Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout208-168Kaitlyn Barcelona Hilcorp North Slope, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
E-mail: kaitlyn.barcelona@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal
Received By: Date:
DATE: 10/19/2021
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
MPU B-22A (PTD 208-168)
Perf 09/05/2021
Please include current contact information if different from above.
37'
(6HW
Received By:
10/19/2021
By Abby Bell at 12:54 pm, Oct 19, 2021
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other:
Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 11,903 feet N/A feet
true vertical 6,932 feet 10,526 feet
Effective Depth measured 11,744 feet 10,375'feet
true vertical 6,928 feet 6,846 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.33 / L-80 10,419' 6,870'
Packers and SSSV (type, measured and true vertical depth)
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13.
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Chad Helgeson
Contact Name:
Authorized Title:Operations Manager
Contact Email:
Contact Phone:
1,757
1,006
Water-Bbl
MD
88'
6,349'
11,780'
TVD
88'
measured
true vertical
Packer
Size
N/A
Casing
Conductor
Length
88'
Junk measured
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
80
Representative Daily Average Production or Injection Data
1781,915
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
208-168
50-029-22747-01-00
Plugs
ADL0025518, ADL0047437, & ADL0047438
5. Permit to Drill Number:
MILNE POINT / KUPARUK RIVER OIL
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
321-425
185
Authorized Signature with date:
Authorized Name:
David Haakinson
dhaakinson@hilcorp.com
1,019
MILNE PT UNIT B-22A
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
80
Gas-Mcf
1,014
Casing Pressure Tubing Pressure
1,004
N/A
measured
6,349'
1,508'
Surface
Liner
Oil-Bbl
11,200psi
Production 10,454'
777-8343
13-3/8"
9-5/8"
2-3/8"
4,600'
6,929' 11,780psi
WINJ WAG
Hilcorp Alaska LLC
2. Operator Name
Senior Engineer: Senior Res. Engineer:
Collapse
N/A
2,020psi
Burst
N/A
3,520psi
7" 10,454' 6,888' 7,240psi 5,410psi
Baker 'HB'
Packer TRDP-1A-SSA See Above
1,927 MD / 1,871
TVD
PL
G
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 3:26 pm, Sep 24, 2021
Chad Helgeson (1517)
2021.09.24 08:24:48 -
08'00'
DSR-9/27/21MGR15OCT2021 RBDMS HEW 9/28/2021
Well Name Rig API Number Well Permit Number Start Date End Date
MP B-22A Eline 50-029-21509-02-00 208-168 9/4/2021 9/5/2021
9/3/2021 - Friday
No operations to report.
9/1/2021 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
9/2/2021 - Thursday
No operations to report.
No operations to report.
WELL SHUT IN ON ARRIVAL. Drifted w/ CH/10'x1.69"WB/GPST/1.72" DUMMY GUN, TAG 10462' (perf depths reached).
GR+CCL correlation log, perforate interval 10456'-10446' with Millenium Charges 6 SPF, 60 degree phase. CCL to top shot
offstet: 92" (confirmed all shots fired). Perforate interval 10446'-10436' with Millenium Charges 6 SPF, 60 defree phase. CCL
to top shot offset: 92" (confirmed all shots fired. WELL LEFT SHUT IN ON DEPARTURE, TURNED OVER TO DSO.
9/4/2021 - Saturday
No operations to report.
9/7/2021 - Tuesday
9/5/2021 - Sunday
CONT from 9-4-21 WSR. Perforate interval 10436'-10426' with Millenium Charges 6 SPF, 60 degree phase. CCL to top shot
offset: 92" (confirmed all shots fired). WELL LEFT SHUT IN ON DEPARTURE, TURNED OVER TO DSO to POP.
9/6/2021 - Monday
DATE REV. BY COMMENTS
TREE: 3 1/8" - 5M FMC
w/ 3 1/2“ Otis Quick Union
WELLHEAD: 11“ 5M FMC w/ 3 1/2”
‘H’ BPV profile.
MILNE
P
O
I
N
T
U
N
I
T
WELL
M
P
B
-
2
2
a
API
N
O
:
5
0
-
0
2
9
-
2
1
5
0
9
9 5/8", 36#, K-55
BTRC 6349‘
PERFORATION SUMMARY
Hilcorp Alaska LLC
PBTD
(
F
l
o
a
t
C
o
l
l
a
r
)
7"
2
6
#
S
h
o
e
MPB-22a
10628‘
10729'
Note: The Camco TRDP-1A-SSA was
locked out of service 6/25/00.
#
1“ x 3 1/2” McMurray FMHO w/ BK latch
md tvd dg
7 5243‘ 4041‘ 59
6 6196‘ 4526‘ 61
5 7150‘ 5027‘ 55
4 7945‘ 5482‘ 54
3 8710‘ 5926‘ 55
2 9504‘ 6377‘ 57
1 10332‘ 6824‘ 58
8 4103‘ 3421‘ 57
9 3119‘ 2822‘ 47
10 2199‘ 2111‘ 30
Baker ‘HB’ Packer (2.89“ ID)10375‘
WLEG 10419‘
WLEG (ELMD)
‘
Camco 2.750 ‘D’ nipple
10413‘
Baker ‘PBR’ Seal Assy (3.00“ ID)10360‘
MK-1 5“ 12 10426‘-10456’ Proposed
MK-2 5” 12 10488‘ - 10518’ Abandoned
B Sands
1.56“ 6 11180‘ - 11271’ 6850‘ - 6851’
1.56” 6 11480‘ - 11740‘ 6868’ - 6874‘
Zone Size SPF MD’ TVD’
Fill tagged w/ slickline o
n
2
/
2
7
/
0
8
a
t
1
0
5
3
3
‘
E
L
M
D
13 3/8“, 48#, K-55
BTRC 88‘
Camco TRDP-1A-SSA SCSSV
1927‘
1/11/05 Lee Hulme Convert drawing to Canvas
KOP @ 500'
MAX Hole Angle:
61 DEG @ 6375‘
DRIFT ID: 2.867"
3 1/2" , 9.3#, BTRS, L-80 TUBING
CAPACITY: 0.0087 BBL/FT
7" , 26#, L-80, BTRC Casing
DRIFT ID: 6.151"
CAPACITY w/ tbg: .0264 bpf
Fish:Calculated
t
o
p
o
f
T
C
P
1
0
5
2
6
‘
KB Elev. = 59‘ Nabors 27E
GL Elev. = 36’ Nabors 27E
(DIL Log dated //)
X
Casing RA Tag
10219‘
Note: SPM #1 has a DV w/o a latch.
The latch broke off 5/9/07.
10416
02-27-08 JRP ELMD to WLEG, Updated TD tag
Top of cement tagged @ 10389‘ MD
3 1/2“ Tbg punched @ 10400 - 405’
12/5/08 Lee Hulme Cement plug back for CTD sidetrack
Btm. Unique 2 3/8” Guide Shoe 11780’
3“ Hole TD @ 11903’(~6885‘ tvd)
3 1/2“ Liner Deployment Sleeve
2.250 ID (3“ GS Fish Neck)
10272‘
DRIFT ID: 1.901"
2 3/8" , 4.7#, STL, L-80 Liner
CAPACITY: 0.00387 BBL/FT
12/19/08 Lee Hulme CTD sidetrack & 2 3/8“ Liner install
CTD window cut 10454 - 10458‘
DV
DV
DV
Dome
SO
Dome
DV
Dome
DV
1.56“ 6 10840' - 11010' MD
UPDATE
8/15/2012
8/15/2012 B. Bixby CT Add Perfs
MK-1 5"12 10,426 '- 10456'6,873' - 6,889'
Update 1.56" 6 10,840 - 11,010' MD
8/15/2012
BTD
12 10426‘-10456’ K-1 MK-1 5"12 10,426 '- 10456'6,873' - 6,889'
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?
Will planned perforations require a spacing exception?Yes No
9.Property Designation (Lease Number):10.Field/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD):
11,903'N/A
Casing Collapse
Conductor N/A
Production 2,020psi
Surface 5,410psi
Liner 11,780psi
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
Commission Representative: GINJ Op Shutdown Abandoned
Chad Helgeson Contact Name:
Operations Manager Contact Email:dhaakinson@hilcorp.com
Contact Phone: 777-8343
Date:
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
C.O. 432D
Baker HB Packer and Camco TRDP-1A-SSA 10,375 MD/ 6,846 TVD and 1,927 MD/ 1,871 TVD
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
11,780'2-3/8'1,508'
10,454'
Authorized Signature:
9/12/2021
3-1/2"
Perforation Depth MD (ft):
See Schematic
6,888'
6,929'
6,349'
10,454'
See Schematic
88' 13-3/8"
9-5/8"
7"
6,349'
9.3# / L-80 / BTRS
TVD Burst
10,419'
MD
N/A
11,200psi
3,520psi
7,240psi
4,600'
6,933'1,522 N/A
MILNE POINT / KUPARUK RIVER OIL
88'88'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
DL0025518
208-168
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-21509-02-00
Hilcorp Alaska LLC
MILNE PT UNIT B-22A
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size:
PRESENT WELL CONDITION SUMMARY
Length Size
6,944'11,744'
David Haakinson
COMMISSION USE ONLY
Authorized Name:
ory
Statu
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
By Samantha Carlisle at 6:49 pm, Aug 25, 2021
321-425
Digitally signed by Chad
Helgeson (1517)
DN: cn=Chad Helgeson (1517),
ou=Users
Date: 2021.08.25 15:41:17 -08'00'
Chad Helgeson
(1517)
DSR-8/25/21
SFD 8/26/2021
SFD 8/26/2021
ADL0047437, ADL0047438, A
MGR31AUG21
10-404
dts 8/31/2021
JLC 8/31/2021
Jeremy Price Digitally signed by Jeremy Price
Date: 2021.08.31 17:47:49 -08'00'
RBDMS HEW 9/1/2021
E-line Perforations
Well: MPU B-22A
Date: 08-23-2021
Well Name:MPU B-22A API Number: 50-029-21509-01
Current Status:Producer [ONLINE]Pad:B-Pad
Estimated Start Date:September 12th, 2021 Service Unit:E-line
Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:208-168
First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M)
Second Call Engineer:Ted Kramer
AFE Number:Job Type:Perforating
Current Bottom Hole Pressure:2,085 psi @ 6,781’ TVD SBHP Survey 07/30/18 |5.91 PPG
Maximum Expected BHP:2,200 psi @ 6,781’ TVD Reservoir Pattern Pressure |6.24 PPG
MPSP:1,522 psi Gas Column Gradient (0.1 psi/ft)
MIN ID:1.901” Drift in 2-3/8” Liner
Max Inclination 60° Sail Angle
Max Dogleg: 14°/100ft @ 10,452’ MD
Brief Well Summary:
MPU producer B-22A is a horizontal sidetracked CTD well completed in the Kuparuk B-Sand. The Kuparuk C-
sand was cemented and isolated from production in preparation for the CTD well. The producer has declined
from 600 BOPD post drill in 2008 to 70 BOPD as of current. The reservoir engineer has identified a potential
uplift of 55 BOPD by perforating the C-sand.
Notes Regarding Wellbore Condition
x The well has no known well integrity problems.
x A 10’ x 1.78” dummy gun drift and tag was completed prior to rigging up E-line.
o Tagged 10,459’ MD.
Objective:
x Perforate Kuparuk C-Sand
Brief Procedure
1. RU E-line. PT PCE to 250 psig Low / 2,500 psig High.
2. Obtain Parent Bore GR Log dated January 1986.
3. RIH with GR and CCL and 10’ dummy gun drift. Confirm Bottom perf interval can be reached on e-line.
4. Log up through 10,150’ MD.
5. Contact Geologist John Salsbury for log tie-in correlation run
a. Phone: 907-350-1088
6. RIH with GR and CCL and perf guns
i. Perforating guns are 1.56” OD, 6 SPF, 60° phase Halliburton Millennium Charges
1. Max Swell: 1.76”
2. Use Max 10’ Gun
7. Contact Geologist John Salsbury for review of tie-in prior to perforating.
a. Phone: 907-350-1088
8. Perforate intervals as followed:
Zone Sand Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Length
Kuparuk C ±10,426’ ±10,456 ±7,294’ ±7,317’ ±30’
E-line Perforations
Well: MPU B-22A
Date: 08-23-2021
a. POOH and LD perforating guns.
i. Document condition of fired guns including any damage or un-fired charges
9. RDMO E-line
1. As-Built Schematic
2. Proposed Schematic
DATE REV. BY COMMENTS
TREE:31/8"-5MFMC
w/ 3 1/2“ Otis Quick Union
WELLHEAD: 11“ 5M FMC w/ 3 1/2”
‘H’ BPV profile.
MILNE
P
O
I
N
T
U
N
I
T
WELL
M
P
B
-
2
2
a
API
N
O
:
5
0
-
0
2
9
-
2
1
5
0
9
9 5/8", 36#, K-55
BTRC 6349‘
PERFORATION SUMMARY
Hilcorp Alaska LLC
PBTD
(
F
l
o
a
t
C
o
l
l
a
r
)
7"
2
6
#
S
h
o
e
MPB-22a
10628‘
10729'
Note: The Camco TRDP-1A-SSA was
locked out of service 6/25/00.
#
1“ x 3 1/2” McMurray FMHO w/ BK latch
md tvd dg
7 5243‘ 4041‘ 59
6 6196‘ 4526‘ 61
5 7150‘ 5027‘ 55
4 7945‘ 5482‘ 54
3 8710‘ 5926‘ 55
2 9504‘ 6377‘ 57
1 10332‘ 6824‘ 58
8 4103‘ 3421‘ 57
9 3119‘ 2822‘ 47
10 2199‘ 2111‘ 30
Baker ‘HB’ Packer (2.89“ ID)10375‘
WLEG 10419‘
WLEG (ELMD)
‘
Camco 2.750 ‘D’ nipple
10413‘
Baker ‘PBR’ Seal Assy (3.00“ ID)10360‘
MK-1 5“ 12 10426‘ - 10456’ Abandoned
MK-2 5” 12 10488‘ - 10518’ Abandoned
B Sands
1.56“ 6 11180‘ - 11271’ 6850‘ - 6851’
1.56” 6 11480‘ - 11740‘ 6868’ - 6874‘
Zone Size SPF MD’ TVD’
Fill
t
a
g
g
e
d
w
/
s
l
i
c
k
l
i
n
e
o
n
2
/
2
7
/
0
8
a
t
1
0
5
3
3
‘
E
L
M
D
13 3/8“, 48#, K-55
BTRC 88‘
Camco TRDP-1A-SSA SCSSV
1927‘
1/11/05 Lee Hulme Convert drawing to Canvas
KOP @ 500'
MAX Hole Angle:
61 DEG @ 6375‘
DRIFT ID: 2.867"
3 1/2" , 9.3#, BTRS, L-80 TUBING
CAPACITY: 0.0087 BBL/FT
7" , 26#, L-80, BTRC Casing
DRIFT ID:6.151"
CAPACITY w/ tbg: .0264 bpf
Fish:Calculated
t
o
p
o
f
T
C
P
1
0
5
2
6
‘
KB Elev. = 59‘ Nabors 27E
GL Elev. = 36’ Nabors 27E
(DIL Log dated //)
X
Casing RA Tag
10219‘
Note: SPM #1 has a DV w/o a latch.
The latch broke off 5/9/07.
10416
02-27-08 JRP ELMD to WLEG, Updated TD tag
Top of cement tagged @ 10389‘ MD
3 1/2“ Tbg punched @ 10400 - 405’
12/5/08 Lee Hulme Cement plug back for CTD sidetrack
Btm. Unique 2 3/8” Guide Shoe 11780’
3“ Hole TD @ 11903’(~6885‘ tvd)
3 1/2“ Liner Deployment Sleeve
2.250 ID (3“ GS Fish Neck)
10272‘
DRIFT ID: 1.901"
2 3/8" , 4.7#, STL, L-80 Liner
CAPACITY: 0.00387 BBL/FT
12/19/08 Lee Hulme CTD sidetrack & 2 3/8“ Liner install
CTD window cut 10454 - 10458‘
DV
DV
DV
Dome
SO
Dome
DV
Dome
DV
1.56“ 6 10840' - 11010' MD
UPDATE
8/15/2012
8/15/2012 B. Bixby CT Add Perfs
DATE REV. BY COMMENTS
TREE:31/8"-5MFMC
w/ 3 1/2“ Otis Quick Union
WELLHEAD: 11“ 5M FMC w/ 3 1/2”
‘H’ BPV profile.
MILNE
P
O
I
N
T
U
N
I
T
WELL
M
P
B
-
2
2
a
API
N
O
:
5
0
-
0
2
9
-
2
1
5
0
9
9 5/8", 36#, K-55
BTRC 6349‘
PERFORATION SUMMARY
Hilcorp Alaska LLC
PBTD
(
F
l
o
a
t
C
o
l
l
a
r
)
7"
2
6
#
S
h
o
e
MPB-22a
10628‘
10729'
Note: The Camco TRDP-1A-SSA was
locked out of service 6/25/00.
#
1“ x 3 1/2” McMurray FMHO w/ BK latch
md tvd dg
7 5243‘ 4041‘ 59
6 6196‘ 4526‘ 61
5 7150‘ 5027‘ 55
4 7945‘ 5482‘ 54
3 8710‘ 5926‘ 55
2 9504‘ 6377‘ 57
1 10332‘ 6824‘ 58
8 4103‘ 3421‘ 57
9 3119‘ 2822‘ 47
10 2199‘ 2111‘ 30
Baker ‘HB’ Packer (2.89“ ID)10375‘
WLEG 10419‘
WLEG (ELMD)
‘
Camco 2.750 ‘D’ nipple
10413‘
Baker ‘PBR’ Seal Assy (3.00“ ID)10360‘
MK-1 5“ 12 10426‘-10456’ Proposed
MK-2 5” 12 10488‘ - 10518’ Abandoned
B Sands
1.56“ 6 11180‘ - 11271’ 6850‘ - 6851’
1.56” 6 11480‘ - 11740‘ 6868’ - 6874‘
Zone Size SPF MD’ TVD’
Fill
t
a
g
g
e
d
w
/
s
l
i
c
k
l
i
n
e
o
n
2
/
2
7
/
0
8
a
t
1
0
5
3
3
‘
E
L
M
D
13 3/8“, 48#, K-55
BTRC 88‘
Camco TRDP-1A-SSA SCSSV
1927‘
1/11/05 Lee Hulme Convert drawing to Canvas
KOP @ 500'
MAX Hole Angle:
61 DEG @ 6375‘
DRIFT ID: 2.867"
3 1/2" , 9.3#, BTRS, L-80 TUBING
CAPACITY: 0.0087 BBL/FT
7" , 26#, L-80, BTRC Casing
DRIFT ID: 6.151"
CAPACITY w/ tbg: .0264 bpf
Fish:Calculated
t
o
p
o
f
T
C
P
1
0
5
2
6
‘
KB Elev. = 59‘ Nabors 27E
GL Elev. = 36’ Nabors 27E
(DIL Log dated //)
X
Casing RA Tag
10219‘
Note: SPM #1 has a DV w/o a latch.
The latch broke off 5/9/07.
10416
02-27-08 JRP ELMD to WLEG, Updated TD tag
Top of cement tagged @ 10389‘ MD
3 1/2“ Tbg punched @ 10400 - 405’
12/5/08 Lee Hulme Cement plug back for CTD sidetrack
Btm. Unique 2 3/8” Guide Shoe 11780’
3“ Hole TD @ 11903’(~6885‘ tvd)
3 1/2“ Liner Deployment Sleeve
2.250 ID (3“ GS Fish Neck)
10272‘
DRIFT ID: 1.901"
2 3/8" , 4.7#, STL, L-80 Liner
CAPACITY: 0.00387 BBL/FT
12/19/08 Lee Hulme CTD sidetrack & 2 3/8“ Liner install
CTD window cut 10454 - 10458‘
DV
DV
DV
Dome
SO
Dome
DV
Dome
DV
1.56“ 6 10840' - 11010' MD
UPDATE
8/15/2012
8/15/2012 B. Bixby CT Add Perfs
I ECEIV
STATE OF ALASKA
AIL OIL AND GAS CONSERVATION COM SION SE P 1 0 2012
REPORT OF SUNDRY WELL OPERATIONS Alaska 0;1 e Gay C :ns C1o2rnmissio�
1. Operations Abandon [] Repair Well Q Plug Perforations Q Perforate el Other ❑evichorage
Performed: Alter Casing 0 Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension 0
Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑
2. Operator 4. Well Class Before Work: 5. Permit to Drill Number:
BP Exploration (Alaska), Inc
Name: Development 0 Exploratory ❑ ° 208 -168 -0
3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number:
Anchorage, AK 99519-6612 504'29-21509-02-00
7. Property Designation (Lease Number): 8. Well Name and Number:
ADL0025518 r MPB -22A
9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s):
To Be Submitted MILNE POINT, KUPARUK RIVER OIL
11. Present Well Condition Summary:
Total Depth measured 11903 feet Plugs measured None feet
true vertical 6944.01 feet Junk measured None feet
Effective Depth measured 11744 feet Packer measured 10375 feet
true vertical 6932.84 feet true vertical 6846.51 feet
Casing Length Size MD TVD Burst Collapse
Structural None None None None None None
Conductor 87 13 -3/8" 48# K -55 23 - 110 23 - 110 0 0
Surface 6327 9 -5/8" 36# K -55 22 - 6349 22 - 4600.34 3520 2020
Intermediate None None None None None None
Production 10433 7" 26# L -80 21 - 10454 21 - 6887.45 7240 5410
Liner None None None None None None
Perforation depth Measured depth See Attachment feet SCANNED MAR 0 1 2013
True Vertical depth See Attachment feet
Tubing (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 20 - 10458 20 - 6889.38
Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker HB Packei 10375 6846.51 Packer
None None None SSSV
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
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: 121 564 891 0 152
Subsequent to operation: 123 555 830 0 194
14. Attachments: 15. Well Class after work:
Copies of Logs and Surveys Run Exploratory ❑ Development Q - Service ❑ Stratigraphic ❑
Daily Report of Well Operations X 16. Well Status after work: Oil , el Gas ❑ WDSPL U
GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035
Printed Name Nit. Summed ye Title Petrotechnical Data Technician
Signatu�� / �, 6F , ` = Phone 564 -4035 Date 9/7/2012
Fo b'Fvis'1000201 n r n' ( �ir Submit 4411 0 R�G1NAL al►v,
•
•
Perforation Attachment
ADL0025518
Pert
Opera Meas Meas
Operation tion Depth Depth TVD Depth TVD Depth
SW Name Date Code Top Base Top Base
MPB -22A 8/14/12 APF 10840 11010 6923.82 6914.24
MPB -22A 12/24/08 PER 11180 11271 6849.59 6852.88
MPB -22A 12/24/08 PER 11480 11740 6868.03 6873.85
AB ABANDONED MIR REMOVED
APF ADD PERF MIS MECHANICAL ISOLATED
BPP PULLED MLK MECHANICAL LEAK
BRIDGE OPEN
BPS PLUG SET OH HOLE
FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED
FIL FILL STO STRADDLE PACK, OPEN
SQF SQUEEZE FAILED SPS SAND PLUG SET
SQZ SQUEEZE SL SLOTTED LINER
PER PERF SPR SAND PLUG REMOVED
RPF REPERF
Casing / Tubing Attachment
ADL0025518
Casing Length Size MD TVD Burst Collapse
CONDUCTOR 87 13 -3/8" 48# K -55 23 - 110 23 - 110
PRODUCTION 10433 7" 26# L -80 21 - 10454 21 - 6887.45 7240 5410
SURFACE 6327 9 -5/8" 36# K -55 22 - 6349 22 - 4600.34 3520 2020
TUBING 10438 3 -1/2" 9.3# L -80 20 - 10458 20 - 6889.38 10160 10530
•
•
•
Daily Report of Well Operations
ADL0025518
ACTIVITYDATE I SUMMARY
rY ell . 01 ... �, prepe prep
RIH W/ 20' X 1.79" BARBELL SET UP AS DUMMY PERF GUN.
7/31/2012 """ CONTINUE ON 8 -1 -12 * **
* ** CONTINUED FROM 7 -3 -12 * ** (pre perf prep)
RAN 20' X 1.79" BARBELL SET UP AS DUMMY PERF GUN.S /D @ 10438' SLM.UNABLE TO GET
ANY DEEPER.
8/1/2012 * ** WELL LEFT S/I ON DEPARTURE * **
CTU 8, 1.5" coil. Job Scope: Add Perfs
8/12/2012 MIRU CTU.
CTU 8, 1.5" coil. Job Scope: Add Perfs
MIRU CTU. N/U BOPE. M/U 1.5" CTC and pull test, 10K, OK. M/U 1.75" JSN drift and cleanout
BHA, PT lube. RIH with JSN BHA: CTC 1.5 x 0.25', Checks 1.5 x 1.0', XO 1.7 x .38', Stinger 1.75
x 3.5', Stinger 1.75 x 2.9', JSN 1.75 x .58'. BHA OAL = 8.62'. Tag fill at 11730'. start pooh. * *job
8/12/2012 continued on WSR 08- 13 -12 **
Continued fro WSR 08 -12 -12 CTU 8 w/ 1.5" CT. Scope; adperfs.
Finish pooh. RIH w/ 1.5" ctc, 1.7" dfcv, disco, 1.67" crossover, 1.5" crossover, 1.5" KJ, 1 11/16"
memory GR, CCL (oal=10.99') Stop @ 11250' puh and flag pipe at 11200', cont. log 40 fpm to
10400' .pooh. PJSM. Lay out PDS tools. Good data. Add 14' to flag depth. PT MHA. PJSM. M/U
30' of SWS 1.56" pert guns. RIH. Correct to flag depth. Circ ball and Perforate 10980 - 11010'.
POH. All shots fired. RIH with 30' gun #2. Correct to flag. Circ ball and perforate 10950- 10980'.
POH. All shots fired. RIH with gun # 3. Tie in and perforate 10920 - 10950'. start pooh.. * *job
8/13/2012 continued on WSR 08- 14 -12 **
Continued from WSR 08 -13 -12 CTU 8 w/ 1.5" CT. Scope; adperfs
Pooh w/ gun# 3. all shots fired. RIH w/ BHA; 1.5" ctc, 1.7" dfcv, disco, 1.67" crossover, 1.5"
crossover, 1.5" KJ, 1 11/16" memory GR, CCL (oat= 10.99'). Log up from 11100'. Flag coil at
11000'. Log up to 10200' for jewelry log. POH. Lay out PDS tools. Correction, add 12.5' to flag
depth. PJSM. M/U 30' of SWS 1.56" perf guns. PT lube. RIH with perf guns. Correct to flag depth.
Pull up and perforate 10890-10920'. POH. PJSM. All shots fired. M/U 30' Gun #5 BHA. PT lube.
RIH with 30' Gun #5. Correct to flag depth. Pull up and perforate 10860 - 10890', POH. PJSM. All
shots fired. M/U 20' Gun #6 BHA. PT lube. RIH with 20' Gun #6. Correct to flag depth. Pull up and
perforate 10840 - 10860'. POH. All shots fired.
TOTAL PERFORATED INTERVAL: 1 - 11010', 1.56 ", PJ charges loaded at 6 SPF.
8/14/2012 * *job continued on WSR 08- 15 -12 **
Continued from WSR 08 -14 -12 CTU 8 w/ 1.5" CT Scope: adperfs
8/15/2012 pooh with gun # 6 all shots fired. R.D. * *job complete **
FLUIDS PUMPED
BBLS
49 50/50 METH
43 1% XS KCL
110 2% KCL SLICK
202 TOTAL
TREE: 31/8 " -5M FMC MPB -22a
w/ 3 1/2' Otis Quick Union KB Elev. = 59' Nabors 27E
GL Elev. = 36' Nabors 27E
WELLHEAD: 11" 5M FMC w/ 3 1/2"
'H' BPV profile.
Camco TRDP -1 A -SSA SCSSV 1927'
13 3/8 ", 48 #, K -55 88`
BTRC
Note: The Camco TRDP -1 A -SSA was
Dorn r locked out of service 6/25/00.
9 5/8 ", 36 #, K -55 6349' , DV p ,
BTRC 1" x 3 1/2" McMurray FMHO w/ BK latch
KOP @ 500' come 111 # and tvd dg
MAX Hole Angle:
61 DEG @ 6375' 10 2199' 2111 30
3 1/2" , 9.3#, BTRS, L-80 TUBING
Dome 9 3119' 2822' 47
DRIFT ID: 2.86T' 8 4103' 3421' 57
CAPACITY: 0.0087 BBUFT SO 111 7 5243' 4041' 59
2 3/8" , 4.7 #, STL, L-80 Liner 6 6196' 4526' 61
DRIFT ID: 1.901" DV t
CAPACITY: 0.00387 BBUFT 5 7150' 5027' 55
. Dv ! 4 7945' 5482' 54
7" , 26#, L -80, BTRC Casing
DRIFT ID: 6.151" 3 8710 5926' 55
CAPACITY w/ thq:.0264 bpf DV 1 2 9504' 6377' 57
Casing RA Tag 10219' 1 10332' 6824' 58
DV p
3 1/2" Liner Deployment Sleeve 1 10272' X -- s
2.250 ID (3" GS Fish Neck) Note: SPM #1 has a DV w/o a latch.
The latch broke off 5/9/07.
Baker `PBR' Seal Assy (3.00" ID) 1 10360'
_._..__.� Baker `HB' Packer (2.89" ID) 1 10375'
Top of cement tagged @ 10389' MD
Camco 2.750 'D' nipple 10413'
3 1/2" Tbg punched c 10400 • 'A/LEG 1 10419`
VVLEG (ELMD) 10416
CTD window cut 10454 - 10458' = 111/4\411111111 3" Hole TD @ 11903' ( -6885' tvd)
PERFORATION SUMMARY •
(DIL Log dated 1.1) Btm. Unique 2 3/8" Guide Shoe 11780'
Zone Size SPF MD' TVD'
' j Fiil fagged W/ slickline on 2/27/08 at 10533' ELMD
MK -1 5" 12 10426' - 10456 Aoanaoneo O Fish:Calculated top of TCP 10526'
MK -2 5" 12 10488' - 10518' Abandoned o .
B Sands , ,
1.56' 6 11180' - 11271' 6850' - 6851' 10628`
1.56" 6 11480' - 11740' 6868' - 6874' PBTD (Float Collar)
7" 26 # Shoe 10729'1
UPDATE
9/15/2012 1 6 10840' - 11010' MD
DATE REV. BY COMMENTS MILNE POINT UNIT
1/11/05 Lee Hulme Convert drawing to Canvas WELL MPB - 22a
02 -27 -08 JRP ELMD to WLEG, Updated TD tag API NO: 50 - 029 - 21509
12/5/08 Lee Hulme Cement plug back for CTD sidetrack
12/19/08 Lee Hulme CTD sidetrack & 2 3/8" Liner install
BP EXPLORATION (AK)
8/15/2012 B. Bixby CT Add Perfs
DATA SUBMITTAL COMPLIANCE REPORT
711/2010
Permit to Drill 2081680 Well Name/No. MILNE PT UNIT KR B-22A Operator BP EXPLORATION (ALASK/~ INC API No. 50-029-21509-02-00
MD 11903 TVD 6944 Completion Date 12/24/2008 Completion Status 1-OIL Current Status 1-OIL UIC N
REQUIRED INFORMATION
Mud Log No Samples No Directional Survey Yes
DATA INFORMATION
Types Electric or Other Logs Run: MWD DIR / GR / RES, GR /CCL (data taken from Logs Portion of Master Well Data Maint
Well Log Information:
Log/ Electr
Data Digital Dataset Log Log Run Interval OH /
type meairrrm i~uniuc~ game aca~G mGU~a no afar[ atop ~.n r~ecervea a.ommenr
jzD C Las 17589 Survey -Misc 0 10018 Case 2/20/2009 Depth, Spin, GR, Temp,
I CCL, Pres
~
J ~Co
g Survey -Misc 2 Col 0 10010 Case 2/20/2009 GLS, MPL, Pres, GR, CCL,
Temp, ILS, CFJ 23-Jan-
i 2009
ED C Pds ~ 17745 Cement Evaluation 9978 11698 Case 3/20/2009 Mem SCMT, Temp, PSP,
GR, CCL, Pres, CBL 23-
Dec-2009
I
og Cement Evaluation 5 Col 9978 11698 Case 3/20/2009 Mem SCMT, Temp, PSP,
GR, CCL, Pres, CBL 23-
Dec-2009
~
~ ~
rED C Las 17868 ~amma Ray 9976 11749 Case 4/14/2009 GR, CCL
D C Las 17869 ~uction/Resistivity 10355 11903 Open 4/14/2009 P61 RPM, GR, RAD, ROP,
RAM, RPD CCL
*
"`
C . Lis 47971 Gamma Ray 9975 11700 Case 5!4/2009 LIS Veri, GR, CCL
REDO
~
~ Rpt LIS Verification 10355 11903 Open 6/3/2009 PB 1 LIS Veri, GR, ROP, ~
RAD, RAS, RPD, RPS
C Lis 18087 Lkfduction/Resistivity 10355 11903 Open 6/3/2009 PB 1 LIS Veri, GR, ROP,
RAD, RAS, RPD, RPS
Log / Induction/Resistivity 25 Col 10379 11903 Open 6/3/2009 PB 1 MD MPR, GR
Log ~ Induction/Resistivity 5 Col 10379 11903 Open 6/3/2009 PB 1 TVD MPR, GR
Log ~ Gamma Ray 25 Col 10379 11903 Open 6/3/2009 PB 1 MD GR i
•
DATA SUBMITTAL COMPLIANCE REPORT
7/1/2010
Permit to Drill 2081680 Well Name/No. MILNE PT UNIT KR B-22A Operator BP EXPLORATION (ALASKA INC API No. 50-029-21509-02-00
MD 11903 TVD 6944 Completion Date 12/24/2008 Completion Status 1-OIL Current Status 1-OIL UIC N
Rpt ~~ LIS Verification 10284 11901 Open 6/18/2009 LIS Veri, GR, ROP, RAD, ~
RAS, RPD, RPS
D C Lis 18184 ~uction/Resistivity 10284 11901 Open 6/18/2009 LIS Veri, GR, ROP, RAD,
RAS, RPD, RPS
Log ~ Induction/Resistivity 25 Col 10440 11903 Open 6/18/2009 MD MPR, GR ~
/ I
Log`s Induction/Resistivity 5 Col 10440 11903 Open 6/18/2009 TVD MPR, GR
Log ~ Gamma Ray 25 Col 10440 11903 Open 6/18/2009 MD GR
~ Log See Notes 2 Col 10440 11903 Open 6/18/2009 Depth Shift Monitor Plot
D Asc Directional Survey 10423 11903 Open 1!30/2009
Plp
t Directional Survey 10423 11903 Open 1/30/2009
/
ED D Asc Directional Survey 10423 11903 Open 1/30/2009 PB 1
/' Directional Survey
---- - 10423
- 11903
- Open 1/30/2009 PB 1
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORM~~ON
Well Cored? Y N ' Daily History Received? ~N
Chips Received? '4`i-P~~ Formation Tops ~ N
Analysis ~...r,~~.~--
Received?
Comments:
Compliance Reviewed By:
Date: ~ `~' ~
r1
U
INTEQ Log & Data Transmittal Form
To: State of Alaska -AOGCC
333 W. 7~" Ave.
Suite 100
Anchorage, Alaska 99501
Attention: Christine Mahnken
Reference: MPB-22A
Contains the following:
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
1 color print - GR Directional Measured Depth Log (to follow)
1 color print - MPR/Directional TVD Log (to follow)
1 color print - MPR/Directional Measured Depth Log (to follow)
LAC Job#: 2345303
~o~ -~~~ >~ 1~~
Sent by: Catrina Guidry Date: 06/1
Received by ~ Date• JUN 1 8 2009
~ t~, ~ Gas Cons. com.m,ssion
PLEASE ACKNOWLEDGE RECEIPT BY SIGNI®~~~2ETURNING
OR FAXING YOUR COPY
FAX: (907) 267-6623
~ ~.~
~~ INES
1 N"t'L:(1
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska 99518
Direct: (907) 267-6612
FAX: (907) 267-6623
//~~
BAKER
HV6HE5
Baker Atlas
PRINT DISTRIBUTION LIST
CUMYANY BY EXYLURA'f1UN (ALASKA)1NC CUUN'fY NUK'1'H SLUYE BURUU(iH
WELL NAME MPB-22A STATE ALASKA
FIELD MILNE POINT UNIT DATE 6/17/2009
THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY
SO #: 2345303
Copies of Copies Digital Copies of Copies Digi[el
Each Log of Film Data Each Log of Film Data
2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS
Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS
Address LR2-1 Address 550 WEST 7TH AVE
900 E BENSON BLVD. SUITE 802
ANCHORAGE AK 99508 ANCHORAGE AK 99501
1 Company STATE OF ALASKA - AOGCC Company
Person CHRISTINE MAHNKEN Person
Address 333 W. 7TH AVE Address
SUITE 100
ANCHORAGE. AK 99501
Company Company
Person Person
Address Address
Company Company
Person Person
Address Address
Company Company
Person Person
Address Address
Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073
This Distribution List Completed By:
Page 1 of 1
//®®
BAKER
M V6NES
CUMYANY
WELL NAME
FIELD
•
Baker Atlas
PRINT DISTRIBUTION LIST
BY EXYLUKA'1'IUN (ALASKA) INC CUUN'I'Y NUR"1'H SLUPE BUKUUGH
MPB-22APB1 STATE ALASKA
MII,NF, POINT iJNIT DATE 5/28/2009
THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY
SO #: 2345303
Copies of Copies Digital Copies of Copi~c Digital
Each Log of Film Data Each Log of Film Data
2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS
Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS
Address LR2-1 Address 550 WEST 7TH AVE
900 E BENSON BLVD. SUITE 802
ANCHORAGE, AK 99508 ANCHORAGE AK 99501
1 Company STATE OF ALASKA - AOGCC Company
Person CHRISTINE MAHNKEN Person
Address 333 W. 7TH AVE Address
SUITE 100
ANCHORAGE, AK 99501
Company Company
Person Person
Address Address
Company Company
Person Person
Address Address
Company Company
Person Person
Address Address , .
Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 `
This Distribution List Completed Bv: ~~jsSjpB
s6ta Coil Cis s. °
R~~ch®raQ~
~~~1~~
Page 1 of 1
~ •
INTEQ Log & Data Transmittal Form
To: State of Alaska -AOGCC
333 W. 7th Ave.
Suite 100
Anchorage, Alaska 99501
Attention: Christine Mahnken
Reference: MPB-22APB1
Contains the following:
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
1 color print - GR Directional Measured Depth Log (to follow)
1 color print - MPR/Directional TVD Log (to follow)
1 color print - MPR/Directional Measured Depth Log (to follow)
LAC Job#: 2345303
Sent by: Catrina Guidry Date:
Received by: Date: JUi~ 0 3 ZOG9
p~ issinn
PLEASE ACKNOWLEDGE RECEIPT Bs(~li~o~ RETURNING
OR FAXING YOUR COPY
FAX: (907) 267-6623
~~~
INTEQ
Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska 99518
Direct: (907) 267-6612
FAX: (907) 267-6623
~~' ` ~~
`0~~~
05/26/09
~~
Sc~~e~g
N0.5242
Alaska Data & Consulting Services Company: State of Alaska
2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-2838 Attn: Christine Mahnken
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
wPu .to6 # Loa Descriotion Date BL Cobr CD
4-04A/T-30 BOCV-00014 CH EDIT PDCL-GR (SCMT) - j 04/27/09 1
4-02/0-28 AYKP-00019 RST 05/07/09 1 1
H-198 B2WY-00004 MCNL 7/09 1 1
18-266 62ND-00001 MCNL - 04/14/09 1 1
J-20B AXED-00020 MCNL ~ 04/12/09 1 1
W-06A AZCM-00021 RST ~ .- L 05/16/09 1 1
15-15C BOOR-00004 MCNL ~ 03/15/09 1 1
14-31 BOCV-000015 RST - / ~ 05/15/09 1 1
E-056 09AKA0035 OH MWD/LWD EDIT 04/06/09 2 1
06-14B 09AKA0031 OH MWD/LWD EDIT 03/27/09 2 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1 ~,~
900 E. Benson Blvd. ~, „ ~ ~ ~'~"
Anchorage, Alaska 99508 `'
Date Delivered: 6 ~ ~ ® .~ ~~Q~
Alaska Data & Consulting Services
2525 Gambell Street, Suite
Anchorage, AK 9 3-28
ATTN: Beth
Received by:
X15 fit t~ ~~. ~~rn~mi~giotr
`~ ~~ch~r~~~
oai27ios
r
schro~~~~~r
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
WPII .Inh 8
NO.
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
1 n.. nesw ..F:.. n.•.
F-45A AP3O-00033 RST GRAVEL PACK LOG 04/17/09 1
P2-07 AVYO-00023
_
PRODUCTION PROFILE 04/05/09 1 1
11-12 AYQO-00019 USIT L -
~ 04/19/09 1 1
X-OS AYTO-00010 USIT Q/~ 04/03/09 1 1
X-01 AZ4D-00012 PRODUCTION PROFILE - d 03/18/09 1 1
Z-21A AP3O-00022 RST 02/24/09 1 1
E-34L1 AYTU-00010 OH LDWG EDIT (IFLEX) 02/08/09 1 1
L-106 22026 OH LDWG EDIT (REDO) 01/10/02 1
MPF-96 09AKA0039 OH MWD/LWD EDIT ~ 02/23/09 2 1
F-19A 40018664 OH MWD/LWD EDIT - 02/14/09 2 1
F-18A 09AKA0034 OH MWD/LWD EDIT 03/16/09 2 1
06-23C 12066550 MCNL ~ 09/14/08 1 1
03-14B BIJJ-00005 MCNL 03/30/09 1 1
11-18 BOCV-00006 RST --1~ 1 03/02/09 1 1
07-20B AWJB-00028 MCNL ~ 02/27/09 1 1
MPB-22A AXED-00005 CH EDIT PDC-GR (CBL) 12/23/08 1
07-29D AXBD-00016 MCNL '~ ~ C5 03/17/09 1 1
09-33A AWJI-00019 MCNL - 04/01/09 1 1
. .. ~.-.vim.-.v.~.~v ~~.-.-vaT~ .i~va-.r 1 vl JIVIIY IIY~.I MIYV nGl VI'11YIIYl7 VIYC lrVr'i CNli l"1 1 V:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2830
ATTN: Beth
Received by:
- ~.
'~.:.
~- h
•
Date 03-13-2009
Transmittal IVumber:93049
BPXA WELL DATA TRANSMITTAL
Enclosed are the materials listed below.
(BPXA FIELD LOG DATA)
If you have anv questions. please contact Douglas Dortch at the PDC at 564-4973
Delivery Contents
1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells:
MPB-22A
MPB-22APB.1
THIS DATA REPLACES PREVIOUSLY DELIVERED DATA MISSING API NUMBERS
Please Sign and~eturn one copy of this transmittal.
Thank You,
Douglas Dortch - -
~-
Petrotechnical Data Center
Attn: State of Alaska - AOGCC _ -
Attn: Christine Mahnken
333 W. 7th Ave, Suite 100
Anchorage, Alaska 99501
~ ~ _~
r'` ,~ ~ ~ ~, ~,
f .,--Z ~ ~ =-,r
Petrotechnical Data Center LR2-1
900 E. Benson Blvd. PO Box 196612
Anchorage, AK 99519-6612
03/18/09
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
N0.5133
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
wPu _~~ti ~
~,p~~ a
~5~,l~ ~~-~~`d`
t ,.
~ y ~...-.
1 °~f~e 1/~~bV~
°'~~ ~~ ^'
~~ ~ ~
,~,
.w
~ .,,.
J-27A
AY3J-00010 -- ----
CBL - /
02/21/09 VV.VI
1 VY
t
S-107 AWJB-26 MEM L L lJ ~ 'a- 02/25/09 1 1
09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1
V-210 AWJB-00025 INJECTION PROFILE 02/23/09 1 1
MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE . ~' 12/23/08 1 1
V-219 12103700 USIT (REVISION #2) . ~ ( 11/21/08 1 1
11-18 BOCV-00006 PRODUCTION LOG / - G/ 03/02/09 1 1
B-25 AVYS-00023 USIT - / ~-" /~ 03/06/09 1 1
N-18A AYKP-00013 PRODUCTION LOG O$- 1'~-S /. - 03/11/09 1 1
F-18 AVY5-00022 USIT ( ~- "~^ _ ' j- ' - 03/04/09 1 1
3-19/R-28 AZ4D-00009 LDL ( ~ 03/06/09 1 1
V-117 BOOR-00003 MEM PRODUCTION PROFILE ~O - ( ~ 03/12/09 1 1
V-211 AY3J-00014 IPROF/RST WFL - ~ 03/16/09 1 1
V-214 AY3J-00013 (PROF/RST WFL - L 03/15/09 1 1
K-O6B AWJI-00017 MCNL ~ 01/28/09 1 1
L5-15 12113027 RST ~ /O ~ / • f 12/09/08 1 1
07-18 12071915 RST ~j 12/01/08 1 1
15-15C AWJI-00015 MCNL '" ~ / 01/02/09 1 1
W-218 40018337 OH MWD/LWD EDIT
- `12!07/08 2 1
R-41 40018496 OH MWD/LWD EDIT ~/ j
( 01/04/09 2 1
H-18 11999064 RST / - t 0 ~- .12/03/08 1 1
~~ ~
. -_. __-.__._..-..___~.~..~~~.. ................ .-..... ..~. v..,.u~aa vnc vvr. ~n..n ~v.
BP Exploration (Alaska) Inc. Alaska Data & Consulting Services
Petrotechnical Data Center LR2-1 2525 Gambell t t ,. 0
r
900 E. Benson Blvd. Anchorage AK -, 88 # "` ~ F r_:
Anchorage, Alaska 99508 ATTN: Beth
Date Delivered: Received by: ~c i~ ~ ~~f`il
~ 3~~~1- ;5 ~ Copy, r~~tt~~d 3~a~o~
Page 1 of 1
Saltmarsh, Arthur C (DOA}
From: Hubble, Terrie L [Terrie.Hubble@bp.com]
Sent: Tuesday, February 24, 2009 10:45 AM
To: Saltmarsh, Arthur C (DOA)
Subject: Correction: MPB-22A, PTD # 208-168
Attachments: MPB-22A 10-407, 01-20-09.pdf
H i Art,
An error on the Completion Report for this well-has been identified. The API number (suffix) is
incorrect. I have made the correction on our copies.
Reported As: 50-029-21509-01-00
Should Have Been: 50-029-21509-02-00
Thanks,
Terrie
2/24/2009
r
V ~~~~ L
TJ~,411/~MI1°~~4L
~~
ProActive Diagnostic Services, Inc.
To: AOGCC
Christine Mahnken
333 W. 7th Ave
Suite 100
Anchorage, Alaska 99501
[907] 793-1225
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT~
The technical data listed below is being submitted herewith. Lease acknowledge receipt by returning
a signed copy of this transmittal letter to the fallowing
BP Ez~loration (Alaska), Inc.
Petratechnical Data Center
Attn: Joe Lastufka
LR2-1
900 Benson Blvd.
Anchorage, Alaska 99508
and
ProActn~e Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Suite C
Anchorage, AK 99518
Fa>C (907j 245,6952
1 ] Gas Lift Survey 23,Jan-09 MPB-22A
2] * *Corrected API #*
_ ;~ ~;
Signed . .~ ~~ ~~ ~ ' ~,~- .
Print Name:
/~~~ 9
Color Log / EDE 501-029-21509-02
~~
~ ~' ~
~~., y --
~; yn,
3'R'~ ~~ ~ ~~~
)Jets I ~°~° d
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAX: (907)245-88952
EaMA1L : ~r~s~e:~3a~~~lge anslleala®rbl®el.ctsrrra WEBSITE : °+vavvw.~tsrncar~l~g.~.m
C:1Documenti; and Settings\Owner\Desktap\Transmi[ BP.docx
•
//%
BsAKER
1~!lGNES
~~~
7260 Homer Drive
Anchorage, AK 99518
To Whom It May Concern: January 30, 2009
Please find enclosed directional survey data for the following wells:
MPB-22APB1 ~ ~ ~ _ C ~~
MPB-22A
MPC-43L1
MPC-43L1-Ol
Enclosed for each well is:
tea copies of directional survey reports
1 ea 3.5" floppy diskette containing electronic survey files
Please sign and return one copy of this transmittal form to:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
to acknowledge receipt of this data.
RECEIVED BY: ~~~ ,State of Alaska AOGCC
DATE: ~ b d nom. ~id`~ q
Cc: State of Alaska, AOGCC
02-x$ -«B
o~
\~~~1
ALAS~IL AND GAS CONSERVATION COMIOiISSION RG~~~~~~~9
WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,JqN 2 0 2009
1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended
zoAAC zs.~os zoAAC zs.»o
^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. 'of Completions One I
®Develo~al9~li Or~~xploratory
^ Service ^ Strati raphic
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Date Comp., S p., or AbarLd„~
1 008 ~ 12. Permit to Drill Number
208-168
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded
12/9/2008 13. API Number ~
50-029-21509-0 -00
4a. Location of Well (Governmental Section):
Surface:
' 7. Date T.D. Reached
12/20/2008 14. Well Name and Number:
MPB-22A
FWL, SEC. 18, T13N, R11E, UM
183' FSL, 1066
Top of Productive Horizon:
1095' FNL, 1814' FEL, SEC. 25, T13N, R10E, UM
8. KB (ft above MSL); 59'
Ground (ft MSL):
15. Field /Pool(s):
Milne Point Unit / Kuparuk River
Total Depth:
1457' FNL, 2798' FEL, SEC. 25, T13N, R10E, UM 9. Plug Back Depth (MD+TVD)
11744' 6933' Sands
4b. Location of Well (State Base Plane Coordinates, NAD 27):
Surface: x- 572144 y- 6023308 Zone- ASP4 10. Total Depth (MD+TVD)
11903' 6944' 16. Property Designation:
ADL 025518
TPI: x- 569327 y- 6016724 Zone- ASP4
- 6016353 Zone- ASP4
th: x- 568346
T
t
l D 11. SSSV Depth (MD+TVD)
1927' 1871' 17. Land Use Permit:
y
o
a
ep
18. Directional Survey ®Yes ^ No
mi le r ni n rin inform r 19. Water depth, if offshore
N/A ft MSL 20. Thickness of Permafrost (TVD):
1800 (Approx.)
21. Logs Obtained (List all logs here and submit electronic and printed information er 20 AAC 25.071):
MWD DIR / GR / RES, GR / CCL ~.//NDOf/~ 10, ~D 6 ~~~?S'77~d
22. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT
WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED
1 - / " 4 g , ,
1 _ " 1750 sx Permafrost'E', 300 sx Class'G'
7" rf -1 300 sx Class 'G', 60 Bbls Arctic Pack
23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD
If Yes, list each i
P
f T
8
B
tt
MD+TVD nterval open
nd N
mb
r):
f
ti
Si SSE DEPTH SET MD PACKER .SET MD
er
ora
on
ze a
u
e
~
o
om;
(
o
op
6 spf
56" Gun Diameter
1 3-1/2", 9.2#, L-80 10419' 10375'
,
.
MD TVD MD TVD
11180' - 11271' 6909' - 6912'
11740' 6927'
6933'
11480' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
-
- DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED
2750' Freeze Protected w/ McOH
26. PRODUCTION TEST
Date First Production:
January 10, 2009 Method of Operation (Flowing, Gas Lift, etc.):
Flowin
Date Of Test:
1/10/2009 HOUrS Tested:
6 PRODUCTION FOR
TEST PERIOD OIL-BBL:
2(j$ GAS-MCF:
93 WATER-BBL:
28 CHOKE SIZE: GAS-OIL RATIO:
346
Ftow Tubing
Press. 325 Casing Press:
1,008 CALCULATED
24-HOUR RATE • OIL-BBL:
1,071 GAS-MCF:
370 WATER-BBL:
110 OIL GRAVITY-API (CORK):
24
27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No
If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water
(submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071.
None :~ ~'~ ~Lt~ ~~ t~ tQQ~ ~' - ` Q
`lam s ;
Form 10-407 Revised 02/2007
CONTINUED ON REVERSE SIDE
.~~~~' ~
~J
2S.` GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS
NAME MD TVD Well Tested? ^ Yes ®No
Permafrost Top If yes, list intervals and formations tested, briefly summarizing test
results. Attach separate sheets to this form, if needed, and submit
Permafrost Base detailed test information per 20 AAC 25.071.
Kuparuk B 10460' 6890' None
Kuparuk B 10493' 6903'
Kuparuk B 10546' 6914'
Formation at Total Depth (Name):
Kuparuk B 10546' 6914'
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~~/
Signed Terrie Hubble Title Drilling Technologist Date
MPB-22A 208-188 Prepared ByNameMumt~er. TerrieHubb/e,564-4628
Well Number Drilling Engineer: Greg Sarber, 564-4330
I
INSTRUCTIONS
GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a
well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.
IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection,
Observation, or Other. Multiple completion is defined as a well producing ftom more than one pool with production from each pool completely
segregated. Each segregated pool is a completion.
IreM 4b: TPI (Top of Producing Interval).
IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28.
IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
IreM 23: If this well is completed for separate production from more than one interval (mutiple wmpletion), 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).
IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain).
IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical
laboratory information required by 20 AAC 25.07E
IreM 29: 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.
Form 10-407 Revised 02/2007 Submit Original Only
BP EXPLORATION Page 1 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
i
Date From - To Hours Task Code NPT Phase Description of Operations
12/4/2008 20:00 - 20:15 0.25 MOB P PRE PJSM on pulling off well.
20:15 - 20:45 0.50 MOB P PRE Pull rig off of well, turn around for driving off pad.
20:45 - 21:00 0.25 MOB P PRE PJSM with Security and rig crew on rig move.
21:00 - 00:00 3.00 MOB P PRE Leave Y pad for MPB-22 via,
Y pad access road to GC2, to GC2 access road, to spine road,
to Milne Pt. Rd, to MPU B Pad.
12/5/2008 00:00 - 06:00 6.00 MOB P PRE Continue to move rig down Spine Road towards MPU.
Near L pad access ~ crew change
06:00 - 06:30 0.50 MOB P PRE Crew change out. Make rounds.
06:30 - 16:00 9.50 MOB P PRE Continue rig move. Approximately 15 miles of 30 mile move at
0700 hrs (15 miles in 9 hrs)
16:00 - 18:00 2.00 MOB P PRE Arive ~ B pad.
Standby for ATP meeting.
18:00 - 19:00 1.00 MOB P PRE ATP meeting with both crews.
19:00 - 19:20 0.33 MOB P PRE Crew change, walk arounds, and PJSM for moving SLB
injector.
19:20 - 20:00 0.67 MOB P PRE Move SLB injector off to side of rig floor from where the chains
were changed to be able to PU the BOP's
20:00 - 20:10 0.17 MOB P PRE PJSM - on PU and secure of BOP's with blocks.
20:10 - 20:30 0.33 MOB P PRE PU and secure BOP's
20:30 - 20:40 0.17 MOB P PRE PJSM - on spotting rig over well.
20:40 - 22:30 1.83 MOB P PRE Move rig over well. Rig spotted at about 40 deg angle to well
rows in order to be able to spot trailer under reel house to load
coil.
Ri acce ted ~ 22:30
22:30 - 00:00 1.50 MOB P PRE Continue to ready rig. ND tree cap and NU BOP's
12/6/2008 00:00 - 06:00 6.00 MOB P PRE Continue to NU BOP's, change out BOP rams, and ready rig.
06:00 - 06:30 0.50 MOB P PRE Crew change. Make rounds. Discuss plan forward.
06:30 - 15:00 8.50 BOPSU P PRE Test BOPe as era roved well I n AOGCC regs, and PTD
#208-168.
Record all data electronically and on AOGCC test form. E-mail
test form to AOGCC. Test witness waived by J. Crisp,
AOGCC.
Continue to rig up equipment. Re-spot office trailer. Rig up
flow back tank and line.
Lower 2" combis leaking. Replace same. Found damaged
ram body.
Complete test.
15:00 - 18:00 3.00 RIGU P PRE Hold PJSM. RU DSM lubric for II "
RD lubricator.
18:00 - 18:30 0.50 RIGU P PRE Crew change and PJSM
18:30 - 20:20 1.83 RIGU P PRE Clean up rig floor from SLB chain change, assemble Injector
Head, RU to stab pipe, PU tools and motors.
20:20 - 20:45 0.42 RIGU P PRE PJSM for stabing pipe.
20:45 - 22:05 1.33 RIGU P PRE Pull test grapple, retighten. Pull pipe over and stab in to
injector.
OC wire. 1200 Mohms, 49 Ohms.
MU 3 ft lubricator.
22:05 - 23:15 1.17 RIGU P PRE Reverse in water.
23:15 - 23:50 0.58 BOPSU P PRE Pressure test Pack off and outer most inner reel valve.
23:50 - 00:00 0.17 RIGU P PRE Pump slack management
12/7/2008 00:00 - 00:15 0.25 RIGU P PRE Continue to pump slack management.
00:15 - 00:25 0.17 RIGU P PRE PJSM for cutting coil.
rnrnea: voicvva i is ia:ov nm
BP EXPLORATION Page 2 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours Task I Code NPT Phase Description of Operations
__ ._ _ --
12/7/2008 00:25 - 01:35 1.17 RIGU I P PRE RU and cut coil.
01:35 - 02:45 1.171 STMILL P W EXIT
02:45 - 02:55 0.17 STMILL P WEXIT
02:55 - 03:45 0.83 STMILL P WEXIT
03:45 - 06:30 2.75 STMILL P WEXIT
06:30 - 10:30 ~ 4.00 ~ STMILL
(n~P~'2
10:30 - 15:30 5.001 STMILL P i WEXIT
15:30 - 16:15 0.75 STMILL P WEXIT
16:15 - 18:10 1.92 STMILL P WEXIT
18:10 - 19:00 0.83 STMILL P WEXIT
19:00 - 19:40 0.67 STMILL N SFAL WEXIT
19:40 - 21:30 1.831 STMILL N SFAL W EXIT
21:30 - 21:40 0.17 STMILL N SFAL WEXIT
21:40 - 22:05 0.42 STMILL N SFAL WEXIT
22:05 - 22:25 0.33 STMILL P WEXIT
22:25 - 00:00 1.58 STMILL P WEXIT
12/8/2008 00:00 - 00:45 0.75 STMILL P WEXIT
00:45 - 01:15 0.50 STMILL P WEXIT
01:15 - 01:29 0.231 STMILL i P i WEXIT
01:29 - 06:00 I 4.521 STMILL I P I I WEXIT
Cut 61.5 ft of coil.
QC Eline 1230 Mohms, 48 ohms.
RD CT Cutter.
Install SLB CTC -pull test to 35,000 #'s
Install BHI Upper Quick Connect.
Test connection - +2000 Mohms, 54 Ohms.
Press Test to 3,500 psi.
PJSM-PU milling BHA.
PU -Milling BHA #1
RIH with milling BHA. EDC open, pumping min rate and returns
to tiger tank.
Tag cement at 10385'.
Log tbg RA tag at 10,330'.
Log GR across DIL log interval from 9450' to 9550'. subtract 8'
correction.
Log GR again across tbg RA tag. Did not see RA this pass.
Log CCL from 10,000' to TOC at 10,379' (corrected) Found
GLM # 1 at 10,317' and HB packer on original completion
depth of 10,375'. -14' correction from tbg punch log.
Mill cement from 10379'.
3100 psi fs at 1.49 bpm in/out. 100-200 psi mtr work. 1.5k#
dhwob.
TF: 180 deg. ROP: 20-25 fph.
Frequent stalling. Cement is hard. ROP slowed to 10 fph.
CHange TF to HS at 10,445'.
Mill to 10,452'. Note increased mtr work and some reactive
torque.
Back ream with HS tool face into tbg tail.
Pull out of hole.
PJSM on LD BHA while POOH
LD Milling BHA #1 and PU window milling BHA #2
BHA will not pass through well head. Attempted to grind off
wear pad but way to hard.
Wait on Weatherford to bring out 2.5 fixed bend motor with no
wear pad.
SLB-used the time to off load old injector chains.
Nordic-RU slick line unit for pressure deployments.
PJSM-PU of tools.
PU -New window millina BHA #2 with 2.5 deg fixed bend motor
with no wear pad.
Stab on injector, run final test on BHA.
RIH with EDC open.
Continue RIH
Log for CCL tie in from 10,225 ft to 10,389 ft.
-8 ft correction
RIH and dry Tag ~ 10,451 ft.
PU to 10,441 ft.
Turn on pumps while setting back down with Q=1.5 bpm Tag
PU to 10,449.4 ft and flag pipe
Mill window following BP RP/Well plan schedule.
Qp=1.46/1.47 bpm ~ 2930 psi
Printed: 1/5/2009 11:19:54 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: MPB-22
Page 3 of 17 ~
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name:. NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
I
Date From:- To Hours Task Code NPT Phase ! Description of Operations
12/8/2008 01:29 - 06:00 4.52 STMILL P WEXIT DPRESX=520 psi
No indication of WOB until 10,450.11 ft DH WOB=0.07#'s
~ 10,450.5 ft DH W0B=0.52#'s
Mill to 10,451.0'
06:00 - 08:30 2.50 STMILL P WEXIT Crew change.
Continue to mill ahead from 10,451'.
2990 psi fs at 1.51 bpm in/out.
Continue to following time milling schedule.
08:30 - 10:00 1.50 STMILL P WEXIT Note WOB begining to fall off at 10,452.9'.
2990 psi fs at 1.51 bpm in/out.
Nore 200-300 mtr work at 10,451.9'. May be crossing center
line.
Slowly mill ahead to keep positive WOB (0.2 to 0.5k#).
Lots of metal in returns.
10:00 - 11:30 1.50 STMILL P WEXIT Mill to 10.354'. ROP slowed down. WOB up to 4.Ok#. Drilling -
off slowly.
3050 psi fs at 1.51 bpm in/out.
11:30 - 11:45 0.25 STMILL P WEXIT Mill to 10,357. ROP increased WOB decreased. A ear t
in formation.
Estimated TOW: 10,350'-
Estimated BOW: 10,354'.
These will be verified once tied in to the B sequence.
11:45 - 12:30 0.75 STMILL P WEXIT Drill an additional 7' of formation to 10,461'.
12:30 - 12:45 0.25 STMILL P WEXIT Hold PJSM to discuss choke operation and schedule.
Open EDC.
12:45 - 14:45 2.00 STMILL P WEXIT Circulate out of hole. Maintain BHP as per pressure schedule
with choke.
14:45 - 15:30 0.75 STMILL P WEXIT At surface. LD millina BHA.Window mill gauged 2.74 go, 2.73
no go. Clear wear pattern across mill face.
Hold 950 psi on wellhead.
15:30 - 18:20 2.83 STMILL P WEXIT PU pressure deploy lubricator.
MU slickline sheave and pack off assembly.
Pressure test same.
18:20 - 18:30 0.17 STMILL P WEXIT PJSM - PU of BHA
18:30 - 19:45 1.25 STMILL P WEXIT PU BHA # ith 1.75 deg motor and bald tip 2.74" crayola mill.
Verify space out depths and measurements for press.
deployment procedures.
19:45 - 21:45 2.00 STMILL P WEXIT RIH with EDC open
21:45 - 22:15 0.50 STMILL P WEXIT Log for CCL tie in from 10,225 to 10,391 ft. -Tagged up.
-11 ft correction.
22:15 - 22:20 0.08 STMILL P WEXIT Try to RIH down cement ramp dry and HS orientation. Started
to stack weight and took about 9K overpull to pull free.
22:20 - 22:40 0.33 STMILL P WEXIT Relog CCL tie in.
+2 ft correction.
22:40 - 23:30 0.83 STMILL P WEXIT Try to RIH through window. Can't get into ramp with out LS
Tag ~ 10,454 ft OU to 10,445 ft and try again. Tag again
~ 10,455.6 ft
PU try again with pumps min rate same.
PU try again with pumps on 1.5 bpm and stalling ~ 10,453 C~
100 FPH
Panted: vsizouy naa:o4Ann
• •
BP EXPLORATION Page 4 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To ';~ Hours Task Code NPT Phase Description of Operations
12/8/2008 22:40 - 23:30 0.83 STMILL P WEXIT Try multiple times getting slower each time. able to get past
10,453.6 ft at 15 FPH.
23:30 - 00:00 0.50 STMILL P WEXIT set down to 10,453.1 ft and then slow down and try to mill
ahead ~ 6 FPH. Mill ahead to 10,453.7 and stalled. PU and
reset to 10,453.6
Slowly mill ahead to 10,454.3 ft and stalled again. PU reset to
10,454 ft
milled to 10,453.8 ft
Op=1.45 bpm ~ 2963 psi &DPRESX=504 psi ECD=10.5 ppg
12/9/2008 00:00 - 01:15 1.25 STMILL P WEXIT Continue millin window slowly advancing and sto in until
motor work oes awa ~ 10,454. ftDPRESX=561 psi
Op=1.56 @ 3100 psi.
Mill to 10,456 ft. no more motor work Push ahead and freely
and Tag ~ 10,461.4 ft.
01:15 - 06:30 5.25 STMILL P WEXIT PU to 2 ft below window and up ream with HS orientation per
plan.
Dry drift down clean.
PU to 2 ft below window and up ream with 45 RT TF.
Drift down clean with HS TF Tag bottom.
PU to 2 ft below window and up ream with 45 L TF.
Drift down was rough ~ 10,454.3 ft tag bottom.
PU to 2 ft below window and up ream with HS TF.
Dry drift and tag again ~ 10,455 ft.
Milled down clean ~ 15 FPH and tag bottom ~ 10,461.6 ft
Pull through clean and Dry drift with Tag again. PU above top
of cement.
Make additional pass down, HS tf with 1.5 bpm in/out. Tag btm
ok.
Attempt to dry drift at 11 fpm. Set down at 10,455'.
Drift ok at min rate.
06:30 - 08:30 2.00 STMILL P WEXIT Circulate out of hole. Follow BHP schedule.
08:30 - 09:00 0.50 STMILL P WEXIT At surface. Review pressure undeploy procedure with crew.
09:00 - 10:30 1.50 STMILL P WEXIT Pressure unde to window dressin BHA,
Crayola mill has a lot of wear on the nose.
auge at 2.74" go, 2.73" no-go.
Lay down tools.
10:30 - 12:30 2.00 DRILL P PRODi Pressure de to DIMS BHA #4 H calo 3.0" re-build bic
DIMS bit #1) on a 1.4 deg motor.
12:30 - 14:45 2.25 DRILL P PROD1 Run in hole following pressure schedule.
14:45 - 15:00 0.25 DRILL P PROD1 Log CCL tie in. Subtract 9' correction.
RIH. Tag TD at 10,461'
Through window drv with out a bobble at TF• HS
15:00 - 16:15 0.00 DRILL P PROD1 Drill ahead from 10,461'.
2800 psi fs at 1.51 bpm in/out.
WHP/BHP/ECD: 22 psi/ 3768 psi/ 10.65 ppg.
TF: 10L
Begin displacement to 8.6 ppg flopro. Drill to 10482'
16:15 - 16:45 0.50 DRILL P PROD1 Wiper to window. Pull thru window to 9450'
Phz Z2 GPB, Phz 2 KUP
16:45 - 18:10 1.42 DRILL P PROD1 Log GR tie-in over 9490-9540', corr -3'
Relog data above and below window area. Log to TD
Wellbore is displaced to fresh Flo Pro mud
18:10 - 00:00 5.83 DRILL P PROD1 Drill from 10482' 1.53/2940/10L w/ 100-300 psi dill, 1.5-3.Ok
Printed: 1/5/2009 11:19:54 AM
~ ~
BP EXPLORATION Page 5 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date ,From - To ~i Hours Task Code NPT Phase Description of Operations
12/9/2008 18:10 - 00:00 5.83 DRILL P PRODi wob w/ 10.70 ECD at 10-30'/hr. Drill to 10591' by midnite
Phz 2/2 MPU, Phz Z2 GPB, Phz 2 KUP
CHILL won't let our 3 vac trucks return to CHILL Base since
they are concerned it may go to Phz 3, but forecast says winds
will die off in the AM. Two of these trucks need to return with
KWF and additional drilling mud
12/10/2008 00:00 - 00:25 0.42 DRILL P PROD1 Drill to 10600' and finish build
00:25 - 00:35 0.17 DRILL P PROD1 Wiper to window
00:35 - 05:30 4.92 DRILL P PROD1 Drill from 10600' 1.49/2880/90L w/ 100-200 psi dill, 1.0-2.Ok
wob w/ 10.71 ECD at 10-30'/hr while turning left and holding 90
deg at 6858' TVD. Get first good survey
Drill to 10700'
MPU Phz 1/2, GPB Phz 2/2, KUP Phz 2/3
CHILL vac trucks leave location
05:30 - 07:15 1.75 DRILL P PROD1 Drill from 10700' .
3100 psi fs at 1.47 bpm in/out. 100-200 psi mtr work.
2-3k# dhwob. whp/bhp/ecd: 22 psV3850 psi/10.88 ppg.
inc/azm/ff: 89.7 deg/168.1 deg/ 110r
07:15 - 07:30 0.25 DRILL P PROD1 Wiper trip back to 10,480'.
Hole smooth.
07:30 - 12:30 5.00 DRILL P PROD1 Drill ahead from 10,750'.
ROP: 30-45 fph.
12:30 - 13:15 0.75 DRILL P PROD1 Drill to 10894'.
Make wiper trip back to window.
Open EDC and pull up to 9450' in side casing.
13:15 - 15:15 2.00 DRILL P PROD1 Log GR tie in from 9450'. Add 1' correction.
Log CCL from 10,300' to 10,390'. Final correction to window
depth, which was drilled with respect to the deepest GLM:
TOW: 10,454'> CoeeEZT ~.
BOW: 10,458'
Close EDC and RIH past window.
Run in hole. Smooth.
15:15 - 19:00 3.75 DRILL P PROD1 Drill ahead from 10,895.
All Fields are Phz 1/2
19:00 - 23:10 4.17 DRILL P PROD1 Drill from 10945' 1.50/2980/90L w/ 100-200 psi dill, 1.0-2.Ok
wob w/ 11.00 ECD at 91 deg at 6859' TVD at 10-25'/hr. Drill to
11050' PVT 394
23:10 - 00:00 0.83 DI31LL P PROD1 Wiper to window was clean. Wiper back to TD had setdown at
10820'. Ream shale area from 10815-10850' to clean up.
Finish wiper to TD
12/11/2008 00:00 - 04:00 4.00 DRILL P PROD1 Drill from 11050' 1.49/2960/908 w/ 100-200 psi dill, 1.0-2.Ok
wob w/ 11.08 ECD at 90 deg at 6860' TVD. Drill 120 api shale
from 11100'
04:00 - 04:40 0.67 DRILL P PROD1 Wiper to window was clean except for 5k OP and MW at
10815'
Wiper in hole from 10475' and set down at 10490' and 10840'.
Red pump to 1.2 bpm to get thru each shale
04:40 - 07:00 2.33 DRILL P PROD1 Drill from 11200' 1.50/2980/908 w/ 100-200 psi dill, 1.3-2.5k
wob w/ 11.04 ECD at 90 deg at 6860' TVD
07:00 - 14:30 7.50 DRILL P PROD1 Drill ahead from 11,255'.
2900 psi fs at 1.50 bpm in/out. 100-200 psi mtr work.
2k# dhwob. IA/OA/PVT: 421 psV167 psU 387 bbls
INC/AZM/TVD: 90.1 deg/246 deg/6860'.
Nrintea: u5iluva ii:ia:oar~rvi
~ ~
BP EXPLORATION Page 6 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours Task ' Code j NPT Phase Description of Operations
12/11/2008 07:00 - 14:30 7.50 DRILL P PROD1 TF: 105r. ROP: 20-30 fph.
Begin mud swap. Leave new flopro in open hole. System
contains 14 ppb kla-gard.
14:30 - 15:30 1.00 DRILL P PROD1 Wiper trip to window.
Pull through window at min rate.
15:30 - 17:00 1.50 DRILL P PROD1 Circulate out of hole at max rate. Hold PJSM with crew near
surface.
Tag up. WHP: 750 psi.
17:00 - 19:20 2.33 DRILL P PROD1 Pressure undeploy BHA as per procedure.
Function test BOPE
19:20 - 20:00 0.67 DRILL P PROD1 Safety mfg re: pressure deploy (first time for this crew)
20:00 - 22:00 2.00 DRILL P PRODi Pressure deploy w/ <20 psi whp
22:00 - 00:00 2.00 DRILL P PRODi RIH w/ BHA #5 circ thru bit 0.31/1615 while following pressure
schedule
12/12/2008 00:00 - 00:30 0.50 DRILL P PROD1 Log GR tie-in down from 9505', Corr -8'
00:30 - 00:55 0.42 DRILL P PROD1 RIIH to EOT, clean. RIH thru window area HS and w/o pump,
clean. Start pump 1.2 bpm at 10500' while bleed off whp. Set
down at 10514' and lost returns acked off . PUH to 20k over,
then attempt to go back down. Work back and forth wo out
movement then PUH at 33k over at 0.5 bpm
00:55 - 01:15 0.33 DRILL P PROD1 PUH thru window and wt slowly fell off to normal 25k after
getting returns back. Bring up rate to 1.2/2440 and recip over
10420-450' while investigate high pitch freq from power pack
traction motor bearing(?). Discuss w/ SWS mechanics
01:15 - 03:45 2.50 DRILL N SFAL PRODi Open EDC and circ 1.71/2850 solids OOH while wo SWS
mechanics
SWS mechanic arrive at 0315 hrs and find no problem.
Assume bearings were cold due to recent ambient temp drop
and with higher injector rpm due to fife hole, they made a high
freq noise
03:45 - 04:25 0.67 DRILL P PROD1 RIH w/o pump, but find solids in window: Wash thru at low
pump rate and gradually make hole. Took 20 min to get to
10500' and had several 6k setdowns and 10k overpulls. Clean
up hole to 10560', then wiper back to window and was clean
both directions
04:25 - 04:35 0.17 DRILL P PROD1 Continue wiper in hole and was clean to set down at 10805'
04:35 - 05:25 0.83 DRILL P PROD1 Ream shale area from 10805' 1.1/2650 w/ -5k set downs and
10k overpulls. Get wellbore clean to 10900'
05:25 - 05:35 0.17 DRILL P PROD1 Log tie-in to GR in OH at 10815'-10850' due to counter slipping
from numerous overpulls. Corr +8'
05:35 - 06:15 0.67 DRILL P PROD1 Continue wiper in hole and next stop was 11118'. Ream from
11118'to
06:15 - 12:00 5.75 DRILL P PROD1 Drill from 11375'.
3100 psi fs at 1.51 bpm in/out. 150-250 psi mfr work.
2.5k# dhwob. IA/OA/PVT: 350 psf/164 psi/366 bbls
WHP/BHP/ECD: 51 psi/3930 psi/11.04 ppg.
INC/AZM/TF: 91.4 deg/283 deg/65r.
ROP: 10 in high API rock, 40-50 in 50 api sands.
12:00 - 13:15 1.25 DRILL P PROD1 Drill ahead from 11,480'.
3600 psi fs at 1.49 bpm in/out.
Continue to add flo-vis to raise system viscosity towards 35k.
Drill to 11,500'.
13:15 - 16:45 3.50 DRILL P PROD1 Log MAD pass in up direction for resistivity. No overpulls but
rrmcea: vai~uuy 11:1 `J:54 HM
BP EXPLORATION Page 7 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours Task Code ~ NPT Phase Description of Operations
12/12/2008 13:15 - 16:45 3.50 DRILL P PROD1
16:45 - 17:00 0.25 DRILL P PROD1
17:00 - 18:00 1.00 DRILL P PROD1
18:00 - 00:00 6.00 DRILL P PROD1
12/13/2008 00:00 - 01:30 1.50 DRILL P PROD1
01:30 - 02:25 0.92 DRILL P PROD1
02:25 - 02:45 0.33 DRILL P PROD1
02:45 - 03:00 0.25 DRILL P PROD1
03:00 - 03:15 0.25 DRILL P PROD1
03:15 - 04:00 0.75 DRILL P PROD1
04:00 - 04:45 0.75 DRILL P PROD1
04:45 - 06:45 2.00 DRILL P PROD1
06:45 - 09:30 2.75 DRILL P PRODi
09:30 - 11:45 2.25 DRILL P PRODi
11:45 - 15:15 3.50 DRILL P PROD1
some mtr work in shales.
Over nulls in shale at 10.830'. Reduce pump to 0.54 bpm,
increase whp. Continue to POOH. Pump at 2950 psi fs at
1.18 bpm in/1.15 out.
Log GR tie in from 10,550'. Add 2' correction.
Run back in hole. 2760 psi fs at 0.95 bpm in.
Some mtr work from 10,820' to 10,850'.
Drill from 11500' 1.45/3600/908 w/ 100-200 psi dill, 1.6-3.3k
wob w/ peg 3k surface wt w/ 11.8 ECD at 92 deg/6857' TVD at
10-40'/hr. Drill thru shale area 11490-11555' at 40'/hr. Drill
sand/siltstone from 11555' painfully slow at <15'/hr. Find out
we went thru the top of the target sand so pointed TF down~t
11558' after NBI showed 94 dea. Spend one hour and about
10 stalls at 11595', then broke thru and were back to 40'/hr
coming back down thru shale again. Penetration increased to
60'/hr and string wt was back to positive by 11610'. Drill to
11617' by midnite w/ 1.40/3600/1758
Drill from 11617' 1.40/3600/1758 w/ 100-300 psi dill, 1.5-3.3k
wob w/ 11.8 ECD at 83 deg to drop back into sand. See
dramatic res change at hard spot at 11595'. Appears a fault
was crossed at 11595' since we are back into 40 api rock with
associated slower penetration again. Drill to 11652'
Wiper to window 1.4/3300 at 25'/min. Slowed down over
known shales and had a few tolerable OP's w/ MW. Had major
OP's w/ MW just before the window. PUH to 10400'. Open
EDC
PUH jetting thru EDC 1.62/3220 and get some good cow
patties over shaker
Log tie-in down from 9515' 1.68/3330. Corr 0.5'
RIH jetting to window. Close EDC
RIH w/o pump and set down at BOW. Pass thru on second trv
and run into immediate packing off. Push thru then bring up
pump. Rest of wiper was fairly clean while slowing speed thru
known shales
Set down at 11534'. Took a little work to ream to TD.
Backream to 11490'. Ream back to TD
Drill from 11650' 1.45/3450/608 w/ 100-300 psi, 2.0-3.2k wob
w/ 11.75 ECD holding 86 deg at 30-40'/hr
Drill ahead from 11,720'.
3250 psi fs at 1.44 bpm in/out. 250-350 psi mtr work.
2-3 k# dhwob. IA/OA/PVT: 435 psi/172 psi/379 bbls.
WHP/BHP/ECD: 29 psi/4169 psi/11.7 ppg at 6862'tvd.
INC/AZM: holding 87-89 deg/313 deg.
Drill to 11.800'.
Make wiper trip to window.
3350 psi fs at 1.4 bpm in.
Note minor mtr work at: 11,550', 11070, 10830'.
Run back in hole. 3010 psi fs at 1.20 bpm in.
Drill ahead from 11,800'.
3510 psi fs at 1.51 bpm in/out.
WHP/BHP/ECD: 40 psi/4261 psi/ 11.95 ppg at 6870'tvd.
PVT: 382 bbls.
Drill to 11,885'. Unable to get much differential.
Pfllltetl: 1/52ggy 11:1 y:54 AM
~ ~
BP EXPLORATION Page 8 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours ~ Task Code NPT ~ Phase I Description of Operations
_ ~ I __
12/13/2008 15:15 - 16:45 1.501 DRILL P I PROD1 I Wiper trip to above window, for BHA/bit change.
16:45 - 18:20 1.581 DRILL P PROD1
18:20 - 20:00 I 1.671 DRILL I P I I PROD1
20:00 - 21:45 1.75 DRILL P PROD1
21:45 - 23:30 1.75 DRILL P PROD1
23:30 - 23:45 0.25 DRILL P PROD1
23:45 - 00:00 0.25 DRILL P PRODi
12/14/2008 00:00 - 00:40 0.67 DRILL P PROD1
00:40 - 01:00 0.33 DRILL P PROD1
01:00 - 01:30 0.50 DRILL P PROD1
01:30 - 02:05 0.58 DRILL N SFAL PROD1
02:05 - 02:35 0.50 DRILL P PROD1
02:35 - 03:45 1.17 DRILL P PROD1
03:45 - 05:00 I 1.251 DRILL I N I DFAL I PROD1
05:00 - 07:30 ~ 2.50 ~ DRILL ~ N ~ DFAL ~ PROD1
07:30 - 09:30 2.00 DRILL N PROD1
09:30 - 11:00 1.50 DRILL N PROD1
11:00 - 13:00 2.00 DRILL N PROD1
13:00 - 14:30 1.50 DRILL N PROD1
14:30 - 16:00 ~ 1.501 DRILL N PROD1
Became bit stuck at 10,819'. Work pipe.
Packed off. Pressure down ct ann to 800 psi.
Work pipe free. Continue to POOH. Circ through window at
min rate.
Open EDC. 3320 psi at 1.72 bpm in/out.
Note increase in cuttings volume over shaker at higher rate.
Beain displacement to 11.0 KW F,
CT depth: 10,361'.
Hole is displaced to 10.92 ppq in/out. POH for bit
PVT 57
LD drilling BHA. Bit was 1-11
RIH Circ thru EDC 0.3/350 and begin displacement to used Flo
Pro mud
Log tie-in down from 9505', Corr -10'
RIH to 10361' and park while fin Circ wellbore back to used
mud
Finish displacement back to used Flo Pro
RIH w/o pump and set down at BOW at 10457' CTD several
times before getting by. Wash thru shale below window and
was not too bad
Wiper in hole from 10550' w/ set downs at 10814'. Wiper was
clean to set down at 11500'. Lost MWD display in ops cab
Slow wiper up hole while BHI rectifies problem (cable parted)
Wiper back in hole from 11300' w/ DD adjusting TF and relay
BHP from MWD office. Set downs at 11505', 11514', 11565'
Drill from 11883.4' w/ three initial stalls 1.42/3500/95L w/
100-300 psi dill, 1.0-2.Ok wob w/ 12.03 ECD at 87 deg at
50'/hr. Drill to 11903' w/ a couple BHA wipers to check BHI
tools
Orientor is very weak and finally won't move-assume hydraulic
fluid leak
Wiper to window. Have to pull very slow thru shales w/ red
pump since TF is 90-120 out of DTF. Pull 10-20k over with lots
of MW thru 11580-11490'. Attempt to RIH and can't go back in
hole for same reason. Had similar fife hole thru 10850-10810'.
Pull thru window w/o a problem w/ TF 160 out
Park at 10350', open EDC and circ Flo Pro 1.25/2550 while w/o
KW F truck to return from MI.
Displace cased hole to 10.6 ppg brine. Maintain BHP of
+/-4000 psi while POH.
Circulate out of hole. Maintain 4000 psi BHP.
Hold PJSM. At surface. Get off well.
Change out mwd tools. MU BHA #7. Stab coil and test tools.
Get on well.
'~ Open EDC. Circ at min rate.
Run in hole.
Log CCL tie in from 10,180'. Subtract 7' correction. Make
internal TF checks.
Displace well to 8.6 ppg flo pro. Load 11.0 ppg brine on to vac
truck.
Close EDC.
Run in hole with HS toolface.
Pfiflt0tl: 1/5/2UUy llay:b4 HM
• •
BP EXPLORATION Page 9 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours Task Code ~ NPT Phase Description of Operations
12/14/2008 14:30 - 16:00 1.50 DRILL N PROD1 Had 4-5 set dns at btm window. Try TF 20 deg left & right.
One pump bump. Run in at 23 fpm HS no pump. Bounced
through ok.
Continue to run in hole. Circ at 0.5 bpm, HS ff.
Work through shale at 10,810-825, 11500-550'.
Unable to get below 11879'. ECD up to 12.Oppg. Acts like flow
is restricted u hole in s
16:00 - 17:30 1.50 DRILL P PROD1 Wiper back to 11575'. Get hung up.
Pressure backside ann to 900 psi. Pull free at 41 k# (ct up wt
27k#). Pull up hole to sand at 11480'.
17:30 - 17:50 0.33 DRILL P PROD1 RIH from 11,390'. 3400 psi fs at 1.48 bpm in/out.
17:50 - 19:00 1.17 DRILL N DPRB PROD1 Slow wiper up hole while discuss. Pull thru window, clean
The openhole from 11480-11600' has become progressively
worse. Not only is there a shale over most of the interval, the
hole tortuosity changes from 94 deg of build to 83 deg of drop
while crossin a robable fault. This would be a ve
spot to get the liner past even if the shales above were clean.
i si a rac since we now have a better idea of where we
need to go
19:00 - 00:00 5.00 DRILL N FLUD PROD1 Park at 10350' and circ thru EDC at 1.5/2970 while wo vac
truck from MI with reconditioned 11.0# KWF (had to add
Bromide/NaCI to reweight from 10.3# to 11.0#). Two rig moves
also hindering a timely return
12/15/2008 00:00 - 00:50 0.83 DRILL N FLUD PROD1
~ WO vac truck w/ KWF
00:50 - 01:40 0.83 DRILL N DPRB PROD1 Start 11.0# KWF down CT 1.5/2800
01:40 - 03:30 1.83 DRILL N PROD1 POOH while fin displace wellbore 1.1/1070 to KWF
03:30 - 04:15 0.75 DRILL N PROD1 LD drilling BHA
04:15 - 05:00 0.75 STKOH N PROD1 MU sidetrack ss
05:00 - 07:15 2.25 STKOH N PROD1 RIH w/ BHA #8 (R60ST w/ 1.7 deg) circ used Flo Pro mud thru
EDC 0.31/480 while displace wellbore back to KWF
07:15 - 07:45 0.50 STKOH N PRODi Log GR tie in from 9495'. Subtract 11' correction.
07:45 - 09:00 1.25 STKOH N PROD1 Displace well from 11.0 ppg KWF to flo pro.
09:00 - 10:45 1.75 STKOH N PROD1 Close EDC.
Iti le attem s to et throu h window. Non successful
and stopped at or very near window btm at 10,457.8 each try.
Toolfaces from 90L to 90R, 45L& R, 20L&R, HS. Set 1-2k# do
wt, attempt to orient. Circ at min rate, attempt at HS TF.
Brass ring most likely gone.
Discuss with town, decide to change bit style and motor angle.
10:45 - 12:15 1.50 STKOH N PROD1 Open EDC. Displace well to 10.7 brine.
Held dicsussion with Nordic crew to get pit leakage problem
fixed.
12:15 - 14:15 2.00 STKOH N PROD1 Pull out of hole. Maintain 10.8-11.0 ppg bhp. Hold PJSM near
surface.
14:15 - 15:15 1.00 STKOH N PROD1 Get off well. LD motor and mill. R-60 ST bit had 65% of brass
cap missing. Two large pieces remain attached.
MU 2.2 deg AKO mtr with 2.74 go, 2.73 no go M-609 (looks like
an M-09 but with fewer and larger cutters).
Test mwd tools. PU same.
15:15 - 17:00 1.75 STKOH N PRODi Run in hole.
17:00 - 18:00 1.00 STKOH N WAIT PROD1 Notified by Security that weather is Phase 3.
POOH to surface.
Hold PJSM in Ops Cab to discuss standby ops.
Printetl: 1/5/2009 11:19:54 AM
BP EXPLORATION Page 10 of 17
Operations. Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours I Task Code NPT ; Phase !, Description of Operations
12/15/2008 17:00 - 18:00 1.00 STKOH N WAIT PROD1 Emphasize buddy system, contact vac truck drivers.
18:00 - 00:00 6.00 STKOH N PROD1 BHA at surface. Maintain WHP at 100 psi to keep 11.0 ppg
egmw on open hole.
12/16/2008 00:00 - 04:45 4.75 STKOH N WAIT PROD1 Circ 0.31/385 thru EDC at surface while WOW
MPU goes to Phz 2/3 at 0030 hrs (wind 25-40 mph, visibility
better)
Conduct crew change at 0230-0330 hrs
Dig out
04:45 - 05:00 0.25 STKOH N PROD1 Safety mtg: resume ops
05:00 - 07:00 2.00 STKOH N PROD1 RIH w/ BHA #9 (M609 w/ 2.2 deg motor) Circ KWF thru EDC
0.31 /476
07:00 - 07:20 0.33 STKOH N PRODi Log tie in down from 9505', Corr -14'
07:20 - 07:40 0.33 STKOH N PROD1 RIH to window
07:40 - 08:45 1.08 STKOH N PROD1 Attem t to et thru window wo pump at TF's from 90UHS/90R.
Attem t hi h s eed lows eed rotate off of li etc. Set
Discuss. Need to dress lip at bottom of window
All Fields Phz 1/2
08:45 - 10:45 2.00 STKOH N DPRB PRODi POH circ KWF 0.8/860 OP's at #3 and #5 GLM's
Crew change at 1000 hrs
10:45 - 11:30 0.75 STKOH N PROD1 Tag up w/ counters reading 140'. LD sidetrack BHA. Bit
looked new. Adjust motor to 1.75 deg
Function test BOPE
11:30 - 16:00 4.50 STKOH N PROD1 Cut off CTC. Pump slack back. Cut off 206' of CT and 138'
wire (1.96% slack). Change packoff. Investigate counter
slippage and change out counter. Install CTC. PT 35k. Head
up BHI. PT CTC 3500 psi. Pump slack forward over bung hole
2.8/3800
16:00 - 16:45 0.75 STMILL N PROD1 MU milling BHA (HCC one-step mill w/ brass ring and BHI 1.75
deg motor)
16:45 - 19:25 2.67 STMILL N PROD1 RIH w/ BHA #10 circ thru EDC 0.53/670 w/ used Flo Pro mud.
Set down at 4523' w/ no mandrels nearby. Had several other
similar spots and assume these are at tubing connections.
Pump thru bit & pass thru problem areas with ease.
19:25 - 19:40 0.25 STMILL N PROD1 Log down for tie-in from 9500ft (-11ft corr.
19:40 - 20:30 0.83 STMILL N PROD1 Continue to RIH. Stop at 10350ft & swap well over to 8.87ppg
using the EDC. gry tag at 10457.4ft. PUH to 10450ft & slowly
RIH at 25ft/hr to 10456ft.
20:30 - 20:50 0.33 STMILL N PROD1 Creep in hole from 10456ft at O.ift/min & look for WOB
increase. Park at 10456.3ft (1501bs WOB).
20:50 - 22:50 2.00 STMILL N PROD1 Dress window at 0.75fph w/ 1.38bpm in & out at 3100psi,
4000psi BHP. Collect samples every hour & inspect for cement
& metal -very little in the way of cuttings. Mill to 10457.3ft &
seems like we are stacking w/ no mill off (went to 1k WOB).
PUH -clean. RIH to 10456ft & get new parameters,
1.39bpm/3060psi. Slowly creep in hole at 20fUhr & get 2001bs
WOB at 10457.1ft. First hr sample showed 1% metal, second
hr sample showed 6% metal & both had no cement.
22:50 - 00:00 1.17 STMILL N PROD1 Dress window at 0.75fph from 10457.ift w/ 1.38bpm in & out w/
100psi motor work, 4020psi BHP.
12/17/2008 00:00 - 00:40 0.67 STMILL N DPRB PROD1 Dress window from 10457.7ft at 0.75fph from 10457.1ft w/
1.38bpm in & out w/ 100psi motor work, 4020psi BHP. At
10458.Oft & with 1.3k WOB, PUH -clean. RIH to 10457ft & get
rnrneo: v~zuua naaavr+m
BP EXPLORATION Page 11 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date ~~ From - To '~, Hours Task Code NPT Phase Description of Operations
12/17/2008 00:00 - 00:40 0.67 STMILL N DPRB PROD1 new parameters, 1.39bpm/3050psi. Slowly creep in hole at
20ft/hr & get 2001bs WOB at 10457.1ft. It appears we are
stacking out. PUH & start over.
00:40 - 01:20 0.67 STMILL N PROD1 Dress window at 0.1ft/min (to keep coil moving) from 10457.1ft
w/ 1.38bpm in & out w/ 100psi motor work, 3980psi BHP. Just
stacking. PUH, slowly RIH.
01:20 - 02:50 1.50 STMILL N PROD1 Dress window from 10457.9ft ?!? w/ 1.38bpm in & out w/ 40psi
motor work, 4000psi BHP. 10% metal in last sample & no
cement, very little cuttings. Finally got it to mill off but depths
seem inaccurate as we are now at 10459.2ft.
02:50 - 03:05 0.25 STMILL N PROD1 PUH to 9500ft.
03:05 - 03:15 0.17 STMILL N PROD1 Log down for tie-in from 9500ft (+1.5ft corr.
03:15 - 03:35 0.33 STMILL N PROD1 RIH & dry tag at 10459.8ft.
03:35 - 04:55 1.33 STMILL N PROD1 Dress window from 10459.2ft w/ 1.38bpm in & out w/ 40psi
motor work, 4000psi BHP. WOB dropped off at 10460.ift.
Assume we lengthened the window by - 2ft~ are - 1ft TVD
deeper. Cannot & do not wish too make it any further than
10463ft. Clean up section from 10456ft to 1046ft & pump a
sweep & look at samples. Very little cuttings & last sample
showed 25% metal - no cement. Dray tag at 10461.5ft. Try min
rate -tag up same spot.
04:55 - 06:15 1.33 STMILL N PROD1 Dress window, again from 10461.4ft w/ 1.38bpm in/out w/
100psi motor work. Very ratty getting to 10461.4ft.
06:15 - 07:30 1.25 STMILL N PROD1 Open EDC at 10120'. Begin displacement to KW F. Attempt to
RIH and set down on connections again. Close EDC and circ
thru mill to get in hole to 10350'. Open EDC to fin
displacement
07:30 - 09:15 1.75 STMILL N PROD1 POOH circ thru EDC
09:15 - 10:00 0.75 STMILL N PROD1 LD millin BH Mill had center wear (3/8" dia x 1/8" deep
hole) into the matrix along with 50% wear on the gauge. Rest
of diamonds were not worn. Recovered a 1" piece of the brass
cap off sidetrack bit
10:00 - 10:15 0.25 STMILL N PROD1 Level back of rig to help remove diesel from rig fuel tank
10:15 - 10:50 0.58 STMILL N PROD1 MU window cleanout ass
10:50 - 12:30 1.67 STMILL N PROD1 RIH w/ BHA #10 while circ 0.37/680 w/ used Flo Pro mud thru
EDC
12:30 - 12:50 0.33 STMILL N PROD1 Log tie-in down from 9510', Corr -11'
12:50 - 13:10 0.33 STMILL N PROD1 RIH to 10350'
13:10 - 14:00 0.83 STMILL N PROD1 Finish displacement to used Flo Pro mud. Close EDC
14:00 - 15:00 1.00 STMILL N PROD1 RIH w/o pump and lose wt at 10161.9'. PU 31k Spud one time
at same depth. Start pump at min rate 0.46/2000 and tag at
10456.8'. Retag to confirm. PU off bottom 6" and start pump
1.0/2300. Slack off wt slowly and got wt to bit and stalled hard
at 10456.2'. Acts like steel and seem to be too high. SD
pump. RIH w/o pump and lose wt at 10462.6' PU 6" Start
pump 1.0/1900 and slack off slowly until first MW and WOB at
10461.3'
15:00 - 16:00 1.00 STMILL N PROD1 Drill from 10461.3' w/ 1.0/1930/5L w/ 0.10-2.1 k wob w/ 40-120
psi dill. Stall at 10462.9' Resume drilling at 1.38/2450/5L.
Lost 0.7k wob and 150 psi MW at 10463.8'. Move TF to 15L at
10465.0' and lost wt and MW at 10465.4'. PUH 26.5k Ream
back down 1.38/2680/40L Drill to 10467.0' Discuss
16:00 - 17:00 1.00 STMILL N PROD1 Drill from 10467' 1.26/2680/15L to 10468.2' and stalled. PUH
rnnceo: iioizuua i is ia:°v „m
~ ~
BP EXPLORATION Page 12 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To I Hours Task Code NPT Phase Description of Operations
12/17/2008 16:00 - 17:00 1.00 STMILL N PROD1 heavy and were bit stuck temporarily. Wash back in hole w/
from 10460' and had fill. Wash back to TD and then had no
MW or wob while RIH to 10469.7'. Assume we are in old hole.
TF of thrown around s H .Drill to 10474.7' and
shale is starting to slough. Try to RIH at min rate, but set down
at TD
17:00 - 18:30 1.50 STMILL N PROD1 Drill from 10474.7' 1.27/2820/30L w/ 100-200 psi dill, 0.5-2.Ok
wob w/ 11.44 ECD and looking likely that we are still in the
previous hole. Make it to 10500ft & had two stalls. Discuss w/
town. Elect to POH for lesser AKO motor.
18:30 - 19:30 1.00 STMILL N PROD1 Kill well from 10400ft w/ 11.Oppg KW F.
19:30 - 21:35 2.08 STMILL N PROD1 POH pumping min rate to keep the hole full. PJSM while POH
regarding handling BHA.
21:35 - 23:55 2.33 STMILL N PROD1 Flow check. Pop off. Blow down BHA. LD BHA. Dial down
motor. Plug in & test tools, swap out HOT. MU new BHA. Stab
onto well. Power up & test tools. set counters.
23:55 - 00:00 0.08 STMILL N PRODi RIH.
12/18/2008 00:00 - 01:35 1.58 STMILL N DPRB PROD1 Continue to RIH.
01:35 - 01:45 0.17 STMILL N PROD1 Log down for tie-in from 9500ft (-10ft corr.
01:45 - 02:05 0.33 STMILL N PROD1 RIH.
02:05 - 04:00 1.92 STMILL N PROD1 Swap well to flo-pro through the EDC.
04:00 - 04:40 0.67 STMILL N PROD1 RIH. Minor wt bobbles at 10457ft & 10463ft. Pump min rate
while RIH below the window. Tag up three times at 10500ft.
Review logs. Discuss w/ town. appears at we are slightly
above the OH section. Turn TF 145E &RIH from 10460ft &
attempt to get back into OH section using 1.5bpm. Tag up at
10500ft.
04:40 - 05:50 1.17 STMILL N PROD1 Drill ahead & attempt to get back into the drilled OH section.
Using 1.4bpm/2900psi fs. WOB dropped at 10506ft & are able
to RIH at -2ft/min. The hole seems ratty &NBI seems to
followin the drilled OH .RIH to 10527' and started
taking wt again
05:50 - 07:00 1.17 STMILL N PROD1 Drill from 10527' w/ 1.41/2900/DTF w/ 200 psi dill, 1.3-2.4k
wob w/ 11.3 ECD. NBI is within a degree of old hole. Won't be
able to get a good survey until about 10600'. Drill to 10564'
Compare GR from both holes and see we are hi her TVD wis ,
so we have been drillin new hole from robabl the new
lowered window
07:00 - 08:10 1.17 EVAL N PROD1 Recip in openhole at reduced pump rate while BHI reboots
PC's to start a new wellbore. Discuss situation in AM call
08:10 - 08:40 0.50 EVAL N PROD1 PUH thru window to 10320' to check HOT stops, okay
08:40 - 08:50 0.17 DRILL N PROD1 RBIH thru window, clean. Wlper to TD was clean
08:50 - 11:10 2.33 DRILL N PROD1 Drill from 10564' 1.39/2680/45L w/ 100-300 psi dill, 1.0-2.5k
wob w/ 11.4 ECD while adjusting TF to land at 6860' TVD Drill
to 10650'
11:10 - 11:30 0.33 DRILL N PROD1 Wiper to window was clean both directions. Attempt to get
survey while RIH
11:30 - 11:50 0.33 DRILL N PROD1 Drill from 10650' 1.38/2710/95L w/ 150-300 psi dill, 1.0-2.5k
wob w/ 11.46 ECD at 90 deg at 6860' TVD to 10665' and get
first good survey
11:50 - 12:30 0.67 DRILL N PROD1 Wiper back to window, then survey back in hole
12:30 - 15:30 3.00 DRILL N PROD1 Drill from 10665' 1.38/2730/95L w/ 150-300 psi dill, 1.0-2.Ok
wob w/ 11.33 ECD at 89 deg. Swap to right side at 10682'
rnntea: iioievua ~i:ia:o4Hm
BP EXPLORATION Page 13 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours ' Task Code ~ NPT ' Phase ~ Description of Operations
12/18/2008 12:30 - 15:30 3.00 DRILL N PROD1 Drill to 10800'
15:30 - 16:00 0.50 DRILL N PROD1 Wiper to window was clean. Swap to fresh mud
16:00 - 18:15 2.25 DRILL N PROD1 Drill from 10800' 1.40/2760/908 w/ 150-300 psi dill, 1.2-2.5k
wob w/fresh mud at the bit w/ 10.93 ECD at 90 deg at 6865'
TVD Drill to 10950'
18:15 - 19:05 0.83 DRILL N PROD1 Wiper to the window & to TD was clean.
19:05 - 19:45 0.67 DRILL N PROD1 Drill from 10950' 1.50/2800/908 w/ 150-300 psi dill, 1.2-2.5k
wob w/ 10.70 ECD. Drill to 11000'.
19:45 - 20:20 0.58 DRILL N PROD1 POH for lesser AKO motor & res tool -clean in OH section.
Pump 5 bbl hi-vis pill to help clean up window area while POH.
3k overpull going through the window.
20:20 - 21:30 1.17 DRILL N PROD1 Open EDC & kill well w/ 11.Oppg KW F.
21:30 - 23:30- 2.00 DRILL N PROD1 POH. PJSM regarding handling BHA while POH.
23:30 - 00:00 0.50 DRILL N PROD1 Flow check well. Pop off. Blow down BHA & LD BHA on the
catwalk. Bit was 2-3 & had 5 chipped teeth on the wing & 3 on
the nose w/ erosion/wash out areas.
12/19/2008 00:00 - 00:25 0.42 BOPSU N DPRB PROD1 Stab onto well. Jet stack.
00:25 - 08:00 7.58 BOPSU P PROD1 Fill hole. Grease valves. Blow down BOP stack. Function test
BOPE. Fill BOP stack w/ water. Qeform bi-weekly BOPE tact
per AOGCC regs to 250psi/3500psi -PASS. Lou Grimaldi
waived witness. Fill hole every 2 hrs _ 1 bbl/hr.
PT packoff and inner reel valve
08:00 - 09:00 1.00 DRILL N PROD1 MU lateral assy
09:00 - 10:40 1.67 DRILL N PROD1 RIH w/ BHA # 13 circ mud thru EDC 0.45/380 w/ KWF returns
10:40 - 10:55 0.25 DRILL N PRODi Log tie-in down, Corr -11.0'
10:55 - 11:15 0.33 DRILL N PRODi RIH to 10350' while finish displace CT to mud
11:15 - 11:30 0.25 DRILL N PROD1 Close EDC. RIH thru window w/ minor wt loss. Start pump
1.1/2500 and set down at 10485' twice. Slow ream to 10491'
11:30 - 11:55 0.42 DRILL N PROD1 Wlper to TD 1.0/2450 was clean
11:55 - 15:30 3.58 DRILL N PROD1 Drill from tag at 11001' 1.40/2860/1058 w/ 100-200 psi dill,
0.40-1.5k wob w/ 11.05 ECD at 92 deg at 6855' TVD Drill to
11150'
15:30 - 18:00 2.50 DRILL N PROD1 MAD pass resistivity 1.40/2600 up hole at 300'/hr to 10470'
18:00 - 18:30 0.50 DRILL N PROD1 Wiper to TD, very ratty at 11050' to 11075', otherwise clean.
18:30 - 20:55 2.42 DRILL N PROD1 Drill from tag at 111501' 1.44/2875/90-1108 w/ 100-200 psi dill,
0.40-1.5k wob w/ 10.75 ECD. DHCT = 146 deg. ST = 83 deg.
Drill to 11300'
20:55 - 22:00 1.08 DRILL N PROD1 Wiper to the window -clean. Wiper to TD, very ratty at 11050'
to 11075', otherwise clean.
22:00 - 00:00 2.00 DRILL N PROD1 Drill from 11300' 1.42/2675/90-1108 w/ 100-200 psi dill,
0.40-1.5k wob w/ 10.85 ECD.
12/20/2008 00:00 - 01:45 1.75 DRILL N DPRB PROD1 Drill from 11380' 1.51/2767/90-1108 w/ 100-200 psi dill,
0.40-1.5k wob w/ 10.85 ECD. 50% returns after drilling 11390'
& slowly recovered to 0.25bpm losses. Drill to 11450'
01:45 - 02:40 0.92 DRILL N PRODi Wiper to the window, motor work & 50% losses while going
through 11075' to 11050".
02:40 - 03:00 0.33 DRILL N PROD1 Open EDC & pump at 2.45bpm while PUH to 9500ft.
03:00 - 03:10 0.17 DRILL N PROD1 Log down for tie-in from 9520ft (+6ft corr.
03:10 - 03:20 0.17 DRILL N PROD1 RIH while pumping at 2.25bpm.
03:20 - 04:10 0.83 DRILL N PROD1 W iper to TD w/ 0.5bpm losses. Tag up at 11050ft. Continue w/
wiper to TD.
04:10 - 08:10 4.00 DRILL N PROD1 Drill from 11454' 1.51/2820/308-30L w/ 0.3bpm losses w/
100-200 psi dill, 0.40-2.5k wob w/ 10.70 ECD. Drill to 11600'
~ ~
BP EXPLORATION Page 14 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours
12/20/2008 08:10 - 09:30 1.33 Task !Code ; NPT Phase
DRILL N PROD1
09:30 - 14:40 I 5.171 DRILL I N
14:40 - 15:30 0.83 DRILL N
15:30 - 16:15 0.75 DRILL N
16:15 - 20:35 4.33 DRILL N
20:35 - 21:45 1.17 DRILL P
21:45 - 23:00 1.25 DRILL P
23:00 - 23:10 0.17 DRILL P
23:10 - 23:30 0.33 DRILL P
23:30 - 00:00 0.50 DRILL P
12/21/2008 100:00 - 02:10 2.171 DRILL ~ P
02:10 - 03:10 1.00 DRILL P
03:10 - 05:00 1.831 DRILL P
05:00 - 06:00 1.00 DRILL P
06:00 - 06:30 0.50 CASE P
06:30 - 09:00 2.50 CASE P
09:00 - 10:00 1.00 CASE P
10:00 - 11:50 1.83 CASE P
11:50 - 12:30 ~ 0.67 ~ CASE ~ P
12:30 - 12:50 0.33 CASE P
12:50 - 13:10 0.33 CASE P
13:10 - 15:00 1.831 CASE ~ P
15:00 - 16:00 1.00 CASE P
16:00 - 16:15 0.25 CASE P
16:15 - 18:45 2.50 CASE P
PROD1
PROD1
PROD1
PRODi
Description of Operations
Wiper to window was clean both directions. Slowed pump and
pulling speed over 11020-11100'
Drill from 11600' 1.49/1.35/2680/90L w/ 100-600 psi dill,
0.5-3.5k wob w/ 11.03 ECD while swap to fresh mud
Wiper to window was clean except for 12k OP at 10530'
Wiper back to TD was clean
Drill from 11750' 1.51/1.39/3180/100L w/ 100-400 psi dill,
1.5-3.5k wob w/ 11.18 ECD at 90 deg at 6874' TVD. Drill in
high GR shale to 11900'. Town called_TD.
PROD1 Wiper to the window.
PROD1 Open EDC at 10350'. Jet at 2.4bpm while PUH to 8000ft. RIH
to 9500ft while jetting at 2.4bpm.
PROD1 Log down for tie-in from 9500ft (+4.5ft corr.
PROD1 RIH while jetting at 2.4bpm.
PROD1 Close EDC & wiper to TD. Tag up at 10470' but bobble past.
Tag up at 10500' but bobble past. Clean up area -good. Pump
20bb1 new flo-pro followed by 150K LSRV flo-pro & 3ppb alpine
beads.
PRODi Wiper to TD. Tag up three times at 11050' w/ 1.2bpm & 1 bpm
& no pumps. Apply 80-100psi WHP & got past w/ no problems.
PU &RIH past area, tag up again. Got through w/ no pumps.
Tag up at 11810', work to 11903'. Very ratty & lots of motor
work & 15k overpulls. Work free & lay in liner pill at full pump .
rate. 3 attempts to get through the window (TF is getting kicked
around).
PROD1 Kill well through the bit w/ 11 ppg brine & slowly PUH. Flow
check - no flow.
PRODi POH while pumping min rate. PJSM while POH regarding LD
BHA.
PROD1 Flow check. Pop off well. LD drilling BHA & reconfigure to run
liner. Bit had 1 chipped tooth on the nose & 1 chipped on the
wing.
PROD1 Crew change/safety mtg
RUNPRD MU Unique Indexing Guide Shoe + BTT float equipment on 50
jts 2-3/8" 4.4# L-80 STL liner. Drift first four connections
RUNPRD MU BTT deployment sleeve w/ GS. MU BHI MWD assy
RUNPRD RIH w/liner assy (BHA #14) circ KWF thru closed EDC
0.23/280
RUNPRD 10400' 29.2k, 13.8k
RIH thru in wan t Attempt to PUH
and can't at 20k over. So, RIH w/ liner to 11795' CTD. PUH
39k. Attempt to RIH further one time w/o success. This is -20'
into the shale that extends to TD (and which confirms that the
liner went into the right hole!)
RUNPRD Start pump 1.68/0.58/4300 and release from GS w/ 27k
RUNPRD Log tie-in down to GR at 9496', corr -11'. This puts TOL at
10272' elmd (covers the bottom GLM ~ 10331' DD) and shoe
RUNPRD POOH w/ CT while displace CT w/ used Flo Pro leaving KWF
in the wellbore
RUNPRD LD liner running assy. LD MWD assy
RUNPRD Safety mtg re: pickle and N2 the CT
RUNPRD Flush CT w/ rig water, corrosion inhibitor, McOH. PT SWS N2
Printetl: 1/5/2009 71:19:54 AM
~ ~
BP EXPLORATION Page 15 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date ~, From - To Hours Task Code NPT Phase Description of Operations
12/21/2008 18:45 - 23:00 4.25 CASE P
23:00 - 00:00 1.00 CASE P
12/22/2008 00:00 - 05:00 5.00 CASE P
05:00 - 07:15 ~ 2.25 ~ CASE ~ P
07:15 - 07:45 0.50 CEMT P
07:45 - 09:55 2.17 CEMT P
09:55 - 10:55 ~ 1.00 ~ CEMT ~ P
10:55 - 11:35 0.671 CEMT ~ P
11:35 - 12:15 0.671 CEMT ~ P
12:15 - 13:20 1.081 CEMT ~ P
13:20 - 14:10 I 0.831 CEMT I P
14:10 - 14:55 ~ 0.75 ~ CEMT ~ P
14:55 - 16:45 1.83 CEMT P
16:45 - 19:00 2.25 CEMT P
19:00 - 21:10 2.17 EVAL P
21:10 - 23:10 2.00 EVAL P
23:10 - 00:00 0.83 EVAL P
112/23/2008 ~ 00:00 - 01:35 ~ 1.58 ~ EVAL ~ P
RUNPRD ~ 4000. Blow down reel w/ N2 and bleed off to tiger tank
RUNPRD Pop off well. Fill hole _ 24bbls. Cut off CTC, trim a-line & prep
end of a-line. RD pull back winch cable. RU coil unstabbing
winch cable & internal slip connector. PJSM regarding handling
coil. Pull coil across & secure it w/ shipping bar & chain.
RUNPRD Lower reel onto trailer. Hoist a-free coil into reel house.
RUNPRD RU inner hardline. RU internal grapple & stabbing winch.
Troubleshoot Opsi reel pressure issues. Pull coil across & stab
into the injector. Prep end of coil. Weld on CTC - 2.25" OD.
Pull test CTC to 20k. RD stabbing winch cable. RU injector pull
back cable. Place injector over bung hole. Filled hole - 25bbls.
RUNPRD Fill coil w/ 10bbls of methanol followed by 8.4ppg 2% KCL slick
water. Pump dart, landed at 43.5bbls away. P.T. coil. 4000 psi
Pump 2nd CT volume of KCI to bung hole 2.68/3400
RUNPRD MU LBRT ass on one 't of 1-1/4" CSH
RUNPRD RIH w/ LBRT assy circ slick 2% KCI 0.25/180 w/ nearly full
returns of 8.75# cut used Flo Pro and KWF
RUNPRD Park at 10200' 22.4k Incr circ rate 1.04/0.60 to remove higher
wt fluids from CT ann (9.5-10.40#). Had 1/1 returns after
wellbore above TOL was displaced to KCI
RUNPRD 10200' 23.Ok Load 5/8" ball and displace at 1.15/840 w/ 24
bbls before clearing reelhouse
RUNPRD 10.8k Red rate to min and RIH to 10287.0' CTD and see wt
loss. Stack 5k to 10289.2' See sli press increase. PUH 28k
have th liner. RBIH and stack 5k. Circ 0.60/0.41/420 for
a few bbls while getting ball closer to seat. Ball seated and
then sheared at 3300 psi. PUH 23.Ok and were released from
liner. RBIH and stack wt
RUNPRD Circ KCI 1.06/0.98/1230
Safet mt re: cement liner
Cementers batch up and up to wt at 1305 hrs
RUNPRD PT SWS ~ 4000 w/ FW. Fix a leak and retest. SWS load CT
w/ 12.0 bbls 15.8 ppg G cement w/ latex at 1.47/1.31/2500 ~
73 deg. Load dart
RUNPRD Displace cement w/ 30 bbls biozan followed by KCI at
1.55/1.40/2300, 1.17/1.09/1150 w/ cement at liner,
1.11/0.98/1250 w/ cement at shoe, 1.12/0.93/1600 w/one bbl
out, 1.10/0.74/2380 w/ 8 bbls out. Plug bumped at 48.8 bbls w/
500 si v r nd .Had 9.0 bbls returns past shoe. Check
floats, okay. Pressure CT to 350 psi and unsting w/ 21.4k.
CIP 1455 hrs
RUNPRD POOH circ while diluting cement w/ biozan and replacing
voidage 0.5/400
RUNPRD LD BTT LBRT. C/O dies in little jerk tongs. RU safety joint.
PJSM regarding handling BHA.
LOWERI MU FCO/mill BHA. PU injector & MU to BHA. Stab onto well.
LOWERi RIH w/ FCO/mill BHA. Pump 80bb1 2% slick 2ppb bio pill _ 50k
LSRV pill while RIH 0.25bpm/271 psi.
LOW ER1 RIH through the liner to TD. 1 bpm/2600psi. Start seeing motor
work _ 200psi & set downs from 10420' to 10500'. Wt ck at
10500', 25k up/9.5k RIW, PUH to 10400'. Divert 10ppg fluid to
cuttings box _ 40bbls. Smooth to 10800'.
LOW ERi Continue to run in the liner w/ FCO/Mill BHA from 10800'.
rnrnea: uoizuua ~ is ro:ov Nm
BP EXPLORATION Page 16 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date ,From - To ~ Hours Task Code NPT I~ Phase ~ Description of Operations
--
-
12/23/2008 00:00 - 01:35 1.58 -
EVAL P - ~ LOW ER1 -
1 bpm/2000psi, pumped 80bbls of hi-vis 2% slick w/ 2ppb
biozan pill, followed by slick 2% KCL. Tag bottom twice at
11756'. Pump 25bb1 pert pill & slowly reciprocate pipe. Got lots
of cement solids over the shaker & rubber pieces too.
01:35 - 03:50 2.25 EVAL P LOW ER1 POH laying in pert pill.
03:50 - 04:25 0.58 EVAL P LOWERI Tag up. Pop off. Drop 1/2" ball & open circ sub using test
pump, surge three times, went at 4000psi.
04:25 - 06:00 1.58 EVAL P LOWERI Stand back 24stds of 1"CSH in the derrick. Recovered 1/2"
ball. LD milling BHA
06:00 - 06:15 0.25 EVAL P LOW ER1 Crew change/safety mtg
06:15 - 07:30 1.25 EVAL P LOWERI RU swizzle stick. Jet the stack and flush surface lines
07:30 - 07:45 0.25 EVAL P LOWERi Safety mtg re: MU logging tool/CSH
07:45 - 09:45 2.00 EVAL P LOWERI MU SWS SCMT tool onto BTT MHA
RIH on 24 stds 1"CSH
09:45 - 11:50 2.08 EVAL P LOWERI RIH w/ BHA #17 circ thru XO 0.31/210
11:50 - 13:00 1.17 EVAL P LOWERI Log down from 10000' at 30Wmin to 11725'.
13:00 - 13:25 0.42 EVAL P LOWERI Pump down backside w/ slick 2% KCL.
Time CTP WHP IA OA
13:05 0 0 294 150
13:07 80 2000 309 150 (pumped 0.6bbls)
13:12 80 1934 308 150
13:17 80 1934 308 150
Bleed off pressure
13:25 - 14:40 1.25 EVAL P LOWERI Log up from 11725' at 30fVmin, stop at 11100' & paint a
'mellow yellow' flag & continue logging up to 10000ft, pump
across the top to keep the hole full while logging.
14:40 - 16:00 1.33 EVAL P LOWERI POH pumping ibpm/1300psi. PJSM while POH regarding
handling BHA.
16:00 - 17:35 1.58 EVAL P LOWERI Tag up. Flow check - no flow. Pop off well. Place injector over
bung hole. Stand back 24 stds of 1 "CSH. Lower logging tools
to ground & check for data/process logs.
17:35 - 18:15 0.67 EVAL P LOWERI Pressure test liner la to 2000 si.
Time WHP IA OA
17:35 2078 294 150
17:55 2064 298 150
18:05 2060 298 150
18:15 - 00:00 5.75 EVAL P LOWERI Down load log data and grosses for town evaluation.
Discuss new erf Ian
Wait on more uns from SLB.
12/24/2008 00:00 - 01:05 1.08 PERFO P LOWERI Continue to wait on SLB "blank" guns.
01:05 - 01:25 0.33 PERFO P LOWERi Load and order new guns.
Kick out 3 guns from previous plan.
01:25 - 01:35 0.17 PERFO P LOW ERi PJSM on PU of guns.
01:35 - 02:00 0.42 PERFO P LOWERI PU perf guns
02:00 - 02:20 0.33 PERFO P LOWERI RU to run 1" CSH.
02:20 - 02:30 0.17 PERFO P LOWERI PJSM on running CSH.
02:30 - 04:45 2.25 PERFO P LOWERI PU 1"CSH, stab on well.
04:45 - 07:10 2.42 PERFO P LOWERI RIH with 28 perf guns and 49 joints 1"CSH. Correct depth at
flag. Taa bottom at 11743ft.
07:10 - 08:25 1.25 PERFO P LOWERI Pump 10bbls of perf pill, followed by 1/2" steel ball, followed by
10bbls of perf pill, chased with 2% slick KCL.
08:25 - 08:50 0.42 PERFO P LOW ERi Perforate drive-by style from 11740ft to 11480ft & 11271 ft to
11180ft. Good indication of firing.
rnncea: voreuuy i is ia:°v r+m
BP EXPLORATION Page 17 of 17
Operations Summary Report
Legal Well Name: MPB-22
Common Well Name: MPB-22 Spud Date: 12/29/1985
Event Name: REENTER+COMPLETE Start: 12/5/2008 End:
Contractor Name: NORDIC CALISTA Rig Release: 12/25/2008
Rig Name: NORDIC 2 Rig Number:
Date I From - To ~' Hours Task Code NPT Phase Description of Operations
12/24/2008 08:50 - 11:00 2.17 PERFO P LOWERI POH. Flow check at TOL - no flow. Continue to POH. PJSM
regarding handling BHA.
11:00 - 15:40 4.67 PERFO P LOWERi Flow check. Pop off. Stand back injector. LD 1" CSH sideways.
15:40 - 15:45 0.08 RIGU P POST MU nozzle BHA. Stab onto well.
15:45 - 17:50 2.08 RIGU P POST RIH to 2750ft. RU Hot Oil. P.T. lines. Pump & lay in 40bbls of
60/40. Tag up. Flow check - no flow.
17:50 - 18:40 0.83 WHSUR P POST Set 3-1/2" 'H' s le BPV..
18:40 - 18:50 0.17 RIGD P POST PJSM for N2 blow down
18:50 - 20:30 1.67 RIGD P POST Pump 60 bls, pump 10 bbls of inhibitor pill, cool down N2, blow
down coil, bled off coil.
20:30 - 22:00 1.50 RIGD P POST Nordic changing out BOP rams.
22:00 - 00:00 2.00 RIGD P POST Unstab injector, pull coil across and secure reel. Remove
stuffing box and prep injector for change out of gripper blocks.
Rig released ~ 00:00 from MPB-22A
12/25/2008 00:00 - 00:30 0.50 RIGD P POST Continue to RD and clear rig floor.
00:30 - 00:45 0.25 RIGD P POST PJSM on pulling mouse hole, and ND of BOP's
00:45 - 04:30 3.75 RIGD P POST Try to pull rat hole casing and could not - frozeen in the ground.
ND BOP's & NU tree cap.
Pressure Test tree cap to 3500 psi
Rig released from MPB-22A @ 04:30_
Nnntea: uoi~uua ii:~a:oaNM
e ~ BP Alaska
p
~~'~~~~ ~ Baker Hughes INTEQ Survey Report
r~~r~
BAKER
HU6HE9
INTEQ
Company: BP Amoco Date: 12/22/2008 Time: 13:56:21 Page:
Field: Milne Point C o-ordinate(NE) Keference: Well: MPB-22, True North
Site: M Pt B Pad Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59.0
Wcll: MPB-22 Section (VS) Reference: Well (O.OON,O.OOE,207.84 Azi)
Wellpath: MPB-22APB1~ Survey Calculation Method: Minimum Curvature Db: Oracle
Field: Milne Point
North Slope
UNITED STATES
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Site: M Pt B Pad
TR-13-11
UNITED STATES :North Slope
Site Position: Northing: 6021548.49 ft Latitude: 70 28 8.986 N
From: Map Easting: 571775.55 ft Longitude: 149 24 49.895 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 0.55 deg
Well: MPB-22 S1otName: 22
MPB-22
Well Position: +N/-S 1756.34 ft Northing: 6023308.29 ft Latitude: 70 28 26.259 N
+E/-W 384.34 ft Easting : 572142.90 ft Longitude: 149 24 38.595 W
Position Uncertainty: 0.00 ft
Wellpath: MPB-22APB1 Drilled From: MPB-22
500292150970 Tie-on Depth: 10423.00 ft
Current Datum: 26:22 12/29/1985 00:00 Height 59.00 ft Above System Datum: Mean Sea Level
Magnetic Data: 11/7/2005 Declination: 24.29 deg
Field Strength: 57591 nT Mag Dip Angle: 80.92 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
35.50 0.00 0.00 207.84
Survey Program for Definitive Wellpath
Date: 11/7/2005 Validated: Yes Version: 2
Actual From To Survey Toolcode Tool Name
ft ft
101.00 10423.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot
10450.00 11903.00 MWD (10450.00-11903.00) MWD MWD -Standard
Annotation
MD TVD -
ft ft
10423.00 6871.63 TIP
10450.00 6885.77 KOP
11903.00 6932.49 TD
Survey: MWD Start Date: 12/11/2008
Company: Baker Hughes INTEQ Engineer:
Tool: MWD;MWD -Standard Tied-to: From: Definitive Path
Survey _ _
___
r 1~1D Incl Azim TVD Sys'I'VD
N/S`
E/W MapN
MapE VS
DLS Toul
ft deg deg ft ft ft ft ft
_ ft ft
_ deg/100ft
- -
_ __
10423.00 58.50 204.00 6871.63 6812.63 -6498.95 -2858.45 6016782.55 569347.84 7081.64 0.00 MWD
10450.00 58.37 204.27 6885.77 6826.77 -6519.95 -2867.86 6016761.47 569338.64 7104.60 0.98 MWD
10472.58 67.50 204.23 6896.03 6837.03 -6538.26 -2876.11 6016743.07 569330.57 7124.65 40.43 MWD
10502.53 74.10 203.50 6905.87 6846.87 -6564.11 -2887.54 6016717.11 569319.39 7152.85 22.16 MWD
10532.53 79.43 199.00 6912.74 6853.74 -6591.32 -2898.10 6016689.81 569309.09 7181.84 22.99 MWD
10562.79 85.12 193.17 6916.81 6857.81 -6620.11 -2906.40 6016660.94 569301.08 7211.17 26.79 MWD
10592.62 89.51 187.79 6918.21 6859.21 -6649.39 -2911.81 6016631.61 569295.95 7239.59 23.26 MWD
10624.80 89.42 180.78 6918.51 6859.51 -6681.46 -2914.21 6016599.53 569293.86 7269.07 21.78 MWD
10653.45 90.03 174.24 6918.65 6859.65 -6710.07 -2912.97 6016570.94 569295.38 7293.78 22.93 MWD
10681.53 89.42 168.11 6918.78 6859.78 -6737.80 -2908.66 6016543.25 569299.95 7316.30 21.94 MWD
10710.65 89.54 161.61 6919.05 6860.05 -6765.89 -2901.06 6016515.23 569307.83 7337.59 22.32 MWD
`~ ~ BP Alaska
~`;.
~~~~~ ~~~~ Baker Hughes INTEQ Survey Report
rr..ir
BAKER
Htlt~NE9
1NTEQ
Cumpuny: BP
Amoco _
Date: 12/22/2 -
008 'l'im
e: 13:56:21
Page:
2
Field: Mil ne Point Co-ordinate(NE ) Referencc: Well: MPB-22 , True North
Site: M Pt B Pad Vertical (TVD) Reference: 26:22 12/29/ 1985 00:00 59.0
Nell: MP B-22 Section (VS) Re ference: Well (O.OON,O .OOE,207.84 Azi)
Wellpath: MP B-22APB1 Survey Calcula tion Method: Minimum Cur vature Db: Orade
Sw~vcy
MD Incl Azim TVD Srs TVll N/S E/W MapN MapE VS DLS Tool
ft deg deg ft ft ft ft ft ft
__ _ ft
.. deg/100ft
10739.52 88.83 165.53 - -
6919.46 6860.46 -6793.58 -2892.90 6016487.63 569316.26 7358.26 13.80 MWD
10770.40 89.39 172.73 6919.94 6860.94 -6823.88 -2887.08 6016457.39 569322.37 7382.33 23.38 MWD
10799.93 89.63 179.76 6920.19 6861.19 -6853.32 -2885.15 6016427.97 569324.59 7407.47 23.82 MWD
10828.31 90.18 186.27 6920.24 6861.24 -6881.65 -2886.64 6016399.63 569323.37 7433.21 23.02 MWD
10860.87 91.65 193.38 6919.72 6860.72 -6913.71 -2892.19 6016367.52 569318.13 7464.15 22.30 MWD
10880.75 91.41 197.86 6919.19 6860.19 -6932.84 -2897.54 6016348.34 569312.97 7483.57 22.56 MWD
10900.93 87.73 199.77 6919.34 6860.34 -6951.94 -2904.05 6016329.18 569306.65 7503.49 20.54 MWD
10923.70 90.46 194.71 6919.70 6860.70 -6973.67 -2910.79 6016307.39 569300.11 7525.86 25.25 MWD
10949.54 90.25 189.26 6919.54 6860.54 -6998.94 -2916.15 6016282.07 569294.99 7550.71 21.11 MWD
10983.32 90.46 196.88 6919.33 6860.33 -7031.82 -2923.79 6016249.12 569287.68 7583.35 22.57 MWD
11007.20 89.45 201.43 6919.35 6860.35 -7054.37 -2931.62 6016226.50 569280.07 7606.95 19.52 MWD
11036.27 88.71 207.18 6919.82 6860.82 -7080.85 -2943.58 6016199.91 569268.37 7635.95 19.94 MWD
11066.47 88.10 213.75 6920.66 6861.66 -7106.86 -2958.88 6016173.76 569253.32 7666.09 21.84 MWD
11096.63 89.33 220.07 6921.33 6862.33 -7130.95 -2976.98 6016149.49 569235.46 7695.85 21.34 MWD
11127.26 90.86 227.02 6921.28 6862.28 -7153.14 -2998.06 6016127.10 569214.59 7725.32 23.23 MWD
11156.64 90.86 233.56 6920.84 6861.84 -7171.90 -3020.65 6016108.12 569192.19 7752.45 22.26 MWD
11186.82 91.96 239.67 6920.1,0 6861.10 -7188.49 -3045.83 6016091.29 569167.17 7778.88 20.56 MWD
11213.77 91.20 246.06 6919.35 6860.35 -7200.77 -3069.79 6016078.78 569143.33 7800.93 23.87 MWD
11240.81 90.95 251.92 6918.85 6859.85 -7210.46 -3095.02 6016068.85 569118.20 7821.28 21.69 MWD
11270.11 90.15 258.50 6918.57- 6859.57 -7217.94 -3123.33 6016061.10 569089.97 7841.11 22.62 MWD
11300.36 90.12 265.29 6918.49 6859.49 -7222.20 -3153.26 6016056.55 569060.08 7858.86 22.45 MWD
11333.04 90.49 272.09 6918.32 6859.32 -7222.95 -3185.91 6016055.48 569027.44 7874.77 20.84 MWD
11362.82 88.80 277.54 6918.50 6859.50 -7220.45 -3215.58 6016057.69 568997.76 7886.41 19.16 MWD
11393.57 90.09 283.40 6918.80 6859.80 -7214.86 -3245.80 6016062.98 568967.49 7895.59 19.51 MWD
11425.77 91.10 288.40 6918.47 6859.47 -7206.04 -3276.75 6016071.50 568936.45 7902.24 15.84 MWD
11455.09 92.21 293.50 6917.62 6858.62 -7195.57 -3304.12 6016081.71 568908.99 7905.76 17.79 MWD
11487.83 92.86 298.19 6916.17 6857.17 -7181.31 -3333.54 6016095.68 568879.43 7906.90 14.45 MWD
11520.88 93.96 303.00 6914.20 6855.20 -7164.53 -3361.93 6016112.18 568850.88 7905.31 14.90 MWD
11549.46 93.10 306.71 6912.44 6853.44 -7148.23 -3385.34 6016128.26 568827.32 7901.83 13.30 MWD
11582.76 87.45 307.25 6912.28 6853.28 -7128.21 -3411.93 6016148.02 568800.54 7896.54 17.04 MWD
11610.55 83.94 308.12 6914.37 6855.37 -7111.27 -3433.86 6016164.74 568778.46 7891.80 13.01 MWD
11641.17 82.00 310.71 6918.12 6859.12 -7091.98 -3457.33 6016183.80 568754.80 7885.71 10.52 MWD
11671.20 84.47 313.61 6921.66 6862.66 -7071.96 -3479.43 6016203.60 568732.50 7878.33 12.63 MWD
11701.50 86.07 317.53 6924.16 6865.16 -7050.40 -3500.56 6016224.95 568711.17 7869.14 13.93 MWD
11732.16 83.73 312.36 6926.88 6867.88 -7028.84 -3522.17 6016246.30 568689.36 7860.15 18.45 MWD
11762.46 87.67 311.05 6929.15 6870.15 -7008.74 -3544.72 6016266.18 568666.61 7852.92 13.70 MWD
11795.23 92.03 309.70 6929.24 6870.24 -6987.52 -3569.68 6016287.16 568641.45 7845.81 13.93 MWD
11826.59 89.48 306.74 6928.83 6869.83 -6968.12 -3594.31 6016306.31 568616.63 7840.16 12.46 MWD
11856.56 86.71 304.05 6929.82 6870.82 -6950.78 -3618.72 6016323.42 568592.06 7836.22 12.88 MWD
11903.00 86.71 304.05 6932.49 6873.49 -6924.82 -3657.14 6016349.00 568553.40 7831.20 0.00 MWD
~~~- ~ BP Alaska
,_ ~
~`~~~~~ Baker Hughes INTEQ Survey Report
^~tr
BAKER
i1tlGi~lES
iii a .•.Y
Company: BP Amoco Date: 12/22/2008 Time: 13:57:42 Page: 1
Field: Milne Point Co-ordinate(NE) Reference: Well: MPB-22, True North
Site: M Pt B Pad Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59.0
Well: MPB-22 Section (VS) Reference: Well (O.OON,O.OOE,209.17Azi)
'~ Wellnarh: MPB-22A Survey Calculation Method: Minimum Curvature llb: Oracle
Field: Milne Point
North Slope
UNITED STATES
Map System:US State Plane Coordinate System 1927
Geo Datum: NAD27 (Clarke 1866) Map Zone:
Coordinate System: Alaska, Zone 4
. Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007
Site: M Pt B Pad
TR-13-11
UNITED STATES :North Slope
Site Position: Northing: 6021548.49 ft Latitude: 70 28 8.986 N
From: Map Easting: 571775.55 ft Longitude: 149 24 49.895 W
Position Uncertainty: 0.00 ft
Ground Level: 0.00 ft North Reference:
Grid Convergence: True
0.55 deg
Well: MPB-22 Slot Name: 22
MPB-22
Well Position: +N/-S 1756.34 ft Northing: 6023308.29 ft Latitude: 70 28 26.259 N
+E/-W 384.34 ft Easting : 572142.90 ft Longitude: 149 24 38.595 W
Position Uncertainty: 0.00 ft
Wellpath: MPB-22A
500292150901 Drilled From:
Tie-on Depth: MPB-22APB1
11362.82 ft
Current Datum: 26:22 12/29/1985 00:00 Hei ght 59.00 ft Above System Datum: Mean Sea Level
Magnetic Data: 12/15/2008
Field Strength: 57670 nT Declination:
Mag Dip Angle: 22.62 deg
80.96 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
35.50 0.00 0.00 209.17
Survey Program for Definitive Wellpath
Date: 12/15/2008 Validated: No Version: 2
Actual From To Survey Toolcode Tool Name
ft ~ ft
101.00 10423.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot
10452.39 11903.00 MWD (10452.39-11903.00) MWD MWD -Standard
Annotation
y1D TVD -_ __ - _ _
ft ft
-
10423.00 _ _ - _ - --
6871.63 TIP
10452.40 6886.66 KOP
11903.00 6944.02 TD
Survey: MWD Start Date: 12/22/2008
Company: Baker Hughes INTEQ Engineer:
Tool: MWD;MWD -Standard Tied-to: From: Definitive Path
Survey __ __. _
MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS "1'001
ft deg deg ft ft ft ft ft ft ft deg/100ft
- -
---.
10423.00 _
58.50 204.00 6871.63 6812.63 -6498.95 -2858. 45 6016782.55 569347.84 7067.97 0.00 MWD
10452.39 60.04 199.53 6886.66 6827.66 -6522.41 -2867. 81 6016759.00 569338.72 7093.01 14.09 MWD
10482.49 70.14 195.29 6899.32 6840.32 -6548.43 -2875. 92 6016732.91 569330.86 7119.69 35.90 MWD
10512.48 76.59 191.33 6907.91 6848.91 -6576.37 -2882. 51 6016704.90 569324.53 7147.30 24.95 MWD
10542.42 81.75 187.58 6913.53 6854.53 -6605.37 -2887. 33 6016675.87 569320.00 7174.97 21.17 MWD
10572.58 86.66 183.95 6916.58 6857.58 -6635.21 -2890. 34 6016646.00 569317.28 7202.49 20.21 MWD
10602.43 89.17 180.45 6917.66 6858.66 -6665.01 -2891. 49 6016616.19 569316.42 7229.07 14.41 MWD
10631.03 89.51 177.15 6917.99 6858.99 -6693.60 -2890. 89 6016587.62 569317.30 7253.74 11.62 MWD
10660.49 89.11 170.58 6918.35 6859.35 -6722.87 -2887. 74 6016558.38 569320.72 7277.77 22.34 MWD
10690.50 88.93 169.87 6918.86 6859.86 -6752.44 -2882. 65 6016528.86 569326.10 7301.11 2.44 MWD
10723.85 88.25 176.68 6919.68 6860.68 -6785.53 -2878. 75 6016495.81 569330.33 7328.10 20.52 MWD
BAKER
d~~ p b ! BP Alaska
'~'~~~' Baker Hughes INTEQ Survey Report INTEQ
_- _ _ _ --
Company: BP Amoco Date: 12/22/2008 Time: 13:57:42 Page: 2
Field: Milne Point Co-ordinate(NE) Reference: Well: MPB-22, True North
Site: M Pt B Pad Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59.0
VVcll: MPB-22 Section (VS) Reference: Well (O.OON,O.OOE,209.17Azi)
Wcllpath: MPB-22A Survey Calculation Method: Minimum Curvature Db: Oracle
Sur~~ey
11~9D Incl Azim TVD Srs TVD N/S E/W J'IapN MapE VS DLS 'Ibol
ft deg deg ft ft ft ft ft ft ft deg/100ft
--- _ __ - -
10753.31 86.50 182.56 6921.03 6862.03 -6814.94 -2878.55 6016466.41 569330.81 7353.69 20.80 MWD
10783.90 87.46 189.01 6922.65 6863.65 -6845.32 -2881.63 6016436.00 569328.03 7381.71 21.29 MWD
10814.78 88.74 193.78 6923.67 6864.67 -6875.56 -2887.73 6016405.70 569322.22 7411.09 15.98 MWD
10848.30 91.20 205.18 6923.69 6864.69 -6907.11 -2898.88 6016374.05 569311.37 7444.08 34.79 MWD
10888.67 93.20 212.35 6922.14 6863.14 -6942.45 -2918.28 6016338.53 569292.32 7484.39 18.43 MWD
10920.39 94.45 221.42 6920.02 6861.02 -6967.74 -2937.26 6016313.06 569273.59 7515.72 28.80 MWD
10952.02 93.41 230.61 6917.84 6858.84 -6989.63 -2959.94 6016290.96 569251.13 7545.89 29.17 MWD
10982.65 94.03 238.32 6915.85 6856.85 -7007.38 -2984.79 6016272.97 569226.45 7573.50 25.20 MWD
11013.41 92.58 243.75 6914.08 6855.08 -7022.24 -3011.65 6016257.85 569199.74 7599.57 18.24 MWD
11044.54 93.78 249.52 6912.35 6853.35 -7034.57 -3040.17 6016245.25 569171.34 7624.23 18.90 MWD
11075.96 91.41 254.67 6910.93 6851.93 -7044.21 -3070.02 6016235.32 569141.58 7647.20 18.03 MWD
11106.85 90.80 257.82 6910.33 6851.33 -7051.55 -3100.02 6016227.68 569111.67 7668.23 10.39 MWD
11136.89 92.67 263.47 6909.42 6850.42 -7056.43 -3129.63 6016222.52 569082.10 7686.93 19.80 MWD
11167.29 90.34 267.46 6908.62 6849.62 -7058.83 -3159.92 6016219.82 569051.84 7703.78 15.19 MWD
11198.41 89.32 271.41 6908.72 6849.72 -7059.14 -3191.03 6016219.21 569020.74 7719.22 13.11 MWD
11230.12 88.37 275.99 6909.36 6850.36 -7057.10 -3222.66 6016220.95 568989.10 7732.84 14.75 MWD
11260.98 85.27 278.99 6911.07 6852.07 -7053.08 -3253.20 6016224.67 568958.52 7744.23 13.97 MWD
11290.82 85.73 282.52 6913.41 6854.41 -7047.53 -3282.42 6016229.94 568929.25 7753.62 11.89 MWD
11320.59 86.47 286.35 6915.43 6856.43 -7040.13 -3311.18 6016237.06 568900.42 7761.17 13.07 MWD
11352.51 86.16 290.03 6917.49 6858.49 -7030.19 -3341.44 6016246.71 568870.07 7767.24 11.55 MWD
11382.23 86.40 296.28 6919.42 6860.42 -7018.53 -3368.69 6016258.10 568842.71 7770.34 21.00 MWD
11411.98 84.56 298.42 6921.76 6862.76 -7004.91 -3395.03 6016271.46 568816.24 7771.28 9.47 MWD
11442.04 85.42 302.76 6924.39 6865.39 -6989.67 -3420.80 6016286.45 568790.33 7770.54 14.66 MWD
11472.70 86.34 301.56 6926.59 6867.59 -6973.39 -3446.69 6016302.47 568764.29 7768.95 4.92 MWD
11503.49 87.85 298.18 6928.15 6869.15 -6958.08 -3473.35 6016317.52 568737.48 7768.57 12.01 MWD
11536.19 88.10 294.98 6929.31 6870.31 -6943.46 -3502.57 6016331.86 568708.12 7770.05 9.81 MWD
11566.87 88.25 289.94 6930.29 6871.29 -6931.75 -3530.90 6016343.29 568679.68 7773.63 16.43 MWD
11599.54 89.63 285.73 6930.89 6871.89 -6921.75 -3561.99 6016352.99 568648.50 7780.04 13.56 MWD
11632.28 87.60 282.48 6931.68 6872.68 -6913.77 -3593.73 6016360.66 568616.69 7788.55 11.70 MWD
11665.38 87.39 278.80 6933.13 6874.13 -6907.67 -3626.22 6016366.45 568584.14 7799.05 11.13 MWD
11703.27 91.35 275.64 6933.55 6874.55 -6902.91 -3663.80 6016370.84 568546.53 7813.21 13.37 MWD
11734.97 90.95 272.41 6932.91 6873.91 -6900.68 -3695.41 6016372.76 568514.90 7826.68 10.27 MWD
11765.78 87.24 268.45 6933.40 6874.40 -6900.45 -3726.20 6016372.69 568484.11 7841.48 17.61 MWD
11797.56 87.15 264.42 6934.95 6875.95 -6902.43 -3757.88 6016370.41 568452.46 7858.64 12.67 MWD
11826.42 83.76 261.27 6937.24 6878.24 -6906.01 -3786.41 6016366.56 568423.96 7875.68 16.01 MWD
11856.73 85.21 258.91 6940.15 6881.15 -6911.20 -3816.13 6016361.08 568394.30 7894.70 9.11 MWD
11903.00 85.21 258.91 6944.02 6885.02 -6920.07 -3861.38 6016351.77 568349.14 7924.49 0.00 MWD
TREE: 3 i/8^ - 5M FMC MPB-22A CTD
w/ 31 rr Otis Quick Unbn KB Elev. = 59' Nabors 27E
GL Elev. = 36' Nabors 27E
WELLHEAD: 11" 5M FMC wl 31l2"
'H' BPV proltb.
13 3/8", 48#, K-55 $$,
BTRC
KOP @ 500'
MAX Hole Angle:
61 DEG @ 6375'
9 5/6", 36#x, K-55 6349' -
BTRC
31/2", 9.3#, BTRS, L-80TUBING
DRIFT ID: 2.867"
CAPACITY: 0.0087 BBL/FT
7" , 26#, L-80, BTRC Casing
DRIFT ID: 6.151"
CAPACITY w/ tba:.0264 bpf
Top 2 3/8" liner at 10,272' -~
Casing RA Tag 10219`
Baker'PBR' Seal Assy (3.00" ID) 10360'
Baker `HB' Packer (2.69° lD) 10375'
Perf @-10385 for tailpipe cementing -
Camco 2.750 `D' nipple 10413'
WLEG 10419'
WLEG (ELMD) 10426`
PERFORATION SUMMARY
fDIL Loa dated //1
Zlf Size SPF MD' TVD'
MK-1
MK-2 5"
5" 1 456'
10488' - 6873' - 6889'
6906' - 6922'
17 pP9
cement
0
of
Camco TRDP-1A-SSA SCSSV 1927'
1" x 3 ill" McMurray FMHO wl BK latch
# rr-d tvd d9
10 2198' 2111 ` 30
9 3119` 2822` 47
8 4102` 3420' 57
7 5242` 4041 ` 59
6 6196' 4526` 61
5 7150` 5027` 55
4 7945` 5482` 54
3 8709' 5926` 55
2 9504` 6377` 57
1 10331 ` 6832' 58
Note: The Camco TRDP-IA-SSA was
locked out of service 6/25/00.
Cement Ramp Window
at 10,460`
2 3/8" Cemented Liner
11,780'
Fill tagged w/ wireline on 2/27/08 at 10533' MD
Fish:Calculated top of TCP 10526'
PBTD (Float colar) 10628`
7" 26 # Shoe 10729'
DATE REV BY COMMENTS MILNE POINT UNIT
1/11/05 Lee Hulme Convert drawing to Canvas WELL MPB-22
12/23/08 Nordic 2 Sidetracked for more oil....... API NO: 50-029-21509
BP EXPLORATION (AK)
„f~C'L Lac :,..IiL. i,~J l~U~1u,!
ALASSA OIL AI1TD GAS
CO1~T5ER'PATIOI•T COI•'II-II5SIOI~T
John McMullen
Engineering Team Leader
BP Exploration Alaska Inc.
PO Box 196612
Anchorage AK 99519-6612
SARAH PALIN, GOVERNOR
333 W. 7th AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Milne Point Field, Kuparuk River Oil Pool, MPB-22A
BP Exploration Alaska Inc.
Permit No: 208-168
Surface Location: 183' FSL, 1066' FWL, SEC. 18, T13N, R11E, UM
Bottomhole Location: 1269' FNL, 3548' FEL, SEC. 25, T13N, R10E UM
Dear Mr. McMullen:
Enclosed is the approved application for permit to redrill the above referenced
development well.
This permit to drill does not exempt you from obtaining additional permits or
an approval required by law from other governmental agencies and does not
authorize conducting drilling operations until all other required permits and
approvals have been issued. In addition, the Commission reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20,
Chapter 25 of the Alaska Administrative Code unless the Commission
specifically authorizes a variance. Failure to comply with an applicable
provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit. When providing notice for a
representative of the Commission to witness any required test, contact the
Commission's petroleum field inspector at (907) 659-3607 (pager).
cerely,
aniel T. Seamount, Jr.
Chair
DATED this ~ day of October, 2008
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA ~ I~'J
ALAS~OIL AND GAS CONSERVATION COM ION
~iCT 2 3 1008
PERMIT TO DRILL Alak~ ~,~~ ~~ ~~~ ~~n~, C~l~~~ir~~f~r~
20 AAC 25.005
1 a. Type of work
^ Drill ®Redrill
^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas
^ Service ^ Multiple Zone
^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if we is pr"o d for:
^ Coalbed Methane ^ Gas Hydrates
^ Shale Gas
2. Operator Name:
BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well
Bond No. 6194193 • 11. Well Name and Number:
MPB-22A
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth:
MD 12875' TVD 7001'ss 12. Field /Pool(s):
Milne Point Unit / Kuparuk River
4a. Location of Well (Governmental Section):
Surface:
'
'
' 7. Property Designation:
ADL 047438, 025518 ' Sands -
183
FSL, 1066
FWL, SEC. 18, T13N, R11 E, UM
Top of Productive Horizon:
1764' FEL, SEC. 25, T13N, R10E, UM
970' FNL 8. Land Use Permit: 13. Approximate Spud Date:
December 15, 2008
,
Total Depth:
1269' FNL, 3548' FEL, SEC. 25, T13N, R10E, UM 9. Acres in Property:
2560 14. Distance to Nearest Property:
10,325'
4b. Location of Well (State Base Plane Coordinates):
Surface: x-572144 y-6023308 ' Zone-ASP4 10. KB Elevation
(Height above GL): 59' feet 15. Distance to Nearest Well Within Pool:
1,725'
16. Deviated Wells: Kickoff Depth: 10440 ~ feet
Maximum Hole An le: 90 d rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhole: 2725 Surface: 2025 '
1 in r r m: c~ io n T in b m n' m n .f. or
Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data
2-3/ " 4.7# TL 2 0' 772' 1 7' 7 x l
1 g, PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations)
Total Depth MD (ft):
10729' Total Depth TVD (ft): Plugs (measured):
7 1' 10533' Effective Depth MD (ft):
10533' Effective Depth TVD (ft):
6930' Junk (measured):
10526'
Casing Len th Size Cement Volume MD TVD
Conductor /Structural 1 - / " T '
Surface 4' /" 175 x P rm f x I 4
Intermediate
Pr i n 1 7" i P 7 1
Liner 1 0 PF ' '
Perforation Depth MD (ft): 10426' - 0518' Perforation Depth TVD (ft): 6873' - 6922'
20. Attachments ',, fling Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis
^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct. Contact Grey Sarber, 564-4330
Printed Name Jo ull Title En ineerin Team Leader
Prepared By Name/Number.
Si nature Phone 564-4711 Date 'z3 6 Terrie Hubble, 564-4628
Commission Use Onl
/
Permit To
ill
N ~LL~' /~~j API Number: bZ
50-029-21509 -00 Permit A pro I p See cover letter for
• ~ r~ h it men
Conditions of Approval: ~,~f Ad•~'~.oJ?
If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: ,~/
Samples Req'd: ^ yes L~ No Mud Log Req'd: ^ Yes L~dNo
HZS Measures: Yes ^ No Directional Survey Req'd: dyes ^ No
Other: 3~vV ~S l ~~ ~s~.
~~ .5 l Date APPROVED BY T COMMIA SIONER
Form 10-401 Revised 12!2005 - ~~ ~ ~^+ ~ {~ t /~ ~ Submit In Duplicate
by
To: Tom Maunder
Petroleum Engineer
Alaska Oil & Gas Conservation Commission
From: Greg Sarber
CTD Engineer
Date: October 23, 2008
Re: Milne Point B-22A PTD request
Approval is requested for a permit to drill a CTD sidetrack from well Milne Point B-22. MPB-22 is a
Kuparuk C/B sand producer that is in direct communication with its injector. MPB-22A will be drilled to a more
optimum location for injection support. /
The sidetrack, MPB-22A, is scheduled to be drilled by Nordic 2 starting December 1, 2008 using the managed
pressure drilling technique. This horizontal lateral will target Kuparuk B sand reserves to capture currently
nonrecoverable resources. The Perforations in the parent well will be abandoned with a cement P&A which is the
subject of a separate sundry application. The "A" sidetrack lateral will exit the parent well at 10,440' and and drill
a 2500' lateral to a TD of 12,875' md. The sidetrack will be completed with a solid, cemented and perforated 2-
3/8" liner from TD to above the window to 10,345'.
Managed Pressure Drilling Technique
The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure
drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is
drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant
bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface
pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying
annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or
fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed
between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke.
This well does not have a functioning tubing sub-surface safety valve that could be utilized to facilitate BHA
deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may
be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams,
see attached BOP configuration). The annular preventer will act as a secondary containment during deployment
and not as a stripper.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure
measurements while drilling and shale behavior. The following scenario is expected for MPB-22A:
• Latest Reservoir pressure in the parent well: 2,725 psi at 7000' TVDSS, 7.5 ppg EMW.
• Expected range of pressures as the lateral is drilled 2,500-3,000 psi. (6.9-8.2 ppg).
• Maximum possible pressure encountered while drilling the lateral is 3.600 psi (9.9 ppg).
• Expected annular friction losses while circulating: 936 psi at KOP and 1160 psi at TD (assuming 90 psi/ft, for
a 2500' lateral).
• Planned mud density: 8.6 ppg equates to 3,076 psi hydrostatic pressure at the window.
• While circulating 8.6 ppg fluid, at the start of the lateral, the bottom hole circulating pressure is estimated to
be 4,012 psi or 11.0 ppg ECD.
• When circulation is stopped, a minimum of 936 psi surface pressure will be applied to maintain a constant
BHP of 11.0 ppg eq.
At the start of the lateral, the mud in the rig pits will be KWF based on the pressures in the parent wellbore. A
separate volume of a second KWF will be stored on location in upright tanks. The tankage will contain 2 wellbore
volumes of KWF weighted up to exceed the maximum possible BHP to be encountered as the lateral is drilled.
•
CTD Sidetrack Summary
C~
Pre-CT Rig Work: The pre CTD work is slated to begin about November 15, 2008.
1. MIT-IA.
2. PPPOT-T
3. Slickline tag PBTD at 10,500 ft to confirm volume of cement required.
4. Dummy off all GLM's.
5. Punch tailpipe at 10,385-87 (2 ft, 4 SPF).
6. Lay 17 ppg cement, minimum 7 bbls, to shut-off perfs and provide for a cement ramp window.
7. MIT-T
8. Pull wellhouse, bleed remove and blind flowlines.
9. Drill mousehole extension ~ ~~r ~~~
Rig Sidetrack Operations: (Scheduled to begin on December 15, 2008 using Nordic rig 2)
1. MIRU Nordic Rig 2
2. NU 7-1116" CT Drilling BOPE and test.
3. Mill 2.74" pilot hole in cement, and cement ramp for window.
4. nnm z.i4° winaow in i° casing.
5. Drill build/turn section with 2.70" x 3.0" bicenter bit, and land well.
6. Drill lateral section to 12,875'. .
7. Flow check well and lay in KWF as needed.
8. Run and cement a 2-3/8" L-80 liner string.
9. Make a cleanout run with mill and motor.
10. Make a logging run with a memory SWS GR-CCL logging tool.
11. Perforate well.
12. Circulate well to KWF brine. FP well to 2000' with methanol.
13. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi.
14. RDMO Nordic 2.
Post-Rig Work:
1. Re-install wellhouse and FL's.
2. Pull BPV.
3. Run Live gas lift design.
4. POP well to a separator (1200' of perforations expected)
~-
~~ ~ ~v~~
Mud Program:
• Well kill: 8.4 ppg brine.
• Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling.
• There is a TRDP on this well, but it has failed and is locked out. KWF will be needed for running and
cementing liner. BHP will be measured prior to tripping to run liner and KWF adjusted as needed.
• Standby KWF. At the start of the well there will be 2 wellbore volumes of 10.0 ppg KWF on location in
upright tanks.
Disposal:
• All Class II drilling and completion fluids will go to Grind & Inject at DS 4, or to the KRU 1 R pad disposal
well.
• All Class II drilling solids will go to Grind & Inject at DS 4.
• All Class I wastes will go to Pad 3 for disposal.
Hole size: 2.70"x3.0" (bi-center bits used)
Casing Program: fully cemented liner
• 2-3/8", L-80 4.70# STL 10,345' and - 12,875' and
• A minimum of 9.5 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and TD
C~ 12,875', with 40% excess in the open hole interval)
• TOC planned at 10,345' (Top of Liner)
Existing casing/tubing~rmation
13-3/8", L-80 48#, Burst 1,730, collapse 740 psi
9-5/8", K-55, 36#, Burst 3,520, collapse 2,020 psi
7", L-80, 26#, Burst 7,240, collapse 5,410 psi
3-1/2", L-80, 9.3#, Burst 10,160, collapse 10,540 psi
Well Control:
• Two wellbore volumes of KW F (-250 bbls) will be on location at all times during drilling operations.
• BOP diagram is attached.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi.
• The annular preventer will be tested to 250 psi and 2500 psi.
Directional
• See attached directional plan. Maximum planned hole angle is 90.0 deg at 10,625'.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property -10,325 ft. (To planned perforations in new lateral)
• Distance to nearest well within pool -1,725' from MPE-26i to planned perforations in new lateral.
Logging
• MW D directional, Gamma Ray and Resistivity logs will be run over all of the open hole section
• Cased hole GR/CCL, logs will be run.
Hazards
• There is a close approach to one existing well beside the parent. That is well Kavearak Point 32-25.
This was an Ivishak exploration well drilled by Chevron in 1969. It has been P&A'd.
• The maximum recorded H2S level on MPB-22 is 17 ppm.
• The maximum recorded H2S level on MP B pad was 43 ppm on well MPB-03. (February 2003).
• Lost circulation risk is low.
Reservoir Pressure
• The reservoir pressure on MPB-22 was last recorded at 2,725 psi at 7,000' TVDSS on 2/27/2008. (7.5
ppg equivalent)
• Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,025 psi.
• As the well is drilled, isolated areas with greater or lesser pressure than that found in the parent wellbore
may be encountered. The expected range of pressures is 2,500-3,000. The maximum possible
pressure that could be encountered is 3,600 psi (9.9 ppg eq).
Greg Sarber
CTD Engineer
CC: Well File
Sondra Stewman/Terrie Hubble
TREE: 3lr~a"-5M FMC MPB-22A Proposed Completion
Md 3 1!2" Oa5 G!uidc union KB Elev. = S9' Nabors 27E
GL Elev. = 36' Nabors ~7E
WELLHEAD: 11' Sh1 FMC va 3 1'7'
H' BPV oroHe.
13 318", 48#, K-55 88~ I
BTRC
FfOP t~ 590'
MAX Foie Angle:
61 DEG ;~ fi37~
Cameo TRDP-IA-SSA SCSS'•: 1927
Nate: The Cameo TRDP-tA-SSA was
locked aut of service 6l251DD.
9 518", 36#, K-55 6349`
BTRC
3 1,7' , 9.3#. BTRS, L~0 TUBING
ORiFT ID: 2.8FiT
CAPACITY. O.C987 BBL'FT
7" . 26#, 1.89. BTRC Casing
DRIFT ID: G.151"
CAPACITY~;~jp:.02Fr4 tspt
Top 2 318" liner at 1Q3d5 -~~
Casing RA Tag 10219`
Baker `PBR' Seal Assy 13.00• ID> 10360`
Baker 'HB' Packer (z.ss• lot 10375'
Pert ~~-10385 for tall~fpe cementing --
Cameo 2.750 `D' nipple 10413`
W LEG t 04't 9'
WLEG (ELFAD}
17 PP9
cement
PERFORATION SUMMARY
{DIL Log dated J; 1
Zone Size SPF MD' TVD'
11K-t 5' 12 10428' - t 045d' 3873' - 8Aa9' ~ ~,
SiK-2 6' 12 10488' - 10518 ~ dSt14' - 8922'
1" x 3112" McMurray FMH~ w! BK latch
;~ and tvd d9
~~ 0 2198` 2111 ~ 30
9 31 '19` 2822' X17
8 1102' 3A20' S7
7 522' X1041' S9
6 6196' 4526' 61
5 7150' 5027` 55
4 7945` 5!182' S4
3 8709' 5926' S5
2 9504' 6377' S7
1 10331 ` 6832' 58
Cement Ramp Window
at 10,440`
2 318" Cemented Liner
12,875'
FIII tagged w! winelfne on 2!27108 at 10533' MD
FIeh:Calculated top of TCP 10526'
peTD ~ art 10628'
- r 2s a snow 10729'
DATE REV. sv c°"ta~rrs MILNE POINT UNIT
1!11105 Lee Hulme Convert drawing to Canvas WELL MPB-22
_. - API NO: 50-029-2'1509
BP EXPLORATION (AK)
BP Alaska
by
Baker Hughes INTEQ Planning Report
1NTEQ
----
~
Company: BP Amoco Date 10/22/2008 Time: 14:37:05 Page: 1
Field: Milne Point Co-ordmafe(NE) Reference: Well: MPB-22, True No rth
Site: M Pt B Pad Vertical (TVD) Reference: 26 :22 12/29/1985 00:00 59.0
Well: MPB-22 Section (VS) Reference: Well (O.OON,O.OOE,270. OOAzi)
Wellpath: Plan 5, MPB-22A Survey Calculation Method: Minimum Curvature Db: Sybase
', Field: Milne Point
North Slope
' UNITED STATES
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
~, Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007
Site: M Pt B Pad
TR-13-11
UNITED STATES :North Sl ope
Site Position: Northing: 6021548. 49 ft Latitude: 70 28 8.986 N I
From: Map Easting: 571775. 55 ft Longitude: 149 24 49.895 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 0.55 deg
Well: MPB-22 -_ Slot Name: 22
MPB-22 '
Well Position: +N/-S 1756.34 ft Northing: 6023308. 29 ft - Latitude: 70 28 26.259 N
+E/-W 384.34 ft Easting : 572142. 90 ft • Longitude: 149 24 38.595 W
Position Uncertainty: 0.00 ft
Wellpath: Plan 5, MPB-22A Drilled From: MPB-22
500292150901 Tie-on Depth: 10423.00 ft
Current Datum: 26:22 12/29/1985 00:00 Height 59. 00 ft Above System Datum: Mean Sea Level
!Magnetic Data: 11 /7/2005 Declination: 24.29 deg
i Field Strength: 57591 nT Mag Dip Angle: 80.92 deg I
Vertical Section: Depth From (TVD)
+N/-S
+E/-W Direction ~
ft
I ft ft deg
_
mo-
35.50 0.00 _
0.00 270.00
Plan: Plan #5 Date Composed: 11/7/2005
copy Mary's plan 5 Version: 8
Principal: Yes -
Tied-to: From
: Definitive Path
Targets
Map Map <---- Latitude ----> <--- Longitude --->
Name Description TVD +N/-S +E!-W Northing Easting Deg Min Sec Deg Min Sec
Dip. Dir. ft ft ft
ft ft
L_ - <=--- _
-- _ -
MPB-22A Polygon 59.00 -6914.24 -4645.57 6016350.00 567565.00 70 27 18.245 N 149 26 55.058 W '
-Polygonl 59.00 -6914.24 -4645.57 6016350.00 567565.00 70 27 18.245 N 149 26 55.058 W
-Polygon 2 59.00 -7122.00 -3847.47 6016150.00 568365.00 70 27 16.206 N 149 26 31.611 W
-Polygon 3 59.00 -7650.90 -2937.47 6015630.00 569280.00 70 27 11.009 N 149 26 4.874 W ',
-Polygon 4 59.00 -5560.16 -2467.14 6017725.00 569730.00 70 27 31.572 N 149 25 51.080 W 'i
I' MPB-22A Fault 1 59.00 -6703.24 -3713.40 6016570.00 568495.00 70 27 20.325 N 149 26 27.679 W
-Polygonl 59.00 -6703.24 -3713.40 6016570.00 568495.00 70 27 20.325 N 149 26 27.679 W
-Polygon 2 59.00 -7022.63 -3781.50 6016250.00 568430.00 70 27 17.184 N 149 26 29.675 W
MPB-22A Fault2 59.00 -6853.21 -4234.92 6016415.00 567975.00 70 27 18.848 N 149 26 42.997 W ~
-Polygon 1 59.00 -6853.21 -4234.92 6016415.00 567975.00 70 27 18.848 N 149 26 42.997 W i
-Polygon 2 59.00 -6593.39 -4212.40 6016675.00 567995.00 70 27 21.403 N 149 26 42.339 W
MPB-22A Fault 3 59.00 -6862.14 -5790.23 6016391.00 566420.00 70 27 18.750 N 149 27 28.684 W ',
-Polygon 1 59.00 -6862.14 -5790.23 6016391.00 566420.00 70 27 18.750 N 149 27 28.684 W '
-Polygon 2 59.00 -7423.28 -3720.38 6015850.00 568495.00 70 27 13.244 N 149 26 27.873 W
MPB-22A Fault4 59.00 -7802.60 -2763.92 6015480.00 569455.00 70 27 9.517 N 149 25 59.775 W
-Polygon 1 59.00 -7802.60 -2763.92 6015480.00 569455.00 70 27 9.517 N 149 25 59.775 W
-Polygon 2 59.00 -6335.88 -2404.65 6016950.00 569800.00 70 27 23.944 N 149 25 49.237 W
MPB-22A Fault 5 59.00 -5847.88 -4770.25 6017415.00 567430.00 70 27 28.732 N 149 26 58.741 W
-Polygonl 59.00 -5847.88 -4770.25 6017415.00 567430.00 70 27 28.732 N 149 26 58.741 W ',
-Polygon 2 59.00 -6702.43 -4828.54 6016560.00 567380.00 70 27 20.327 N 149 27 0.437 W
MPB-22A Target 1 6919.00 -7232.68 -3263.46 6016045.00 568950.00 70 27 15.120 N 149 26 14.455 W ~i
by ~ BP Alaska
Baker Hughes INTEQ Planning Report
Iltr
~i~vo+~es
1NTGQ
Company: __
BP Amoco _-
Date: - -
10/22/2008 Time:
__
14:37:05 Page: 2
Field: Milne Point Co-ordinBte~NE) Reference: Well: MPB-22, True North
Site: M Pt B Pad Vertical (TVD) Reference: 26 :22 1 2/29/1 985 00:00 59.0
WeIL• MPB-22 Section (VS)Reference: Well (O.OON,O.OOE,270.OOAzi)
Wellpath: Plan 5; MPB-22A Survey Calculation Method: Mi nimum Curvature Db: Sybase
Targets
Map Map o---- Latitude ----> <--- Longitude ---s
Name Description TVD +N/-S +FJ-W Northing Fasting Deg Min Sec Deg Min Sec
Dip..... Dir. ft ft ft ft ft
MPB-22A Target 3 6939.00 -6835.8 7 -3959.72 6016435.00 568250.00 70 27 19.020 N 149 26 34.913 W
', MPB-22A Target 4
I 7014.00 -6782.3 3 -4324.25 6016485.00 567885.00 70 27 19.544 N 149 26 45.622 W
I
MPB-22A Target 2 7024.00 -6948.64 -3675.77 6016325.00 568535.00 70 27 17.912 N 149 26 26.570 W
!~ MPB-22A Target 5 7059.00 -6729.62 -4603.78 6016535.00 567605.00 70 27 20.061 N 149 26 53.834 W '
Annotation
MD TVD
'. ft ft
,10423.00 6871.63 TIP i
!; 10440.00 6880.53 KOP
i 10454.00 6887.26 End of 40 Deg/100' DLS
10600.26 6919.87 4
10785.26 6919.87 5
11385.26 6919.87 6 i
11535.26
6919.87
End of 18 Deg/100' DLS i
11685.26 6921.10 8
11895.26 6924.39 9
11985.26 6926.28 10
i 12195.26 6938.97 11
' 12275.26 6949.06 12
' 12425.26 6979.07 13
12575.26 7013.98 14
12725.26 7042.05 15
12875.26 7059.61 TD _ _ _ _~
Plan Section Information _ __
MD Incl Azim TVD +N/-S +FJ-W DLS Build Turn TFO Target
ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg
10423.00 58.50 204.00 6871.63 -6498.95 -2858.45 0.00 0.00 0.00 0.00 ~',
10440.00 58.42 204.17 6880.53 -6512.18 -2864.36 0.97 -0.47 1.00 118.95
i 10454.00 64.02 204.17 6887.26 -6523.37 -2869.38 40.00 40.00 0.00 0.00
~ 10600.26 90.00 199.75 6919.87 -6654.49 -2921.95 18.00 17.76 -3.02 350.00
10785.26 90.00 166.45 6919.87 -6836.63 -2931.82 18.00 0.00 -18.00 270.00
11385.26 90.00 274.45 6919.87 -7228.54 -3265.99 18.00 0.00 18.00 90.00
11535.26 90.00 301.45 6919.87 -7182.73 -3407.37 18.00 0.00 18.00 90.00
11685.26 89.07 319.43 6921.10 -7085.83 -3521.06 12.00 -0.62 11.98 93.00
11895.26 89.16 294.23 6924.39 -6960.98 -3687.78 12.00 0.04 -12.00 270.00
11985.26 88.43 305.00 6926.28 -6916.58 -3765.89 12.00 -0.82 11.97 94.00
12195.26 84.76 280.02 6938.97 -6836.88 -3957.93 12.00 -1.75 -11.90 261.00
12275.26 80.77 271.22 6949.06 -6829.09 -4036.81 12.00 -4.98 -11.01 245.00
12425.26 76.32 289.02 6979.07 -6803.57 -4180.91 12.00 -2.97 11.87 106.00 ~~
~~ 12575.26 77.00 270.53 7013.98 -6778.94 -4324.05 12.00 0.45 -12.33 270.00
12725.26 81.59 288.25 7042.05 -6754.84 -4468.78 12.00 3.06 11.81 77.00
'
12875.26 85.07 270.46 7059.61 -6730.81 -4615.17 12.00 2.32 -11.86 280.00
'I
~ BP Alaska
by
Baker Hughes INTEQ Planning Report
Company: _ ---
BP Amoco
! Field: Milne Point
Site: M Pt B Pad
(( WeIL• MPB-22
I Wel-path: Plan 5, MPB-22A
Survey
-- ----_
Date: 10/22!2008 Time: 14:37:05 Page: 3
Co-ordinate(NE) Reference: Well: MPB-22, True North i
Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59.0
Section (VS) Reference: Well (O.OON,O.OOE,270.OOAzi)
Survey Calculation Method: Minimum Curvature Db: Sybase
NID Inc! Azim
ft deg deg
i 10423.00 58.50 204.00
10425.00 58.49 204.02
10440.00 58.42 204.17
10450.00 62.42 204.17
10454.00 64.02 204.17
---
SS TVD N/S
ft ft
6812.63 -6498.95
6813.68 -6500.51
6821.53 -6512.18
6826.46 -6520.11
6828.26 -6523.37
10475.00 67.74 203.46 6836.84 -6540.90
10500.00 72.18 202.66 6845.41 -6562.51
10525.00 76.62 201.91 6852.13 -6584.78
10550.00 81.06 201.18 6856.96 -6607.59
10575.00 85.51 200.46 6859.88 -6630.79
10600.00 89.95 199.76 6860.87 -6654.24
10625.00 90.00 195.30 6860.87 -6678.07
10650.00 90.00 190.80 6860.87 -6702.42
10675.00 90.00 186.30 6860.87 -6727.14
10700.00 90.00 181.80 6860.87 -6752.07
10725.00 90.00 177.30 6860.87 -6777.06
10750.00 90.00 172.80 6860.87 -6801.96
10775.00 90.00 168.30 6860.87 -6826.62
10785.26 90.00 166.45 6860.87 -6836.63
10800.00 90.00 169.11 6860.87 -6851.03
10825.00 90.00 173.61 6860.87 -6875.74
10850.00 90.00 178.11 6860.87 -6900.67
10875.00 90.00 182.61 6860.87 -6925.66
10900.00 90.00 187.11 6860.87 -6950.57
10925.00 90.00 191.61 6860.87 -6975.23
10950.00 90.00 196.11 6860.87 -6999.50
10975.00 90.00 200.61 6860.87 -7023.22
11000.00 90.00 205.11 6860.87 -7046.25
11025.00 90.00 209.61 6860.87 -7068.45
11050.00 90.00 214.11 6860.87 -7089.68
11075.00 90.00 218.61 6860.87 -7109.80
11100.00 90.00 223.11 6860.87 -7128.71
11125.00 90.00 227.61 6860.87 -7146.27
11150.00 90.00 232.11 6860.87 -7162.38
11175.00 90.00 236.61 6860.87 -7176.95
11200.00 90.00 241.11 6860.87 -7189.88
11225.00 90.00 245.61 6860.87 -7201.08
11250.00 90.00 250.11 6860.87 -7210.51
11275.00 90.00 254.61 6860.87 -7218.08
11300.00 90.00 259.11 6860.87 -7223.76
11325.00 90.00 263.61 6860.87 -7227.52
11350.00 90.00 268.11 6860.87 -7229.33
11375.00 90.00 272.61 6860.87 -7229.17
11385.26 90.00 274.45 6860.87 -7228.54
11400.00 90.00 277.11 6860.87 -7227.06
11425.00 90.00 281.61 6860.87 -7222.99
11450.00 90.00 286.11 6860.87 -7217.01
11475.00 90.00 290.61 6860.87 -7209.14
11500.00 90.00 295.11 6860.87 -7199.43
11525.00 90.00 299.61 6860.87 -7187.94
11535.26 90.00 301.45 6860.87 -7182.73
11550.00 89.91 303.22 6860.89 -7174.85
11575.00 89.75 306.22 6860.96 -7160.61
E/W - 1VIapN MapE DLS VS TFO 'fool
ft ft ft deg/100ft ft deg
-2858.45 6016782.55 569347.84 0. 00 2858.45 0.00 MW D ~~,
-2859.14 6016780.98 569347.17 0. 97 2859.14 118.95 MWD
-2864.36 6016769.26 569342.06 0. 97 2864.36 118.94 MWD I
-2867.92 6016761.30 569338.58 40. 00 2867.92 360.00 MWD'',
-2869.38 6016758.03 569337.15 40. 00 2869.38 0.00 MWDI
-2877.12 6016740.42 569329.58 18. 00 2877.12 350.00 MWD'.
-2886.32 6016718.73 569320.60 18. 00 2886.32 350.29 MWD
-2895.44 6016696.37 569311.69 18. 00 2895.45 350.56 MWD
-2904.45 6016673.48 569302.91 18. 00 2904.45 350.77 MWD
-2913.27 6016650.19 569294.31 18. 00 2913.27 350.91 MWD
-2921.86 6016626.66 569285.95 18. 00 2921.86 350.99 MWD
-2929.39 6016602.76 569278.65 17. 84 2929.39 270.60 MWD
04
-2935 6016578
36 569273.24 18. 00 2935.04 270.00 MWD
.
-2938.75 .
6016553.62 569269.76 18. 00 2938.75 270.00 MWD
-2940.52 6016528.67 569268.24 18. 00 2940.52 270.00 MWD
-2940.32 6016503.68 569268.68 18. 00 2940.32 270.00 MWD i
-2938.17 6016478.81 569271.08 18. 00 2938.17 270.00 MWD',
-2934.06 6016454.20 569275.42 18. 00 2934.06 270.00 MWD':.
-2931.82 6016444.21 569277.76 18. 00 2931.82 270.00 MWD',
-2928.70 6016429.84 569281.02 18. 00 2928.70 90.00 MWDI,
-2924.94 6016405.17 569285.01 18. 00 2924.94 90.00 MWD
-2923.14 6016380.26 569287.06 18. 00 2923.14 90.00 MWD
-2923.29 6016355.27 569287.15 18. 00 2923.29 90.00 MWD
-2925.41 6016330.35 569285.27 18. 00 2925.41 90.00 MWD
-2929.47 6016305.65 569281.45 18. 00 2929.47 90.00 MWD
-2935.46 6016281.33 569275.70 18. 00 2935.46 90.00 MWD
-2943.33 6016257.53 569268.06 18. 00 2943.33 90.00 MWD
-2953.04 6016234.41 569258.58 18. 00 2953.04 90.00 MWD'.
-2964.52 6016212.11 569247.31 18 .00 2964.52 90.00 MWD.
-2977.71 6016190.75 569234.32 18 .00 2977.71 90.00 MWD,
I
-2992.53 6016170.48 569219.70 18 .00 2992.53 90.00 MW D
I
-3008.88 6016151.42 569203.54 18 .00 3008.88 90.00 MWD
-3026.66 6016133.69 569185.93 18 .00 3026.66 90.00 MWD
-3045.77 6016117.39 569166.98 18 .00 3045.77 90.00 MWD
-3066.08 6016102.63 569146.82 18 .00 3066.08 90.00 MWD
-3087.47 6016089.50 569125.55 18 .00 3087.47 90.00 MW D ~I
-3109.81 6016078.08 569103.33 18 .00 3109.81 90.00 MWD;
-3132.96 6016068.43 569080.27 18 .00 3132.96 90.00 MWDI .
-3156.78 6016060.63 569056.53 18 .00 3156.78 90.00 MWD
-3181.12 6016054.71 569032.25 18 .00 3181.12 90.00 MWD ''
-3205.83 6016050.71 569007.58 18 .00 3205.83 90.00 MWD
-3230.75 6016048.67 568982.67 18 .00 3230.75 90.00 MWD
-3255.75 6016048.58 568957.68 18 .00 3255.75 90.00 MW D
-3265.99 6016049.11 568947.43 18 .00 3265.99 90.00 MWD .
~
-3280.65 6016050.45 568932.76 18 .00 3280.65 90.00 MW D '.
-3305.31 6016054.28 568908.06 18 .00 3305.31 90.00 MWD
-3329.58 6016060.03 568883.74 18 .00 3329.58 90.00 MWD
-3353.30 6016067.67 568859.95 18 .00 3353.30 90.00 MWD
-3376.33 6016077.15 568836.83 18 .00 3376.33 90.00 MWD
-3398.53 6016088.42 568814.52 18 .00 3398.53 90.00 MWD
-3407.37 6016093.55 568805.63 18 .00 3407.37 90.00 MWD
-3419.82 6016101.31 568793.10 12 .00 3419.82 93.00 MWD
-3440.37 6016115.34 568772.42 12 .00 3440.37 93.00 MWD
by ~' BP Alaska
Baker Hughes INTEQ Planning Report uvTE
Q
Company: BP Amoco Date: 10/22!2008 Time: 14:3 7:05 Page: 4
Field:.. Mil ne Point Co-ortlinate(NE) Reference: Well: MPB-22, Tru e North
Site: M Pt B Pad Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59.0
Well: MP B-22 Section (VS)Reference: Well (O. OON,O.OOE,270.OOA zi)
Wellpath: Pla n 5, MPB- 22A Survey Calculation Method: Minimu m Curvatu re Dh: Sybase
Survey
-
MD
Inc!
Azim
SS TVD - --
N/S - ---
E/W
MapN
NIapE
DLS
VS
TFO
Took
ft .deg deg. ft ft ft ft ft deg/100ft ft deg
11600.00 89.59 309.21 6861.10 -7145.32 -3460.14 6016130.44 568752.50 12.00 3460.14 92.99 MW D ~I
11625.00 89.44 312.21 6861.31 -7129.02 -3479.09 6016146.56 568733.40 12.00 3479.09 92.97 MWD',
j 11650.00 89.29 315.20 6861.59 -7111.75 -3497.16 6016163.65 568715.16 12.00 3497.16 92.95 MWD
11675.00 89.13 318.20 6861.94 -7093.56 -3514.30 6016181.67 568697.85 12.00 3514.30 92.91 MWD,
11685.26 89.07 319.43 6862.10 -7085.83 -3521.06 6016189.33 568691.02 12.00 3521.06 92.87 MWD
11700.00 89.07 317.66 6862.34 -7074.79 -3530.81 6016200.28 568681.16 12.00 3530.81 270.00 MWD
11725.00 89.08 314.66 6862.74 -7056.76 -3548.12 6016218.13 568663.67 12.00 3548.12 270.03 MWD
11750.00 89.08 311.66 6863.14 -7039.66 -3566.36 6016235.05 568645.28 12.00 3566.36 270.08 MWD
11775.00 89.09 308.66 6863.54 -7023.54 -3585.46 6016250.98 568626.02 12.00 3585.46 270.13 MWD
~ 11800.00 89.10 305.66 6863.94 -7008.45 -3605.38 6016265.88 568605.96 12.00 3605.38 270.17 MWD
11825.00 89.11 302.66 6864.33 -6994.41 -3626.06 6016279.72 568585.15 12.00 3626.06 270.22 MW D
I 11850.00 89.13 299.66 6864.71 -6981.48 -3647.45 6016292.44 568563.64 12.00 3647.45 270.27 MWD
11875.00 89.15 296.66 6865.09 -6969.69 -3669.48 6016304.02 568541.49 12.00 3669.48 270.31 MW D
11895.26 89.16 294.23 6865.39 -6960.98 -3687.78 6016312.54 568523.11 12.00 3687.78 270.36 MW D
11900.00 89.12 294.79 6865.46 -6959.02 -3692.09 6016314.47 568518.78 12.00 3692.09 94.00 MWD
11925.00 88.91 297.79 6865.88 -6947.95 -3714.49 6016325.32 568496.27 12.00 3714.50 93.99 MW D ~,
11950.00 88.71 300.78 6866.40 -6935.72 -3736.29 6016337.33 568474.36 12.00 3736.29 93.94 MWD'i
11975.00 88.51 303.78 6867.01 -6922.38 -3757.42 6016350.47 568453.10 12.00 3757.42 93.88 MWD',
11985.26 88.43 305.00 6867.28 -6916.58 -3765.89 6016356.18 568444.59 12.00 3765.89 93.81 MWD',
12000.00 88.15 303.26 6867.72 -6908.32 -3778.08 6016364.33 568432.31 12.00 3778.08 261.00 MWD'
12025.00 87.69 300.29 6868.63 -6895.16 -3799.32 6016377.27 568410.95 12.00 3799.32 261.05 MWD'
12050.00
' 87.23 297.32 6869.74 -6883.13 -3821.20 6016389.09 568388.96 12.00 3821.20 261.16 MWD;
~
12075.00
86.78
294.35
6871.05
-6872.25
-3843.67
6016399.75
568366.39
12.00
3843.67
261.29
MWD'.
12100.00 86.34 291.38 6872.55 -6862.55 -3866.66 6016409.23 568343.30 12.00 3866.66 261.45 MWD',
12125.00 85.91 288.40 6874.24 -6854.07 -3890.11 6016417.48 568319.77 12.00 3890.11 261.63 MWD:.
12150.00 85.49 285.43 6876.12 -6846.81 -3913.96 6016424.50 568295.86 12.00 3913.96 261.83 MWD I
12175.00 85.08 282.44 6878.17 -6840.82 -3938.14 6016430.27 568271.62 12.00 3938.14 262.05 MWD
12195.26 84.76 280.02 6879.97 -6836.88 -3957.93 6016434.01 568251.80 12.00 3957.93 262.30 MW D
12200.00 84.51 279.51 6880.41 -6836.08 -3962.58 6016434.76 568247.14 12.00 3962.58 245.00 MWD
12225.00 83.26 276.77 6883.08 -6832.56 -3987.18 6016438.04 568222.50 12.00 3987.18 245.05 MWD
12250.00 82.01 274.02 6886.28 -6830.23 -4011.86 6016440.13 568197.80 12.00 4011.86 245.34 MWD
12275.00 80.79 271.25 6890.02 -6829.10 -4036.55 6016441.03 568173.11 12.00 4036.55 245.69 MWD
12300.00 79.97 274.11 6894.20 -6827.96 -4061.17 6016441.93 568148.48 11.78 4061.17 106.39 MWD
i 12325.00 79.18 277.06 6898.73 -6825.57 -4085.64 6016444.08 568123.99 12.00 4085.64 105.52 MWD
12350.00 78.42 280.02 6903.58 -6821.93 -4109.89 6016447.49 568099.71 12.00 4109.89 104.98 MWD
12375.00 77.69 282.99 6908.76 -6817.05 -4133.85 6016452.13 568075.70 12.00 4133.85 104.41 MWD
12400.00 76.99 285.98 6914.24 -6810.95 -4157.47 6016458.00 568052.03 12.00 4157.47 103.79 MWD
12425.00 76.32 288.99 6920.01 -6803.65 -4180.67 6016465.08 568028.77 12.00 4180.67 103.14 MWD
12450.00 76.34 285.96 6925.92 -6796.34 -4203.83 6016472.16 568005.54 11.75 4203.83 269.88 MWD
12475.00 76.39 282.88 6931.82 -6790.29 -4227.36 6016477.98 567981.96 12.00 4227.36 270.72 MWD
12500.00 76.49 279.79 6937.68 -6785.52 -4251.18 6016482.52 567958.09 12.00 4251.18 271.45 MWD,
~~, 12525.00
76.62
276.71
6943.50
-6782.03
-4275.24
6016485.78
567934.00
12.00
4275.24
272.17 ,
MWD
12550.00 76.79 273.63 6949.25 -6779.84 -4299.47 6016487.74 567909.75 12.00 4299.47 272.89 MWD
12575.00 77.00 270.56 6954.92 -6778.95 -4323.80 6016488.39 567885.42 12.00 4323.80 273.60 MWD,
12575.37 77.00 270.53 6955.00 -6778.94 -4324.16 6016488.39 567885.06 8.49 4324.16 274.30 MPB-2 A
12600.00 77.68 273.49 6960.40 -6778.10 -4348.17 6016489.00 567861.04 12.05 4348.17 77.00 MWD',
12622.14 78.32 276.12 6965.00 -6776.28 -4369.75 6016490.61 567839.45 12.00 4369.75 76.35 MPB-?~ A
12625.00 78.41 276.46 6965.58 -6775.97 -4372.54 6016490.89 567836.66 12.00 4372.54 75.80 MWD
12650.00 79.16 279.42 6970.44 -6772.58 -4396.82 6016494.04 567812.34 12.00 4396.82 75.73 MWD
12675.00 79.94 282.37 6974.98 -6767.94 -4420.96 6016498.46 567788.16 12.00 4420.96 75.16 MWD
12700.00 80.75 285.30 6979.17 -6762.04 -4444.89 6016504.12 567764.18 12.00 4444.89 74.62 MWD
12725.00
i 81.58 288.22 6983.01 -6754.92 -4468.54 6016511.01 567740.47 12.00 4468.54 74.13 MWD !i
--
-/.~l'~
by BP Alaska
Baker Hughes INTEQ Planning Report 1NTE
Q
Compam: BP Amoco Date: 10/22/2008 Time: 14:37:05 Page: 5
Field: Milne Point Co-ordinake(NE) Reference: Well: MPB-22, True North i
Site: M Pt B Pad Vertical (T~D),Reference: 26:22 12/29!1985 00:00 59.0
~ We{{: MPB-22 Section (VS);Reference: Well (O.OON,O.OOE,270.OOAzi) ~
Wel{path: Plan 5, MPB-22A Survey Calculation Method: Minimum Curvature Db: Sybase
Survey
MD Inc! Az{m SS TVD N/S E/W MapN MapE DLS V5 TFO Too
ft deg deg ft ft ft ft 8 deg/100ft ft deg
12750.00 82.12
285.30
6986.55
-6747.77 ----
-4492 23 6016517.93 -
567716.71 11.76 4492.23
280.28
MWD
12775.00 82.67 282.32 6989.86 -6741.86 -451629 6016523.61 567692.59 12.00 4516.29 280.42 MWD
12800.00 83.24 279.35 6992.93 -6737.20 -4540.65 6016528.03 567668.19 12.00 4540.65 280.81 MWD
12825.00 83.83 276.39 6995.74 -6733.79 -4565.26 6016531.20 567643.55 12.00 4565.26 281.18 MWD
12850.00 84.44 273.44 6998.30 -6731.66 -4590.03 6016533.09 567618.76 12.00 4590.03 281.51 MWD
• 12875.00 85.06 270.49 7000.58 -6730.81 -4614.91 6016533.70 567593.88 12.00 4614.91 281.81 MWD
BP Alaska
wEUr~rx oer~uu
mopx~~n aa~i
V Tx. an MD. tOUa.oo
ReL Ww~e. M:3]12YBMYBS OOOO Sa.0011
LEGEND
- - MPB-T2 (MPB-22J
Plan 5, MPB-2TA
Plan NS
by
cam imamaoa~.
~. ien»~nrssro
Eman. Osm,cnae4m®Inbp.can
i
A
O
a
a
b
LEGEND
KAVEP
R32
25
KAVEAR32
25 T Plan: Plan #5 (MPB-22/Plan 5, MPB-22A)
BP Alaska .
-
(
-
1
Bombatlill (Plan Bombatlill)
Brea (Plan Bree)
Dale (Plan Ddle)
- MP8-01 (MPB-01)
~ ~
~
~ M
A2imnNS to Trua NoM
Magnelc NOr16. 24.29'
Magnelk FieIE
Sven
1M1
5]591nT Crealetl By BP
Checked: Dale: 10/2212008
Dale:
WELIPwTN DETwIL+ -- MPB-02 (MPB-02) 9
.
DiD Angle: 8092° 'on~acl In or
u
~i
Pl+n s MPs-YL
i
MPB-02 (Plan MPB-02A1
MPB
03
MPB
03
Data:lt!]I2005
M
tl
l
6
200]
~
6iY Mich
xalaon
Yo011
2~S0Y01 (
-
)
-
MPB-04A (MPB-04AJ ~`
TL+\ 1 o
e
:
ggm CeN f90'113Ct~~/~
•+ron<W+IIYUtk: YP0.32
T.. +:r xo: so42s
ou MPB-04 (MPB-04) \C Ei»an M1nl n:icl:.,..i,. ~..~-~.:.i..,......
. MPB-05 (MP8-05)
Wx. p+lume YY .3]1]139/xM3OOUO SY.0011 MPB-05 (MPB-OSA)
MPB-06 (MPB-O6)
V.Mc<c+:r ~~Y 1
w:pJ+ ~Wi ~~w From T~lo MPB-07 (MPB-07)
MP8-08 (MPB-08)
- MPB-08 (Plan MPB-08A)
no.ao o.oo o.os as.so MPB-09 (MPB-09)
-
REFERENCE INFORMATION MPB-10 (MPB-101
MPB-11 (MPB-11)
MPB-12 (MPB-121
Co-ordinate (N/E) Reference: Well Centre: MP8-22, True NorBJ -' MPB-13 (MPB-13)
Vertical (TVD Reference: 2fi : 22 12/29/1985 00'00 59.D0
~ MPB-14 (MPB-14)
Seclien (VS
Reference: Slot-22 (0.00N,O.OOE) --- MPB-15 (MPB-15)
Measured Depth Reference: 26:22 12129/1985 00:00 59.00
Calculation Method'. Minimum Curvawre MPB-16 (MPB-161
MPB-17 (MPB-1 ])
MPB-18 (MP8-18)
sY ru MPB-19 (MPB-19)
MPB-20 (MPB-20)
Y.. x ro ul rvo .wa . oi.a n.o. +.+ T+rsu MPB-21 (MPB-21)
MPB-21 (MP8-21PB1)
MPB-22 (MP8-22)
MPB-23 (MPB-23)
- MP8-241MPB-24)
--- MP8-25 (MPB-25)
MPB-27 IMPB-27)
MP8-501MP8-50)
MPCFP-1 (MPCFP-1)
MPCFP-2A (MPCFP-2A)
~~--- MPCFP-2 (MPCFP-2)
--- %an 5, MPB-22A
t4 fxYxvY Ys.4T n4.4a ]ssssi ano.Y+ a4v.rT taas aso.44 44YS..T Plan #5
\ 150
7
-5000 - MPCFP•2A (MPCFP•2A~
MPCFP-2 MPCFP-2
/ ~ ~.
t -'
MPB-75
MP8.15
.... ._, .. .. ~
.
.
I
'
~
- ./
-
T +~{
I t~
~
~
4
-
I
r t
i I
F Y _r~ ~_- t _1- {
1 l ~
~
' -
-
~ 1 -
-5200
1T a I. .~ 1. . i 1...
tT ... _
1_ } .rJ_ ~ :: MPCFP.1 MPCFP-1
I z
I r
~:
~~i,:
~
t
{ k
~ ~s__
1
~4
r .
T~.- T
~
T :
r ;
~ _.
-5600- :-
.
i
I :.. T
-..
'~ -
_
{
_ --± r .
-.. I-:, r {
j
~ .,
..
60
i' 69 X50
X900 j1.__ T
_.
~' l l
1~
t
_
'
n t
_ - ~ _..
TT
r
J :
_.
-sfioo-
~
f - ~ +1~ 1
. -
~
{
f
r }- t f 1
r ,~. -
70Y19ooo
7B56FOSO .
'-
a~.~. ...
-
.:
'
r } f't-'t_t 1 t -:, 1- r ' I' ~ ]150 MPB-21 (MPB-21PB1)
C i_J_ ~-rl ~"1 - 7200
a 620o I
G 1 { t -F..~
~
~
~ L ~ -
1
- /
__
' MPB-2~1 MPB-271
I l r
1~
~ -6400 H ,_
~ -
B .
~
I
~l
..~
l r ~ rY + -
I ..-~4 i ~
1 I
.••. _ r { t 1~
.,
. KAVEAR32-25 KAV FAR32-25 1 .
..
-( _'..
t ~ ~-r TT
1
J ~
.
t - -.' 1 T T 1 ~
~. - ~
~ ,. _
--
Plan 5. MPB•22A ~ 705 f~
MPB-22 (MPB-22)~V///70
0 7050 _
.,
r _ .~ { ~~~~T -
~ ~ -
~'~~- f
~ l i" _ T
, ~ ~~
[
6800
_
O 6850 ~ 1
..
T.
1t
1 ' ~
'...- _ i- ~
f~1 f 1-_-I Jt
r+}
~ _
~ 1 ~
{ } ,
_ I '
~ 1
.' I
o
r 3 *~ - ~ 1
- t ~
~
-
T
i aooo _ ~ 1....
p _ C j.
T
~ -
F t
~
~
-
1A -7200 1
.. ,~ -
~ r ~
T Yt 1
{ ..
I ~ r -T 1 I
-7aoo
?_
~ ~ 1 r ~ -..-_ +~ ~_
i_
~
f_
,_ .. -_,. ~~. ~ .. ~ {{
. 1 1 ~. -~ -I- ..
~
_ ....T... _1 1
i 1 +
+
y
-7600 -_
_ _ t
F
,
t ~ ~
-
~
T
I ' - _
~ _
•.'
1 N -- J
'
~
~ ~ I-
r~
t 1 1
-. ri-,
- ~-YF JY--~
~~ ~
T1~ 1~.
J
~ ~
t f '-Y t 7~ t
1.
-7800 -
F' S- ~
1
_ ~ _:
i i. 1 1 ,1
. j-- 1 ~1- ~r } 1...
1..
~
fi
~
-_
Y
I J~ ..
T t+-{. _
I f t t
_
_
J --F 1.
__
r ~
+} ..
- 1#_.-~
_. .....
; ~. ~.
l-
y
J
A
T
-
-
.__
J_1. T t l
J
{ ~-
-'
t
__ -
~ ~ ~ ~
.-.....__._ F
h
~
r i i
~
~ ~
r (~ ~~ -
-8000
?- r-
r" lY ~~- ~
t }__
-
~ ~ I
Tr
T- I 1... _ .I_
1~ _ --__~}ref
~ -~7
Tr_t
1-T~ i:
Y
' tl i.ri
t 1
~
1
I
~
I
I
1
~ { y7-fi1 I 4 - i ~ t+-1 t- {I '{}. 1 r
~ ~
_
.
.
1
_r.
' - - '. ,
. ~,. -1
k -
_4
~~ ~r. TI
~~~ '1-.. fTT
' _
..
_
1.1
,..~~1 _t- ,
1
-
I
Y~
-
~y
:'.. ~..- ~ If~_ : _. '1_. ~l
i {.
-- ._+_ ~.
. '~ 1'
~,
~
...
T ~
:
-
I
eaoo j -. 1
...
i
'
- _. _ . ..
~ _
~
_
--~-
-
-
-
'
-
--
-
-~
-
-
~
~
~~ ~ ~
~
~
^
-
'-
-
-
-
-
-
--
-
-rT-
_
r r)
-Try
r
n
r
rr
T
T^T
?
l n
~
r -:
r
1
-
r
~
r)
~
1
T
r
-r--T
TtTTT-r-Tr,T
TT ~ t ~TT~*~^ TTTTTTT'Yr~
1T ~,
T 1-T
r~
-7fi - - - - - - DO -3400 -3200 -3000 -2800 2600 -24D0 -220D -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200
00 7400 -7200 -7000 -6800 E600 -6400 6200 -6000 -5800 5600 0 5200 -S000r -0800 ~60D -0400 2~ 00 -4000 3800 3fi T„
^
Tr
~~-
I 1
0 200
West(-)IEast(+) [200ft/in]
WtLI. DRTAILS ANTI-CULI.ISIUN SRTTINGS COMPANY Uh:I'AIIS SURVEY PROGRAM WF.LLPATII UI:TAl1.S
Nance ~N/-5 "Pl-W N.rMulg toting altitude I.ungiwda Slw Inmrpulalinn MelhWMD hlR~rval: SU.W UP Amucu Upllrlm UryUl to Snrvcy/Plen "fwl Plan S. MYR--??A
Depth Range Frum: 10423 W Tu: 12X]5.?( 51x1292150901
MPR-2?1756.34 ]X4.14 W'_310R2Y 5]3143.10 )0"'%'26.25YN 14Y"29'JN.595W __ Maximum RanNC: 14N].9N Refcrcnlc: Plan: Plau kS Calculaliun Mvdmd: Minin um C'wvumre 104?3W I?x)5.?6 Pla~med'. Plar .YS VY MWU
Lrrur System: ISCW SA Pwurl Wellpath: MYU--~~
Satin Methal: Iruv CyliMer NaM 1 ie au:NU: IU4?31X1
Lrrur Swfare: UIIiPlical-Casing
Wumiux McWlxl: RW~~x dead Rig: Nurdia?
Rcf Uamm: 26:?? 12/29/14x5 W W 54 u01i
-- - V.S<w~riun Origin Origin Slartiug
AnNlc -N/-S -1/-W Prum'fVU
~~ 2JO.W" 0.W II.IIU }S.SU
IYS ' , - 19>---_
INU / / ~ ~--- -1 ~\ \ KAVFAR3~ 251KAVFAR3 ). M jur Riak
I]7 // -.~ y} - \ \ , ' Bmnhadill (Plea B had II) M j rRisk
\\ BRC (Plus Brc<) M } R k
/~- DalelPlul Dale)MJ Rk
165 165 MPH 01 [MPH 01)MJ R'k
MPB 0' (MPB U2) M) R sk
ISx /j / ~ ~_~ h5% ~ ~ \ ~ MPB U>(PIur MPBU A) Mvjur Risk
rv ~ ~ ~ MPR UJ (MPB tl3) M J R sk
150 ~ ~ ~g //~ - -- _.I Sfr-~~
MPB U4A (MPB 04A) M J Risk
~{ ~ -- - \ \.\ MPR U4 (MPB (b) M 3 k k
l4J 1 ~ - - W ~ -\ MPR 051MPR lUl M } R 'k
135 / / / S .2'-1 - 433 \ ~~ ~ ~ ~ MPH 05 (MPB lISA) M J R 'k
~ / ~ q -^ MQ9 ~ \ MPB 00 (MPB W)MJ R-k
12% 10$32 / 0' 2 k - 1 x ~ ~ \ - MPB U71MPB U7) M J R -k
1)U ~'/ _~~ ~/ ~C i __` \ \\\\ MPB %(PIa tlMPR%A) M~juRi+k
Ill % ~ ~ - IF. - \~ \ \~\ MPB U9 lMP8 (19) MJ R k
MPR IU (M PB 1(11 M J R -k
~j ~ / / ~~ ~ MPB II IMPB 11) M } R'k
IIIS ~ f _~ Qla~ ~ _\ ~ ~ MPB I)1M P8121 MJ R'k
~~ _ ~ --- MPR Ii1MPB IJ) MI R' k
/ j /~ j/ / / / ~- \\. ~ MPR 14 (MPB 14) M J R'-k
1 // ~p _ MPB I (MPB I>I MJ R'k
i
x3 ~ b3 ~ \~ ~\ ~\ MPR I6 (MPH Ifi) M / R -k
~ ~ ~ MPR I] MPB 1] R k
N
/ / j//// \~\ \ \ ( ) MI
,bN~ /
75 / / '~U6.4\ \ \\ \ \ __.. MPB IY Ih1PR 191 Ml R:k
/ / \ \ MPR 'U (MPB ~U) MJ R k
% r~ _ ' `
QQ -_
' MPR I(MPB ~I)MJ R:k
(tl / ~y i / / /~~- -- \ \ ~ \ \ \ MPB 1 (MPB nIPBI) M3 R'vk
`~ \ ~ MPB (MPB 1 M J R -k
MPR l MPR J M R'k
45 / pf / ~ ~- 4 IOSNS ~ MPR 4(MPB 41 M; R':k
~ MPB (MPR 51 M R k
h1PN '7 (MPB '71 MJ R''k
}% / / - __ \
l/ ~ / / ~ ~ ~\~ ~ MPB II lMP8507 MJ R'k
-- MP(FP I (MP(hP II M J Rsk
lu
a / / / / ~ ~ \ ~ I MP(hP AIMPC hP A) M ] rftisk
,3 I I / /. ~ i lOSga~ \ I MP(hP IMPC FP'_).M Jur Ruk
INS ~ / ~ I' ~ \ ` PI S MPB-33A
i I ~ /
g I I i i i ~ '. I I ~ ~ /~ _I .1(/.j~,Y \~~ II I I I
. ~~ ~ I
~~ ~~ ~ -+- ~ ~--~-I , ~ o ; - --~ - Xly.
- --- I ~ s
( , r er =nwa
~ x ~~
Ns I ION I ~ \ \\ ~~/ '~ / I
~. _. - -
3 I_ ~'~ 5~
1N y \ \ \ ~ -~Z /~ /.
~ ~ /
\ / /
- ~ /
45 1 \ \ ~~
53 T /
~s -,;1~5a, `~ ~--- ~5_-~j ~/ by
%}
41 ~ ~+~ ~~\` ~ - ~~-
IUS 2Jl ~ ~ ~ ~ ~--- -1 S ~ ~~ - I'll
i / / ~
113 ~ ~ ~ ~ ~- - ttn~~ -
~ ~ /
135 \ ~\~, ~ ~ ~~---- ~.~- % ~ '/~ ~ BAKER
~~
_ ~- /. / ,
I7J \ - t] - ~ /
INU ~ ~ ~
INtl \ \~~-'--1k~-~ ~ /~ / SI:C'fIO:Y ULI AILS
IYS \` ~---IY`r----_;%~ S.. MU hlc Aii 'IVU *N/-S -I:/-W ULa~g II-av.: VS.. Inrg.;
_~ ~ 1 104?3.W 5x.50 ?1X.00 fix]1.6J -b49x.Y5 = x5xA5 U.UU U.W _ 5x.45
1X0 - 1044UW SN.42 20J.1) 6x%053 -6512.Ix x%64.36 0.9) II%.95 ?%n43fi
S 10454W fi4.U? ?W.I) fixx).?fi -65?J 3) -?tl69 Jx 40.00 I1.W 2xnY.3x
4 10600.26 YO.W IYY.)5 6914.%) -66S44Y ~Y21!J5 IxAU 350-W 24?IYS
5 10)%5 ~fi Yl1.W 166.45 6YI9 tl) -b%Jb.bJ ~Y31.82 IR00 2)U-W 29311t'_
b IIJ%5.?fi YU.W ?J4 JS 691Y.%J -J22x59 -3265.99 1X110 W.W 126594
11535 ~fi 90W 30145 691Y x] -)I%?.J3 -340]3] IxW WW 340].1]
x 116%5 ~fi %9.0) 31Y.43 69?1.10 -)0%S.%3 -352 L06 12WU 91.W }521.06
9 11x95 ~fi 8Y.Ifi ?Y4?3 6924.34 -bY611.Yx -36x).7x I2.W ?7U.W }6x7.>%
Travelling Cylinder AUmuth(TPU~N'.11 ldcgf va Canlm to LLTVC SC motion 15Nm 10 II9%526 %x4} }OSW 69?fi?x -6916.Sx -J]fi5 N9 I?W 9iW }]65 xY
P ( ( II 121Y5.?fi x4.)fi ?%UL2 6YJx.YJ -683fi.x% -JYSJ93 12.W 261.W 195 ).YJ
I? I??]5?6 %11.)) ?]I ~? 6944.06 -6x?Y.UY -0036.x1 1? W ?45.W 4U3n.x1
13 124?5.26 76.}? ?%Y.U2 hYJY.UJ -6x03-5) -41x0.Y1 12 W 104W 41NLL41
14 13575 ~6 7).W 270.SJ )OIJ.Yx -6)7&Y4 -4324.05 I?W 2]U.Iq i3_'4-US
s
SR~``Z b ~ BP Alaska ~ BNUGH•
"`~+~`" P Anticollision Report 1NTEQ
Company: BP Amoco Date: 10/22/2008 Time: 15:50:35 Page: 1
Field: Milne Point
Reference Site: M Pt B Pad Caordinat e(NE) Reference: Well: MP B-22, True North
Reference Well: MPB-22 Vertical (T VD) Refere nce: 26:22 12/29/1985 00:00 59.0
Reference w'etlpaths Plan 5, MPIi-22A Dh: Oracle
GLOBAL SCAN APPLIED: All welipaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM
Interpolation Method: MD Inte rval: 25.00 ft Error Model: ISCWSA Ellipse
'~ Depth Range: 10423.00 to 12875.26 ft Scan Method: Trav Cylinder North
Maximum Radius: 1483.98 ft _
Error Surface: Ellipse + Casing
r Definit
t ~
Da 11/7/2005 Validateda
No Version: 0 I,
I, Planned From To Survey Toolcode Tool Name
i
~
ft ft
101.00 10423.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based g yro multishot '~,
i 10423.00 12875.26 Planned: Plan #5 V9 MWD MWD -Standard
-
---
--------
-
Casing Points
MD TVD Diameter HoleBize Name'
ft ft in in
12875.26 7059.61 2.375 3.500 2.375" -- I,
Summary
c----__..___-- Offset Weilputh --------~ Reference '? .Offset Ctr-Ctr No-Go Allowable i
Site Well Wellpath ` MD MD Distance Area Deviation Warning
ft ft ft ft ft
-- -
EX IWVEAR32-25
KAVEAR32-25 -
KAVEAR32-25 V8
1
0850.14 -
6925.00 - _
122.64 1743.24 -1620.60
FAIL: Major Risk
I M Pt B Pad MPB-21 MPB-21 V1 Out of range
~' M Pt B Pad MPB-22 MPB-22 V1 1 0425.00 10425.00 0.00 1527.62 -1527.62 FAIL: Major Risk
M Pt E Pad MPE-13 MPE-13 V3 Out of range
M Pt E Pad MPE-13 MPE-13A V3 Out of range
M Pt E Pad MPE-13 MPE-13AP61 V3 Out of range
M Pt E Pad MPE-13 MPE-13APB2 V3 Out of range
M Pt E Pad MPE-19 MPE-19 V2 Out of range
M Pt E Pad
MPE-26
MPE-26 V23
1
2225.00
6975.00
1082.48
449.34
633.14 i
Pass: Major Risk 1
Site: EX KAVEAR32-25
Well: KAVEAR32-25 Rule Assigned: Major Risk
Wellpath: tCAVEAR32-25 V8
- Inter-Site Error:
_ _ 0.00 ft
Reference Offset Semi-Major Axis - Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing(HSflistance Area Deviation Warning
ft ft ft ft ft' ft deg deg in ft ft ft
1 10830.43 6919.87 5450.00 5449.46 410.02 121.03 179.32 4.73 9.625 1475.45 195.57 1279.88 Pass ~i
10831.18 6919.87 5475.00 5474.46 410.51 121.84 179.54 4.82 9.625 1450.54 197.78 1252.77 Pass ii
10831.90 6919.87 5500.00 5499.45 410.98 122.65 179.75 4.90 9.625 1425.64 200.07 1225.57 Pass
10832.57 6919.87 5525.00 5524.45 411.42 123.46 179.96 4.99 9.625 1400.74 202.44 1198.30 Pass
10833.20 6919.87 5550.00 5549.44 411.83 124.27 180.17 5.08 9.625 1375.84 204.91 1170.94 Pass
10833.80 6919.87 5575.00 5574.44 412.21 125.07 180.37 5.18 9.625 1350.95 207.47 1143.48 Pass
10834.35 6919.87 5600.00 5599.44 412.57 125.88 180.57 5.28 9.625 1326.06 210.12 1115.93 Pass
10834.87 6919.87 5625.00 5624.44 412.91 126.41 180.76 5.38 9.625 1301.17 212.81 1088.36 Pass
10835.39 6919.87 5650.00 5649.44 413.25 126.91 180.96 5.49 9.625 1276.29 215.61 1060.68 Pass
10835.89 6919.87 5675.00 5674.43 413.57 127.41 181.16 5.60 9.625 1251.41 218.53 1032.88 Pass ~
10836.39 6919.87 5700.00 5699.43 413.89 127.91 181.37 5.71 9.625 1226.53 221.58 1004.96 Pass
10836.87 6919.87 5725.00 5724.43 414.21 128.42 181.58 5.83 9.625 1201.67 224.76 976.90 Pass
10837.34 6919.87 5750.00 5749.43 414.52 128.92 181.79 5.96 9.625 1176.80 228.09 948.71 Pass
10837.81 6919.87 5775.00 5774.43 414.82 129.42 182.00 6.09 9.625 1151.94 231.58 920.36 Pass
10838.26 6919.87 5800.00 5799.43 415.11 129.92 182.22 6.22 9.625 1127.09 235.23 891.86 Pass ',
II 10838.70 6919.87 5825.00 5824.42 415.40 130.42 182.44 6.37 9.625 1102.25 239.06 863.18 Pass ~,
10839.14 6919.87 5850.00 5849.42 415.68 130.92 182.66 6.51 9.625 1077.41 243.08 834.33 Pass
', 10839.56 6919.87 5875.00 5874.42 415.96 131.42 182.90 6.67 9.625 1052.58 247.32 805.25 Pass
10839.97 6919.87 5900.00 5899.42 416.22 131.91 183.13 6.83 9.625 1027.75 251.81 775.94 Pass
10840.38 6919.87 5925.00 5924.42 416.49 132.41 183.38 7.00 9.625 1002.94 256.54 746.40 Pass
10840.77 6919.87 5950.00 5949.42 416.74 132.91 183.63 7.18 9.625 978.13 261.52 716.61 Pass
10841.15 6919.87 5975.00 5974.42 416.99 133.41 183.88 7.37 9.625 953.34 266.77 686.57 Pass
', 10841.52 6919.87 6000.00 5999.42 417.23 133.91 184.15 7.57 9.625 928.55 272.31 656.24 Pass
by BP Alaska ~' BN;~~s
'r=+` Anticollision Report 1NTEQ
Company: BP AmOCO Date: 10!22/2008 Time: 15:50:35 Page: 2
Field: Milne Point ''
Reference Site: M Pt B Pad Co-ordinate(NE) Reference: Well: MPB-22, True North
Reference Well: MPB-22 Vertical (TVD) Reference: 26:22 12/29/1985 00:00 59A
Reference Wellgath: Plan 5, MPB-22A Db: Oracle
Site: EX KAVEAR32-25
Well: KAVEAR32-25 Rule Assigned: Major Risk
Wellpath: ICAVEAR32-25 V8 Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Aads Ctr-Ctr No-Go Allowable
', MD TVD MD TVD "'Ref Offset TFO+AZI TFO-HS CasingJHSfllstance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft
10841.88 6919.87 6025.00 6024.41 417 47 134.40 184.42 7.78 9.625 903.78 278.18 625.60 Pass
10842.24 6919.87 6050.00 6049.41 417.69 134.79 184.71 8.00 9.625 879.02 284.34 594.68 Pass
~, 10842.58 6919.87 6075.00 6074.41 417.92 135.14 185.00 8.23 9.625 854.27 290.86 563.41 Pass
10842.91 6919.87 6100.00 6099.41 418.13 135.49 185.31 8.48 9.625 829.54 297.79 531.75 Pass
110843.24 6919.87 6125.00 6124.41 418.35 135.83 185.64 8.75 9.625 804.82 305.15 499.67 Pass
10843.56 6919.87 6150.00 6149.41 418.55 136.18 185.97 9.03 9.625 780.12 313.00 467.12 Pass
10843.87 6919.87 6175.00 6174.41 418.75 136.52 186.33 9.32 9.625 755.45 321.38 434.07 Pass
'~ 10844.17 6919.87 6200.00 6199.41 418.95 136.87 186.70 9.64 9.625 730.79 330.34 400.45 Pass
10844.46 6919.87 6225.00 6224.41 419.14 137.21 187.09 9.98 9.625 706.16 339.94 366.22 Pass
10844.74 6919.87 6250.00 6249.41 419.32 137.55 187.51 10.35 9.625 681.55 350.24 331.31 Pass
10845.01 6919.87 6275.00 6274.41 419.50 137.90 187.95 10.74 9.625 656.98 361.34 295.64 Pass
10845.28 6919.87 6300.00 6299.41 419.67 138.24 188.42 11.16 9.625 632.43 373.30 259.13 Pass
10845.54 6919.87 6325.00 6324.41 419.84 138.59 188.92 11.62 9.625 607.93 386.24 221.68 Pass
10845.78 6919.87 6350.00 6349.41 420.00 138.93 189.46 12.11 9.625 583.46 400.28 183.18 Pass
10846.02 6919.87 6375.00 6374.40 420.15 139.27 190.04 12.65 9.625 559.05 415.55 143.50 Pass
i 10846.25 6919.87 6400.00 6399.40 420.30 139.62 190.67 13.24 9.625 534.68 432.21 102.48 Pass
10846.48 6919.87 6425.00 6424.40 420.45 139.96 191.36 13.88 9.625 510.38 450.45 59.94 Pass
i
I' 10846.69 6919.87 6450.00 6449.40 420.59 140.30 192.10 14.59 9.625 486.15 470.49 15.67 Pass
i 10846.89 6919.87 6475.00 6474.40 420.72 140.65 192.92 15.37 9.625 462.00 492.59 -30.59 FAIL
!. 10847.09 6919.87 6500.00 6499.40 420.85 140.99 193.82 16.24 9.625 437.95 517.08 -79.13 FAIL
10847.28 6919.87 6525.00 6524.40 420.97 141.33 194.83 17.21 9.625 414.01 544.32 -130.31 FAIL
10847.46 6919.87 6550.00 6549.40 421.08 141.65 195.95 18.30 9.625 390.20 574.75 -184.55 FAIL
~ 10847.63 6919.87 6575.00 6574.40 421.20 141.91 197.20 19.52 9.625 366.55 608.91 -242.36 FAIL
10847.81 6919.87 6600.00 6599.40 421.32 142.18 198.63 20.92 9.625 343.09 647.50 -304.41 FAIL
10847.99 6919.87 6625.00 6624.40 421.43 142.45 200.26 22.52 9.625 319.86 691.35 -371.48 FAIL i
10848.17 6919.87 6650.00 6649.40 421.55 142.71 202.14 24.37 9.625 296.93 741.45 -444.53 FAIL ~,
10848.34 6919.87 6675.00 6674.40 421.66 142.98 204.33 26.52 9.625 274.35 799.03 -524.68 FAIL i
10848.52 6919.87 6700.00 6699.40 421.78 143.24 206.90 29.06 9.625 252.23 865.52 -613.29 FAIL Iii
10848.70 6919.87 6725.00 6724.40 421.89 143.51 209.95 32.08 9.625 230.70 942.57 -711.86 FAIL i,
10848.88 6919.87 6750.00 6749.40 422.01 143.77 213.61 35.71 9.625 209.941031.91 -821.97 FAIL
i 10849.05 6919.87 6775.00 6774.40 422.12 144.04 218.04 40.11 9.625 190.201135.04 -944.84 FAIL
10849.23 6919.87 6800.00 6799.40 422.24 144.30 223.45 45.49 9.625 171.841252.36 -1080.52 FAIL
I; 10849.41 6919.87 6825.00 6824.40 422.35 144.57 230.08 52.08 9.625 155.351381.53 -1226.19 FAIL
10849.58 6919.87 6850.00 6849.40 422.47 144.84 238.13 60.10 9.625 141.371514.72 -1373.35 FAIL
10849.76 6919.87 6875.00 6874.40 422.58 145.10 247.70 69.64 9.625 130.721635.46 -1504.74 FAIL
10849.94 6919.87 6900.00 6899.40 422.70 145.37 258.61 80.52 9.625 124.251719.04 -1594.78 FAIL
10850.14 6919.87 6925.00 6924.40 422.81 146.14 270.22 92.11 9.625 122.641743.24 -1620.60 FAIL
10850.42 6919.87 6950.00 6949.40 422.96 147.02 281.72 103.54 9.625 126.07 1699.30 -1573.23 FAIL ',
10850.76 6919.87 6975.00 6974.40 423.15 147.90 292.22 113.98 9.625 134.151601.65 -1467.50 FAIL
10851.18 6919.87 7000.00 6999.40 423.38 148.78 301.29 122.97 9.625 146.111476.01 -1329.89 FAIL
10851.67 6919.87 7025.00 7024.39 423.65 149.65 308.86 130.45 9.625 161.101344.60 -1183.50 FAIL
10852.24 6919.87 7050.00 7049.39 423.96 150.53 315.08 136.57 9.625 178.341220.54 -1042.21 FAIL
10852.87 6919.87 7075.00 7074.39 424.30 151.41 320.19 141.57 9.625 197.251109.40 -912.15 FAIL
10853.58 6919.87 7100.00 7099.38 424.69 152.29 324.42 145.66 9.625 217.391012.30 -794.91 FAIL
10854.36 6919.87 7125.00 7124.38 425.12 153.17 327.94 149.05 9.625 238.45 928.37 -689.91 FAIL
110855.22 6919.87 7150.00 7149.37 425.58 154.05 330.93 151.88 9.625 260.21 856.00 -595.79 FAIL
'i 10856.14 6919.87 7175.00 7174.37 426.09 154.93 333.48 154.27 9.625 282.50 793.49 -510.98 FAIL ~
10857.14 6919.87 7200.00 7199.36 426.63 155.81 335.70 156.31 9.625 305.22 739.28 -434.06 FAIL
10858.21 6919.87 7225.00 7224.35 427.22 156.69 337.64 158.06 9.625 328.26 692.19 -363.94 FAIL ~,
i 10859.36 6919.87 7250.00 7249.34 427.84 157.56 339.37 159.58 9.625 351.56 650.94 -299.38 FAIL
~ 10860.57 6919.87 7275.00 7274.33 428.50 158.44 340.92 160.91 9.625 375.08 614.58 -239.50 FAIL
~•'''s by ~ BP Alaska ~ BHlEGN~
'~+~` Anticollision Report INTEQ
~ Company: BP Amoco Date: 10/22/2008 Time: 15:50:35 Page: 3
~, Field: Milne Point
:`Reference Site: M Pt B Pad Co-ordinate(NE) Reference: Well: MPB-22, True North
Reference WeII: MPB-22 Vertical (TVD) Reference: 26:22 12(29/1985 00:0059.0
'i Reference Wellpath: Plan 5, MPB-22A Db: Oracle
Site: EX KAVEAR32-25
Well: KAVEAR32-25 Rule Assigned: Major Risk
Wellpath: KAVEAR32-25 V8 Inter-Site Error: 0.00 fl
---- -
Reference Offset Semi-Major Axfs Ctr-Ctr No-Go Allowable
~ )vID TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/Flsflistance Area De~~iation
ft ft ft ft ft ft deg -deg in ft ft ft
Warning ^ I
10861.86 6919.87 7300.00 7299.32 429.21 159.31 342.33 162.09 9.625 398.78 582.35 -183.58 FAIL
I, 10863.22 6919.87 7325.00 7324.30 429.95 160.18 343.61 163.13 9.625 422.62 553.64 -131.02 FAIL
'~ 10864.65 6919.87 7350.00 7349.29 430.73 161.05 344.80 164.06 9.625 446.59 527.93 -81.34 FAIL
110866.16 6919.87 7375.00 7374.27 431.55 161.91 345.91 164.90 9.625 470.66 504.80 -34.14 FAIL
i 10867.74 6919.87 7400.00 7399.25 432.41 162.92 346.95 165.65 9.625 494.81 484.01 10.81 Pass
10869.33 6919.87 7425.00 7424.23 433.28 164.40 347.92 166.34 9.625 519.04 465.46 53.59 Pass
10870.93 6919.87 7450.00 7449.21 434.15 165.88 348.84 166.96 9.625 543.34 448.53 94.81 Pass
10872.52 6919.87 7475.00 7474.20 435.02 167.35 349.70 167.54 9.625 567.70 433.04 134.66 Pass
10874.12 6919.87 7500.00 7499.18 435.89 168.82 350.51 168.06 9.625 592.11 418.81 173.29 Pass
10875.71 6919.87 7525.00 7524.16 436.69 170.28 351.28 168.55 9.625 616.56 405.66 210.90 Pass
10877.30 6919.87 7550.00 7549.14 437.39 171.74 352.01 168.99 9.625 641.06 393.46 247.60 Pass
10878.89 6919.87 7575.00 7574.12 438.08 173.20 352.72 169.41 9.625 665.58 382.15 283.43 Pass
10880.49 6919.87 7600.00 7599.10 438.78 174.65 353.39 169.79 9.625 690.14 371.65 318.50 Pass
10882.08 6919.87 7625.00 7624.08 439.48 176.09 354.03 170.15 9.625 714.73 361.87 352.86 Pass
10883.67 6919.87 7650.00 7649.06 440.17 177.54 354.66 170.49 9.625 739.35 352.75 386.60 Pass
10885.25 6919.87 7675.00 7674.04 440.87 178.97 355.26 170.81 9.625 763.98 344.22 419.76 Pass
10886.84 6919.87 7700.00 7699.02 441.57 180.40 355.84 171.10 9.625 788.64 336.23 452.41 Pass
10888.43 6919.87 7725.00 7724.00 442.26 181.83 356.40 171.38 9.625 813.32 328.72 484.59 Pass
10890.01 6919.87 7750.00 7748.98 442.95 183.25 356.95 171.64 9.625 838.01 321.67 516.34 Pass
10891.59 6919.87 7775.00 7773.96 443.65 184.67 357.48 171.89 9.625 862.72 315.02 547.70 Pass
10893.17 6919.87 7800.00 7798.94 444.34 186.08 358.00 172.12 9.625 887.45 308.75 578.69 Pass
10894.75 6919.87 7825.00 7823.93 445.03 187.48 358.50 172.34 912.18 302.82 609.36 Pass
10896.32 6919.87 7850.00 7848.91 445.72 188.81 359.00 172.55 936.93 297.19 639.74 Pass
10897.87 6919.87 7875.00 7873.89 446.40 190.14 -0.52 172.75 961.70 291.86 669.84 Pass
10899.41 6919.87 7900.00 7898.87 447.07 191.47 -0.06 172.94 986.47 286.79 699.68 Pass
10900.93 6919.87 7925.00 7923.85 447.64 192.79 0.40 173.12 1011.25 281.95 729.30 Pass
10902.43 6919.87 7950.00 7948.83 448.13 194.11 0.84 173.29 1036.05 277.32 758.72 Pass
10903.92 6919.87 7975.00 7973.82 448.62 195.42 1.27 173.46 1060.85 272.92 787.93 Pass
10905.40 6919.87 8000.00 7998.80 449.10 196.73 1.69 173.62 1085.66 268.73 816.93 Pass
10906.85 6919.87 8025.00 8023.78 449.58 198.04 2.11 173.77 1110.47 264.73 845.75 Pass
10908.30 6919.87 8050.00 8048.77 450.06 199.34 2.51 173.91 1135.30 260.91 874.39 Pass
10909.72 6919.87 8075.00 8073.75 450.52 200.64 2.90 174.05 1160.13 257.26 902.87 Pass
10911.13 6919.87 8100.00 8098.73 450.99 201.93 3.29 174.18 1184.97 253.77 931.20 Pass
10912.53 6919.87 8125.00 8123.72 451.45 203.22 3.67 174.31 1209.81 250.43 959.39 Pass
10913.90 6919.87 8150.00 8148.70 451.89 204.26 4.03 174.43 1234.66 247.16 987.50 Pass
10915.20 6919.87 8175.00 8173.69 452.32 205.17 4.39 174.54 1259.52 243.99 1015.53 Pass
10916.43 6919.87 8200.00 8198.68 452.73 206.08 4.72 174.66 1284.39 240.96 1043.43 Pass
10917
59 6919
87 8225
00 8223
67 11
453 206.99 5.04 174.76 1309.26 238.05 1071.20 Pass
.
10918.68 .
6919.87 .
8250.00 .
8248.66 .
453.47 207.90 5.33 174.87 1334.13 235.27 1098.86 Pass
10919.70 6919.87 8275.00 8273.65 453.80 208.82 5.62 174.97 1359.02 232.60 1126.42 Pass
~~ 10920.65 6919.87 8300.00 8298.64 454.11 209.74 5.88 175.06 1383.90 230.04 1153.86 Pass
10921.53 6919.87 8325.00 8323.64 454.40 210.67 6.14 175.15 1408.80 227.58 1181.21 Pass
1 10922.35 6919.87 8350.00 8348.63 454.67 211.61 6.37 175.24 1433.70 225.23 1208.47 Pass
10923.09 6919.87 8375.00 8373.63 454.91 212.55 6.59 175.33 1458.60 222.96 1235.64 Pass
10923.77 6919.87 8400.00 8398.62 455.14 213.26 6.79 175.41 1483.51 220.74 1262.77 Pass
a~~~
i ' a ~ BP Alaska ~ B H
`°t+~`'~ p Anticollision Report INTEQ
; Company: BP AmoCO Date.. 10/22/2008 Time: 15:50:35 Page: 4
~ Field: Milne Point ~
i Reference Site: M Pt B Pad Co-ordinate(NEjReference: Well: MPB-22, True North
~, Reference Wcll: MPB-22 Vertical (TVDj Reference: 26:22 12129/1985 00:00 59.0
~i Reference Wellpath: Plan 5, MPB-22A Db: Oracle
' Site: M Pt B Pad
Well: MPB-22 Rule Assigned: Major Risk
Wellpath: MPB-22 V1 Inter-Site Error: 0.00 ft
Reference Offset Semi=Major Axis Ctr-G'tr No-Co Allowable
MD TVD MD TVD Ref `Offset' TFO+AZI TFO-HS Gasing/IiSDistance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft j
10425.00 6872.68 10425.00 6872.68 462.97 463.05 204.02 0.00 0.001527.62 -1527.62 FAIL
10449.98 6885.45 10450.00 6885.77 463.53 465.00 23.09 178.92 0.35 239.81 -239.45 FAIL
10474.64 6895.71 10475.00 6898.90 463.63 467.10 20.35 176.88 3.46 275.95 -272.49 FAIL
10498.68 6904.00 10500.00 6912.08 463.69 469.15 17.75 175.04 8.54 343.99 -335.45 FAIL
10521.83 6910.38 10525.00 6925.31 463.69 471.14 15.93 173.92 15.47 393.51 -378.04 FAIL
10543.92 6914.96 10550.00 6938.51 463.62 473.09 14.27 172.91 24.10 438.05 -413.95 FAIL
10564.86 6917.93 10575.00 6951.62 463.50 474.98 12.66 171.91 34.24 480.57 -446.33 FAIL
' 10584.56 6919.49 10600.00 6964.64 463.35 476.83 11.18 170.99 45.77 517.40 -471.63 FAIL
10603.41 6919.87 10625.00 6977.57 462.82 478.42 9.32 170.13 58.56 550.54 -491.98 FAIL
10623.71 6919.87 10650.00 6990.45 460.31 477.71 4.32 168.79 71.94 610.36 -538.42 FAIL
10643.45 6919.87 10675.00 7003.32 455.79 475.17 358.98 167.00 85.64 687.69 -602.05 FAIL II,
10662.51 6919.87 10700.00 7016.20 449.89 470.98 353.55 165.01 99.72 770.96 -671.24 FAIL ',
10680.80 6919.87 10725.00 7029.07 442.89 465.39 348.19 162.94 114.23 853.23 -739.00 FAIL
10698.25 6919.87 10750.00 7041.95 434.90 458.63 342.99 160.87 129.21 930.17 -800.96 FAIL
10714.83 6919.87 10775.00 7054.83 425.74 450.94 337.99 158.85 144.69 998.98 -854.29 FAIL
i' 10730.50 6919.87 10800.00 7067.70 416.33 442.55 333.23 156.92 160.69 1059.23 -898.53 FAIL
Site: M Pt E Pad
Well: MPE-26 Rule Assigned: Major Risk
Wellpath: MPE-26 V23 Inter-Site Error: 0.00 ft
- -__ _- _-
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFO+AZI:TF0.H5 Casing/Ilsflistance Area Deviation Warning
ft ft ft ft ft ft `deg deg in ft ft ft
12125.00 6933.24 5850.00 5678.79 48.20 4.03 320.30 31.89 7.000 1482.12 184.38 1297.74 Pass
12130.53 6933.64 5875.00 5702.67 52.78 4.02 320.35 32.60 7.000 1465.14 196.76 1268.38 Pass
12132.78 6933.80 5900.00 5726.58 54.65 4.03 320.78 33.30 7.000 1448.35 201.82 1246.53 Pass
12135.02 6933.97 5925.00 5750.50 56.50 4.04 321.23 34.01 7.000 1431.74 206.77 1224.97 Pass
12137.23 6934.14 5950.00 5774.44 58.33 4.05 321.69 34.74 7.000 1415.32 211.60 1203.72 Pass j
~I 12139.42 6934.30 5975.00 5798.40 60.15 4.06 322.18 35.49 7.000 1399.09 216.30 1182.79 Pass
12141.58 6934.46 6000.00 5822.39 61.94 4.06 322.68 36.25 7.000 1383.06 220.88 1162.17 Pass
12143.71 6934.63 6025.00 5846.40 63.71 4.07 323.21 37.03 7.000 1367.24 225.35 1141.89 Pass
12150.00 6935.12 6050.00 5870.44 68.92 4.05 323.29 37.87 7.000 1351.65 236.34 1115.31 Pass '
i 12150.00 6935.12 6075.00 5894.50 68.92 4.07 324.09 38.67 7.000 1336.27 237.27 1099.00 Pass
II 12150.00 6935.12 6100.00 5918.58 68.92 4.09 324.91 39.48 7.000 1321.13 238.18 1082.95 Pass
! 12150.00 6935.12 6125.00 5942.65 68.92 4.11 325.75 40.32 7.000 1306.37 239.10 1067.27 Pass
!, 12150.00 6935.12 6150.00 5966.64 68.92 4.13 326.61 41.18 7.000 1292.11 240.01 1052.10 Pass
', 12156.10 6935.60 6175.00 5990.56 74.36 4.11 326.82 42.13 7.000 1278.34 254.70 1023.64 Pass
i 12158.25 6935.78 6200.00 6014.40 76.27 4.12 327.50 43.06 7.000 1265.13 260.56 1004.57 Pass
'.
12160.39 6935.95 6225.00 6038.20 78.18 4.13 328.20 44.01 7.000 1252.41 266.49 985.92 Pass '
12162.52 6936.12 6250.00 6061.96 80.08 4.15 328.92 44.99 7.000 1240.18 272.45 967.73 Pass
12164.63 6936.30 6275.00 6085.69 81.96 4.16 329.67 45.99 7.000 1228.44 278.43 950.01 Pass ',
12166.73 6936.47 6300.00 6109.39 83.83 4.17 330.44 47.01 7.000 1217.21 284.43 932.78 Pass
12168.80 6936.65 6325.00 6133.05 85.68 4.18 331.24 48.05 7.000 1206.51 290.43 916.08 Pass j
12175.00 6937.17 6350.00 6156.68 91.20 4.17 331.61 49.16 7.000 1196.37 305.82 890.54 Pass
j 12175.00 6937.17 6375.00 6180.27 91.20 4.19 332.68 50.23 7.000 1186.75 307.26 879.49 Pass
12175.00 6937.17 6400.00 6203.84 91.20 4.21 333.76 51.32 7.000 1177.69 308.64 869.05 Pass ~
12175.00 6937.17 6425.00 6227.38 91.20 4.23 334.87 52.43 7.000 1169.19 309.96 859.23 Pass
12178.83 6937.50 6450.00 6250.90 94.67 4.23 335.58 53.59 7.000 1161.23 320.77 840.46 Pass
12180.77 6937.67 6475.00 6274.39 96.42 4.24 336.51 54.76 7.000 1153.85 326.90 826.94 Pass ',
12182.71 6937.84 6500.00 6297.91 98.18 4.25 337.46 55.93 7.000 1146.85 333.04 813.81 Pass
12184.68 6938.02 6525.00 6321.49 99.97 4.26 338.41 57.12 7.000 1140.10 339.24 800.85 Pass
12186.69 6938.20 6550.00 6345.12 101.79 4.27 339.36 58.31 7.000 1133.59 345.51 788.07 Pass
.'!~+!!.
BP Alaska ~ BAKBR`~
~; ~~ fJp NUGHlS
'•f+~~ Anticollision Report >NTEQ
Company: BP Amoco Date: 10!22/2008 Time: 15:50:35 Page: 5
Field: Milne Point
~~ Refereuce Site: MPt B Pad Co-orrrinate(NE) Reference: Well: MPB-22, True North
Reference Well: MPB-22 Vertical (TVD) Reference: .26:22 12/29/1985 00:00 59.0
RefereuceWellpath: Plan 5, MPB-22A Db: Oracle
Site: M Pt E Pad
Well: MPE-26 Rule Assigned: Major Risk
Wellpath: MPE-26 V23 Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFt?+AZI TFQ-HS CasinglHSDistance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft
~I 12188.74 6938.38 6575.00 6368.81 103.64 4.27 340.32 59.52 7.000 1127.33 351.84 775.49 Pass
12190.80 6938.56 6600.00 6392.55 105.51 4.28 341.29 60.73 7.000 1121.34 358.19 763.14 Pass
12195.26 6938.97 6625.00 6416.34 109.54 4.27 342.00 61.98 7.000 1115.63 370.70 744.94 Pass
~i 12195.26 6938.97 6650.00 6440.19 109.54 4.29 343.21 63.19 7.000 1110.19 371.61 738.58 Pass
12197.03 6939.13 6675.00 6464.07 111.19 4.30 344.25 64.42 7.000 1105.08 377.31 727.77 Pass
12199.06 6939.32 6700.00 6487.98 113.07 4.30 345.28 65.67 7.000 1100.43 383.60 716.83 Pass
12200.00 6939.41 6725.00 6511.91 113.94 4.32 346.42 66.92 7.000 1096.28 386.69 709.58 Pass
12200.00 6939.41 6750.00 6535.86 113.94 4.34 347.67 68.16 7.000 1092.63 387.04 705.59 Pass
~, 12200.00 6939.41 6775.00 6559.84 113.94 4.35 348.93 69.42 7.000 1089.50 387.24 702.26 Pass
12207.11 6940.11 6800.00 6583.83 120.51 4.32 349.49 70.76 7.000 1086.81 406.79 680.02 Pass
12209.12 6940.32 6825.00 6607.84 122.36 4.33 350.56 72.05 7.000 1084.69 412.09 672.60 Pass
~~ 12211.12 6940.53 6850.00 6631.86 124.21 4.33 351.64 73.35 7.000 1083.09 417.18 665.91 Pass
12213.11 6940.74 6875.00 6655.91 126.05 4.33 352.72 74.65 7.000 1081.99 422.03 659.96 Pass
12215.09 6940.96 6900.00 6679.99 127.88 4.34 353.80 75.95 7.000 1081.38 426.62 654.76 Pass
12217.06 6941.17 6925.00 6704.09 129.71 4.34 354.89 77.25 7.000 1081.24 430.94 650.30 Pass
12219.03 6941.39 6950.00 6728.23 131.52 4.34 355.98 78.56 7.000 1081.59 434.98 646.61 Pass
12225.00 6942.08 6975.00 6752.38 137.04 4.32 356.68 79.92 7.000 1082.48 449.34 633.14 Pass
12225.00 6942.08 7000.00 6776.55 137.04 4.33 357.96 81.19 7.000 1083.85 447.66 636.19 Pass
12225.00 6942.08 7025.00 6800.73 137.04 4.35 359.24 82.47 7.000 1085.74 445.79 639.95 Pass
12225.00 6942.08 7050.00 6824.93 137.04 4.37 0.51 83.74 7.000 1088.16 443.74 644.42 Pass
~I 12225.00 6942.08 7075.00 6849.12 137.04 4.38 1.77 85.00 7.000 1091.15 441.51 649.63 Pass
12230.89 6942.78 7100.00 6873.32 142.41 4.36 2.46 86.33 7.000 1094.64 453.99 640.66 Pass
12232.90 6943.03 7125.00 6897.51 144.25 4.36 3.51 87.61 7.000 1098.71 456.34 642.36 Pass
~ 12234.93 6943.29 7150.00 6921.71 146.11 4.36 4.55 88.87 7.000 1103.30 458.46 644.84 Pass
12236.96 6943.54 7175.00 6945.92 147.96 4.37 5.58 90.12 7.000 1108.40 460.32 648.08 Pass
12238.99 6943.80 7200.00 6970.14 149.81 4.37 6.60 91.37 7.000 1114.00 461.92 652.08 Pass
12241.02 6944.07 7225.00 6994.37 151.66 4.37 7.60 92.60 7.000 1120.08 463.26 656.82 Pass
12243.05 6944.34 7250.00 7018.63 153.52 4.37 8.60 93.82 7.000 1126.60 464.35 662.24 Pass
12457.39 6986.67 7275.00 7042.92 125.59 5.12 17.98 92.93 7.000 1132.13 234.85 897.28 Pass
~ 12460.20 6987.33 7300.00 7067.23 126.84 5.10 18.85 94.14 7.000 1137.91 236.36 901.55 Pass
12463.00 6987.99 7325.00 7091.54 128.09 5.07 19.70 95.34 7.000 1144.18 237.86 906.31 Pass
12463.15 6988.03 7326.40 7092.90 128.16 5.07 19.75 95.41 7.000 1144.54 237.95 906.59 Pass
Well
9.23
2.25
2'.
gross
~~
:~" Gombi
SOT
71116" X 3118" Flanged Adapter
Swab Valve
SSV
Master Valve
Lock Down Screws
Ground Level
6050000
6000000
5950000
5900000
5850000
EPA Aquifer Exemption - 40 CFR 147.102 (b)(3)
400000
500000
600000
700000
800000
~~
•
TRANSMI'I"I'AL LE
T
TER CHEC IST
WELL NAME /
/
/~~~iC ~ '
PTD# 2UV ,--/~
Develo
ment
S
_
p
s `
_____Non-Conventional WeU ervice _____ Exploratory Strati
~pbic Test
FIELD: ~/G~ ~lL~. ~~!/l ~ POOL
,~t~c
~~' K
~ 1< <c
~ ~~ ~( ~"c
.
~c,
.
.
:
Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS
WHAT (OPTIONS)
APPLIES ~~. FOR APPROVAL LETTER
MULTI LATERAL The permit is for a new wellbore segment of existin
g
well
(If last two digits in Permit No. . AP[ No. SO-
API number are -
between 60-69) Production should continue to be reported as a function of the
original API number stated above.
PILOT HOLE In accordance with 20 AAC 25.005(fj, a!1 records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name ( PIS and AP[ cumber
(50•
_~ from records, data aad logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to perforate and produce / infect is contingept
upon issuance of a conservation order approving a spacing
exception.
assumes the
liability of any protest to the spacing exception that may occur.
DRY DITCH
SAMPLE All dry ditch sample sets submitted to the Commission must be in
no greater than 30' sample intervals from below the permafrost or
fr
om where samples are frst caught and 10' sample intervals
throw
ct tones.
Non-Conventional
Well please note the following special condition of this permit:
production or production testing of coal bed me}~hane is not allowed
for nam f wel,~! until after fComaanv Namel has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. _(Con~oanv Named must contact the
Commission to obtain advance approval of su
h
t
ll
c
wa
er we
testing
ro
Rev: 1/1 !2008
WELL PERMIT CHECKLIST Field i;, Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT KR B-22A Program DEV Weil bore seg ^
PTD#:2081680 Company BP EXPLORATION (ALASKA) INC Inftiai ClasslType DEV 1 PEND GeoArea 890 Unit 11328 ONOff Shore On Annular Disposal ^
Administration 1 Pe[roitfeeattached - -- ------- - ---- - --- --- -- - NA- - --- -~ --- --- - ----- --- -- --- -- -- -
2 Leasenumkerappropriate__--_--------------------------_----- Yes_ ___.--Productive-interval and TDwililieinAAl.25518- - - - -.--------------------------------
3 Unique weltname and number . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ . _ _ _ - - _ _ _ _ _ _ _ Yes - _ _ _ _ _ Originally permitted ky-PTD_#2051740, which expired in Novembe[ 2007.- _ - - . - - - _ _ _ . _ _ _ _ _
4 WelUocatedina-c~fnedpool--._____________________.___________ Yes_ ______Kupar_ukRiverQltP00l,ggve[nedkyConservationQ[derNo.432C___-----.______.__________
5 Well located proper distance from drilling unit_koundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . Yes _ _ _ _ _ _ Conservation Order No. 4320 contains no spacing restrictions with respect to dr_iiling unit koundaries. _ _ _ _ _ _ _ _
6 Well located Doper distance from other welts_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ _ _ Yes _ _ _ _ _ _ Conservation Order No. 4320 has no interwell-spacing_restricticns. _ _ - _ _ - _ _ - _ _ _ _ _ - - _ _ _ . _
7 Sufficient acreage ayailakle in dolling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ _ _ _ _ _ Con_senration Order No. 4320 has n9 interwell_spscing-restrictions, Wellbore will ke-more khan 500' from _ _ _ .
8 If-deviated, is weilbore plat_included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . _ _ an external property linewhere_ownership or_landcwnershp changes. _ _ _ - - _ _ . _ _ - _ _ _ _ _
9 Qperator4nlyaifectedparb----- -- -- - - ---- ----- Yes - -- -- -- --- ---- --- ---- -- - -- -- -
10 Operator has_appcopriate kond in force - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
11 Permit cankeissu_edwJthoutconservationorder-_------------------------ Yes- -----------------------.---------------------------- - -- ---
Appr Date 12 Permitcaobeissuedwithoutadminist[alive.approva(------------------------- Yes- ---------------------------------------------- - ----- -- - ----
13 Cart Permit be approvedbefere15-daY-waft---------------------------- Yes- --------------------------------------------------------------------
SFD 1012412008 14 Well locatedwiihinareaa~strataauthorizedky_InjectionOrdar#(putlQ#in-comments).(For_ NA__ _______----------------------------------------------------------------
15 AilwelJswithin114-milearea_ofreyiewidentified(ForseN--ice well only)--___________ NA__ _________________________________________________--_____________________.
16 Pte-produced injector, duration of prep[odstction less than 3 months (For_service welt only) - - -~- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
17 Nonconven,gas-cgnformstoAS31,05,030Q.1.A),(j,2.A-D)---------------- ----- NA-- ----------_----------------------------------------------------------
Engineering 18 Conductor string,provided----------------------------------------- NA_ _____Conductorsetin MPB-2(185-302).-----------------------------------------------
19 SurfacecasingprotectsallknownUSDWs______________________________ NA-- -____Allaquifersexempted,40CFR_147.14?(k)(3)andAEO2,____________--___-__-__._________
20 CMT_voiadequate_tocireulateonconductor&surf-csg_______--------__ _-- NA- _____SurfacecasingseiinMPB-22.-_-__--_________-_..__--_____--___._-_---
21 CMTvoladeguate_torte-'lnlongstringiosurfcsg_______-___________________ NA__ __-___Production_casingsetin_MPB-22.-_________________--____________----__-_____
22 CMT.willcoyer-allknownproductiyehorizons_-___-_____-__-______. -_-- Yes- ----------------------------------------------------- -- ----
23 Casing designs adequate forC,_T,8&_perroofrost_--__-------------____-- Yes- --------------------------------------------------- -- - ---
24 Adequate tankage_or resenre pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ Yes _ _ -Rig equipped with steel pits: No reserve pit plannad._ Alt waste io approved disposalwell(s), - _ _ _ _ _ _ _ _
25 )fa_re-d[ill,has_e10.403forahandonmentkaenapproved-----.--------------- Yes- -----308-388------------------------------------------------------- --
26 Adequate w.elikore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ Proximity analysis perfomled, Clow approach identified. Traveling cylinderpath calculated.. - - - - _ _ _ _ _ _ _ _
27 Ifdiverterrequired,doesiimeetregulations------------------------------- NA_ _____BQPStack already in placa_____________._______-__________-______--. --
Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ Maximum expected formation pressure up l0 9.8 EMW. Plan touse-dynamic overbalance-with 8:6-ppg flud and _ _
TEM 1013012008 29 BOPIS,_dotheymeetregulation-__________--_----------------__- Yes- -------app6edsurfacep[essure_________________________-----_-.--------------
30 BOPS-press rating appropriate; test to_(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated at 2025 psi, 3500_psi_BOP testplanned, _ _ _ : - - _ _ _ - _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
31 ChDke_manifold comPiie`i wIAPI_ RP-53 (May e4) - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -
~~"" 32 Work will occurwith9utoperationshutdown__-__-__-_---
- - - - - Yes- ----------------------------------------------------------- -- -- --
33 IS presence of H2S gas prokakle_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ - _ _ _ H2$ is reported-at MPB pad• .Mud-should preciude_H2$ on rig.. Rig has sensors and alarms. _ - _ _ _ _ _ _ _ _ _ _
34 _MechanicalconditlonofwellsWithinAQRverifed(F4rse[vicewell only)-------------- NA. __-_--__--__.__--_______.._-____.._______-----------------~-------
Geology 35 Pe[mitcanbeissuedw/ohydrogensulfidemeasures_____-__-___--.________ No__ ______S-?2measured17ppm of H2$_________________________________________________
36 Data_presented on potential Qverpressura zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ ResaNOir pressu[es encAUntered may range from 6.8 to-9.8 ppg, YII_ill ke_drilled_using a coiled tubing rig, _ _ _ _
Appr Date 37 Setsrnicanalysisofshallowgaszones_________-_-_____________________ NA__ ___---$.Sppgmud-and_managedpressuredrNlingtecbniques._______-___--__--.___._--___._____
SFD 1012412008 38 :$eakedconditionsurvey_(itoft-shore)_._______--_-------------_____- NA_ _____-.----
--------------------------------------------------------------
39 Contactnamelphonefory~eekry_progress[epotls_(explotatoryonly]_-------------- -NA- ------------------------------------------------------------------------
Geologic Engineering Public
D
te The -02 API suffix is required for this "A" redrill because the initial permftfor B-22A (PTD 2051740, API 0.029.21509-01)
Commissioner: a
Date: Commissioner: Date Commissione
Cy~~~~~-3~v~ ~ In•3/~ expired on 1111512007, and RBDMS does not allow "recycling" of APi numbers.
o~
Well History File
APPENDIX
Information of detailed nature that is not
•
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special efitort has been made to chronologically
organize this category of information.
**** REEL HEADER ****
MWD
09/04/28
BHI
O1
LIS Customer Format Tape
**** TAPE HEADER ****
MWD
08/12/14
2345303
O1
2.375" CTK
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
Version Information
VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20
WRAP. NO: One line per frame
Well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 10355.0000: Starting Depth
STOP.FT 11903.0000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent Value
COMP. COMPANY: BP Exploration (Alaska), Inc.
WELL. WELL: MPB-22APB1
FLD FIELD: Milne Point Unit
LOC LOCATION: 70 deg 28' 26.259"N 149 deg 24' 38.595"W
CNTY. COUNTY: North Slope Borough
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 2.375" CTK
DATE. LOG DATE: 14 Dec 2008
API API NUMBER: 500292150970
Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
SECT. 18
TOWN.N T13N
RANG. R11E
PDAT. MSL
EPD .F 0
LMF DF
FAPD.F 59
DMF DF
EKB .F 0
EDF .F 59
EGL .F 0 .
CASE.F N/A
OS1 DIRECTIONAL
Remarks
Description
Section
Township
Range
Permanent Datum
Elevation Of Perm. Datum
Log Measured from
Feet Above Perm. Datum
Drilling Measured From
Elevation of Kelly Bushing
Elevation of Derrick Floor
Elevation of Ground Level
Casing Depth
Other Services Line 1
(1) All depths are Measured Depths (MD) unless otherwise noted.
~a~ -<~~ ~ ~so~' ~
•
(2) All depths are Bit Depths unless otherwise noted.
(3) All True Vertical Depths (TVDSS) are Subsea corrected.
(4) All Formation Evaluation data is realtime data.
(5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the
Advantage
after
surface system to log this well..
(6) Tools ran in the string included Casing Collar Locator, an
Electrical Disconnect and Circulating Sub, a Drilling
Performance Sub (Inner and Outer Downhole Pressure, Vibration and
Downhole Weight on Bit), a Directional and Gamma Sub, and
a Hydraulic Orienting Sub with a Near Bit Inclination Sensor.
(7) Data presented here is final and has been depth adjusted to a PDC
(Primary Depth Control) log above the KOP (Kick Off Point) of
10454 ft MD carrying the final shift at KOP to the bottom logged
interval per Dennis Urban with BP Exploration (Alaska), Inc.
The PDC was provided by Gearhart GR DIL dated 10 Jan 1986.
(8) The sidetrack was drilled from MPB-22 through a milled window in a
7 inch liner.
Top of window 10454 ft.MD (6828.8 ft.TVDSS)
Bottom of window 10458 ft.MD (6830.8 ft.TVDSS)
(9) Tied to MPB-22 at 10423 feet MD (6812.6 feet TVDSS).
(10) The resistivity interval from 10478 ft to 11375 ft MD
(6839.1 ft to 6859.7 ft TVDSS) was logged as a MAD Pass 24 hours
drilling on run 5.
(11) The interval from 11869 feet to 11903 ft MD (6871.7 ft to 6874.0 ft
TVDSS)
was not logged due to sensor to bit offset at well TD.
MNEMONICS:
GRAX -> Gamma Ray [MWD] (MWD-API units)
ROP_AVG -> Rate of Penetration, feet/hour
RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected
(OHMM)
RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected
(OHMM)
RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected
(OHMM)
RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected
(OHMM)
TVDSS -> True Vertical Depth (Subsea)
CURVE SHIF T DATA
BASELINE, MEASURED, DISPLACEMENT
10360.3, 10360.3, ! 0
10364.7, 10364.3, ! -0.414062
10373, 1 0372.8, ! -0.207031
10380.5, 10380.7, ! 0.207031
10387.3, 10387.5, ! 0.207031
10407.6, 10407, ! -0.62207
10414.5, 10413.2, ! -1.24414
10418.7, 10418.7, ! 0
10423.2, 10421.6, ! -1.65918
10427.2, 10427.6, ! 0.414062
10432.6, 10433, ! 0.414062
10436.4, 10435.8, ! -0.62207
10439.1, 10438.3, ! -0.829102
10442.8, 10443, ! 0.207031
10446.8, 10446.3, ! -0.414062
10450.1, 10450.3, ! 0.207031
10454, 1 0454.2, ! 0.207031
EOZ
END
! BASE CURVE: GROH, OFFSET CURVE: GRAX
Tape Subfile: 1 97 records...
Minimum record length: 10 bytes
Maximum record length: 132 bytes
•
**** FILE HEADER ****
MWD .001
1024
*** LIS COMMENT RECORD ***
~!!!!!!!!!!!!!!!!!! Remark File Version 1.000
The data presented here is final and has been depth shifted to a PDC
(Primary Depth Control) log above the KOP (Kick Off Point)of 10454 ft MD
carrying the final shift at KOP to the bottom logged interval per
Dennis Urban with BP Exploration (Alaska), Inc. The PDC was provided
by Gearhart GR DIL dated 10 Jan 1986.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
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
6 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAS MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
24
Total Data Records: 87
Tape File Start Depth = 10355.000000
Tape File End Depth = 11903.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2 100 records...
Minimum record length: 34 bytes
Maximum record length: 4124 bytes
•
**** FILE HEADER ****
MWD .001
1024
*** LIS COMMENT RECORD ***
!!!!_~!!!!!!!~!!!!!! Remark File Version 1.000
This file contains the raw-unedited field MWD data.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 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: 36
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAS MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
24
Total Data Records: 173
Tape File Start Depth = 10354.750000
Tape File End Depth = 11903.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3 186 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** TAPE TRAILER ****
MWD
08/12/14
•
2345303
O1
**** REEL TRAILER ****
MWD
09/04/28
BHI
O1
Tape Subfile: 4 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
~J
Tape Subfile 1 is type: LIS
Tape Subfile 2 is type: LIS
DEPTH GR ROP
RPD RPS
10355.0000 -999.2500 -999.2500
-999.2500 -999.2500
10355.5000 79.4000 -999.2500
-999.2500 -999.2500
10400.0000 87.7500 28.2125
-999.2500 -999.2500
10500.0000 109.9605 24.0998
9.1666 11.0618
10600.0000 79.7387 19.2998
15.4950 16.5340
10700.0000 38.0195 18.8205
26.2185 35.7403
10800.0000 70.7191 36.4598
16.8927 16.6721
10900.0000 41.8988 30.9195
25.5887 35.6728
11000.0000 50.7008 32.4600
32.9317 39.4029
11100.0000 117.4424 41.6799
11.0130 11.4000
11200.0000 102.6185 60.5246
14.8794 16.9080
11300.0000 55.9395 16.7598
38.6660 54.1440
11400.0000 70.2799 34.8465
44.1073 56.4780
11500.0000 145.1791 39.5801
9.1111 8.4941
11600.0000 41.1980 54.9320
37.8956 59.7830
11700.0000 76.0576 28.2412
32.5600 39.6657
11800.0000 54.9199 30.5199
43.9350 52.8720
11900.0000 -999.2500 46.3607
-999.2500 -999.2500
11903.0000 -999.2500 53.4605
-999.2500 -999.2500
Tape File Start Depth = 10355.000000
Tape File End Depth = 11903.000000
Tape File Level Spacing = 0.500000
RAD
-999.2500
-999.2500
-999.2500
8.8980
16.6550
20.3649
22.7395
17.7580
40.0878
13.4190
19.1844
43.2200
110.8349
12.2850
26.5912
42.4559
61.3506
-999.2500
-999.2500
RAS
-999.2500
-999.2500
-999.2500
11.0611
14.2900
16.8147
14.8680
20.1851
25.0652
9.8430
11.4820
23.2190
28.6268
9.0420
23.5465
21.5195
27.8359
-999.2500
-999.2500
~~
•
Tape File Depth Units = feet
Tape Subfile 3 is type: LIS
DEPTH GR ROP
RPD RPS
10354.7500 -999.2500 -999.2500
-999.2500 -999.2500
10355.0000 -999.2500 -999.2500
-999.2500 -999.2500
10400.0000 84.0000 28.4000
-999.2500 -999.2500
10500.0000 109.4000 24.3000
9.9410 12.2770
10600.0000 81.1000 19.5000
15.4950 16.5340
10700.0000 38.5000 18.3000
26.4940 36.6440
10800.0000 71.6000 36.7000
16.8030 16.5340
10900.0000 43.1000 31.4000
20.5370 37.7200
11000.0000 49.9000 32.5000
33.0670 39.7500
11100.0000 115.0000 41.8000
11.0130 11.4000
11200.0000 104.1000 55.8000
14.9210 16.8820
11300.0000 56.5000 17.0000
38.6660 54.1440
11400.0000 70.4000 28.2000
44.4360 56.8460
11500.0000 146.1000 39.5000
9.0150 8.4060
11600.0000 43.2000 42.6000
37.8940 59.7830
11700.0000 78.5000 27.0000
32.5600 39.9760
11800.0000 55.0000 30.6000
43.9350 52.8720
11900.0000 -999.2500 45.6000
-999.2500 -999.2500
11903.0000 -999.2500 52.9000
-999.2500 -999.2500
Tape File Start Depth = 10354.750000
Tape File End Depth = 11903.000000
Tape File Level Spacing = 0.250000
RAD
-999.2500
-999.2500
-999.2500
9.1210
16.6550
20.4330
22.4680
18.7450
38.2260
13.4190
19.2180
43.2200
118.4840
12.0980
26.4330
42.3110
61.8010
-999.2500
-999.2500
RAS
-999.2500
-999.2500
-999.2500
12.5890
14.2900
17.0830
14.7050
18.8130
24.6820
9.8430
11.5240
23.2190
29.2870
8.8870
23.6090
21.6240
27.9420
-999.2500
-999.2500
•
•
Tape File Depth Units = feet
Tape Subfile 4 is type: LIS
tapescan.txt
**** REEL HEADER ****
MWD
09/06/10
BHI
O1
LIS Customer Format Tape
**** TAPE HEADER ****
MWD
08/12/21
2345303
O1
2.375" CTK
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
version Information
VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20
WRAP. NO: one line per frame
well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 10384.5000: starting De th
STOP.FT 11901.5000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent value
COMP. COMPANY: BP Exploration (Alaska), Inc.
WELL. WELL: MPB-22A
FLD FIELD: Milne Point Unit
LOC LOCATION: 70 deg 28' 26.259"N 149 deg 24' 38.595"w
CNTY. COUNTY: North Slope Borough
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 2.375" CTK
DATE. LOG DATE: 21 Dec 2008
API API NUMBER: 500292150902
Parameter Information Block
#MNEM.UNIT Value
#--------- -------------------------
SECT. 18
TOWN.N T13N
RANG. R11E
PDAT. MSL
EPD .F 0
LMF DF
FAPD.F 59
DMF DF
EKB .F 0
EDF .F 59
EGL .F 0
CASE.F N/A
OS1 DIRECTIONAL
Remarks
Description
Section
Township
Range
Permanent Datum
Elevation Of Perm. Datum
Log Measured from
Feet Above Perm. Datum
Drilling Measured From
Elevation of Kelly Bushing
Elevation of Derrick Floor
Elevation of Ground Level
Casing Depth
Other Services Line 1
(1) All depths are Measured Depths (MD) unless otherwise noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All True vertical Depths (TVDSS) are subsea corrected.
(4) All Formation Evaluation data is realtime data.
Page 1
• •
tapescan.txt
(5) Baker Hughes INTEQ utilized coilTrak downhole tools and the Advantage
surface system to loy this well..
(6) Tools ran in the string included Casing Collar Locator, an
Electrical Disconnect and Circulating Sub, a Drilling
Performance sub (Inner and outer Downhole Pressure, vibration and
Downhole weight on Bit), a Directional and Gamma Sub, and
a Hydraulic orienting sub with a Near Bit Inclination Sensor.
(7) Data presented here is final and has been depth adjusted to a PDC
(Primary Depth Control) log provided by Schlumberger GR CSG dated
28 Dec 2008 per Dennis Urban with BP Exploration (Alaska), Inc.
(8) The sidetrack was drilled from MPB-22A through a milled window in a
7 inch liner.
Top of window 10454 ft.MD (6828.8 ft.TVDSS)
Bottom of window 10460 ft.MD (6831.3 ft.TVDSS)
(9) Tied to MPB-22 at 10423 feet MD (6812.6 feet TVDSS).
(10) Baker Hughes INTEQ runs 4 through 9 were used to drill the MPB-22APB1 well.
(11) The RoP data from 10460 feet to 10564 feet MD (6831.3 feet to 6857.0 feet TVDSS)
is not presented due to an unintentional sidetrack on run 12.
(12) The resistivity interval from 10447 feet to 11000 feet (6824.9 feet to
(6855.8 feet TvDSS) was logged as a MAD Pass 20 hours after drilling run 13.
(13) The interval from 11869 feet to 11903 feet MD (6882.2 feet to 6885.0 feet TvDSS)
was not logged due to sensor to bit offset at well TD.
MNEMONICS:
GRAX -> Gamma Ray [MWD] (MWD-API units)
ROPJaVG -> Rate of Penetration, feet/hour
RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM)
RACHX -> Resistivity (AT)(LS)2MHZ-Compensated Borehole Corrected (oHMM)
RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM)
RPCHX -> Resistivity (PD)(LS)2MHZ-Compensated Borehole Corrected (oHMM)
TVDSS -> True Vertical Depth (Subsea)
CURVE SHIFT DATA
BASELINE, MEASURED,
10441.2, 10446.5,
10450.7, 10453.8,
10460.8, 10463.7,
10462.5, 10467.1,
10468.1, 10470.2,
10470.4, 10473.1,
10472.9, 10475.8,
10481, 10484.3,
10482.2, 10485.9,
10486.8, 10488.8,
10488.2, 10491.5,
10490.3, 10493.8,
10498.2, 10500.2,
10502.9, 10505,
10511.4, 10512.8,
10514.7, 10517,
10521.5, 10523.2,
10525.7, 10527.7,
10531.4, 10533.3,
10538, 10538.9,
10539.5, 10541,
10551.5, 10553,
10557.1, 10558.4,
10569.3, 10573.1,
10580.7, 10582.6,
10585.7, 10587.8,
10592.1, 10593.6,
10594.4, 10596.1,
10598.6, 10598.8,
10600.2, 10600.9,
10609.9, 10611.1,
10612.4, 10613.6,
10618.4, 10619.4,
10626.3, 10628.1,
10633.5, 10636,
10638.1, 10640,
10643.5, 10645.6,
10646, 10648,
DISPLACEMENT
5.38965
3.10938
2.90234
4.56055
2.07227
2.69434
2.90234
3.31641
3.73145
2.07324
3.31641
3.52344
2.07324
2.07324
1.45117
2.28027
1.65918
2.07324
1.86621
0.829102
1.45117
1.45117
1.24316
3.73145
1.86621
2.07324
1.45117
1.6582
0.207031
0.62207
1.24414
1.24316
1.03711
1.86621
2.4873
1.86523
2.07324
2.07324
Page
•
tapescan.txt
10655.7, 10656.8, ! 1.03613
10657.4, 10659.5, ! 2.07324
10664.8, 10666.7, ! 1.86621
10671.7, 10674.4, ! 2.69531
10679.3, 10681.8, ! 2.48828
10683.5, 10685.8, ! 2.28027
10685.6, 10688, ! 2.4873
10691.4, 10693, ! 1.6582
10700.7, 10702.1, ! 1.45117
10703, 10704.4, ! 1.45117
10708.8, 10709.8, ! 1.03613
10710.6, 10712.3, ! 1.65918
10715, 10717.7, ! 2.69434
10717.9, 10719.8, ! 1.86523
10727.8, 10729.9, ! 2.07227
10731.2, 10732.8, ! 1.6582
10738.8, 10739, ! 0.207031
10744.4, 10744.4, ! 0
10747.9, 10749.8, ! 1.86523
10753.1, 10754.7, ! 1.6582
10762.4, 10763.9, ! 1.45117
10768, 10769.9, ! 1.86523
10772.8, 10774.6, ! 1.86523
10785.5, 10787.9, ! 2.4873
10802.5, 10804.1, ! 1.65918
10808.3, 10810.1, ! 1.86621
10813.2, 10815.1, ! 1.86523
10826.3, 10828.1, ! 1.86621
10850.4, 10853.5, ! 3.10938
10880.3, 10882.1, ! 1.86523
10886.1, 10888.4, ! 2.28027
10915.1, 10918, ! 2.90234
10930, 10931.7, ! 1.6582
10988.7, 10990.3, ! 1.6582
11001.8, 11002.9, ! 1.03711
11020.5, 11022.8, ! 2.28027
11034.8, 11035.8, ! 1.03711
11039.3, 11039.1, ! -0.207031
11052, 11052.2, ! 0.207031
11057.2, 11058.4, ! 1.24316
11059, 11060.7, ! 1.6582
11071.5, 11074, ! 2.4873
11080.4, 11080.4, ! 0
11082.8, 11083.6, ! 0.829102
11096.9, 11098.7, ! 1.86523
11203.8, 11204.4, ! 0.62207
11209.6, 11210.4, ! 0.829102
11288.8, 11288.2, ! -0.62207
11305.6, 11304.8, ! -0.830078
11308.9, 11306.9, ! -2.07324
11325.1, 11321.6, ! -3.52441
11327.4, 11324.7, ! -2.69531
11357.3, 11355.2, ! -2.07324
11370.5, 11367.8, ! -2.69434
11372.2, 11369.9, ! -2.28027
11393.3, 11389.4, ! -3.93848
11395.6, 11392.1, ! -3.52441
11399.1, 11395, ! -4.14551
11401.6, 11397.3, ! -4.35254
11404.1, 11399.8, ! -4.35352
11426.4, 11422.9, ! -3.52441
11471.8, 11467.7, ! -4.14648
11488, 11485.1, ! -2.90234
11495.7, 11492.1, ! -3.52441
11499.8, 11497.3, ! -2.4873
11504, 11501.5, ! -2.48828
11505.6, 11503.5, ! -2.07324
11527.7, 11523.3, ! -4.35254
11529.6, 11525.6, ! -3.93848
11535.6, 11531.8, ! -3.73145
Page 3
•
tapescan.txt
11542.6, 11538.5, ! -4.14648
11558.6, 11554, ! -4.56055
11567.7, 11563.5, ! -4.14648
11575.8, 11570.6, ! -5.18262
11588.7, 11585.4, ! -3.31738
11592, 11588.5, ! -3.52441
11593.2, 11591, ! -2.28027
11595.7, 11593.4, ! -2.28027
11602.8, 11598.6, ! -4.14551
11607.5, 11603, ! -4.56055
11609.2, 11604.8, ! -4.35254
11619.8, 11615.8, ! -3.93848
11626.6, 11622.2, ! -4.35352
11644.6, 11641.5, ! -3.10938
11648.4, 11644.5, ! -3.93848
11655.7, 11650.5, ! -5.18262
11659.8, 11653.8, ! -6.01172
11665, 11661.3, ! -3.73145
11674.3, 11671.2, ! -3.10938
11692.6, 11691.3, ! -1.24414
EOZ
END
! BASE CURVE: GROH, OFFSET CURVE: GRAX
Tape subfile: 1 208 records...
Minimum record length: 10 bytes
Maximum record length: 132 bytes
**** FILE HEADER ****
MWD .001
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File version 1.000
The data presented here is final and has been depth shifted to a PDCL
from schlumberger GR CSG dated 28 Dec 2008 per Dennis urban with
BP Exploration (Alaska), Inc.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 28 bytes
Logyin direction is down (value= 255)
OptlCa~ LOS Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames-per record is: 36
one depth per frame (value= 0)
Datum specification Block sub-type is:
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
1
Name Tool Code Samples units size Length
1 GR MWD 68 1 AAPI 4 4
Page 4
•
tapescan.txt
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAs MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
24
Total Data Records: 85
Tape File Start Depth = 10384.500000
Tape File End Depth = 11901.500000
Tape File Level spacing = 0.500000
Tape File Depth units = feet
**** FILE TRAILER ****
Tape subfile: 2 98 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** FILE HEADER ****
MWD .001
1024
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File version 1.000
This file contains the raw-unedited field MWD data.
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame size is: 28 bytes
Loggin 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: 36
one depth per frame (value= 0)
Datum specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
6 Curves:
Name Tool Code Samples Units Size Length
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
3 RAD MWD 68 1 OHMM 4 4
4 RAs MWD 68 1 OHMM 4 4
5 RPD MWD 68 1 OHMM 4 4
6 RPS MWD 68 1 OHMM 4 4
24
Page 5
i
tapescan.txt
Total Data Records: 170
Tape File Start Depth = 10378.750000
Tape File End Depth = 11903.000000
Tape File Level Spacing = 0.250000
Tape File Depth units = feet
**** FILE TRAILER ****
Tape Subfile: 3 183 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** TAPE TRAILER ****
MWD
08/12/21
2345303
O1
**** REEL TRAILER ****
MWD
09/06/10
BHI
O1
Tape Subfile: 4 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
D
Tape subfile 1 is type: LIS
Tape subfile 2 is type: LIS
DEPTH GR ROP RAD RAS
RPD RPs
10384.5000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10385.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10400.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10500.0000 37.0040 -999.2500 11.2525 10.2364
13.4475 11.7350
10600.0000 65.4446 43.9356 15.1490 11.9377
13.7161 14.3988
Page 6
•
tapescan.txt
10700.0000 67.5130 47.3259 29.1329 20.8437
20.3034 20.9084
10800.0000 74.9332 62.4582 14.6203 14.0341
16.2921 19.2171
10900.0000 43.5356 86.3144 24.6041 23.7843
36.0086 39.1625
11000.0000 35.5382 91.7593 15.8160 17.4963
27.1592 43.3321
11100.0000 37.6018 87.5561 18.4893 18.2307
26.0824 38.2145
11200.0000 44.9087 70.8786 18.0649 18.1479
27.9120 43.5835
11300.0000 40.7032 65.4000 18.3760 22.9090
34.0553 56.7930
11400.0000 46.4557 91.3394 10.6354 9.8819
13.9121 19.3705
11500.0000 55.6000 46.9000 22.3740 15.8540
20.5290 24.4040
11600.0000 94.6666 44.7861 42.3010 27.6663
35.9147 44.5006
11700.0000 36.1006 33.3719 28.2435 23.3239
27.2287 34.4202
11800.0000 151.8607 56.8613 9.7725 6.0176
7.1498 6.9870
11900.0000 -999.2500 42.9801 -999.2500 -999.2500
-999.2500 -999.2500
11901.5000 -999.2500 41.1803 -999.2500 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 10384.500000
Tape File End Depth = 11901.500000
Tape File revel Spacing = 0.500000
Tape File Depth Units = feet
Tape subfile 3 is type: LI5
DEPTH GR ROP RAD RAS
RPD RPS
10378.7500 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10379.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10400.0000 -999.2500 -999.2500 -999.2500 -999.2500
-999.2500 -999.2500
10500.0000 33.9000 -999.2500 11.7770 13.2110
14.4910 24.0460
10600.0000 60.1000 48.6000 15.1850 11.6880
13.4450 14.0130
10700.0000 56.6000 53.4000 33.1170 21.3440
21.3760 22.0540
Page 7
tapescan.txt
10800.0000 75.1000 61.6000 13.8480
16.4070 19.5020
10900.0000 38.4000 91.8000 23.4810
34.3820 49.2990
11000.0000 38.8000 84.1000 16.3720
27.4800 43.3470
11100.0000 35.2000 68.7000 18.5830
26.1970 38.4220
11200.0000 40.7000 73.4000 18.3760
27.9120 43.3090
11300.0000 38.5000 66.7000 18.7460
34.3820 58.2280
11400.0000 69.3000 75.1000 4.5790
2.8110 2.3510
11500.0000 55.7000 49.2000 22.2790
20.2590 24.0460
11600.0000 95.1000 53.2000 42.0290
33.9600 41.8570
11700.0000. 34.9000 30.6000 28.2790
27.9260 35.0190
11800.0000 154.3000 63.5000 10.0980
7.3380 7.1330
11900.0000 -999.2500 42.9000 -999.2500
-999.2500 -999.2500
11903.0000 -999.2500 40.9000 -999.2500
-999.2500 -999.2500
Tape File Start Depth = 10378.750000
Tape File End Depth = 11903.000000
Tape File revel Spacing = 0.250000
Tape File Depth units = feet
0
Tape Subfile 4 is type: LIS
12.9700
23.3460
18.9790
17.6450
18.1970
21.1850
2.7770
15.7430
27.6840
24.7960
6.3500
-999.2500
-999.2500
Page 8
