------------------
t-----
)
WDFN
LCC
CN
WN
FN
COUN
STAT
2p427.xtf
150
Phillips Alaska, Inc.
2P-427
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM
ROPS
GRAM
ROPS
GRAM
ROPS
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
84
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units
Size Length
1
2
GRAM MWD
ROPS MWD
68
68
1
1
GAP I
FPHR
4
4
4
4
-------
8
Total Data Records:
138
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing =
Tape File Depth Units = feet
116.000000
2996.000000
0.250000
**** FILE TRAILER ****
Tape Subfile: 3
211 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .003
1024
*** LIS COMMENT RECORD ***
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
FILE HEADER
LDWG File Version 1.000
Extract File: FILE012.HED
~
)
3
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
')
log header data for each bit run in separate files.
2
.2500
START DEPTH
2996.0
STOP DEPTH
8912.0
#
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
DIR
CCN
ORD
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RES IS.
GAMMA RAY
#
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 TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
03-MAY-02
MSB 18704
4.75 SDN
MEMORY
8963.0
2996.0
8912.0
0
58.0
63.0
TOOL NUMBER
DAS 1363
10045227
10045227
MPR 1073
SRIG 2117
6.750
3030.0
LSND
9.80
.0
.0
100
.0
.000
.000
.000
.000
123.0
.0
.0
.0
Sandstone
0.00
.000
.0
0
BIT RUN 2 (MWD Run 2) .
GR/MPR/oRD/cCN.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWD-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
REMARKS:
PE,. )HILLIPS ALASKA (WAYNE CAMPAIGN),)
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM)
FOUR FIXED DEPTH RESISTIVITY CURVES FROM THE MPRTEQ
PROCESSING ARE PRESENTED HERE AS FOLLOWS:
RSI0 - MPRTEQ 10" FIXED DEPTH OF INVEST. RESIS.
RS20 - MPRTEQ 20" FIXED DEPTH OF INVEST. RESIS.
RS35 - MPRTEQ 35" FIXED DEPTH OF INVEST. RESIS.
RS60 - MPRTEQ 60" FIXED DEPTH OF INVEST. RESIS.
$
(OHMM)
(OHMM)
(OHMM)
(OHMM)
#
*** INFORMATION TABLE: CONS
MNEM VALU
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p427.xtf
150
Phillips Alaska, Inc.
2P-427
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM GRAM GRAM 0.0
RPCL RPCL RPD 0.0
RPSL RPSL RPCSLM 0.0
RPCH RPCH RPS 0.0
RPSH RPSH RPCSHM 0.0
RACL RACL RAD 0.0
RASL RASL RACSLM 0.0
RACH RACH RAS 0.0
RASH RASH RACSHM 0.0
RSI0 RSI0 RSI0 0.0
RS20 RS20 RS20 0.0
RS35 RS35 RS35 0.0
RS60 RS60 RS60 0.0
BDCM BDCM BDCM 0.0
DRHM DRHM DRHM 0.0
DPEM DPEM DPEM 0.0
NPCK NPCK NPCKSM 0.0
ROPS ROPS ROPS 0.0
RPTH RPTH RPTHM 0.0
TCDM TCDM TCDM 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 84 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
12
1
FRAME SPACE =
0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
20 Curves:
) ')
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPSL MWD 68 1 OHMM 4 4
4 RPCH MWD 68 1 OHMM 4 4
5 RPSH MWD 68 1 OHMM 4 4
6 RACL MWD 68 1 OHMM 4 4
7 RASL MWD 68 1 OHMM 4 4
8 RACH MWD 68 1 OHMM 4 4
9 RASH MWD 68 1 OHMM 4 4
10 RSI0 TEQ 68 1 OHMM 4 4
11 RS20 TEQ 68 1 OHMM 4 4
12 RS35 TEQ 68 1 OHMM 4 4
13 RS60 TEQ 68 1 OHMM 4 4
14 BDCM MWD 68 1 G/C3 4 4
15 DRHM MWD 68 1 G/C3 4 4
16 DPEM MWD 68 1 BN/E 4 4
17 NPCK MWD 68 1 PU-S 4 4
18 ROPS MWD 68 1 FPHR 4 4
19 RPTH MWD 68 1 MINS 4 4
20 TCDM MWD 68 1 DEGF 4 4
-------
80
Total Data Records: 1973
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing =
Tape File Depth Units = feet
2996.000000
8912.000000
0.250000
**** FILE TRAILER ****
Tape Subfile: 4
2094 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** FILE HEADER ****
LDWG .004
1024
*** LIS COMMENT RECORD ***
! ! ! ! ! ! ! ! ! !! ! ! ! ! ! ! ! !
! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and
BIT RUN NO:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
MWD
$
LDWG File Version 1.000
Extract File: FILE013.HED
4
log header data for each bit run in separate files.
2R
.2500
START DEPTH
8912.0
STOP DEPTH
10402.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
TD DRILLER (FT):
07-MAY-02
MSB 18704
4.75 SDN
MEMORY
10402.0
'"
,
TOP LOG INTER. ) (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG)
MINIMUM ANGLE:
MAXIMUM ANGLE:
8S )0
1040¿~0
0
61. 0
63.0
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DIR
CCN
ORD
MPR
GRAM
$
BOTTOM)
TOOL TYPE
DIRECTIONAL
CAL. COR. NEUTRON
OPT. ROT. DENSITY
MULT. PROP. RESIS.
GAMMA RAY
TOOL NUMBER
DAS 1434
10044706
10044706
MPR 1073
SRIG 2117
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.750
3030.0
#
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 TEMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
LSND
9.80
.0
.0
400
.0
.000
.000
.000
.000
131. 0
.0
.0
.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
Sandstone
0.00
.000
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
.0
0
#
REMARKS:
BIT RUN 2R (MWÐ Run 3) .
GR/MPR/oRD/cCN.
CURVE GLOSSARY:
GRAM - GAMMA RAY APPARENT (MWÐ-API)
RPCL - DEEP PHASE RESISTIVITY (OHMM)
RPSL - MEDIUM PHASE RESISTIVITY (OHMM)
RPCH - SHALLOW PHASE RESISTIVITY (OHMM)
RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM)
BDCM - BULK DENSITY COMPENSATED (G/CC)
DRHM - DENSITY CORRECTION (G/CC)
DPEM - PHOTOELECTRIC CROSS SECTION (B/E)
NPCK - NEUTRON POROSITY, CALIPER & SALINITY
CORRECTED (SANDSTONE PU)
ROPS - RATE OF PENETRATION (FPHR)
RPTH - FORMATION EXPOSURE TIME (MIN)
TCDM - TEMPERATURE (DEGF)
PER PHILLIPS ALASKA (WAYNE CAMPAIGN), THE
FOLLOWING CURVES ARE NOT PRESENTED ON THE
MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR
THE SAKE OF COMPLETENESS:
RACL - DEEP ATTENUATION RESISTIVITY (OHMM)
RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM)
RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM)
RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM)
FOUR FIXED DEPTH RESISTIVITY CURVES FROM THE MPRTEQ
PROCESSING ARE PRESENTED HERE AS FOLLOWS:
RS10 - MPRTEQ 10" FIXED DEPTH OF INVEST. RESIS.
RS20 - MPRTEQ 20" FIXED DEPTH OF INVEST. RESIS.
RS35 - MPRTEQ 35" FIXED DEPTH OF INVEST. RES IS.
RS60 - MPRTEQ 60" FIXED DEPTH OF INVEST. RES IS.
$
(OHMM)
( OHMM)
(OHMM)
(OHMM)
#
*** INFORMATION TABLE: CONS
MNEM VALU
-)
------------------------------
WDFN
LCC
CN
WN
FN
COUN
STAT
2p427.xtf
150
Phillips Alaska, Inc.
2P-427
Meltwater
North Slope
Alaska
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM
ODEP
----------------------------------------------------
GRAM
RPCL
RPSL
RPCH
RPSH
RACL
RASL
RACH
RASH
RSI0
RS20
RS35
RS60
BDCM
DRHM
DPEM
NPCK
ROPS
RPTH
TCDM
GRAM
RPCL
RPSL
RPCH
RPSH
RACL
RASL
RACH
RASH
RSI0
RS20
RS35
RS60
BDCM
DRHM
DPEM
NPCK
ROPS
RPTH
TCDM
GRAM
RPD
RPCSLM
RPS
RPCSHM
RAD
RACSLM
RAS
RACSHM
RSI0
RS20
RS35
RS60
BDCM
DRHM
DPEM
NPCKSM
ROPS
RPTHM
TCDM
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 84 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale units: Feet
Frame spacing: 0.250000
Frame spacing units: [F ]
Number of frames per record is:
One depth per frame (value= 0)
Datum Specification Block Sub-type is:
12
1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
20 Curves:
Name Tool Code Samples Units Size Length
1 GRAM MWD 68 1 GAP I 4 4
2 RPCL MWD 68 1 OHMM 4 4
3 RPSL MWD 68 1 OHMM 4 4
4 RPCH MWD 68 1 OHMM 4 4
5 RPSH MWD 68 1 OHMM 4 4
6 RACL MWD 68 1 OHMM 4 4
7 RASL MWD 68 1 OHMM 4 4
8 RACH MWD 68 1 OHMM 4 4
9 RASH MWD 68 1 OHMM 4 4
10 RSI0 TEQ 68 1 OHMM 4 4
11 RS20 TEQ 68 1 OHMM 4 4
12 RS35 TEQ 68 1 OHMM 4 4
13 RS60 TEQ 68 1 OHMM 4 4
14 BDCM MWD 68 1 G/C3 4 4
15 DRHM MWD 68 1 G/C3 4 4
"'}
16 DPEM MWD 1 BN/E 4 4 )
17 NPCK MWD 68 1 PU-S 4 4
18 ROPS MWD 68 1 FPHR 4 4
19 RPTH MWD 68 1 MINS 4 4
20 TCDM MWD 68 1 DEGF 4 4
-------
80
Total Data Records: 497
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing =
Tape File Depth Units = feet
8912.000000
10402.000000
0.250000
**** FILE TRAILER ****
Tape Subfile: 5
618 records...
Minimum record length:
Maximum record length:
8 bytes
4124 bytes
**** TAPE TRAILER ****
LDWG
03/11/05
01
**** REEL TRAILER ****
LDWG
03/11/03
AWS
01
Tape Subfile: 6
2 records...
Minimum record length:
Maximum record length:
132 bytes
132 bytes
