Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout184-011MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg DATE:
P.I. Supervisor
SUBJECT:
FROM:
Petroleum Inspector
Section:31 Township:9N Range:12W Meridian:Seward
Drilling Rig:Rig Elevation:Total Depth:9722 ft MD Lease No.:ADL 0017595
Operator Rep:Suspend:P&A:X
Conductor:O.D. Shoe@ Feet Csg Cut@ Feet
Surface:13 3/8"O.D. Shoe@ 3589 Feet Csg Cut@ Feet
Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet
Production:9 5/8"O.D. Shoe@ 9096 Feet Csg Cut@ Feet
Liner1:7"O.D. Shoe@ 9685 Feet Csg Cut@ Feet
Liner2:7"O.D. Shoe@ 5319 Feet Csg Cut@ Feet
Tubing:3 1/2"O.D. Tail@ 8463 Feet Tbg Cut@ Feet
Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified
Perforation Bridge plug 8464 ft 7799 ft 14 ppg Wireline tag
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remarks:
Attachments:
Brad Whitten
Casing/Tubing Data (depths are MD):
Plugging Data (depths are MD):
No MIT-IA was attempted as the operator says it will not pass due to a hole in the IA that is above the cement plug. The cement
tag was at 7799 ft MD and the sample bailer ran by Pollard Wirelline brought back good cement.
August 24, 2025
Guy Cook
Well Bore Plug & Abandonment
MGS ST 17595 Baker-23
Hilcorp Alaska LLC
PTD 1840110; Sundry 325-339
None
Test Data:
Casing Removal:
rev. 3-24-2022 2025-0824_Plug_Verification_MGS_State_17595_Baker-23_gc
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
Middle Ground Shoal
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,722 See schematic
Casing Collapse
Structural
Conductor
Surface 1,130psi
Production 3,090psi
Liner 7,020psi
Liner 7,020psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Casey Morse
Contact Email:Casey.Morse@hilcorp.com
Contact Phone:(907) 777-8322
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
N/A
6/18/2025
5,3191,437
3-1/2"
5,260
See schematic See schematic
9,685
Perforation Depth MD (ft):
9,096
8,608 - 9,404
700
7"
8,325 - 8,885
9,0447"
265 30"
13-3/8"
9-5/8"9,096
3,589
MD
5,750psi
2,730psi3,560
8,678
3,589
Length Size
Proposed Pools:
265 265
9.2# / L-80
TVD Burst
8,463
8,160psi
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0017595
184-011
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20369-00-00
Hilcorp Alaska, LLC
MGS ST 17595 23
AOGCC USE ONLY
8,160psi
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
Operations Manager
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Middle Ground Shoal Oil N/A
9,065 9,593 8,992 3410 N/A
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 10:24 am, Jun 04, 2025
Digitally signed by Dan
Marlowe (1267)
DN: cn=Dan Marlowe (1267)
Date: 2025.06.04 08:55:11 -
08'00'
Dan Marlowe
(1267)
325-339
Conditions of approval on original sundry 324-357 still apply.
A.Dewhurst 10JUN25
10-407
BJM 6/9/25
X
DSR-6/11/25JLC 6/11/2025
Gregory C. Wilson Digitally signed by Gregory C. Wilson
Date: 2025.06.12 09:41:53 -08'00'06/12/25
RBDMS JSB 061225
Oil Zone P&A Program
Well: Ba-23
Well Name:MGS ST 17595 23 (Ba-23)API Number:50-733-200369-00
Current Status:Shut-in Injector Permit to Drill Number:
Regulatory Contact:Juanita Lovett
First Call Engineer:Casey Morse (907) 777-8322 (o) 603-205-3780 (M)
Second Call Engineer:Eric Dickerman (907) 564-4061 (o)
Current Bottom Hole Pressure (est):4240 psi @ 8320’ TVD (static column of 9.8 ppg brine)
Max. Potential Surface Pressure:3410 psi Gas Column Gradient (0.1 psi/ft)
Current Pressures (T/IA/OA/OOA):5/vac/23/0 psi
History
Drilled in 1984 and completed as an oil producer. It was worked over in 1996 as a waterflood
injector.
The well was shut-in in 2003.
Perforations were plugged with 36 bbls of LCM and the TxIA was loaded with 9.8 ppg brine in
2010.
13-3/8” Casing landed @ 3589’ MD. Mixed & pumped 1800 sxs 13 ppg Class G w/
10% D-20, 2% S1, 0.2% D46 and 0.5% D65 followed by 700 sxs 15.8 ppg Class G
w/ 2% S1 and 0.2% D46. Good returns during first 1200 sxs, partial returns for
remaining job. Estimated lost 400 sxs of 13 ppg lead and 500 sxs 15.8 ppg tail.
Ran 1-1/4” tubing to 235’ and did a top job with 600 sxs 15.8 ppg Class G w/ 2%
CaCl.
9-5/8” Casing landed @ 9095’ MD. Mixed & pumped 1100 sxs Class G w/
additives followed by 750 sxs 15.8 ppg Class G w/ additives.
TOC from Bond Log indicated at 7740’ MD (5/20/96).
Current Status:
Shut-in. Perforations are plugged with a Calcium Carbonate LCM pill and the Tubing and IA are
loaded with 9.8 ppg KWF.
In October 2024, Hilcorp attempted to set a CIBP in the end of tubing. While running in hole, the
CIBP hung up in scale at 4500’, and the tool string sheared off at the rope socket. Slickline
attempted to fish the tool string and ended up encountering scale in the tubing. Multiple bailer
runs recovered scale down to 6,161’ and the 2.57” LIB made it to 6,138’ without any notable
impression. At that time, the operations were discontinued to winterize the platform.
Pre-P&A Diagnostics Performed:
1) T: vac / IA: vac / OA: 13 PSI (OA pressure dropped to 0 while pumping)
2)Pumped 9.8 ppg brine down tubing filled w/ 26bbls, caught fluid, continue
pumping taking returns up IA @ 3 BPM, 900psi. Pump 182 bbls get returns,
continue pumping to get freeze protect out; getting clean 9.8 brine back. Pump
201 bbls total, FCP 1200psi @ 2.75BPM
3)Attempt to inject, pressure up w/ 2.5bbls to 1500psi, hold 5 min bled down to
1200psi.
Oil Zone P&A Program
Well: Ba-23
Objective
Plug and abandon the MGS Oil Pool in the Ba-23.
Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (E). Hilcorp requests the existing
completion packer @ 8464’ MD be used in place of a mechanical bridge plug at a MD distance
of 144 feet above the existing top perforated interval. Cement will be placed above packer. The
base of the proposed P&A plug is at ~8455’ MD. There is only one Pool between that depth and
the top of perforations at 8608’ MD, the Middle Ground Shoal Oil Pool.
Procedural steps:
Coil Tubing
1. MIRU Coiled Tubing and pressure control equipment
2. PT lubricator to 250psi low / 3500psi high
3. Working fluid will be 9.8 ppg brine
a. Take returns to surface up the CT x tubing annulus
4. MU fishing BHA
5. RIH to latch eline fish. POH
a. If fish is below the end of tubing, no need to recover.
b. If CIBP gets hung up or sets above the tubing punch at 8,449’, plan to make up a
mill BHA and mill the CIBP to re-establish TxIA circulation through the tubing
punch holes.
6. RIH with new CIBP and set at ±8,500’ (below the tubing punches 8,449 – 8,455’).
7. RDMO CT
Fullbore
1. Fluid pack the tubing and IA with 9.8 ppg brine.
2. Pump Tubing x IA cement plug as follows:
¾ 20 bbls RIW (Raw-Inlet-Water) w/ Surfactant Wash (down Tbg and out IA)
¾ 50 bbls 14 ppg Class G cement (down Tbg and out IA). Record volume of fluid
recovered)
¾ Foam Wiper Ball
¾ 68 bbls of 9.8 ppg brine displacement of cement (puts TOC in Tbg @ ~7740’,
equivalent with IA)
¾ Tubing volume from punch to 7740’: 0.0087 bpf * (8455’-7740’) = 7 bbls
¾ IA volume from punch to 7740 = 43 bbls
o 8455 to 7740: 0.0589 bpf * 715’ = 43 bbls (53.5 ppf)
Total Cement Volume: 50 bbls
¾ Tubing volume from 7740’ to surface: 0.0087 bpf * 7740’ = 68 bbls
¾ IA volume from 7740’ to surface: 429 bbls
o 7740 to 6413: 0.0589 bpf * 1327’ = 78 bbls (53.5 ppf)
o 6413 to 5319: 0.0613 bpf * 1094’ = 67 bbls (47 ppf)
o 5319 to 3882: 0.0252 bpf * 1437’ = 36 bbls (7” scab liner)
o 3882 to 141: 0.0639 bpf * 3741’ = 239 bbls (40 ppf)
Variance approved. -bjm
Oil Zone P&A Program
Well: Ba-23
o 141 to surface: 0.0589 bpf * 141 =8 bbls (53.5 ppf)
Fullbore/Slickline
1. CMIT TxIA to 2300 psi (AOGCC Witnessed).
2. Tag TOC in Tbg (AOGCC Witnessed).
Attachments:
1.Current Schematic
2.Proposed Schematic
3.Coil BOP Diagram (Fox Energy)
WBD_Ba-23.docx Page 1 CDM 6/2024
Baker Platform 17595 Ba-23
N Middle Ground Shoal
Cook Inlet Basin, Alaska
Middle Ground Shoal
Last Completed: 05/25/1996
Water Injector
Size Type Wt/ Grade/
Conn
ID Top Btm Cmt
Sack
CMT
Top
30” Structural 1.25” Wall 27.5 Surf 265 Driven
13-3/8” Surface
68, 54.5, 61,
K55, K080T,
BTC
12.459 Surf 3589
11.2º
2500 +
600 top
job
Surf
Top Job
9-5/8” Intermed.47, 40, 53.5
S95, N80 BTC 8.835 Surf
9096
44.3º1850 7740
CBL
7” Liner 29, L80, BTC 6.184 8985 9685 210 8985
7”Scab
Liner 29, L80, BTC 6.184 3882 5319 none none
Completion
3-1/2” Tubing 9.2#, L80,
BTC
2.992” 32’ 8463’
Completion Jewelry Detail
No. Depth Length ID OD Item
1 6100+CIBP and setting tool left in hole 10/2025
284645.853.8508.130HES 9-5/8” MHR PKR
385041.382.8133.960HES 3-1/2” x 2-13/16” BTC “X” NIPPLE
485380.772.9924.250HES 3-1/2” RE-ENTRY/PUMP OUT PLUG
538833.48 BAKER 7-5/8” x 9-5/8” JF PKR
1436 7” Scab liner (covers leak from 4296’ - 4341’)
653195.60 BAKER 3D HANGER w/re-entry guide
2010 – Well Tubing punched 8449’ – 8455’ and circulated with 9.8 ppg brine.
2010 – RIH w/2.73” GR to 8510’ RKB, no problems.
7/23/05 – Passed MIT – pressure tested to 1500 psi. (Not witnessed)
9/26/02 – Passed MIT – tested to 2000 psi. (AOGCC witnessed) (Casing lost 30 psi in 30
minutes)
1996 – Ran casing patch and set RTTS at 5291’. Pressure test above to 2500 psi – good.
Pressure test below to 2500 psi – lost 420 psi in 1 hour. AOGCC ok’d running tubing
anyway. Set PX plug and prong in tail and tested to 3500 psi – good.
Fish 8860 PX PLUG & PRONG LOST IN HOLE
8864-9414 4” TCP ASSEMBLY (550’)
Perforation Data
8608 9404 G-1 - G-5 Open
PBTD =9593’ TD = 9722’
MAX HOLE ANGLE = 55
O @ 9500’ MD
30”
265’
7”
9685’
RKB: MSL = 100’
Mudline= 202’ Water Depth= 102’
9-5/8”
9095’
2
7” Scab liner:
3883’ - 5319’
13-3/8”
3589’
Tubing
Punch 8449’-
8455’
TOC CBL
7740’1
5
6
MGS Oil Top
6057’
3
XN
7” TOL:
8985’
9.8
ppg
brine
MGS Gas Base
4740’
4
KB: MSL
Mean Sea Level
Mud Line
ADL: 17595 PTD: 184-011 API: 50-733-20369-00
Leg 4, Slot 2 MGS St 17595 23
Current Schematic
WBD_Ba-23.docx Page 1 CDM 6-12-24
Baker Platform 17595 Ba-23
N Middle Ground Shoal
Cook Inlet Basin, Alaska
Middle Ground Shoal
Last Completed: 05/25/1996
Water Injector
Size Type Wt/ Grade/
Conn
ID Top Btm Cmt
Sack
CMT
Top
30” Structural 1.25” Wall 27.5 Surf 265 Driven
13-3/8” Surface
68, 54.5, 61,
K55, K080T,
BTC
12.459 Surf 3589
11.2º
2500 +
600 top
job
Surf
Top Job
9-5/8” Intermed.47, 40, 53.5
S95, N80 BTC 8.835 Surf
9096
44.3º1850 7740
CBL
7” Liner 29, L80, BTC 6.184 8985 9685 210 8985
7”Scab
Liner 29, L80, BTC 6.184 3882 5319 none none
Completion
3-1/2” Tubing 9.2#, L80,
BTC
2.992” 32’ 8463’
Completion Jewelry Detail
No. Depth Length ID OD Item
184645.853.8508.130HES 9-5/8” MHR PKR
28500 TTP
385041.382.8133.960HES 3-1/2” x 2-13/16” BTC “X” NIPPLE
485380.772.9924.250HES 3-1/2” RE-ENTRY/PUMP OUT PLUG
538833.48 BAKER 7-5/8” x 9-5/8” JF PKR
1436 7” Scab liner (covers leak from 4296’ - 4341’)
653195.60 BAKER 3D HANGER w/re-entry guide
2010 – Well Tubing punched 8449’ – 8455’ and circulated with 9.8 ppg brine.
2010 – RIH w/2.73” GR to 8510’ RKB, no problems.
7/23/05 – Passed MIT – pressure tested to 1500 psi. (Not witnessed)
9/26/02 – Passed MIT – tested to 2000 psi. (AOGCC witnessed) (Casing lost 30 psi in 30
minutes)
1996 – Ran casing patch and set RTTS at 5291’. Pressure test above to 2500 psi – good.
Pressure test below to 2500 psi – lost 420 psi in 1 hour. AOGCC ok’d running tubing
anyway. Set PX plug and prong in tail and tested to 3500 psi – good.
Fish 8860 PX PLUG & PRONG LOST IN HOLE
8864-9414 4” TCP ASSEMBLY (550’)
Perforation Data
8608 9404 G-1 - G-5 Open
PBTD =9593’ TD = 9722’
MAX HOLE ANGLE = 55
O @ 9500’ MD
30”
265’
7”
9685’
RKB: MSL = 100’
Mudline= 202’ Water Depth= 102’
9-5/8”
9095’
2
7” Scab liner:
3883’ - 5319’
13-3/8”
3589’
Tubing
Punch 8449’-
8455’
TOC CBL
7740’
1
50 bbls cement
Est TOC ~7740’
5
6
7
8
MGS Oil Top
6057’
3 XN
7” TOL:
8985’77
8
9.8
ppg
brine
4
MGS Gas Base
4740’
KB: MSL
Mean Sea Level
Mud Line
ADL: 17595 PTD: 184-011 API: 50-733-20369-00
Leg 4, Slot 2 MGS St 17595 23
Proposed Schematic
KLU A-1
Well Head Rig Up
1
1
1
1
4 1/16" 15K Lubricator - 10 ft
100" Gooseneck
HR680 Injector Head
4 1/16" 10K Flow Cross, 2" 1502 10k Flanged
Valves
4 1/16" 15K Lubricator - 10 ft
API Flange Adapter 10K to 5K for riser/wellhead
Hydraulic Stripper 4 1/6" 15K
API Bowen CB56 15K
4 1/16" 10K Combi BOPs
Blind/Shear Ram
Pipe/Slip Ram
4 1/16" 10K bottom flange
4 1/16" 5K flanged Riser - 10 ft if necessary
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Exploratory Development
3. Address:Stratigraphic Service
6. API Number:
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Yes No
9. Property Designation (Lease Number): 10. Field:
Middle Ground Shoal
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD):
9,722 See schematic
Casing Collapse
Structural
Conductor
Surface 1,130psi
Production 3,090psi
Liner 7,020psi
Liner 7,020psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
AOGCC Representative: GINJ Op Shutdown Abandoned
Contact Name: Casey Morse
Contact Email:Casey.Morse@hilcorp.com
Contact Phone:(907) 777-8322
Authorized Title:
Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other Conditions of Approval:
Post Initial Injection MIT Req'd? Yes No
APPROVED BY
Approved by: COMMISSIONER THE AOGCC Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
N/A
6/30/2024
5,3191,437
3-1/2"
5,260
See schematic See schematic
9,685
Perforation Depth MD (ft):
9,096
8,608 - 9,404
700
7"
8,325 - 8,885
9,0447"
265 30"
13-3/8"
9-5/8"9,096
3,589
MD
5,750psi
2,730psi3,560
8,678
3,589
Length Size
Proposed Pools:
265 265
9.2# / L-80
TVD Burst
8,463
8,160psi
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0017595
184-011
3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20369-00-00
Hilcorp Alaska, LLC
MGS ST 17595 23
AOGCC USE ONLY
8,160psi
Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft):
Operations Manager
Subsequent Form Required:
Suspension Expiration Date:
Will perfs require a spacing exception due to property boundaries?
Current Pools:
MPSP (psi): Plugs (MD):
17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval.
Authorized Name and
Digital Signature with Date:
Tubing Size:
PRESENT WELL CONDITION SUMMARY
Middle Ground Shoal Oil N/A
9,065 9,593 8,992 3410 N/A
No
Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov
By Grace Christianson at 3:38 pm, Jun 19, 2024
Digitally signed by Dan
Marlowe (1267)
DN: cn=Dan Marlowe (1267)
Date: 2024.06.19 15:09:12 -
08'00'
Dan Marlowe
(1267)
324-357
No cement present outside casing across MGS Gas pool or top of MGS oil pool. Need to address isolation of MGS Gas pool in separate sundry.
DSR-6/21/24
X-bjmAbandon-bjm
Provide 48 hrs notice for AOGCC opportunity to witness cement tag and CMIT TxIA to 2300 psi.
This sundry does not approve the proposed surface plug at this time.
Top of cement inside tubing and IA must be no shallower than TOC outside 9-5/8" casing.
10-404
SFD 6/20/2024
X
BJM 9/6/24*&:
Jessie L. Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2024.09.06 14:40:34 -07'00'
09/06/24
RBDMS JSB 091024
Oil Zone P&A Program
Well: Ba-23
Well Name:MGS ST 17595 23
(Ba-23)
API Number:50-733-200369-00
Current Status:Shut-In Injector Rig:SL, FB, cement
Estimated Start Date:June 2024 Estimated Duration:2 days
Reg.Approval Req’d?Yes
Regulatory Contact:Juanita Lovett
First Call Engineer:Casey Morse 603-205-3780 (M)
Second Call Engineer:Ryan Rupert 907-301-1736 (M)
Current Bottom Hole Pressure (est):4240 psi @ 8320’ TVD (static column of 9.8 ppg brine)
Max. Potential Surface Pressure:3410 psi Gas Column Gradient (0.1 psi/ft)
Current Pressures (T/IA/OA/OOA):5/vac/23/0 psi
History
Drilled in 1984 and completed as an oil producer. It was worked over in 1996 as a waterflood
injector.
The well was shut-in in 2003.
Perforations were plugged with 36 bbls of LCM and the TxIA was loaded with 9.8 ppg brine in
2010.
13-3/8” Casing landed @ 3589’ MD. Mixed & pumped 1800 sxs 13 ppg Class G w/
10% D-20, 2% S1, 0.2% D46 and 0.5% D65 followed by 700 sxs 15.8 ppg Class G
w/ 2% S1 and 0.2% D46. Good returns during first 1200 sxs, partial returns for
remaining job. Estimated lost 400 sxs of 13 ppg lead and 500 sxs 15.8 ppg tail.
Ran 1-1/4” tubing to 235’ and did a top job with 600 sxs 15.8 ppg Class G w/ 2%
CaCl.
9-5/8” Casing landed @ 9095’ MD. Mixed & pumped 1100 sxs Class G w/
additives followed by 750 sxs 15.8 ppg Class G w/ additives.
TOC from Bond Log indicated at 7740’ MD (5/20/96).
Current Status:
Shut-in. Perforations are plugged with a Calcium Carbonate LCM pill and the Tubing and IA are
loaded with 9.8 ppg KWF.
Pre-P&A Diagnostics Performed:
1) T: vac / IA: vac / OA: 13 PSI (OA pressure dropped to 0 while pumping)
2)Pumped 9.8 ppg brine down tubing filled w/ 26bbls, caught fluid, continue
pumping taking returns up IA @ 3 BPM, 900psi. Pump 182 bbls get returns,
continue pumping to get freeze protect out; getting clean 9.8 brine back. Pump
201 bbls total, FCP 1200psi @ 2.75BPM
3)Attempt to inject, pressure up w/ 2.5bbls to 1500psi, hold 5 min bled down to
1200psi.
Objective
Plug and abandon the Ba-23.
Oil Zone P&A Program
Well: Ba-23
Hilcorp requests a variance to 20 AAC 25.112 (c) (1) (E). Hilcorp requests the existing
completion packer @ 8464’ MD be used in place of a mechanical bridge plug at a MD distance
of 144 feet above the existing top perforated interval (perforations are plugged with LCM).
Cement will be placed above packer. The base of the proposed P&A plug is at ~8455’ MD.
There is only one Pool between that depth and the top of perforations at 8608’ MD, the Middle
Ground Shoal Oil Pool.
Hilcorp requests a variance to 20 AAC 25.112 (d) (1).Hilcorp requests that the surface
cement plugs extend up to the wellhead and tree valves. This is to ensure the well is properly
cemented and to avoid any uncertainty as to the cement top. The platform legs and wells will
need to be severed completely at or near the seafloor to remove the legs eventually, and the
extra cement in the casing strings should not impede this operation significantly.
Procedural steps:
Slickline
1. Set tubing tail plug below tubing punches @ ~8500’.
Fullbore
1. Fluid pack the tubing and IA.
2. Pump Tubing x IA cement plug as follows:
¾ 20 bbls RIW (Raw-Inlet-Water) w/ Surfactant Wash (down Tbg and out IA)
¾ 322 bbls 14 ppg Class G cement (down Tbg and out IA). Record volume of fluid
recovered)
¾ Foam Wiper Ball
¾ 31 bbls of 9.8 ppg brine displacement of cement (puts TOC in Tbg @ ~3500’,
equivalent with IA)
¾ Tubing volume from punch to 3500’: 0.0087 bpf * (8455’-3500’) =43 bbls
¾ IA volume from punch to 3500 = 248 bbls
o 8455 to 6413: 0.0589 bpf * 2042’ =120 bbls (53.5 ppf)
o 6413 to 5319: 0.0613 bpf * 1094’ =67 bbls (47 ppf)
o 5319 to 3882: 0.0252 bpf * 1437’ =36 bbls (7” scab liner)
o 3882 to 3500: 0.0639 bpf * 382’ =25 bbls (40 ppf)
Total Cement Volume with 10% excess: 322 bbls
¾ Tubing volume from 3500’ to surface: 0.0087 bpf * 3500’ =31 bbls
¾ IA volume from 7000’ to surface:223 bbls
o 3500 to 141: 0.0639 bpf * 3359’ =215 bbls (40 ppf)
o 141 to surface: 0.0589 bpf * 141 =8 bbls (53.5 ppf)
Fullbore/Slickline
1. CMIT TxIA to 1500 psi (AOGCC Witnessed).
2. Tag TOC in Tbg (AOGCC Witnessed).
E-line
1. Perforate the Tubing & Casing @ ~500’ MD.This perf at 500' and surface plug is not approved as part of
this sundry. -bjm
7 bbls -bjm
7740' MD. -bjm
IA volume to 7740' = 42 bbls -bjm
Variance Approved. -bjm
Recalculate as needed. -bjm
The surface plug scope is not approved as part of this sundry. -bjm
54 bbls -bjm
7740'
CMIT to 2300 psi (25% of TVD of casing shoe) -bjm
Cement plug top must target TOC outside 9-5/8" casing at 7740' MD. Adjust
volume accordingly. -bjm
Oil Zone P&A Program
Well: Ba-23
Fullbore
1. Verify circulation down the tubing and out the IA / OA.
2. Pump TxIAxOA cement plug
¾ 30 bbls RIW w/ surfactant wash down tubing
¾ Circulate 2x bottoms up from the OA, IA (64 bbl, 63 bbl)
¾ 77 bbls 14 ppg Class G cement
i. Circulate out the OA until good cement returns are observed at surface,
then swap to taking returns from the IA
ii. Circulate out the IA until good cement returns are observed at surface
¾ Tubing volume from 500’ to surface: 0.0087 bpf * 500’ =5 bbls
¾ IA volume from 500’ to 141’: 0.0639 bpf * 359’ =23 bbls (40 ppf)
¾ IA volume from 141’ to surf: 0.0589 bpf * 141 =8 bbls (53.5 ppf)
¾ OA volume from 500’ to 49’: 0.0646 bpf * 451 =29 bbls (54.5 ppf)
¾ OA volume from 49’ to surf: 0.0597 bpf * 49 =3 bbls (68 ppf)
Attachments:
1.Current Schematic
2.Proposed Schematic
WBD_Ba-23.docx Page 1 CDM 6/2024
Baker Platform 17595 Ba-23
N Middle Ground Shoal
Cook Inlet Basin, Alaska
Middle Ground Shoal
Last Completed: 05/25/1996
Water Injector
Size Type Wt/ Grade/
Conn
ID Top Btm Cmt
Sack
CMT
Top
30” Structural 1.25” Wall 27.5 Surf 265 Driven
13-3/8” Surface
68, 54.5, 61,
K55, K080T,
BTC
12.459 Surf 3589
11.2º
2500 +
600 top
job
Surf
Top Job
9-5/8” Intermed.47, 40, 53.5
S95, N80 BTC 8.835 Surf
9096
44.3º1850 7740
CBL
7” Liner 29, L80, BTC 6.184 8985 9685 210 8985
7”Scab
Liner 29, L80, BTC 6.184 3882 5319 none none
Completion
3-1/2” Tubing 9.2#, L80,
BTC
2.992” 32’ 8463’
Completion Jewelry Detail
No. Depth Length ID OD Item
184645.853.8508.130HES 9-5/8” MHR PKR
285041.382.8133.960HES 3-1/2” x 2-13/16” BTC “X” NIPPLE
385380.772.9924.250HES 3-1/2” RE-ENTRY/PUMP OUT PLUG
438833.48 BAKER 7-5/8” x 9-5/8” JF PKR
1436 7” Scab liner (covers leak from 4296’ - 4341’)
553195.60 BAKER 3D HANGER w/re-entry guide
2010 – Well Tubing punched 8449’ – 8455’ and circulated with 9.8 ppg brine.
2010 – RIH w/2.73” GR to 8510’ RKB, no problems.
7/23/05 – Passed MIT – pressure tested to 1500 psi. (Not witnessed)
9/26/02 – Passed MIT – tested to 2000 psi. (AOGCC witnessed) (Casing lost 30 psi in 30
minutes)
1996 – Ran casing patch and set RTTS at 5291’. Pressure test above to 2500 psi – good.
Pressure test below to 2500 psi – lost 420 psi in 1 hour. AOGCC ok’d running tubin g
anyway. Set PX plug and prong in tail and tested to 3500 psi – good.
Fish 8860 PX PLUG & PRONG LOST IN HOLE
8864-9414 4” TCP ASSEMBLY (550’)
Perforation Data
8608 9404 G-1 - G-5 Open
PBTD =9593’ TD = 9722’
MAX HOLE ANGLE = 55O @ 9500’ MD
30”
265’
7”
9685’
RKB: MSL = 100’
Mudline= 202’ Water Depth= 102’
9-5/8”
9095’
2
7” Scab liner:
3883’ - 5319’
13-3/8”
3589’
Tubing
Punch 8449’-
8455’
TOC CBL
7740’
1
4
5
6
7
MGS Oil Top
6057’
3
XN
7” TOL:
8985’
4
5
4
1
66
7
9.8
ppg
brine
MGS Gas Base
4740’
KB: MSL
Mean Sea Level
Mud Line
ADL: 17595 PTD: 184-011 API: 50-733-20369-00
Leg 4, Slot 2 MGS St 17595 23
Current Schematic
WBD_Ba-23.docx Page 1 CDM 6-12-24
Baker Platform 17595 Ba-23
N Middle Ground Shoal
Cook Inlet Basin, Alaska
Middle Ground Shoal
Last Completed: 05/25/1996
Water Injector
Size Type Wt/ Grade/
Conn
ID Top Btm Cmt
Sack
CMT
Top
30” Structural 1.25” Wall 27.5 Surf 265 Driven
13-3/8” Surface
68, 54.5, 61,
K55, K080T,
BTC
12.459 Surf 3589
11.2º
2500 +
600 top
job
Surf
Top Job
9-5/8” Intermed.47, 40, 53.5
S95, N80 BTC 8.835 Surf
9096
44.3º1850 7740
CBL
7” Liner 29, L80, BTC 6.184 8985 9685 210 8985
7”Scab
Liner 29, L80, BTC 6.184 3882 5319 none none
Completion
3-1/2” Tubing 9.2#, L80,
BTC
2.992” 32’ 8463’
Completion Jewelry Detail
No. Depth Length ID OD Item
184645.853.8508.130HES 9-5/8” MHR PKR
28500 TTP
385041.382.8133.960HES 3-1/2” x 2-13/16” BTC “X” NIPPLE
485380.772.9924.250HES 3-1/2” RE-ENTRY/PUMP OUT PLUG
538833.48 BAKER 7-5/8” x 9-5/8” JF PKR
1436 7” Scab liner (covers leak from 4296’ - 4341’)
653195.60 BAKER 3D HANGER w/re-entry guide
2010 – Well Tubing punched 8449’ – 8455’ and circulated with 9.8 ppg brine.
2010 – RIH w/2.73” GR to 8510’ RKB, no problems.
7/23/05 – Passed MIT – pressure tested to 1500 psi. (Not witnessed)
9/26/02 – Passed MIT – tested to 2000 psi. (AOGCC witnessed) (Casing lost 30 psi in 30
minutes)
1996 – Ran casing patch and set RTTS at 5291’. Pressure test above to 2500 psi – good.
Pressure test below to 2500 psi – lost 420 psi in 1 hour. AOGCC ok’d running tubin g
anyway. Set PX plug and prong in tail and tested to 3500 psi – good.
Fish 8860 PX PLUG & PRONG LOST IN HOLE
8864-9414 4” TCP ASSEMBLY (550’)
Perforation Data
8608 9404 G-1 - G-5 Open
PBTD =9593’ TD = 9722’
MAX HOLE ANGLE = 55O @ 9500’ MD
30”
265’
7”
9685’
RKB: MSL = 100’
Mudline= 202’ Water Depth= 102’
9-5/8”
9095’
2
7” Scab liner:
3883’ - 5319’
13-3/8”
3589’
Tubing
Punch 8449’-
8455’
TOC CBL
7740’
1
322 bbls
cement
77 bbls
cement
Perf ~500’
5
6
7
8
MGS Oil Top
6057’
3 XN
7” TOL:
8985’77
8
9.8
ppg
brine
4
MGS Gas Base
4740’
KB: MSL
Mean Sea Level
Mud Line
ADL: 17595 PTD: 184-011 API: 50-733-20369-00
Leg 4, Slot 2 MGS St 17595 23
Proposed Schematic
Superseded
WBD_Ba-23.docx Page 1 CDM 6-12-24
Baker Platform 17595 Ba-23
N Middle Ground Shoal
Cook Inlet Basin, Alaska
Middle Ground Shoal
Last Completed: 05/25/1996
Water Injector
Size Type Wt/ Grade/
Conn
ID Top Btm Cmt
Sack
CMT
Top
30”Structural 1.25” Wall 27.5 Surf 265 Driven
13-3/8” Surface
68, 54.5, 61,
K55, K080T,
BTC
12.459 Surf 3589
11.2º
2500 +
600 top
job
Surf
Top Job
9-5/8” Intermed. 47, 40, 53.5
S95, N80 BTC 8.835 Surf 9096
44.3º1850 7740
CBL
7”Liner 29, L80, BTC 6.184 8985 9685 210 8985
7” Scab
Liner 29, L80, BTC 6.184 3882 5319 none none
Completion
3-1/2” Tubing 9.2#, L80,
BTC
2.992” 32’ 8463’
Completion Jewelry Detail
No. Depth Length ID OD Item
1 8464 5.85 3.850 8.130 HES 9-5/8” MHR PKR
2 8500 TTP
3 8504 1.38 2.813 3.960 HES 3-1/2” x 2-13/16” BTC “X” NIPPLE
4 8538 0.77 2.992 4.250 HES 3-1/2” RE-ENTRY/PUMP OUT PLUG
5 3883 3.48 BAKER 7-5/8” x 9-5/8” JF PKR
1436 7” Scab liner (covers leak from 4296’ -4341’)
6 5319 5.60 BAKER 3D HANGER w/re-entry guide
2010 – Well Tubing punched 8449’ – 8455’ and circulated with 9.8 ppg brine.
2010 – RIH w/2.73” GR to 8510’ RKB, no problems.
7/23/05 – Passed MIT – pressure tested to 1500 psi. (Not witnessed)
9/26/02 – Passed MIT – tested to 2000 psi. (AOGCC witnessed) (Casing lost 30 psi in 30
minutes)
1996 – Ran casing patch and set RTTS at 5291’. Pressure test above to 2500 psi – good.
Pressure test below to 2500 psi – lost 420 psi in 1 hour. AOGCC ok’d running tubing
anyway. Set PX plug and prong in tail and tested to 3500 psi –good.
Fish 8860 PX PLUG & PRONG LOST IN HOLE
8864-9414 4” TCP ASSEMBLY (550’)
Perforation Data
8608 9404 G-1 -G-5 Open
PBTD =9593’ TD = 9722’
MAX HOLE ANGLE = 55O @ 9500’ MD
30”
265’
7”
9685’
RKB: MSL = 100’
Mudline= 202’ Water Depth= 102’
9-5/8”
9095’
2
7” Scab liner:
3883’ - 5319’
13-3/8”
3589’
Tubing
Punch 8449’-
8455’
TOC CBL
7740’
1
54 bbls cement
Est TOC ~7740’
5
6
7
8
MGS Oil Top
6057’
3 XN
7” TOL:
8985’ 77
8
9.8
ppg
brine
4
MGS Gas Base
4740’
KB: MSL
Mean Sea Level
Mud Line
ADL: 17595 PTD: 184-011 API: 50-733-20369-00
Leg 4, Slot 2 MGS St 17595 23
Proposed Schematic
David Douglas Hilcorp North Slope, LLC
Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 777-8337
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 08/22/2024
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL T20240822
Log Image Files for the well listed in the table below:
Well Name PTD # API #
MGS ST 17595 23 184-011 50-733-20369-00-00
SFTP Transfer - Data Folders:
Please include current contact information if different from above.
184-011
T39469
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2024.08.22 11:04:09 -08'00'
Im ect Well History File Cov~!l~:age '
XHVZE
This page identifieS those items that were not scanned during the initial production scanning
phase. They are available in the original file, may be scanned during a special rescan activity or
are viewable by direct inspection of the file..
L ~' ~- ,~) 1 L Well History File Identifier
RESCAN DIGITAL DATA
[] Color items: n Diskettes, No.
D Grayscale items: [] .Other, No/Type
[] Poor Quality Originals:
[] Other:
NOTES:
OVERSIZED (Scannable)
[] Maps:
[] Other items scannable by
large scanner
O:~~Scannable)
~"~' Logs of various kinds
Other
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATEJ IS/
Project Proofing
BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/
Scanning Preparation ,~ x 30 = +
BY: BEVERLY BREN VINCENT SHERY.L~ LOWELL
Y
Production Scanning
Stage 1 PAGE COUNT FROM SCANNED FILE: ] ~ 0
P,~OUNT MATC,ES.UMBER ~. SCA..~,G PREPARAT~O.: ~ YES
Stage 2 IF NO IN STAGE '~, PAGE(S) DISCREPANCIES WERE FOUND: YES
BY; BEVERLY BREN VINCE~~IARIA LOWELL
0 = TOTAL PAGES
NO
NO.
III IIIIIIIIIII II III
ReScanned ~.,~ivid. al p~,~.~e [special attentions] $camfing completed}
RESCANNED BY: BEVERLY BREN VINCENT SHEEYL MARIA LOWELL
h
General Notes or Comments about this file:
DATE:
Is~
Quality Checked
)
)
Chevron
III
Timothy C Brandenburg
Drilling Manager
Union Oil Company of California
P.O. Box 196427
Anchorage, AK 99519-6247
Tel 907 263 7657
Fax 907 263 7884
Email brandenburgt@chevron.com
October 10,2005
~=i~:~~~~S~:U~::ion Commission ~Ntl) NO\¡ I) ß 2.0~J)i'n .
333 W. th Avenue
Anchorage, Alaska 99501
~L\-/O\I
\~ -' d-~
Re: Baker Platform Pilot Pre-Abandonment Work Summary
." ...' ....' , .'~',.
Dear Commissioner Norman,
This letter is intended to update the Alaska Oil and Gas Conservation Commission on the status of
Unocal's pilot pre-abandonment work on the Baker Platform in Cook Inlet, Alaska.
On October 22, 2004, Unocal proposed that a pilot program be initiated on the Baker platform to develop
a safe, cost effective, and optimal method for the abandonment of multiple well bores. As noted in the
letter of October 22, 2004, Unocal has operated the Baker and Dillon Platforms under a "lighthouse"
mode where all oil and gas production has been shut-in. The Dillon Platform was shut-in December 2002
and the Baker Platform was shut-in August 2003.
Unocal commenced the pilot study with a diagnostic program on five water injection wells and three oil
wells on the Baker Platform in July 2005. The diagnostic program consisted of pressure and temperature
surveys for baseline data, mechanical integrity of the completion, injectivity tests to the formation, and
pressure measurement on the outer casing annuli. The injection wells initially surveyed were Baker 7,
8rd, 12, 15rd, and 27. The oil wells surveyed were Baker 13, 28, and 30.
Unocal did not anticipate that any of the oil wells on the Baker platform would have a bottom hole
pressure (BlIP) gradient exceeding seawater. However, when it was discovered that Baker well 28 had a
static BlIP of9.0 ppg, the diagnostic program was expanded to include all of the oil wells and water
injection wells on the Baker Platform as well as six wells on the Dillon Platform.
The Baker water injection wells have mostly held their residual pressure since being shut-in. Their BlIP
gradients range from 5.8 to 9.4 ppg. Three oil wells on the Baker platform have BlIP gradients that
exceed a seawater gradient. Two additional wells have pressures that exceed an oil gradient but are below
a seawater gradient. Under the right conditions, these wells could be capable of unassisted flow. The
Baker Platform Well BlIP Summary is attached.
The Dillon well BHPs are all below a seawater gradient of 8.4 ppg. No additional diagnostic well work
on the Dillon platform has been initiated.
r'dJ~~. 1(' ATE
,J ,~.-'.~ \ toO" t~ \
. þ .,,...
Union Oil Company of California / A Chevron Company
http://www.chevron.com
)
)
Commissioner John Norman
Alaska Oil & Gas Conservation Commission
October 10, 2005
Page 2
No temperature anomalies were noted on the Baker platform with the exception of Baker well 28. Baker
28 exhibited a temperature anomaly at approximately 5,000 feet MD, as noted on the attached Baker
Composite Temperature Chart. An assessment of Baker 28 is attached with the recommendation of no
remedial activity. Chevron intends to conduct annual temperature/pressure surveys on Baker 28 to
monitor the well status. There were no temperature anomalies noted on the Dillon platform wells.
The pilot abandonment program commenced with plugging perforations on the water injection wells
initially identified (i.e. Baker wells 7, 8rd, 12, 15rd, and 27). The plugging of the perforations received
Sundry approval and the integrity testing of the cement plugs was witnessed by an AOGCC
representative. In addition, perforations were plugged in the water supply well Baker 501 and in the gas
well Baker 32. In light of the Chevron Corporation acquisition ofUnocal, the well plugging operations
for the oil wells on the Baker platform has been omitted from the 2005 pilot program to allow time to
reassess economic potential under Chevron's criteria. Furthermore, the gas potential from the Baker is
also being re-assessed.
To better prepare for the winter, Chevron will be applying heat on both the Baker and Dillon platfonns.
In addition, the wells capable of receiving a freeze protect fluid in their respective annuli will be freeze
protected.
If you have any questions or concerns, please contact me at 907-263-7657.
Sincerely,
~Ø~'-A~7
Timothy C. Brandenburg
Drilling Manager
Attachments
Cc: Dale Haines
Gary Eller
Union Oil Company of California / A Chevron Company
http://www.chevron.com
Baker Platform Well BHP Summary
Last Updated: October 7,2005
Pressure
Survey Measured Gradient Equivalent Mud
Well Well Type Date MD (ft) TVD (ft) BHP (psia) (psi/ft) Weight (ppg) Notes
Ba-4 Injector 27-Jul-05 7850 7843 3141 0.400 7.7
Ba-5 Producer 30-Jul-05 6284 5566 2753 0.495 9.5
Ba-6 Producer 20-Jul-05 5712 5709 2811 0.492 9.5
Ba-7 Injector 7-Jul-05 6244 5630 2712 0.482 9.3
Ba-8rd Injector 7 -Jul-05 7100 6937 3288 0.474 9.1
Ba-9rd2 Injector Perfs cemented, no survey planned 'oc_"
Ba-11 Producer 21-Jul-05 8379 8113 3273 0.403 7.8
Ba-12s Injector 6-Jub05
Ba-121 Injector 16-Jul-05 7121 6106 2941 0.482 9.3
Ba-13 Producer 6-Jul-05 7916 7661 3236 0.422 8.1
Ba-14 Gas No survey
Ba-15rd Injector 5-Jul-05 6480 6286 3050 0.485 9.3
Ba-16 Injector No survey
Ba-17 Injector No survey
Ba-18 Gas No survey
Ba-20 Producer 28-Jul-05 4134 4030 1242 0.308 5.9 Obstruction in tubing at 4139'
~Ba-23 Injector 23-Jul-05 8841 8499 2584 0.304 5.8
Ba-25rd Producer 22-Jul-05 9495 9033 3208 0.355 6.8
Ba-27 Injector 6-Jul-05 7779 5999 2928 0.488 9.4
Ba-28 Producer 3-Jul-05 8441 5308 2497 0.470 9.0
Ba-29 Producer 28-Jul-05 7923 7594 2165 0.285 5.5
Ba-30 Producer 4-Jul-05 10966 9109 3593 0.394 7.6 -
Ba-31 Producer 29-Jul-05 11433 10636 3795 0.357 6.9
Ba-32 Producer No survey
,. ~
)
..
~~~=:E :J ~~!Æ~~«!Æ
A.I~A.SIiA. OIL AM) GAS
CONSERVATION COMMISSION
Mr. Dave Cole
Oil Team Manager
UNOCAL
P.O. Box 196247
Anchorage, AK 99516-6247
Re:
Middle Ground Shoal Unit
Platforms Dillon and Baker
Dear Mr. Cole:
)
FRANK H. MURKOWSK', GOVERNOR
333 W. ]TH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
IJ¡.,:-DII
\~~
This letter confirms your conversation with Cow..mission Engineer Tom Maunder last week regarding the
multiple Applications for Sundry Approval (Form 403) you submitted in mid October regarding changing
the monitoring frequency on the 16 wells on Dillon Platform and 23 wells on Baker Platform. Production
and injection operations were halted on these platforms in 4th Q 2002 and 2nd Q 2003 respectively.
Attached, please fmd the Sundry Applications, which are being returned without approval~ because the
relief you request needs to be sought through a different procedure.
The intent of submitting sundry notices for each well was to establish a monthly pressure and general
monitoring frequency for all wells on Dillon and Baker. There is a requirement in place 'for some, of the
water injection wells that pressures and rates are to be monitored daily and reported monthly. Since the
platforms are unmanned and not operating, it is not possible to obtain daily information. When
operations were curtailed, a monthly monitoring frequency was established in the Plans of Development
(POD) annually filed with the Division of Oil and Gas and Unocal desires to assure that this monitoring
scheme is accepted by the Commission.
As noted in the conversation, changing the monitoring frequency where presently in place and
establishing a monthly monitoring frequency in general is not an action that is best accomplished with
multiple sundry notices. A letter application requesting the desired monitoring schedule should be made
under the applicable Area Injection Orders (AlO 7 for Baker and AIO 8 for Dillon) and Conservation
Orders (CO 44 and CO 54) for the platforms/unit. The Commission looks forward to receiving your letter
applications. If prior monthly monitoring information has not been submitted to the Commission, that
information should be ubmitted forthwith.
,~' Sincer~~
. No an Daniel T. Seamount, Jr.
Commissioner
BY ORDER OF THE COMMISSION
DATED this !.2day of November, 2004
Ene!.
SCANNErj NO",!\,/ "), <) '¡' [' -
" d L. JULi
...
If,
1. Type of Request:
3. Address:
7. KB Elevation (ft):
79'
8. Property Designation:
BAKER
11.
Total Depth MD (ft):
9,722'
Casing
Structural
Conductor
Su rface
Intermediate
Production
Liner
Perforation Depth MD (ft):
8,608' to 9,404'
Packers and SSSV Type:
') STATE OF ALASKA )
ALAS",A OIL AND GAS CONSERVATION COMMlbSION
APPLICATION FOR SUNDRY APPROVAL
20 AAC 25.280
Operational shutdown U
Plug Perforations D
Perforate New Pool D
4. Current Well Class:
Suspend U
Repair well D
Pull Tubing D
909 West 9th Ave.
Anchorage AK 99501
Development
Stratigraphic
D
D
Perforate U WaiverU Annular Dispos. U
Stimulate D Time Extension D Other 0
Re-enter Suspended Well D Monitor Frequency
5. Permit to Drill Number:
Exploratory D
Service 0
9. Well Name and Number:
Ba-23
10. Field/Pools(s):
MIDDLE GROUND SHOAL
PRESENT WELL CONDITION SUMMARY
Total Depth TVD (ft):
Effective Depth MD (ft):
Abandon U
Alter casing D
Change approved program D
2. Operator Name: Union Oil of California
aka Unocal
9,062'
Length
9,593'
Size
MD
3,589' 13-3/8"
9,095' 9-5/8"
700' 7"
Perforation Depth TVD (ft):
8,324' to 8,854'
Plugs (measured): IJUnk (measured):
PX plug & Prong @ 8,860'
Burst Collapse
TVD
3,559'
8,675'
8,590'-9253'
Tubing Grade:
2,734 psi 1,128 psi
6,865 psi 4,894 psi
8,160 psi 7,028 psi
Tubing MD (ft):
3-1/2" 9.2#, L-80
Packers and SSSV MD (ft):
8,464'
12. Attachments: Description Summary of Proposal
Detailed Operations Program D BOP Sketch
14. Estimated Date for
Commencing Operations:
13. Well Class after proposed work:
Exploratory D Development
15. Well Status after proposed work:
Oil D Gas D
WAG D GINJ D
16. Verbal Approval:
Commission Representative:
Date:
17. I hereby certify that the foregoing is true and co ect to the best of my knowledge.
Printed Naml"; 7)A/¡cole
Signatur~4./ a~
Title
Phone
Oil Team Supervisor
907-263-7805 Date
COMMISSION USE ONLY
Conditions of approval: Notify Commission 0 that a representative may witness
Plug Integrity
0
Other:
Subsequent Form Required:
Approved by:
Mechanical
Contact
D
Service 0
Plugged
WINJ
D
0
WDSPL
Abandoned
D
D
27-Sep-2004
Sundry Number:
.2C)tf -L/'3S-
- I"""\I_-"-n,.,.o.
RBDMS BFL NOV 2 2 20D4
APPLICA TION RETURNED 11/17/04
NOT APPROVED BY COMMISSION
0 q I G , ~, [\ I ~YORDEROF
THE COMMISSION
COMMISSIONER
~3
Form 1 O-~evised 12/2003
n
RECEIVED
OCT 1 2 2004
,ska Oil & Gas Cons. Commission
Anchorage
Date:
Submit in Duplicate
MEMORANDUM
State of AlaSka
Alaska Oil and Gas Conservation Commission
TO: Cammy O. Taylor
Chair
THRU: Tom Maunder
Petroleum Engineer ~
FROM: Lou Grimaldi
Petroleum Inspector
DATE: September-26, 2002
SUBJECT: Mechanical Integrity Tests
UNOCAL
Baker Platform
Ba-4, 16, 17, 23
Middle Ground Shoal Field
NON- CONFIDENTIAL
Packer Depth Pretest Initial 15 Min. 30 Min.
WellI Be-4 J Typelnj.I S I T.V.D. I 4621 I Tubingl 2950 ! '2950 I 2500. I 2556 [IntervalI 4
P.T.D.I 1690090 IType'testl. P. ITest psil 1155 I Casing I'..1550 I 1050 I 1050 I 1050 I PIE IP'-
Notes:
WellI Ba-16
* "e'nj'l s I Tu'bing 11050 I 1050 I 1040 I 1040I Interva'l4
Typetestl ' P ITestpsil 1267 I Casingl' 410i ~6"o i ~6~0 I' 1650 I' P/FI P
Notes:
WellI Ba-17 lTypelnj. I S I T.V.D. I 5280 J'TubingI 1660 1'2050 1 2050 ] 2060 JlntervalI 4
P.T.D.I 1852170 /Typetestl P ITestpsil 1320 I casingl 600 11550 '1 151011500 I' PIE I P
Notes:
WellI Ba-23 I Typelnj.I S I T.V.D. 10~ I Tubing 13040 13050
I I I lntervall 4
P..T.D.I 18~,0110 IType'testl ' P I Testpsil 2053 ICaSingl' 300 I 2170 I 21501 21401 P/F" I P
Notes:
Type INJ. Fluid Codes
F = FRESH WATER INJ.
G = GAS INJ.
S = SALT WATER INJ.
N = NOT INJECTING
Type Test·
M= Annulus Monitoring
P= Standard Pressure Test
R= Internal Radioactive Tracer Survey
A= Temperature Anomaly Survey
D= Differential Temperature Test
Interval
I= Initial Test.
4= Four Year Cycle
V= Required by Variance
W= Test during Workover
O= Other (describe in notes)
Test's Details
I arrived the platform and was met by Mike gott (operator) who provided me with the well info. We tested four wells
today with all passing their tests.
I toured the platform during the tests and found it to be in good condition considering the reduced personel.
M.I.T.'s performed: Four
Attachments:
Number of Failures: None
Total Time during tests: 4 hours '
cc: Chris Myers
Steve Meyer
MIT report form
5/12/00 L.G.
MIT MGS Baker 09-26-02 LG.xls
9/27/2002
Monthl3, Injection R,--'~rt
~YA'YERFI'_,OOD ,~JEC~)R MONTHLY REPORT
:BA23 :$0?332036900501
His Volume Tbg 9,625 C~' "I~.375 Csg
Well Date On Injeeted PIm.g.q Press Press
~A23 -' 6/i/01 12 - 354 3500 650 40
~A23 6/2/01 24 " 602 = 3500 ' 600 " 40 --
iiii i ·
]~,~23 6/~/o~ -'2~' ~4~ '~oo Woo 4o
.,
BA 23 " 614/0~"-' 2~ 543 3500 600 " 40
· - -..-- i J.I
BA~) .... 6/~/01 24 i 538 3~00 ' GOO 40
..... d.. ...........
-~^2~ o/6/0 24 ~s 3~oo 600 40
.. I i i , i i Il -. II
[~AZ~ 6/"/t01 ,, 24 ~35 ~00 600 40
· ii _. _ ii -. i
iiX-2~ '6~'/o~ 24 ~3i ~soo ~2s 40
i ii . la i
BA 23 6/10/01 24 529 3500 625 40
i i I i
~ i ii i iii iii
.
BA 23 6/12/01 0 0 1800 1100 41
...... ii ii i
~'A23 - 6/13/01 0 ' 0 1500 1160 41
BA 23 6/I 4/01 0 0 1320 1160 41
BA 23 6/15/01 0 6 1150 1170'- 41
.... ii i
BA 23 6/16/01 0 0 1000 1175 40
..... · · . .i I.L n I
BA 23 6/17/01 0 0. 900 1175 4I
I~ 23 6/1810! 0 0 800 1170 40
BA 1~ 6/19/01 0 0 ?~0 ! 17~ 40
.i [- -- i: - - ... i ii i · I_~r'
Ill .iii ill
BA 23 6/2 I/01 0 0 573 I 150 40
Il I ' --I I I I II I I
BA33 " §/~2/01 o -':0 550 1100 40
BA 23 '6/23t0 ] 0 0 :5:50 11 ~0 40
BA 23 6/24/01 0 0 525 1150 40
t. I_. 12. I I. _I · Lt I . . IJi I JOt I
BA 23 6/2~/01 0 0 500 i 150 40
an 2~ " ~/2~/°'1 o ~) ~oo ...... 1~5o ...... 40
_lilTS
BA 23 [- 6/'27/01 -"" 0 0 ~00 1150 40
i I al · i i il .jll
BA 23 6/28/01 0 0 300 1150 40
BA 23 6/29101 0 0 250 1150 40
lq · ii I ii i i I
BA 23 0/30/01 0 0 200 11 ~'0 40
· ..... n , .1 i ii ·
ar,; ~%,i' n~ 232 on (his wahaite ac,:! this la~ge ~'~t~ boom bit 4 ~} tiTTles 6~m~ I0/27/2000.
,*ATERFLOOD INJ]gCTOR .MONTHLY REPORT
EiAKER PLATIK)KM: BA 23: $07332036900S0!
H~ Volume Tbg 9,G2~ C~g
~ _ .. .... i l__.. :-- Il j i . _ . I I II
BA 23 ~/2/01 24 552 3~00 5~0 40
....... , ~.j[ ~_. .~ ....
~A 25 513101 24 ~39 3500 5~0 40
BA~ 5/4/01 24 ~ 537 35~ . $50 40
BA2~ 51~101 24 ~39 ~00 ~0 40
.....
BA 23 $/6/01 24 ~3~ ~00 550 40
..........
~_~ ...................
BA 23 fi~/01 24 fi35 3500 550 40
d _~ - , ---,, , , _._*~ . i _ . Ill _..Ilt i
B& 23 ~1 24 533 3500 550 40
..le. . _1 a ~ A.L. I I
~A 2~ ~/01 24 ~3 ~ 3~00 ~SO
............... ~0
BA 23 5110~ 1 24 527 ~500 40
........... _.
BA23 ~/11~1 24 ~37' ' ~00 550 - -
........ ...: - ~
BA 23 ~/12/01 24 ~39 3~00 550 40
...........
BA 23 ~/13/01 24 ~36 3~00 5~0 40
BA 23 ~/14/01 24 517 3fi00 ~60 41
.......................... ......
BA 23 5/16~I . 0 0 1850 - 1060 '-- 41
I ,1 ' ' _~. i.i ~ .liS,l, _ s I
· .... -- .~. ....
BA 23 ~/19101 24 848 3500 450 ,11
.......
BA 23 5~0/01 24 663 3500 475 4 l
BA 23 5~1/01 24 613 3500 ~00 40
..... ~ ..... ~. --,
BA 23 ~2~ 1 24 587 3500 ....... 500 40
. . , .~-
a-
BA 23 5~3101 24 ~70 ~00 ~50 40
BA2~ ~12~/01 24 ~ 5~8 3~ 5~ 40
.... ~ ..
BA 2~ 5~*~/01 24 $~6 3500 ~50 40
!- ~ i all I ; ~-~
'B'k-23 ........ ~7/ol 24 ~6 3~00 ~SO 40
~ i i ,, k ,, ~ 'l- _ .... -. -' --
~tA 23 .... 5~8~1 ~ 553 ~ ~$0 40
' . I I I n [ lit ' ' .Ifl
BA 23 5~ 0/01 24 $41 35~ 550 40
........
BA 23 3/31/01 24 $44 3 ~00 ~0
.......... -
RECEIVED
JUN 0 5 ;7001
~~'0~,~~ Monthly Injection Report
__'. - , ~ -.. ~ . . ~ -.... ,~ ~ · ~ ._ -- .~, ...... ~ - ..
:¥ ~ FERFLOOD INJECTOR MONTHLY REPO,RT
BAKER PLATFORM: BA 23: ~6900501
Hr~ ¥olume Tbg 9.62~ Csg 13.37~ Csa
Weft Date On .Injected .. Press Press Press
ii i ii I . ~ i
II II '
BA 23 411/01 24 602 3500 425 40
BA 23 -~2/01 ~ 610 ' 3500 425 40
BA-23 4/~/0 i 24 597 3 ~00 450 40
- . , ~ ii
~n23 4/4/01 24 ~8~ -" 3~00 450 '40
,- i ii i i
~n ~5' 4/~/0 z 2~ sS7 ~500 ~so 40
BA 23 416101 23 ~1 . 3~0~ , , 475 40
BA 23 ~ 4/7101 24 564 " 3~00 475 a0
BA 23 4/~/01 24 ~9 3~ '- 47~ '40 ....
_~ a i .- _'
BA 23 4/9/0i'- 24 -~59 3500 480 40
l, .I l[ Il Il I Ii
~BA 23 4/10/01 21 523 3fi00 J00 40
, . .a _ . i
, BA 2~ 4/11/01 23 562 3500 500 40
.
__llr I d'l II .I I I
BA 23 4/12/01 24 555 3~00 500 40
~A 23 d/i ~)~t 24 ~49 ~oo 500 4o
i ~ ~ I i ii .~ i
~BA 23 r.. 4/14t01 21 503 3500 550 d0
~. ,. .....
..
~X 2~ 4ns/6i 2n 5~ ~oo" soo
BA 23 6/01 24 fi53 35~ 500 40
i 1_ P Il_Il . ' 1
BA 2~ 4/17/01 24 ~47 35~ 525 40
~ta_ n i i n i ~ _ at, ,
BA 13 4/I8/01 ~ 547 3~00 525 40
i-i i ,~ ~ i1 _.. , ,
BA 2~ ~/19/01 24 $45 3500 ~2~ 40
._ ~ I~1 I I i i ~ II I II
BA 2~ 4120/01 24 545 ~50~ ~25 40
i [ la I I [ i l~ I I II I
-~A 23 4/21/0t 24 542 3~00 52~
· i I 11 i ., i a I il
BA 23 " 4/22/01 24 ~42 3J00 ~25 40
.~ a i __a nil
BA 23 ~/01 24 540 ~500 550 40
'' I I i I I i I ii
~ 23 ~24/~ l 22 513 ~ 500 550 40
I Il I a , ~1 I -~l I.
BA 23 4/25/01 24 552 3~00 550 40
i i · . . Il I . I ' . I [ I'
~A 23 4/26101 24 544 3500 550 40
. i . i I i i _,. Il l
BA 2~ 4/27/01 24 ~38 3500 ~0 40
I ill Ill nlm - I . I
~A 23 4/29/01 24 53S 3500 SS0 40
I i IL : I
BA23 4/30/01 24 529 3500~t" 550 40
You va~ t.~.~r numh~' 4.24 ~. ............ tld~ p.~ge lm 'b,.'~rt hJl ~7 time, v. in~ 10/27r;.000.
http://kodiak,anchorlown-unoeal.com/SUtweillanceff~e~or~m~ceRep o~.~p 5/1/01
~UNO~ Monthly Injection Report
WATERFLOOD INJECTOR MONTHLY .REPORT
BAKER PLATFORM: BA 23: 507332036900S01
..... .. w~.~e Xb~ 9,~zs c~ '" i'~.3?s cst
Well Date
On Injected Pr~s Press Press
BA 23 12/1/00 24 549 3500 700 43
I lin
.....
BA 23 12/2/00 24 548 3500 700 43
.... · 1 i lalllll
BA 23 12/3/00 24 ~51 3500 700 43
BA 23 12/4/00 24 55 ! 3500 700 43
BA 2.3 12/5/00 24 543 3500 700 43
i i ~-- ~ i ~'--
BA 23 12/6/0~) 24 600 3500 700 43
........
BA 23 12/7/00 24 1438 3500 690 43
_.1
BA 23 12/8/00 24 1392 3500 690 43
BA 23 12/9/00 24 1 ! 28 3500 675 42
........ i,,.n i
BA 23 12/10/00 24 1141 3500 675 43
a -i
BA 23 12/11/00 24 577 3500 675 43
BA 23 12/12/00 24 552 3500 675 4~
I il ! illl . .1 ·
~BA 23 12/13/00 24 550 3500 655- 43
fiA 23 12/14/00 24 546 3500 675 43
BA 23 12/15/00 24 544 3500 675 4~'
BA 23 12/16/00 23 544 3500 675 43
BA 23- ...... 12/17/00 ~4 ~4~ 3500 650 " 43
· .
BA 23 12/18/00 24 551 3500 650 43
BA 23 12/19/00 24 550 3500 6~0 43
BA 23 '-i ~/20/00 24 552 3500 I 625 43
1~ ,,nm l[
BA 23 12/21/00 24 548 3500 625 42
B^ 23 I2/22/00 ..... 24 547 3fi00 62~ 43
B^ 2~ I2/2a/00 22 480 35% 625 4'~
BA 23 12/24/00 23.5 592 3500 600 42
___ ~_l. _ ,11 1--, Il i
BA 23 12/25/00 24 556 3525 615 43
BA23 12/26/00 24 551 -" 3510 610 - 43
I p fill l
~-A 23 12/27/00 24 549 3500 620 43
BA 23 12/28/00 .... 24 54g 3500 615 42
..
BA 23 12/29/00 24 5~0 3500 610 42
II I il
BA 23 12/30/00 24 548 3500 "~10 ~2
Illl I I I
BA 23 12/31/00 24 54g 3500 600 42
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http://kodiak, anchortown.uno cal,com/Surveillance/Injcctor_Vm, ianceReport.asp I / 1/01
:/UNO Monthly Injection Report
.... .- - ...e..,. - ~...~ ~. - ....... ~ ...... ~ ~~ ..... :~ - ---.- ~- --- - -~----~--~- ....... -- ~---
WATERFLOOD INJECTOR MONTHLY REPORT
BAKER PLATI~ORM: BA 23: 507332036900801
Well Date Hes Volume Tbg 9.625 Csg 13,375 Csg
I}A 23 .... ~ 1/1/00 '' 24 564 3500 720 44
. . i ..............................
BA 23 11/2/00 24 ~63 3500 ?25 44
............................................... ~
ISA 23 11/3/00 24 563 3500 ?50 44
....................................
,
~A 23 11/4/~0 -- ~4- ............... ~66 3500 750 44
:BA 23 11/5/00 24 543 3500 750 44
BA 23 ] 1/6/00 24 286 3525 750 46
.....
BA 23 11/7/00 24 562 3500 750 44
ISA 23 11/$/00 24- 557 3500 750 44
ii i i ·
BA 23 11/9/00 24, 5:57 3500 750 44
. .
BA 23 11/10/00 24 557 3500 750 44
.................................. L. i i ii Illlll
BA 23 I l/11/00 24 554 3500 750 44
i
BA 23 11/12/00 24 555 3500 750 44
BA 23 11/13/00 24 557 3500 750 44
BA 23 11/14/00 24 548 3500 750 44
!
]~n2~ IU25/00 ----2'4' ............... ~61 ........ 3~00 .............. 750 44
....
BA 9.3 11/16100 24 555 3500 750 44
BA 23 11/17/00 24 560 3500 750 44
BA 23 l 1/18/00 24 558 3500 750 44
lSIA 23 t 1/19/00 24 553 3500 750 44
BA 23 11/20/00 24 554 3500 725 44
,,,
BA 23 11/21/00 22 535 3500 725 44
BA 23 11/22/00 24 570 3500 700 44
! i ii i .... i ...........
BA 23 l ~/23/00 24 557 3500 ?00 44
BA 23 1 ~/24/00 24 557 iS00 ?00 44
BA 2~ 11/2~/00 24 5f8 3500 ?00 44
BA 2~ 11/26/00 20 514 3500 700 44
i · Illml .....
BA 23 11/27/00 24 57:5 3500 700 43
u
BA 23 11/2~/00 24 545 3500 710 43
fl i i ' i i .lllmll
I~A 23 11/29/00 24 555 3500 700 43
BA 23 11/30/00 24 551 3500 700 43
............ iii s ·
http://kodiak,anchortown,unocal.com/Surveinance/lnjector_VarianccRcport.asp 12/1/00
Monthly Injection .Report
WATERFLOOD INJECTOR MONTHLY REPORT
BAKER PLATFORM: BA 23: 507332036900$01
Well Date It!~ ~'olume ~bg 9,62S Csg 13.3
On lajocte~l l'ress l're~s
! I -
ii I ii i
BA 23 t011/00 24 570 3500 750 46
I! · II II I
DA 23 10/2/00 24 565 3500 750 45
BA 23 L0/3/00 24 565 3500 750
II , I.
BA2~ 10/4/00 24 535 3500 750 46
I im · i i
BA 23 10/5/00 -'24 376 3500 725 46
i I I · ii ii i II
iBA 23 . 10/6/00 24 564 3500 730 46
al · II I II i ~ · --
BA 23 10/7/00 24 566 3500 730 46
BA 23 10/8/00 24 564 3500 730 46
_
k_... II I Il _ i i
BA 23 10/9/00 24 563 3500 750 45'
fiA 23 10/10/00 24 562' 3 ~00 750 45
aX23 ld/lz/oO ' '~i' 4*6 ;soo ' %0 " 4~' '
I III i I I
!B^ 2~ I 0/I3/00 24 $S8 3500 750 45
BA 23 ' 10/14/00 24 ' 566 "3500 ;/50 ' 4~ '
BfOg3-' , 10/15/00 '24,, [. 567 [3550, , 750 46
BA 23 10/16/00 ~ 12.5 390 3500 800 46
I I I ii ~. il iii I I i'--
BA 23 10/17/00 24 621 3500 '750 46
BA23' 10/lg~/oo 24 "t 580 ~500 750 ' 45 "
-. ii i I 11 i i il I i I i ,.--
'BA 23 10/19/00 24 576 3500 750 45
I II i I I . I i II .
~A 2~ 10/20/00 17 424 3500 775 45
I . I I I Ill ' '
BA"23 10/21>00 24 538 3500 ?so 4~
II I I II i I i I --
BA 23 10/22/00 24 ~80 3500 750 45
~ Ill ~ Ill I · _ II II I
BA 23 10/23/00 24 565 3500 750 45
I -- I .. I . I I1 I ~ I III
BA 23' 10/-24/00 24 ~6.n 3520 750 45
II ii I. I I . i · I i
BA 23 10/2~/00 24 531 3520 750 45
I ! i I I
.
BA 23 ! 0/26/00 24 170 ~ 500 750 45
_.
I · i I II i
BA 23 10/27/00' 24 374 3500 750 44
ii ~ I I I i I i
BA 23 t0/2g/00 24 559 3500 7~0 44
I _. I i i I i I I i _ I
B^ 23 . ,,,10/29/00 24 , ,5:57 3500 750, 44
BA23 10!30/00 23,5 556 3500 725 -' '44
ii i i I
BA 23 -' 10131/00 24 564' 3500 725 44
,,1, I I I I
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http://kodiak,anchortown, unocal com/Survcillance/Injector_VarianeeReport.asp 11/1/00
Monthly Injection Report
- ' - .....2ooo',,.i
I ......
ATERFLOO INJECTOR O flLY REPORT
B~ P~TFO~: BA 23: 507332036900S01
I H il I! I . II ·
Well Date H~ Volume Tbg 9.615 Cs~ 13.3'/5 Cs
On Injected Press Pre~s Press
pi i i
·
BA 23 711/00 24 M9 3500 700 30
I I I f II I .. IlII
DA 23 7/2~00 24 585 3500 700 35
Illl I I Ill
BA 23 7~3~00 24 550 3500 700 40
BA 23 7/4/~0 24 577 3500 600 4 S-
BA 23' ' 7/5)00 "~4 572 3500 700 ' 48
· - i ii III I i i
BA 23 7/6/00 24 46~ 3500 7~0 ' 40
· i i .. ·
BA 23 7/7/00 24 632 3500 700 48
il t i l
BA 23 715/00 24 585 3500 700 48
ti I Il I I I
BA 23 7/9/00 24 570 3500 700 48
_.. i I ! il I - · II I
BA 23 7/10/00 24 572 3500 700 48
i i i · il
BA 23 7111/00 24 572 ' 3500 '700 48
iii · i i Ill
BA 23 7112/00 24 510 3500 700 4B
i n n _ i i i -.. i
BA 23 7/13/00 20.75 53a 3500 725 48
DA23 " 7/14/0O' 24 '57~ 35~)0 725 '48 '
' II .. I I .
BA 23 7115/00 24 331 3500 725 48
Il I 11 [
BA 23 7/16/00 24 4~4 3500 740 4 g
'-~. I i Il
iBn 23 7/17/00 24 567 3500 750 48
! i
BA 23 7/lgt00" 24 "54g 3500 750 48
.II Il I
BA 23 7119/00 24 473 3500 7~0 48
· i a i i ,i _..
BA 23 7/20/00 24 570 3500 750 48
i
BA 23 7/2i/00 24 552 3500 750 48
~.. I I Il · I I I
BA 23 7122/00 24 571 3500 750 48
Il Il II I Illlt l
BA 23 7123100 24 590 '- 3500 '750 48
BA 23 7/24/00 20.5 473 2900 800 48
--' i I
DA 23 7~25/00 17 515 3500 750 48
BA 23 7126/00 24 525 3500 750 48
i i i il · i i 01 i
BA 23 7/27/00 24 556 3500 750 48
fl i i i
BA 23 7128/00 24 566 3~00 750 48
I i /I ii Il
BA 23 7/29100 24 558 3500 750 48
I II Il [
BA 23 7/30/00 24 450 3500 750 48
Il [If I I I I
BA 23 7/31/00 24 491 3500 750 48
I _ I [ Il I I Il I I I I
http://home.anchortown, unocal, com/Surveillance/Injector_VarianceReport,asp 8/4100
' ' ' 'UNOC LA PLATFORM" ' B~KER ' "
WELL. #23 PRESSURES
Monltl: ,,~'~,~-c~V 4,~0 , . . :. ,,.
· .
.Date,-Tubing_ 9 ~/.8" 13 3/8" BBL's Inj_ecMd . Co,mmeflts
2 "~,,<? , ~ o c, ~,~ ,, ,
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a I I al a II Iii mi II I
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Copies To: Julie Kobemtein, Kenai Office
Well ;t23 File (=), M~
..... uNocAL PLA.TFORI~ BAKER
WELL #23 PRESSURES
Month:
Date.~ Tubing 9 5/8" 13 3/8" BBL's lnject~.d Comments
, . ~ ~ F~ ~ ~
2 ~ cD ,,..o O, /;
,.
,
.
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Well #23 File (c). ~ c~, ~, Fon~. 2~,ms~
' UNOCAL pi' ~..l. FOr~l~ 1~4Kr~ ', 2 ' ,
WELL #23 PRESS~
,
,Da~ ~ Tubing ~ ~8" 13 3/8" BBL's In~e~d Commen~ _,
/
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12
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,
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Copies To:
Julie Koberstein, Kenai Office
Well #23 File (c), ,~s cmce, ~:~, ~orr~, =3pr~.~
· i
..... UNOCAL PI~ATFOA~ --
WELL//23 PRESSURES
Month:
,Date :~i Tubing 9 518" ,.13 318" BBL's Injected Comments
. , . ,
, , ,
, , ,
, , ,
,
= -,~--/
2s o 0 ~ 0 ,,
, , ,
=~ 0 . 0 .~0 . ~ "
, , ,,
,
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Jutie Koberstein, Kenai Office
Well #23 File lc;, ,~s c'f~, --~_.~l, ,-'erm~. Zs=r~.~
l~OV-OS-~U rlUN 10; bi
UNQ,O,~j...OSS~Z. G~S GRP
F~X NO, 90726,3..7.~7~4
F'fiX NO, 90726?
Unocal Corporation
Agricultural Products
909 West 9'~ Avenue. P.O. Box 196247
Anchorage, Alaska 99519-6247
Telephone (907) 263-7830
UNOCALO
September 14.199g
Blair Wondzcl
State of Alaska
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
P, 02/U4
~', gl/O~
8~c6'
Re: Middle Ground Shoal
Baker B-23
Dear Blair:
This letter is to document your approval of Baker B-23 MIT. Attached is a copy of the Mechanical Integrity
Test form dated 11/6/98 and a¢¢ompanying chart.
In the Pretest Condition the well was on injection m 509 BWPD, 2350 psi tbg pressure and 100 psi csg
pressure. The well was shut-in to conduct the test so as to achieve a >500psi differential pressure between
csg and tbg, The casing was pressured up to 2250pai on the chart recorder (2100psi on the gage) while the
tbg was allowed to bleed offto the formation during the test. The final csg pressure at the end of the test
was 215Opsi on the chart recorder which is within the 10% allowable tolerances.
Please review this data. If this well passes it's MIT, please sign and sonda copy of this letter and MIT
form to Steve Tyler at fax number 263-7874 otherwise call me at 263-7636,
Sincere. ly, .
Chet Starkel [.,
Advanced Reservoir Engineer
Cook Inlet Waterflood Management
Please return a signed and dated copy of this letter to document notification for our records.
Blair Wondzel /~)'- Dat~ ' '
AOOCC
Aogcc Baker 23 MIT.doc
RevimM 9/29/98 gev. #1
I. - I I IIIIII Jl I I ~ 011111111 II II I II IIII I I
ALASKA OIL AND GAS CONSERVATION COMMISSION
MECHANICAL INTEGRITY TEST
Ti~E OF
ANNULUS
FLUID
.~lt Watex
PRET~T
'rBG
CSG
START
TIME
TBG
CSG
PRESS
TIME
TI~
30 MIN
TIME
TBG
CSO
PRESS
P' ~'=;PRODUCE WATER
S = $~.I.T WA~ ~
t -- INIEC'II~IG
N
ANNULAR FLUID:
~L
G~YCOL
SALT
"~
Z
,,~
~OON
,
f~N/f~N ',.-I
~LSLg9~L06 'ON X~.4
aa9 su9 i.~ssU'~TuooNn
89: ~ ~ I~.4 66-60-~aV
NOV-09-98 HON
16:57
UNOO~L ~SSET G~S GRP
FaX NO. 9072637874
~..--~.
Unocal Corporation
Agricultural Products
909 West 9'~ Avenue, P.O. Box 196247
Anchorage, Alaska 99519-6247
Telephone (907) 263-7830
UNOCAL )
P, OI/03
September 14, 1998
Blair Wondzel
State of Alaska
Alaska Oil and Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, AK 99501
Re: Middle Ground Shoal
Baker B-23
Dear Blair:
This letter is to document your approval of Baker B-23 MIT. Attached is a copy of the Mechanical Integrity
Test form dated 11/6/98 and accompanying chart.
In the Pretest Condition the well was on injection at 509 BWPD, 2350 psi tbg pressure and 100 psi csg
pressure. The well was shut-in to conduct the test so as to achieve a >500psi differential pressure between
csg and tbg. The casing was pressured up to 2250psi on the chart recorder (2100psi on the gage) while the
tbg was allowed to bleed offto the formation during the test. The final csg pressure at the end of the test
was 2150psi on the chart recorder which is within the I0% allowable tolerances.
Please review this data. If this well passes it's MIT, please sign and send a copy of this letter and MIT
form to Steve Tyler at fax number 263-7874 otherwise call me at 263-7636.
Sincerely,_
Chet Starkel
Advanced Reservoir Engineer
Cook Inlet Waterflood Management
Please return a signed and dated copy of this letter to document notification for our records.
Blair Wondzel ~
AOGCC
Date
ttOV 0 9 998
~aska ~ & ~ Cc~s. C~r~i~,:~
Aogcc Baker 23 MIT.doc 11/09/98
I
Middle Gruund Shoal
Wall Wa,-23 Injector
MIT Prolram
Revised 9.r2919S Rev. #1
B-23
ALASKA OIL AND GAS CONSERVATION COMMISSION
MEC~~CAL ~E~,'rY TEST
Company_Uno,~l Alasi~_ __ Field
TY~E~
ANNULUS
FLUID
SaltWater
CASING ltEQ
SgF./WT/GRADE TEST
PRESS
2053
P~
'lBO
CSG
PRESS
TIME
TBO
l~ESS
TIME
'FBG
CSG
PRESS
CD
Z
Z
0
Z
P = I~ODUCE WATER
S-- ,~L,T WA~ ~
O.
ANNUL~ FLUID:
DIESEL
GLY(3~
..;~I,T WATER
Initial
Woakovet
NOV-09-98 MON 16:58
UNOCAL hSSET GhS GRP
F6X NO, 9072637874
.,--%,
F,
NOON
r"
..-
· .
Tubing Open
B-23 Mechanical integrity Test (First)
rlnle
1 2 3 4
Time 1106 1123 1138 1153
Pressure 2510 2480 2430 2390
B-23 Mechanical Integrity Test
2 3 4 5 6 7 8 9 10 11 12
T~me
I 2 3 4 5 6 7 8 9 10 11 12
Time 1303 1308 1313 1318 1323 1328 1333 1338 1343 1348 1353 1358
Pressure 2530 2510 2490 2470 2450 2430 2420 2400 2380 2360 2340 2325
Page I
Tubing Plugged
325O
275O
;Z ii;: i:i X:i'i'; i'X'/'i'i i Z'Z ii Z'Z i i'Z'Z'; ?i'i?i'i?!'i'i?i?!'!'!':':': :': :i :':':':':':: :':':'::: :;:;:;:;:;:':i:;:;:: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ! i:!:i:i:! i ii! ! i: :: ! :-:':::: ::::"
1750 .................. :::::::::: ............ :? ............. ~ ................ ::::::::::::::::::/:::::::x:::::::::::::<:::::<:::-'?::::::::: .......................... ~ .........................................
1612 1617 16"22 1627 1632 1637 1642
Tub. psi]
Cas. psi
Time 1612 1617 1622 1627 1632 1637 1642
Tub. psi 3850 3839 3831 3825 3821 3815 3812
Cas. psi 1940 1930 1915 1900 1880 1860 1850
i::::: ::::::::::::: ::::::::::::::::: ::::::::5::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::: :::::::::: ::::;:: ::::::: :.....
::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ':::::::::'::
:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........... 1:::::::::::: ....
:::::: :' ~::::: :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::: ::::: ::: ::::::::: .::
· :::.::: ::::: ::::::::::::::::::::::::::: ::::::~::: :'::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :':::::::: :'::: ::::: :::': :':: :::::::
2000 ........................................... ~ ........... ~:::?' .............. :::::::::::::::::::::::::::: ................ ~::~::? ................................................................
1 &57 1702 1707 1712
Tub. psiI
Cas. psi
Time 1657 1702 1707 1712
Tub. psi 2080 2080 2080 2079
Cas. psi 2560 2535 2520 2500
Page 2
BAKER 23
PROPOSED
-iNJECTION
COMPLETION
.
1. 3-1/2" 9.2# BTc L-80 TBC~
0- 8515' -
2. I-rES "MSIT' PACKER
3. "X" NIPPLE - -
4. WlRELINE RE-ENTRY
GUIDE
PERFS
8608'-8664'
8710'-8790'
8820'-9184'
PERFS
9212' - 9404'
· 9593' PBTD
9722' TD
13-3/8" 54.5#, 61#, 68# ~ 3589'
~ f f Ir/; ,~ '/'- ,?:/£ a'
TOP OF 7" LINER ~ 8985'
9-5/8" 40#, 43.5#, 47#, 53.5# ~ 9085'
fls'oo -- 2 a Fo.,5"6
~oo = ~,~rot. 05/
79, ~,2,//oo = ·
ff/d,t.o't +
7" 29# LINER ~ 9685'
.-__
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS;
1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate:
Pull tubing: Alter casing: Repair well: Other: x Convert to Inj.
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)
Union Oil Company of California (UNOCAL) Development: 118 RKB MLW feet
3. Address Exploratory: 7. Unit or Property name
Stratigraphic:
P.O. Box 196247, Anchorage, AK 99519 Service: MGS State 17595
4. Location of well at surface 8. Well number
1980' FNL, 472' FWL, Sec. 31, T9N, R12W, SM 23
At top of productive interval 9. Permit number/approval number
~ 8608' MD, 2775' FNL, 332' FVVL, Sec. 31, T9N, R12W, SM 84-11
At effective depth 10. APl number
50- 733-20369
At total depth 11. Field/Pool
@ 9722' MD, 3182' FNL, 1051, FVVL, Sec. 31, T9N, R12W, SM L. Kenai Conglomerate/MGS Field
12. Present well condition summary
Total depth: measured 9722 feet Plugs (measured)
true vertical 9062 feet
Effective depth: measured 9593 feet Junk (measured)
true vertical 8992 feet
Casing Length Size Cemented Measured depth True vertical depth
Structural
Conductor
Surface 3589' 13-3/8" 3100 sx 3589' 3480'
Intermediate 9095' 9-5/8" 1850 sx 9095' 8675'
Production
Liner 700' 7" 210 sx 9685' 9037'
Scab Liner 1436' 7" 3883'
Perforation depth: measured
true verticalRECEIVED
Tubing (size, grade, and measured depth) d U L 0 2 !9 9 6
L.s.: 3-1/2", 9.2~, N-80 0-8566' SS: 3-1/2", 9.2~, n-80 0-8566' TCP GUNS 8864'-9414'
Packers and SSSV (type and measured depth)
HES 9-5/8" MHR PACKER 8464' Alaska 0il & Gas Cons. Commission
13. Stimulation or cement squeeze summary Anc.,hora§e
Intervals treated (measured)0RIGINAL
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure
5-8-95
Prior to well operation _ m 0 70 PSI SI
INJ HOR-3500 PSI
Subsequent to operation _ M 753 BPD 95 PSI 2950 PSI
15. Attachments: 16. Status of well classification as:
Copies of Logs and Surveys run: X
Daily Report of Well Operations: X Oil: Gas: Suspended: Service: INJ WELL
17. I hereby cedify that the foregoing is true and correct to the best of my knowledge:
Signed: Dale Haines Title: Drilling Manager Date: June 6, 1996
Form 10-404 Rev 06115/88
SUBMIT IN DUPLICATE
BAKER 23
DAY 1 (5/12/96)
COMMENCE OPERATIONS AT 12:00 HRS ON 5/12/96. SKID RIG
FROM WELL 31 TO WELL 23. HAD PREVIOUSLY CIRCULATED AND
KILLED WELL. N/D TREE, N/U BOPE
DAY 2 (5/13~96)
CONT. N/U BOPE, TEST SAME. P/U OFF HANGER AT 280K WORKED
BOTH STRINGS TO 380K WITH NO MOVEMENT. R/U AND CUT
SHORT STRING JUST ABOVE KOBE CAVITY AT 8555' POOH LID
SHORT STRING,
DAY 3 (5/14/96)
CONT. POOH W/SHORT STRING. R/U ON LONG STRING ATTEMPT
TO PULL NO MOVEMENT AT 250K. R/U TO CUT LIS. RIH W/
CHEMICAL CUTTER FOR 2 7/8" TUBING. COULD NOT PASS 8615'
FILL, RIH W/JET CUTTER FOR 3 1/2" TUBING. CUT AT 8598'. POOH
W/CUTTER HUNG UP IN KOBE CAVITY PULL WIRE FREE AT WEAK
POINT. LEAVING CUTTER STUCK IN CAVITY. POOH LID TUBING.
RECOVERED CUTTER IN KOBE CAVITY.
DAY 3 (5/14/96)
L/D 3 1/2" TUBING, CHANGE PIPE RAMS RIH W/OVERSHOT AND JAR
ASSY. LATCH FISH AT 8595' JAR AT 115 K OVERPULL
DAY 4 (5/15/96)
CONTINUE TO JAR ON FISH (TOTAL 3 HRS).NO MOVEMENT.
PERFORM BLIND BACKOFF. POOH LID FISH. RECOVER 80' OF
GUNS. RIH W/OVERSHOT. LATCH GUNS AT 8711' JAR ON FISH TO
175 K OVER FOR 2 HRS. PERFORM BLIND BACKOFF. POOH LID
FISH . RECOVER 1 JT OR 14.5' OF GUNS. RIH W/OVERSHOT.
LATCH GUNS AT 8725' JAR ON FISH TO 175 K OVER FOR 1/2 HR.
PERFORM BLIND BACKOFF. POOH
BAKER 23
PAGE 2
DAY 5-7 (5/17-19/96)
POOH L/D FISH . RECOVER 1 JT OR 14.5' OF GUNS. RIH W/
OVERSHOT. LATCH GUNS AT 8721' JAR ON FISH TO 175 K OVER
FOR 10 MIN. PERFORM BLIND BACKOFF. POOH RECOVER 4 JT OR
54.87' OF GUNS. RIH W/OVERSHOT. LATCH GUNS AT 8776' JAR
ON FISH TO 175 K OVER FOR 10 MIN. PERFORM BLIND BACKOFF.
POOH RECOVER 1 JT OR 14.8' OF GUNS. TOF 8801'. RIH W/7 5~8"
WASH PIPE, WASH OVER GUN FISH TO 8848' SLOW GOING POOH
DUE TO TORQUE. FOUND SHOE FLARED. RIH W/OVERSHOT.
LATCH GUNS AT 8801' JAR ON FISH TO180 K OVER FOR 60 MIN.
PERFORM BLIND BACKOFF. POOH RECOVER 2JT OR 29.65' OF
GUNS. TOF 8831' RIH W/OVERSHOT. LATCH GUNS AT 8831' JAR
ON FISH TO 190 K OVER FOR 60 MIN. PERFORM BLIND BACKOFF.
POOH RECOVER 1 JT OR 14.46' OF GUNS. TOF 8846'. RIH W/ 7 5~8"
WASH PIPE, WASH OVER GUN FISH TO 8862' SLOW GOING POOH
DUE TO TORQUE. FOUND SHOE WORN OUT. RIH W/OVERSHOT.
LATCH GUNS AT 8846' PICKUP ON GUNS WITH NO OVERPULL FISH
CAME FREE. POOH RECOVER 2 JT OR 28.47' OF GUNS. TOF 8864'.
FISH WAS MILLED HEAVILY ON ONE SIDE. DECISION TAKE TO
STOP FISHING OPERATIONS AND COMPLETE WELL. P/U BIT AND
SCRAPER.
DAY 8 (5/20/96)
RIH WI 8 1/2" BIT AND SCRAPER TAG BOTTOM AT 8860' CBU AND
POOH R/U SCHLUMBERGER TO RUN CET/CBL/GR LOG. RAN LOG
FROM BOTTOM AT 8853' TO 7330' WLM ESTIMATED TOP OF
CEMENT AT 7740'. LID DRILL PIPE. RUN 3 1/2" COMPLETION
DAY 9 (5/22/96)
CONT. RUNNING COMPLETION DISPLACE WELL TO PACKER FLUID.
DROP BALL AND PRESSURE UP TO SET PACKER AT 8464'.
ATTEMPT TO PRESSURE TEST ANNULUS. PUMP AWAY 3 BPM AT
350 PSI, HOLE IN CASING ABOVE PACKER. RELEASE ANCHOR
FROM PACKER POOH AND STAND BACK TUBING. RIH W / 9 5/8"
RTTS PACKER. PERFORM PRESSURE TESTS AND LOCATE LEAK
FROM 4296' TO 4301'.
BAKER 23
PAGE 3
DAY 10 (5~22~96)
FINISH LOCATING HOLE, POOH WI RTTS, TEST BOPE. CHANGE
DRILLING LINE. RIH W/8.475 FULL COVERAGE MILL TO DRIFT 9 5/8"
53 LB CASING. PERFORM MAINTENANCE WHILE WAITING 9 HRS ON
ISOLATION LINER EQUIPMENT
DAY 11 (5~23~96)
OFFLOAD ISOLATION LINER EQUIPMENT FOUND BAKER SUPPLIED
WRONG CASING X-OVER; OBTAINED CORRECT X-OVER (12-1/2
HRS LOST) AND RIH. SET LOWER AND UPPER PACKERS OF LINER
ASSEMBLY TO ISOLATE BAD CASING IN INTERVAL 4296' TO 4341'
(REENTRY GUIDE AT 5319' AND TOP OF ASSEMBLY AT 3882'.)
PRESSURE TESTED - OK. RAN 3-1/2" COMPLETION STRING.
DAY 13-15 (5/25-27/96)
POOH 3 1/2" COMPLETION STRING. RIH W/7" RTTS SET AT 5291'
PRESSURE TESTED 9 5~8" AND 7" CASING ABOVE THAT POINT TO
2500 PSI. PRESSURE BELOW RTTS TO 2500 PSI. LOST 420 PSI IN
ONE HR. POOH W/RTTS. STATE OK'D RUNNING COMPLETION.
RUN 3 1/2" COMPLETION. PRESSURE UP AGAINST 'PX' PLUG. PLUG
BLEW OUT AND DROPPED IN HOLE. TEST ANNULUS TO 1500 PSI
FOR 30 MIN. 100 PSI DROP. OK'D BY AOGCC. NOTE: THE AOGCC
WILL REQUIRE SOME SPECIAL REPORTS ON THIS WELL, THEY
WILL SEND A LETTER OUTLINING THOSE. SET 'PX' IN TAIL PIPE.
TEST TUBING TO 3500 PSI. RETRIEVE PLUG. N/D BOPE, N/U
TREE. PERFORM MIT WITNESSED BY STATE INSPECTOR. SIGNED
OFF WITH PROVISION THAT TUBING ANNULUS PRESSURES BE
REPORTED MONTHLY TO AOGCC.- EST. INJECTION AT 2 BPM 1900
PSI. PUMP A TOTAL OF 40 BBLS. SKID RIG OVER WELL 31.
CLEANING AND PREP RIG FOR SHUT DOWN. FINAL REPORT.
RECEIVED
JUL 0 2 199G
Alaska. 0il ~.: Gas Cons. Commission
UNOCAL )
KB = 100' MSL; CSG HEAD ELEVATION = 68'
SIZE WT
BAKER PLATFORM
WELL # 23
CURRENT COMPLETION: 5/27/96
CASING AND TUBING DETAIL
GRADE CONN TOP BOTTOM
13-3/8 68.0 K-080T
61.0 K-55
54.5 K-55
9-5/8 53.5 N-80
47 C-95
47 N-80
40 S-95
7" 29 L-80
7" 29 L-80
Tubin~
3-1/2 9.2 L-80
0 3589
0 9095
8985 9685
SCAB 3883 5319
0 8464
3
~ .: 6
7
JEWELRY DETAIL
NO. DEPTH ITEM
I 8464
2 8504
3 8538
4 3883
5 5319
6 8860
7
HES 9-5/8" MHR PKR
HES 3-1/2" x 2-13/16" BTC "X" NIPPLE
HES 3-1/2" RE-ENTRY/PUMP OUT PLUG
BAKER 7-5/8" x 9-5/8" JF PKR
BAKER 3D HANGER
PX PLUG & PRONG LOST IN HOLE
8864-9414 4" TCP ASSEMBLY
PERFORATION DATA
TOP BTM ZONE SPF DATE COMMENTS
8608 8664 G-1 4 3-26-84
8710 8790 G-2 4 3-26-84
8820 9184 G-3 & G-4 4 3-27-84
9212 9404 G-5 4 3-28-84
Tubing Perforations
RECEIVED
PBTD = 9593'
TD = 9722'
KICK OFF POINT = 1450'
MAX HOLE ANGLE = 45°
JUL 0 2 i99~
0[I & GaS Cons. Go,mrnlsSlOn
Anchorc. ge
O :kDR1LLING\S CHEMATIC\GP\GPPkBA23-RD.DOC
DRAWN BY: BKS
REVISED: 6/10/96
UNOCAL )
KB - 100' MSL; CSG HEAD ELEVATION - 68'
BAKER PLATFORM
WELL # 23
PREVIOUS COMPLETION: 4/7/84
CASING AND TUBING DETAIL
SIZE WT GRADE CONN TOP BOTTOM
13-3/8 68.0 K-080T 0 3589
61.0 K-55
54.5 K-55
9-5/8 53.5 N-80 0 9095
47 C-95
47 N-80
40 S-95
7" 29 L-80 8985 9685
Tubing
Long String
3-1/2 9.2
Short String
3-1/2" 9.2
0 8566
0 8566
JEWELRY DETAIL
NO. DEPTH ITEM
8566 KOBE (Pump Cavity)
8566-9414 4'~FCP ASSEMBLY
PERFORATION DATA
TOP BTM ZONE SPF DATE COMMENTS
8608 8664 G-1 4 3-26-84
8710 8790 G-2 4 3-26-84
8820 9184 G-3 & G-4 4 3-27-84
9212 9404 G-5 4 3-28-84
Tubing Perforations
PBTD = 9593'
TD = 9722'
MAX HOLE ANGLE = 45°
KICK OFF POINT = 1450'
O :kDRILLING\S CHEMATIC\GP\GPPkBA23 PREV. DOC
DRAWN BY: BKS
REVISED: 6/10/96
"-' STATE OF ALASKA
ALASK,~ L)iL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request: Abandon: Suspend: Operation shutdown: Re-enter suspended well:
Alter casing: Repair well: Plugging: Time extension: Stimulate:..~
Change approved program: Pull tubing: Variance: Perforate: Otheri x 64~,nvert to
2. Name of Operator 5. Type of well: 6. Datum elevation (DF or KB)
Union Oil Company of California (Unocal) Development: x 118 RKB MLW feet
3. Address Exploratory: 7. Unit or Property name
Stratigraphic:
P.O. Box 196247 Anchorage, AK 99519 Service: MGS State 17595
4. Location of well at surface 8. Well number
1980' FNL, 472' FWL, Sec. 31, T9N, R12W, SM 23
At top of productive intervalINAL 9. Permit number
@ 8608' MD 2775' FNL, 332' FWL, Sec. 31, T9N, R12W, SM 0 R I G 84-11
At effective depth 10. APl number
50- 733-20369
At total depth 11. Field/Pool
@ 9722' MD, 3182' FNL, 1051' FWL, Sec. 31, T9N, R12W, SM -' Lower Kenai Conglomerate/MGS Field
12. Present well condition summary
Total depth: measured 9722 feet Plugs (measured)
true vertical 9062 feet
Effective depth: measured 9593 feet Junk (measured)
true vertical 8992 feet
Casing Length Size Cemented Measured depth True vertical depth
Structural
Conductor
Surface 3589' 13-3/8" 3100 sx 3589' 3480'
Intermediate 9095' 9-5/8" 1850 sx 9095' 8675'
Production
Liner 700' 7" 210 sx 9685' 9037',:~.
Perforation depth: measured ~"~i~, ~ ~,,..~, ~.~. .... ~i ~,~ ~' ~_~:'~;'"'"
true vertical See attached
[-.~t4R I '5 lg'3G
Tubing (size, grade, and measured depth)
· .
L.S.: 3-1/2", 9.2~, N-80 0-8566' SS: 3-1/2", 9.2~, N-80 0-8566' TCP guns 8566'-9414' .,~;¢,~r~ 0i! & ..... 00~'15. C0iTiiT~!~SlOi?..
Packers and SSSV (type and measured depth)
13. Attachements Description summary of proposal: x Detailed operations program: x BOP sketch: x
14. Estimated date for commencing operation 15. Status of well classification as:
4/6/96 Pat Ryan 263-7864
16. If proposal well verbally approved: Oil: Gas: Suspended:
Name of approver Date approved Service: Injection
17. I hereby ' t the 'ng tr he best of my knowledge. '~.~
· '
Signed: .~~~ Title: Z~,L.C~C~,J f,~ ~ ~;J ,~N,(7'.N ~--4~ Date:
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness JApproval No_.
Plug integrity BOP Test ~ Location clearanceJ ~.~
Mechanical Integrity Test ~ Subsequent form required 10- ~
Approved Copy
Original Signeo By ¢/,¢~u/,r'~d
David
W.
Johnston
Approved by order of the Commissioner /~/,~
Commissioner Date
Form 10-403 Rev 06tl 5/88
SUBMIT IN TRIPLICA'~
PERFORATIONS
MEASURED DEPTH
8608'-8664'
8710'-8790'
8820'-9184'
9212'-9404'
TRUE VERTICAL DEPTH
8326' - 8358'
8404'-8457'
8487'-8735'
8763'-8886'
BAKER 23
CURRENT COMPLETION
1. 3-1/2" 9.2 # LONG STING
0 - 8566'
· 2. 3-1/2" 9.2# SHORT STRING
0 - 8566'
3. KOBE CAVITY (~ 8566'
4. 4" TCP ASSEMBLY
8566' - 9414'
PERFS
8608' - 8664'
8710' - 8790'
8820' - 9184'
PERFS 9212' - 9404'
9593' PBTD
9722' TD
13-3/8" 54.5//, 61#, 68# ~ 3589'
TOP OF 7" LINER ~ 8985'
9-5/8" 40#, 43.5#, 47#, 53.5# ~ 9085'
7" 29# LINER ~ 9685'
BAKER 23
PROPOSED
INJECTION
COMPLETION
1. 3-1/2" 9.2# BTC L-80 TBG~
0 - 8515'
13-3/8" 54.5#, 61#, 68# ~ 3589'
2. HES "MSI-I" PACKER
3. "X" NIPPLE
4. WIRELINE RE-ENTRY
GUIDE
PERFS
8608'-8664'
8710'-8790'
8820'-9184'
PERFS
9212'-9404'
9593' PBTD
9722'TD
TOP OF 7" LINER ~ 8985'
9-5/8" 40#, 43.5#, 47#, 53.5# ~ 9085'
%~ 7" 29# LINER ~ 9685'
MGS 17595 BAKER 23
PROPOSED WORKOVER
March 5, 1996
PROCEDURE
1. M~U RIG 428 OVER MGS 17595 #23, LEG 4, SLOT 2.
2. KILL WELL WITH WATER.
3. INSTALL BPV' S, ND TREE, NU & TEST BOP.
4. CUT SHORT STRING & POOH LAYING DOWN SAME.
5. POOH LAYING DOWN LONG STRING AND 4" TCP CASING GUNS.
6. RIH WITH 6" BIT AND CLEAN OUT TO 9593' ETD.
7. RIH WITH 9-5/8" "MHS" PACKER PICKING UP 3-1/2" TUBING TO 8550'.
.
SPACE OUT AND LAND TUBING. SET PACKER AND TEST SEALS AND
ANNULUS TO 2500 PSI.
9. INSTALL BPV' S,. ND BOP, NU & TEST TREE.
FILL-~
,; FLOW ~
ANNULAR
BOP
,
i 135/~"5000 psi ,
I
,
I
.
PIPE RAMS
13s/fi'5000 psi
,~,, ~ n~, BLIND RAMS
· 4 - ~ ~ ~¥~ 5" '
CHECv V-~T~;: 13 ~ 5000 pm
'~ ~' ~ HCR : , HCR
LINE ~U ~.~~3s/i5ooo p~ CHOKE
I
LINE~
RISER
5000 pm
CHAKACHATNA RIG 4-2:8
BOPE: STACK
13 5%. 5000 psi
VENTOg~DE
VENT UNE
3' RELIE~ VALVE .-~
Sc'TAT ~ PSI
j _ I.i £ _ I11 - - ..... iii i
J~l~l
PANIC UNE
4' §,0001~ol
8AtL V,4LV~
4 ~/~-~
x 4 1/16-5t4 tll, l~
TARGET
81JNO ~UB
4 1/16-5U FLG.
WILLIS
'¢L, U4P
FRIB CONNE¢I*tOH
BUFF~
TANK
SIPHON UNE
8" UUD RETURN UNE
COOK ~
Ol~.,. Clt- 1:12592
ARCO Alaska, Inc.
Date:
Subject:
From/Location:
Telephone:
To/Location:
August 3, 1994
ARCO Cased Hole Finals
Karla Zuspan/ATO- 1529
(907) 265-6547
Distribution
P.O. Box 100360, ~...._'.horage, AK
Transmittal #: 94069
99510,d~ ~'
WelJ' ' Log"l~a~e ...... To~l Type RUn Contractor
Number (M-D-Y)
·
, ,
16-24 7-11-94 Prod Prof 1 SCH
" 14-07 ~-12-94 LeakDet I L ' SCH
~'2-32 7-10-94 Per~ RecOrd I ..... SCI;-I' '
09-43 7-12-94 Per Record I SCH
09-06 7-11-94 Leak Det 1 SCH
07-03 7-10-94 Dual Burst TDT-P I S(~H 'i
'"d1-18 ~-9-94 "' Peri Re~ord ' I SCH
Number of Records: 7
Karla Zuspan
Distribution: Central Files Phillips
ANO-8 Geology BPX
Exxon "State of Alaska
Mobil
Please ac~ledge rT//~~,g a cot~44~f~ransmittal.
ARCO Alaska, Inc. I$ a Subsidiary of AtlantlcRIcht'leldComl3any
Bill Sheffield
Governor
ALA$1(A OIL A,~D GAS CO#SEtTYATIO/i cO,~, ~,~iSS/O~!
3001 PORCUPINE DRIVE
ANCHORAGE,ALASKA 99501;-3192
TELEPHONE (907) 279-1433
We wish to bring to your attention that the Commission has not
yet received the following required items on the subject well
· which our records indicated .was completed _~--~-g~
Article 536(b) of Title 20, Chapter 25, Alaska Administrative
Code, stipulates that this material shall be filed within 30
days after completion of a drilled well.
Please 'submit the above missing material.
Sincerely,
Chairman
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
3001 Porcupine Drive
Anchorage, Alaska 99501
(907) 279-1433
..
State o[ Alaska
TO: AJa~ka Oil and Gas Conservation_ ~
3001 ror.eupi~ D~,'v~ -
Anehorago, Al~ka 90501
Receipt of the following material which was transmitted via
.,/~.~?~/~e!~ is hereby acknowledged:
/
~UANTITY
DESCRIPTION
RECEIVED:
DATED:
Copy sent
YES
to
sender
NO
SCHLUMBERGER OFFSHORE SERVICES
Amoco Production Company
P.O. Box 779
A Division of Schlumberger Limited
HOUSTON. TEXAS 77001
JUNE 20,1984 .L=^...K.-v ,o
iCHLUMBI'RGI'R OII'II'II. IORE sI'RVICI'I
/~ 500 W. International Airport Rd.'
......... Anchorage_ Alaska 99502
ATTN: ffETH CUZZORT
Anchorage, Alaska 99510
A~ention: District Engineer
Gentlemen:
Enclosed are3 BLprintsofthe
Comp(3ny Amoco Production Co.
Field MIDDLE GROUND SHOALS
LITHO-ANALYSIS
on:
,Well. MGS 17595 WELL #23 (69121)
,Coun~ KENAI State. Alaska
Additional prints are being sent to:
1 BLprints
Platform - Kenai
1 BL prints
Senior Field Foremen - Kenai
1RRolled Sepia
1BL prints
Area Operations Superintendent
Production Department
Chevron USA~ Inc.
~.o. ~ox 7-s~ -~~
9'~--- : ~'~
Anchorage Alaska 9 ~_~~'
1RFolded Sepia
I BL prints
AI~i & Gas
~Commission -
'~~horage , Alaska
1BL nrints
Staff Geologist - Anchorage
__prints
1 RFolded Sepia
1 BL nrints
Proddction Manager, New Pro jects
ARCO ~eska
P.O. ~:3&(Y'.-.-: z"-:~'~.:'?
Anch~':~AlaSka:~ ~9 510
prints
These open hole prints were sent
to Anchorage Amoco Office for
distribution.
The film is returned to AMOCO
(Far West Div. Prod. Manager)
Received by'
Date'
We app.~eciate the privilege of serving you.
LV E
JUN 22 1~ ~ ' ~
Alaska 0il & Gas Cons. Commission
.^ Anch0ra~e
Very truly yours,
SCHLUMBERGER OFFSHORE SERVICES
....... ::_:.:_ :...
"CATHY WRIGHT
DISTRICT MANA~I'R
Bill Sheffield
Governor
ALASKA OIL AHD GAS ~,0#S££¥AT10#
DATE:
RE:
3001 PORCUPINE DRIVE
ANCHORAGE,ALASKA 99501~-3192
TELEPHONE(907) 279-1433
We wish to bring to your attention that the Commission has not
yet received the following required items on the subject well
which our records indicated was completed . ~/p .~f--/~?'-- g~
Article 536(b) of Title 20, Chapter 25, Alaska Administrative
Code, stipulates that this material shall be filed within 30
days after completion of a drilled well.
Please submit the above missing material.
Sincerely,
Chairman
W. G. Smith
District Manager
Amoco Production Company
Post Office Box 100779
Anchorage, Alaska 99510
907-272-8471
May 4, 1984
File' TJZ-OO4-WF
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Gentlemen'
Well Completion Report
Middle Ground Shoal 17595 Well No. 23
Platform Baker, Cook Inlet, Alaska
Attached in duplicate is a State of Alaska Form 10-407, Well Completion or
Recompletion Report and Log for the subject well. Directional surveys,
magnetic tapes of the well logs, and a well history are also enclosed for
your information.
Core chips and descriptions of each will be forwarded to you as soon as
our analysis is completed.
Very truly yours,
W. G. Smith
District Manager
Attachments
KLS/dds
STATE OF ALASKA
ALASKa..,iL AND GAS CONSERVATION C,_ iMISSION
WELL COMPLETION OR RE:COMPLETION REPORT AND LO
1. Status of Well Classification of Service Well
7
OIL [] GAS [] SUSPENDED []. ABANDONED'i--] sERvIcE []
2. Name of Operator 7. Permit Number
Amoco Production Company 84-11
3. Address 8. APl Number
·
P. 0. Box 100779, Anchorage, Alaska 99510 5o-733-20369 -
4. Location of well atsurface~eg 4, 'Slot 2, MGS Platform Baker 9. unit or LeaseName Middle
1986' FNL, 472' F.-NL Section 31 T9N, R12N, S.M. ~round Shoal State 17595
- ,
At Top Producing lnterval G-1 Sand at 8608' MD, 8324' TVD -824 '- We, Number
2775' FNL, 332' FWL, Sec. 31, T9N, R12W, S.M. ~ V~RIFIED 23
At Total Depth 9722' MD, 9064' TVD, -8985' SS, 3182' FNL,/Sur'. ~-~111'FieldandPoof
1051' FWL, Sec. 31, T9N, R12W, S.M. IB.~._6_~]Lower Kenai Conglomerate
5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. :JMi ddl e Ground Shoal Fi el d
79.4 KBI ADL 17595
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions
01-21-84 03-20-84 04-07-84 CompletedI 102 feetMSLI 16
' I
.17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
9722, 9064 9593' 8992 YES gl NO [] N/A feetMD 0
22. Type Electric or Other Logs Run
See Attached List
23. CASING, LINER AND CEMENTING RECORD
SETTING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
. See Atta(:hed List
:
., .
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
Dual 3.5" 8543 NA
See Attached List --.
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
·
; :! - i : .. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED
.None
:
.. .
:,'t : ' .
27. PRODUCTION TEST
....
Date ¢:i'r~;t PrCduction ': ' - ;-; ';1 Method of Operation (Flowing, gas lift, etc.)
03-30-84I Hydraulic Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO
~4/07/84: ':' .12 '- TESTPERIOD I~ 129 - .50 1 Open 388
Fiow'Tubing cas[ngPressure iCALCULATED .. OIL-BBL .. GAS:MCF WATER-BBL OIL GRAVITY-APl (corr)
' Press"1:00 100' ' !24_HOuB .RATE I~. '258 100 ' 2 35. g
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
.
.
.Core #1 9130-9148 (ReCovered 12" of' oily sand'and conglomerate).
Core<-#2 9148-9176-(Recover'ed,26' of~Tight-Fractured-Oil Stained conglomerate)
Note' Core chips, and descriptions will be forwarded to your office.m.~,~-~.,, ~;~'-
MAY ';,~ 9 "q?,4_
0il &
Form 10-407
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
' .GEOLOGIC M~ARKERS'~ ....... FORMATION'. ~rESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE vERT. DEPTH GOR,and time of each phase. ,
Tyonek "A" 5802 573t None
Middle "B" 6480 .', 6388
Kenai "C" 7338 7224
Sands "D" 7610 7479
"E" 7945 7778
"F" 8250 8037
,,G_i ,, 8608 8324 ~
Lower "G-2" 8710 8402
Kenai "G-3" 8820 8482
Con- "G-4" 8970 8588
91o- "G-5" 9204 8754
merate
31. LIST OF ATTACHMENTS Logs, Casing Record, Perfo.ration Summary, ChronologiCal We! 1 Hi story,
and Directional Survey '
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
·
./
INSTRUCTIONS
General' This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation 'is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24.'- if this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23' Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none".
· ,
........................ ' ......... : .,"-~PERRY-SUN WELL ,.:,I_RVEYING C'r~MPANY ...................
A N C H 0 R A (} E A L A S K A
PAGE
-:. ? AMOC'O PRODLICTI ON COMPANY DATE OF'".:.LIRVE¥' NAR'P°..FI 24, 1;~84
...... -; ...... MGS ~$23 (SEC 31 T~/N Ri'SW) ........................... '-, ...... L.. .... CCff'IPUTATION DATE ................... BO'.BS--'GYRO'.~;C:OPIC .'SURVEY .........................
MIDDLE GROUND SHOAL MARCFI 26, · 1';~84 dOB NI_IMBER AK-BO-40()16
~ · ALASKA I<ELLY BUSHING ELEV. = 7¢~.40 FT.
· ' ............... .......................... _' '..] ..... ]. ......... .r .......... L'"" ......' ,: "' ' '" , ........... B ...... ~')~ .......: ................ OF'ERA'FOR-MOGUIRE"' , ....
' .,.' VERTICAL SECTION E:AL~jI.ILATED 'ALOIqL, 'C:LOSLIRE .~~, ~ ~ ~5 ~ ~~/~ ~0 ¢/0~
' ':'":~ ............ ]'RUE .............. SUB-SEA .............:COURSE CCIURSE DOG-LECi TOTAL-
~' :.. MEASURED VERT I C:AL VERT I CAL I NCL I NAT Z CIN . El I REC:'F I ON " ..... '
olzVIzR I TY ' REC:TANGULAR C:OORD I NATES VER)
':,' DEF'TH DEPTH DEF'TH DEG M I N DEL REEo DEG/100 NORTH/Stol .... ITH EAST/WEST
'"'"' I ' "'N."' O. ? E ' . . .' ...
."~ :..~ 0 0.00 ' -7'?.40 .... .' 0 '0 0,00 0 00 0 O0 0 ~'~"
~u~ :1.00 Z00.00 20.60'.... 0 .4:3 . S 56.'JF~ E ' 0.72 0.35 S 0.52 E.:']'" 0.54
.
· . ~ ~ ............... 200 ~ ':79. 'F/?) ....... J 20 ,. 5'F/ ,.' .0 -,,'. 40 ~J ............ S 62.50,.: E ...................... 0 .. 07.--' ............. 0 .-¢~?,7-- :~; 1 ,.~4--~ ....... ~ · ~Z,~:
S '~ ' ':'.'5!. 60 E" 0;:30 1 74 S ":' 72 E ';' 7
300 299 9 ::: c, ,:, 0 5':' (") ...., . .
~ ~ I. I_1 . . .lI ,. , t , J J ,
400 397~ 'F~7 320 ~,7 0 .... ':"~'" ' '-"70 l'~ 'E 0 5]'~ ':'
== ..::, . . = 36 S "" 66 E 3 7]
., ..~ 500 . · - 4'~'2. ?7 ........... 420.57.= ............ 0 ..... 84- . , N..,,72.19...."N.]:,'.'. ...... "O..'-=:x~, ""'.~.:31 .... S G:...48~ ~.-6(
'.~,~U.._,c, . · , 1 .... ~ .... N 64:30 'W 0.48 ~ 1.76 b 17 E '. '~ ~':
""""'"~'~" .... -_ Iq 44. t~',? W 0.40' ' '. 0.'87 z, 0. ::'/- E' ":" ~" ''
.,.: ..' . .....~,.: ' 700 677. '~.4' '.: : 620. 54":: ".. ' ":..' 0 '""' '
,-. _,., . ~.~
' ~'"':~'"'"' ':'"": ' ' ] ~o .......... ¥--~'---.720,.53~:.L....~,LA ..... 5c,..,...:... N .... ' . 0 N <'~ ~.-19~-~ .... :':"- 0.-2/~'- N 0 ~-04-N':,-':'L''' ': ' ~<'~,-
.... _ ~ , ".:~ .:,., · . _ ' . .
,: ~ 00 '-' 'T~'~. '~ 2 o ~, r) 5'-' '~' " " '
,= ....... .,-,~,,..,~ 0 30 N :36.1'F~'W 0.37 1.27 N 0.72 W -1.4
.'.. 1000 ~')?}., ?~2 9'~'C~.. ~. 52 . . 0 . 27 "h.I. ~'-'~].. :=:9_. W ~. 0,"14 1 ,9'=7, .. N 1 , 13 W "' -2, ~,='-'"
. ', . ,..,',.,'
.... 1100 .......... 10':/'~,.'~2 ..... ---1020,52-----$..-.A "-" ' "-"~" 50 W--. .: ...... A,.iO '-' 6~,~-N. ' "= "
........ . . -~-,la-,~ ..... N o,~. .l, ........... : ..... 1.~.4~,~ W
;'~..'::"" '"'~' 1200 '11 ~9 . ') 1 11'20.51'" '.,.. . ' :' 0 '" 37 .'- . .. .. 'N' i ..."~. . c~_ E' ', · 0.'46 ':'~,, 45 N. 1., 4'F/' W -
- ' . ~ ;~.. 91 ~ 220'. 51 "~':' '~ .
.;.c:'..,. ' 1300 1~ . ' · . . 0 :.:.142. : ::: .... N 51.1 .E 0,42 4,36 N 0,88 W '" -.~"I
'? '~ ....... 1400 ......... 18~'F)," ' - " . ." - 5 ,'.24- N 0.,.-08-. E 4,
~)..' :':'-~:-:' 182~'~ ,-.50 : "-:0.'-]47-'--~-.N .44.1' ~... E 0 ;.. 13 --
,:{,~.;., . .,
:~., 1Sc'~(') 1499. '~'~ " -~. 7 .i
~-. . . ~,:, 1420 48 ~ '1':' N ~,7 /-,':) W 1 6'~ /-,, 14 N 0.4:3 W
~ . - . m · · . '--' m -- .' m . .
~c~ ................. .-. ..... ~ ........... N 8/~ ~() ~ "".~5 6.,-6G..-N ...... 4,-2'~.--~ ...............
",..,;;'~'.,'.'~]':,c'.~'. ~ 650 ~ ~47~, b7 ~: ':~.: ..[ 570, 27.' · 4 "43 :' . N 86, 30 N 2, 68 6.88 N 7.8'.~ N · -?.
...... · .~ _. .. .... ~.:, · '' 7 14 N 12 42 W -li.8::
.
~ ~75(:) -~74~ ~4-,;:?~',.'1~.-7~ .... ' /. ' 5=' "' '-' _ .....
, . - ..... .. _ -.-..._, ........ o :::A 6'~.-N · . 2:36 7-~J?--N 17~77-N 14 ~('
', ~,~ · : .. . .
.... ''' ' I BO 0 i 778 72 1719' 32 7 ~ 1 S '''87 10 W 1 C/ 1 6 '-- =' N 24 40 W 1
~?~;.~:.......' · . _ ....... ;/._, . '--
;(',~' :' '"'" .. '" ~ ~00 18 f/7 72 1 ::: 18. '::? ' · ":E:" ' ':"-' '' ':"
;~ 8'~' 30 W ('~ '-'= 5 63 N :38 44 W - i '-'"
.
.. . · . .. .. '~--~"'* / ~- ~ .-~ ,- .~ .,
~ """ '~'~- ~'-2000--.,: .... 1'~6 6._ ~-~1~. ~'= "' ......... .
, 17..~ .......... ]. 8~26'~ ' '-:.S-.,:,~, o?-..W 0 0'~--- - ----~..-72-.N .~,~-,-y4-W -
.~i" 2100 20~5.~,==~, . 2016,15 . . 8 04 -.. ':'._, 81,87 N 0,1z: 1,74 txl 67.5':/~.. W '-31'.0:
;; Jc) 21 ~4 ":'~] '? 114 'F/5 9 8 · "' 84. .-,~ c~,:
, - .:, (] W (') AA ('). 14 S ::,Z 87 W
~": ~ ": 2:3r)0~--22~2 .'~2 ............ 271'" ~'-' . . ~..' '- -- '
. , _ o .-~, ~ ..... 10,--'1 _ . .2.'-' :5 :~./-,_ 9 ......... W 1 .- 1 A -1-~ 5- S ........ '~ '~, A '~'-~-W
fi"', ; ........ ~._. ,, .~...~. .
'~';' "-' 2400 23:~/1' i1 27,11 71 ~1 31 S 84 ::::':~ W 1 29 3 81 S 118,42 W -48,~:.
:;/"-. 2500 :248';~, O0 ' 240?, 60. 12 '. 4 S 7'F~. 60 W 1.21 6.5'~ S ~ 38.64 W -54, 4'~
.
'? ~ --,~,-, o.-, ~'~' - '~':' ' ' 6? :30 W 2 14 ---12.,-i '-' -' .~ :'-" 5~.,-.W ':"'-' .2~
.... 2600 ........... ~W~'6,LO~''-- ~WO Z. 42--' ...... 'L"''I 1 '--'
......
- ~ ~1 ,. ~ , ......... ~ .......
':' '. ' ' '" I ........... F'AGE ....';'
......................... ' .... .=,FERRY-oLN WELL SLIRVEYING COMF'ANY ..................................... -':" ...................... ..-
.. ANCHORA~}E ALASKA ·
AMOCO F'RODLICTION C:C[MPANY , [;ATE OF ._-,I_[~VEY MARCH 24, 19:34
,
~ · .~'., .-, . _
MGS 4{40 ('.SEC ~1 ]'gN R'i 3W) .......... '~'"'. ....... 'F:.FiMF'I ITATION DATE ................... BAS:-~ AyRCr._~F:C,F'IC ._IJRVEY
'? ' MIDDLE GROI_IND SHAAL MARCIq 26:, 1984 ,JOB NI_IMI'4ER AK-BA-40016
,
'i:' ALASKA .'. KELLY BU:E;HING F'LEV. = 7'-2.40 FT.
;.:-. ...................................... OF'ERATAR-MC;AU I RE
,.. .. .:. , ........ "'"'. ................................ .: ................. '.'": ........... ' ...... ." ..................... ~.'";"r-'"'..-'"?T'"'."'-:'"i ........ -
i". 'r: :'":' ' ' --' ]'--' ' '" ' "' "
VERTICAL SECTION CALCLILATED ALONG L'LE':'LIRE .....
, ;." ,
[.:' .... ,': '.,. .
.............. :' TRUE .............. SUB-'..:;EA...,:.: .... ,.'. ....... :.i31']URSE.,..: ...... CCHJRSE ......... DOG-LECi,..., ..... ~, ......... . ............... TOTAL.: ............ ~. ................ ~ .....
~'!'"'~'"':.: ,-' I , ' ' -' ' ' INF:LINATIC!N' ' DIREC:TIFdq 'i:;EVFRITY 'RECTANGULAR COuRDINATE.$; VERT.:.
,. .. MEA~,LRED. VERTIL. AL VERTICAL
, ,' -- -- 1--' ~ t-. 1-' ~ I-" '
.,: ' DEF'TH F~EP]'H.. DEF'TH DE,-i MIN DEAREE'.2: DEF. i/lC)C) NC, F(TH/'.2:FIUTH EA,-,T/WE.-,T ,-,E_.TION
,, :. ,.,.~ . ,
.
· ,
" "'" "" " ' ' ' ' 176 '~2. W .
. i,~, ~ 2700 . ..'6,.-,4.79. 2605.3':".;' ' . '11 15' S 63 '"c ':'
. , ,. . .:, J, W ,, 1 . ._,6 20 .14 :-3 .. -,...,,-,'=":' ':,;~:
.... :: ~ 2:-":00 ""~""':' ..... 00' ':" '":,'"zc~'q 60 1. c~ ' '":'"" : '""' ' .,::.,-,. 19 S 1"--'c';'._, ,F, 4.~ W -5o. 1
~ .:i'c .,:.- .... , : ...,:- ....... .' ' '.' .,:.,., :~.i. .o 66. :1. 9 W 0 9Pi '-"-' . .....
,
...... Z: ............. 2900 ":"-"--,' 9 "-~':' '-' .7:2: '"'
~c.,,:, 1 4':" "-" '-' ' '-' ' . ·
............... --..c,O.c, c).,:: ..... . ................... .,:, '":~(') ~ .W ......... 1 41.-: ............ 34,30 '-' 10 ..=,CJ-W ..... ~__~-Z_..,l::,:.,, ;.:.'.7
: ' 30Cl0 '-"-?'-"; '-.? ' ,('.~ '7':-.,' '-"-'/-, "'i'.::'
..'; ,-',L, 0:]-; 2':.-,'c~0 .6:3 : .. . :l:2: ".2; .76'... ,[:~ W . . 38 ,/_.,:s:. ,.E; ~... _, ._.,_ W -&:::._ _ '":".. 1
· , ~ ,,
.. :.. ~. 3100 ...'--: 078 .76 ' · , '.F' 9 S.,' 9,36' , ':.-,'. ' ' ":' ,' .'.:..;'" 7 :,:-: . 10," 'W . 0 . ""-'..:,,--, 42.24 ,..':; 241. '?. '-.-,'. W - 67.4 ._.=,
' . ..3'-.-.'00 ..... , ..3177,.53 ' .-,- c.,,,-, ,'5'7 ' ''-" .76'~ 69.. W O. '-"-' :'"" "-- '-' '-'?,
..... -.o.~; ,.: 1.3 ::,. ......... :: '::'' . ...-..: ........... 4.,...,..6 ...... .,: ....... .,::.,..7 26-.W -71-,,..0:3
..... ',":' .............. :.~,., 0. ,' ................
.,
. .., : ,,
,:, ":: c.~ C) '3276. '""" '"' c
.,:..:, 3196 c,..: ~; ...:::.~ 6'.~,'.='-,:'~ W i 2F.: ,'_"5',C~ 34 S 272..=,7 W -7:2: 4'.-.-,'
,:. . , .::,.
· ' :' . ._1 # _ . . ,,..., ·
%. i_t ...,., ' ,. .
; , .' . . : ,
· r. '-' '] i0 '57 S' 7C) 50 W 1 '1.6 .s/- 4n S
,,'. ' ~.,,~ ,:,40~ 3374.6:3' :)'" ._, .,:..'"':-"-.":',, ~.. ._ . .,:. ..:,":' "' . . . , .. , . ._ _,. . _'-::':-':'?.. ,27 W -75."::1,.
/ ~ ~::-' F-,tN CJ '-' ''''' .'.' .. ':-"-"-": c, : '--"' 7 ' .. '-,,-, Z. "" ' '-' ' '~" - ':":, ,
..... 8... ,: ..... . 3472 1 69 W...::-,.:. ......... 0,~..',: ........:,,...6L~.-..: ............ ...-07., ...... ,,-.W-L~-----77 ,62
· .,.7o ..... .,..-.;,.,, :38',': ..." .-,:.'11 .:~.'7.,?,:,~ ............ . ,
· ~ll~.~. . ' ' ,
3 5 7.0.8 9 3 4'? 1.4 9 1 1 1 1, ,
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~ ALA.=.KA .. KELLY BUF;HING ELEV. = 79.40 FT.
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8100 7 910 02 v"":' C~ A'2 .=, c, '-.
. .c ......... = 41 b, 60'. 80
............. 7 ~.,~. z9 .......... 7872.89 ........ ~ ........ 31
. -.,¢~ .............. ~, .,.~,7
"' " ~ ~' ':'/' "" 54 '-'¢
8200' 7994 81 ,....,..: 7::; 1~, 41 1 ~,_,
'(:::' ":?' 8300 8079 13 :::?.:'?'~,: 799'2 72 ..... '
. .~,.:, 24 '="" ¢ '>
.................. '=---8400 ..... : ....... 8161 .. 04 .... ~-, 8081.64 ........ '.,.-.. E: /: ......... 34 .... ~.',-.. S...
',E:SC~O 8240. 56 ::: 161. 16 3:E: 2 '.=;
:3/=,00 8:318.25 82:38.85 39 ' 58 ".E;
................... 8700 ....... 8394.11' .........S314.71 ...: ..... '4.1 .... ,.19 ............ S
6:800 :-':467, 45 8;38:::. 05 4.4.
Z~~ ~,~C,(,. o~.~.:, 61
i_, ._ %.,. ,_1 ·
..... -, . ,:..~ .-,.~
_1 O0 86:E:0.
. .~ ~ 12 I--I
¢ ~, 200 ..... =.7,. 1.43
~'~'~ '?400 '=' '='':' 6
............ '.-','500 -.. 8'P:3F/. G 1
7~t ' 2 600 89'? 5.7/-, 8916.36 55 50
. c, ¢7~ · ._, 1 ' - .-,.-, · .-,U . ,
...................~&~~'~ %I.L. .. , ' "
7~.~' 9064.2~ ......... ~-8-9:--:4..86 .... ----55~--.50 .........
..
515.30
55'..6?
57, 10
57., 50
58. :{:'0 E
59.10 .I.Z
5'?. :30 E.
S. 5'?. 50
,.~.. k.~i,:) ,'-,(-
· ', ._ .. ,Z, .)
'"
.;:,.
S 60 89
::: 62.'.
.E;-- 6:3. 0
S 63. 0 E
S 6:3. 0 E
':' 6:--: .L_q .. E
· . ~o4.78
E ':' '-'F ~'~'" .:, ,.,,., 1 ~. W
· .- ~: .) ,.,,~,=,. 11 '" : =' '- '=' '1'"'
IE 2..., 7 . ~,,., u..., (.~ ~:, .., 14 .... ? W 271.06
E ....... ] .............. -'."'¢'= ' '. .... ~ ,'-, c, .-, ,- .
~ o._, ........ -~ .... ,74..4,..- ................. .-~-4 7.:, ... ,¢ ~ ..... W.------~I
E '-' .... "-? :i'~'-? 07 '-] n.~,c¢ q,-, .-, .-,
· .' .:,.-. ......... -,.,... · ~,:, W' ,:.5-'. 1
· '-' '-' c ..... , · 54
E 1 t/.:, 6..'4.5".' '-'""-'
...,. ~ .:,,=, ..'. 13 W '-":~ ~
IE', ......................... 3 .~ ;,70 ........... 638,... 16-S .......... 359 .-1.8-W .--~---41...7-.
E 3 '"~' '~'-' '" -
o.,'- o..,z, o6 b; 337 '"'-'
.:,,-, W 440
· · -- ·
"'" ':' '=' 293 75 W 4,'_=:7 79
'E 1 ol 6o4.21
ii ,..i , ~ ·
' L' . ' ' '~, "3 "]. "'? ~ '1, .-., r,-- ,-. .-, ",
-E .......................... ~. .... ............... / z .../,-,.., .J-x: ............... .-,4/=, '-"-',::.,,_~-~ w ~'' ................ " ='-'"',.:, / ., ..';'~,..
E ' :L,.,'= () '7 ~ .... 1 "='-' '.:,'" 19/:, '::"'":' ,.. ....
.... ,,: .... .,.. W ~";' (')
~.11 7:=:6,40 'S 144.48 W 644 ~',
. ['-' 1 ..37 821.60.. '=' :.'-:9,66 .- W 700,38
'-"- '=' 31 9'.-.: W 757 L::G
· _,"-" ', t 0 ,:,.:, 7. "44 ._. . . ~ · . -
O. 71 c,'-"-?; .:,'-'. o'- ,=,'-' ~q 28.27 E 8 ]
- '.-~".'9' '-?"" S '"'-
· -0 )J;I.- ...... .-... ,..-/_ .................. . ....
. o :.~. ciA- IE ....... 87 ,7
E ~'~ ""'-' '-? b' ~
· ._ 4 E '? 16
..... =,,--, ; ._,._,. 04 '._=; 131 ?] - .
E 1.04 · '?/65.65 S 14'.--.;. 66 E. 934.
· ~ E ................. 0..74 ..... 1. c:iO 1.. ' '-' '" '-'
.-,
:::;:, -,-. ,. .... , .... . .
'E :2. '" "' , .~1 o . ..'74.-.'.-, E 1053 1"
E : 57 '.-_-: 342. '?0 ' E ' 111/_-,. 5
E ............... 2.5:"_-': ..... 1..1-.1-2 ..-1:3-.S ............ 4 t 5,424.~.. E .....1,181,
,Z, ,--, C;, '-., ,-,'
0.0(') ' 114'2.7c-) S 4 ......... 7 E 1 .. 47. ,:,,
0 ' c')0 1 i ,:,'7 -:,/. ,=. 562 · 70 E 131:3.8
..... '.. O' O0 ........ ~"'-"=-- ='" '-'
.~ :,. .,:,-.~ c,-,: ....... 57:=: .-'.¢'-"--E~--1~::'."~
' "':,~0 ,-. -, . .-,
HORIZONTAL DISPLACEMENT = 1...',=..'--'2.~ FEET AT oLUTH, DE]'~
-.' ._1
'I'HE CALCLILATION i='ROCEDURES ARE BASED ON ]'HE LISE C. iF THREE DIMENSIC~NAL
50 MIN,
EAST AT MD .0.722
RADILIS OF CLIRVATLIRE METHOD.
' Su~gesned form to be inserted in each "Active" well folder to d~eck
for timely compliance with our regulations.
' Operator,' W~I 1 Name and Number . ' '
Reports and Materials to be received by: ~-- ~7'--:~y~L/~'' "~
Required Date Received Remarks
· ,
· Ccmpletion Re~ort Yes
_Well . History. Yes
..
_Samples
Core..~_ . Description~_ ~ y ~.
Registered · . ~'~.'
Inclina~on S~ey ~
~Dire~ional ~ey ~ ~/
Drill Stm Test Re~s /u--*/~
~~ ~ta~- ~/~ ,
SCHLUMBERGER OFFSHORE SERVICES
A Division of Schlumberger Limited
HOUSTON. TEXAS 7700!
PLEASE REPLY TO
May 3, 1984
Amoco Production Company
Amoco Building
17th & Broadway
Denver, Colorado 80202
Attention:Far West Division Production Manager
SCHLUMBERGER OFFSHORE SERVICES
500 W. International Airport Rd.
Anchorage, Alaska 99502
Gentlemen: 1 RFolded Sepia 5" DIL; 2" DIL LINEAR,
Enclosed are2 BLprintsofth~e 2" & 5" NGT,LDT/CNL;(2)SHDT,GR/CCL
Company Amoco Production ko. ,Well MGS 17595 #23
Field Middle Ground Shoals ,County. Kenai C;tate. Alaska
on:
,
Additional prints are being sent to:
1 BL-rints
]Far i~st Division Ge°lo§ist
Exploration
Denver
__prints
2 BL nrints
District Production Manager
Getty Oil Company
Three Park Central, Suite 700
1515 Arapahoe Street
Denver, Colorado 80202
2 BL nrints
Staff Director of Reservoir Engr
Phillips Petroleum Company
8055 E. Tufts Ave. Pkwy.
Denver, Colorado 80237
prints
__prints
prints
prints
These open hole prints were sent
to Amoco Far West Division for
distribution.
The film is returned to AMOCO
(Denver)
We appreciate the privilege of serving you.
.
Date
Alaska ~ Cons. Commission
Anchorage
Very truly yours,
SCHLUMBERGER OFFSHORE SERVICES
SO~-1565 A
DISTRICT MANAGER
SCHLUMBERGER OFFSHORE SERVICES
a DiVision of Schlumberger Limited
HOUSTON. TZXAS 77001
May 3, 1984
Amoco Production Company
P.O. Box 779
Anchorage, Alaska 99510
A~ention: District Engineer
500 W. International Airport Rd.
Anchorage, Alaska 99502
Gentlemen: 5" DIL;2" DIL LINEAR,
Enclosed are3 BLprintsof the 2" & 5" NGT,LDT/CNL; (2)SHDT~GR/CCL
Company Amoco Production Co. , Well MGS 17595 #23
Field. , County State. Alaska
Additional prints are being sent to:
[ BLprints
Platform - Kenai
1 BL prints
Senior Field Foremen - Kenai
1BL frints
Staf Geologist - Anchorage
1 RRolled Sepia
1BL prints
Area Operations Superintendent
Production Department
Chevron USALInc.
P. 8
~z~_chorage, Alaska 99~-1~
1RFolded Sepia
1 BL prints
Alaska Oil & Gas Conservation
Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
1RFolded Sepia
1BL nrints
Prod6ction Manager, New Projects
ARCO Alaska, Inc.
P.O. Box 360
Anchorage, Alaska 99510
prints
These open hole prints were sent
to Anchorage Amoco Office for
distribution.
The film is returned to AMOCO
(Far West Div. Prod. Manager)
We appreciate the privilege of serving you.
Rece~.ved...z~:
MAY 0
.~-~
Date'
..... q, (),1 I?:n flnnn~ 0nmmissi0.
Anchorage
Very truly yours,
SCHLUMBERGER OFFSHORE SERVICES
$0~-1565-A
DISTRICT MANAGER
MGS 17595 WELL NO. 23
22. Type Electric or Other Logs Run:
Mud Log
03-12-84 , Dual Induction (DIL)
Litho density-compensated neutron
(LDT-CNT), gamma-ray (SGR)
Natural gamma-ray spectrometry
(NGT)
Stratigraphic high resolution
dipmeter (SHDT)
2200-9722'
3588-9088'
3550-9082
3550-9082
3609-9080
03-21-84
Dual induction, gamma-ray (DIL-GR) 9078-9706
Litho density-compensated neutron
(LDT-CNT), gamma-ray (SGR)
Natural gamma-ray spectrometry
(NGT)
9000-9689
9000-9689
Stratigraphic high resolution
dipmeter (SHDT)
9066-9700
Al~o~a Oil & ~cs Cons. Commission
23. CASING, LINER AND CEMENTING RECORD
CASING SIZE
WEIGHT/FOOT
GRADE
MGS 17595 WELL NO. 23
SETTING DEPTH MD
TOP BOTTOM
HOLE SIZE
CEMENTING
RECORD
AMOUNT
PULLED
13.375"
68.0#
61.0#
54.5#
K-O80T
K-55
K-55
O' 3589'
17.5"
3,100 sx
Class G
9.625"
1i
53.5#
53.5#
47.0#
47.0#
43.5#
40.0#
40.0#
29.0#
P-110
N-80
CF-95
N-80
S-95
S-95
N-80
L-80
8985'
O' 9095'
9685'
12.25"
,5II
1850 sx
C1 ass G
210 sx
Class G
MGS 17595 WELL NO. 23
24. Perforations Open To Production (MD + TVD of Top and Bottom and
Interval, Size and Number)
MD TVD
NET FEET SIZE
8608' - 8664' 8324' - 8367' 56 0.5"
8710' - 8790' 8402' - 8460' 80 0.5"
8820' - 9184' 8482' - 8740' 364 0.5"
9212' - 9404' 8760' - 8884' 192 0.5"
TOTAL = 692
Number - 4 JSPF Each Interval
2768 Perforations
01-17-84
to-01-21-84
01-22-84
01-22-84
to 01-23-84
01-23-84
01-23-84
01-23-84
01-24-84
01-25-84
to 01-26-84
01-26-84
to 01-27-84
01-27-84
to 01-28-84
01-28-84
to 01-29-84
01-29-84
to 01-30-84
01-30-84
01-30-84
to 01-31-84
01-30-84
to 01-31-84
01-31-84
CHRONOLOGICAL WELL HISTORY
MIDDLE GROUND SHOAL 17595 WELL NO. 23
PLATFORM BAKER, COOK INLET, ALASKA
Rigged up over Leg 4, Slot 2. Cleaned
out 30" conductor and spud well on
01-21-84
Drilled out of conductor casing from
118' to 285'
Dyna-drilled from 285' to 331'
Drilled to 490'
Dyna-drilled from 490' to 533'
Drilled to 583'
Ran gyroscopic directional survey
Drilled to 1,447'
Dyna-drilled from 1,447' to 1,827'
Drilled to 2,479'
Dyna-drilled from 2,479' to 2,624'
Drilled to 2,815'
Dyna-drilled from 2,815' to 2,935'
Drilled to 3,241'
Drilled to 3,241'
Dyna-drilled from 3,241' to 3,314'
R.E C
Alaska Oil & ecs Cons.
. . ~: ~
02-01-84
02 -01-84
to 02-02-84
02-02-84
02 -05 -84
02-06-84
to 02-10-84
02-10-84
02-11-84
02-11-84
to' 02-12-84
02-12-84
to 02-13-84
02-13-84
to 02-14-84
02-14-84
02-15-84
to 02-16-84
02-17-84
to 02-18-84
02-18-84
to 02-22-84
02-22-84
to 02-23-84
02-23-84
to 02-24-84
02-24-84
to 02-29-84
Dyna-drilled from 3,314' to 3,373'
Drilled to 3,601'
Ran 13-3/8" casing to 3,589' and
cemented with 3,100 sx Class "G" cement
TST BOPE to 3,000 psi x Hydril to 1,500
psi. Drilled out shoe to 3,611' MD and
ran leak-off test to 14 ppg equivalent
mud weight
Drilled to 5,521'
Dyna-drill to 5,530'
Drilled to 5,640'
Dyna-drill to 5,794'
Drilled to 5,884'
Dyna-drill to 6,070'
Drilled to 6,209'
Dyna-drill to 6,432'
Drilled to 6,502'
Dyna-drill to 6,819'
Drilled to 6,896'
Dyna-drill to 6,994'
Drilled to 7,951'
SCHLUMBERGER OFFSHORE SERVICES
A Division of Schlumberger Limited
HOUSTON, TEXAS 77001
APRIL 4,1984 .-£^SE .£.-Y To
SCHLUMBERGER OFFSHORE SERVICES
Amoco Production Company
P.O. Box 779
Anchorage, Alaska 99510
attention: District Engineer
500 W. International Airport Rd.
Anchorage, Alaska 99502
gentlemen: (2) SHDT' S,LISTINGS & 3 TAPES (4930)
Enclosed are3 BLprintsofthelSHDT~LISTINGS & 4 TAPES (4928)~VOLAN & Io~.TINGS
Company Amoco Production Co. , Well MGS 17595 WELL #23 (,69065)
Field MIDDLE GROUND SHOAL , County KENAI ~;tate Alaska
Additional prints are being sent to:
1 BL "rints
PlatfOrm - Kenai
I BL prints
Senior Field Foremen - Kenai
1 RRolled Sepia
1BL prints
Area Operations Superintendent
Production Department
Chevron USA, Inc.
P.O. Box 7-839
Anchorage, Alaska 99510
1 RFolded Sepia
1 BL prints
~q~i-aska Oil & Gas Conservation
~ ~u-~ i-n~ ~r i v---~
Anchorage, Alaska
99501
1BL nrints
Staff Geologist - Anchorage
~prints
1 RFolded Sepia
1 BL "rints
Proddgtion Manager, New Projects
ARCO Alaska, Inc.
P.O. Box 360
Anchorage, Alaska 99510
prints
These open hole prints were sent
to Anchorage Amoco Office for
distribution.
SOS--1565.A
The film is returned to AMOCO
(Far West Div. Prod. Manager)
We appreciate the privilege of serving you.
Date'
Very truly yours,
SCHLUMBERGER OFFSHORE SERVICES
CATHY WRIGHT
DISTRICT MANAGER
SCHLUMBERGER OFFSHORE SERVICES
A Division of Schlumberger Limited
HOUSTON. TEXAS 77001
APRIL 4,1984
Amoco Production Company
Amoco Building
17th & Broadway
Denver, Colorado 80202
A~ention~ Far West Division Production Manager
PLEASE REPLY TO
SCHLUMBERGER OFFSHORE SERVICES
500 W. International Airport Rd.
Anchorage, Alaska 99502
Gentlemen: 1RFolded Sepia (2) SHDT'S,LISTINGS & 3 TAPES (4930),
£nc~osed are2 B~rintsofth~SHDT,LISTINGS & 4 TAPES (4928)~VOLAN & b~STINGS
Compan' Amoco Production Co. ,We~ MGS 17595 WELL #23 · , (69065
Fie~d M~DDLE GROUND SHOAL ,Coun~ KENAI State. ALASKA
Additional prints are being sent to:
1 BL int
pr s
Far West Division Geolo§£st
Exploitation
Denver
__prints
2 BL ~rints
District Production Manager
Getty Cil Ccmpany
Three Park Central, Suite 700
1515 Arapahoe Street
Denver, Colorado 80202
2 BL prints
Staff Director of Reservoir Engr
Phillips Petroleum Company
8055 E. Tufts Ave. Pkwy.
Denver, Colorado 80237
prints
__prints
prints
prints
These open hole prints were sent
to Amoco Far West Division for
distribution.
The film is returned to AROCO
(Denver)
We appreciate the privilege of serving you.
Date' A!~si<a 0ii & (~'c3 Co~s. C0mn]~ssion
Very truly yours,
SCHLUMBERGER OFFSHORE SERVICES
SOS--1565 -A
CATHY WRIGHT
DISTRICT MANAGER
L. A. Darsow
District Superintendent
Amoco Production Company
Post Office Box 100779
Anchorage, Alaska 99510
907-272-8471
April 13, 1984
File: WGS-O77-WF
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Gentlemen'
Monthly Report of Operations
Middle Ground Shoal State 17595 Well Nos. 23 and 27,
Platform Baker Cook Inlet, Alaska
Attached in duplicate is State of Alaska Form 10-404, Monthly Report of
Drilling and Workover Operations, for the above referenced wells,
reporting March 1984, activities.
Very truly yours,
W. G. Smith
District Manager
Attachment
PLE' dmh
.. ,- STATE OF ALASKA ~
MONTHLY ALASK/~qL AND GAS CONSERVATION ¢'-'MMISSION
REPOIt3 OF DRILLING AND WOhKOVER OPERATIONS
· Drilling well ~1~ ~' Workover operation []
Middle Ground Shoal 17595 Well No. 23
Production Company
3. Address 8. APl Number
P. O. Box 100779, Anchorage, Alaska 99510 5o- 733-20369
9. Unit or Lease Name
MGS State 17595
2. Name of operator
Amoco
4. Location of Well
at surface
Leg 4, S10t 2,
Baker, 1,986'
R12W, S.M.
Middle Ground Shoal Platform
FNL, 472' FWL, Sec. 31, T9N,
5. Elevation in feet (indicate KB, DF, etc.)
79.4' KB
t6. Lease Designation and Serial No.
ADL 17595
7. Permit No.
84-11
10. Well No.
23
11. Field and Pool
Lower Kenai C0ngl0merate
Middle Ground Sh0al Field
For the Month of. Ha rch ,19 84
'12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spud date - 01/21/84
Depth at end of month -
Footage drilled - 1771'
See attachment
9722' MD TD; 9593' PBTD
13. Casing or liner
run and quantities of cement, resul~ of pr~sur9 tests
Ran 9-5/8" casing to 9095' MD and cemented with 1,850 sx Class G
cement. Pressure tested casing to 1500 psi for 30 minutes.
Ran 7-inch liner 8985-9685 ft. and cemented with 210 sx Class G
cement. Tested liner lap to 1500 psi for 30 minutes.
14. Coring resume
and brief description
Core #1 9130-9148 ft. Recovered 12 ft. of oily sand and
conglomerate.
Core #2 9148-9176 ft. Recovered 26 ft. of tight-fractured-
oil stained conglomerate.
!5. Logs run and depth where run
Run #1
Run #2
3550-9100
9000 -9722
ft.;
ft.;
DIL,
DIL,
CNL-LDT, NGT-GR, and SHDT
CNL, NGT-GR, and SHDT
~1G. DST data, ~a, shows of H2S, miscellaneous data
Zone
G-1
G-2
G-3 & G-4
G-5
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Depth (MD-ft.)
8608-8664
8710-8790
8820-9184
Apchnr~j:~_~
NOTE--Report on this form is required for~h calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the'TSth'~' of the succeeding month, unless otherwise directed. '
Form t0-404 Submit in duplicate
ATTACHMENT
03-01-84
to 03-02-84
03-02-84
to 03-04-84
03-04-84
03-05-84
03-06-84
03-07-84
to 03-13-84
03-13-84
to 03-14-84
03-15-84
03-16-84
03-17-84
03-18-84
03-18-84
to 03-21-84
03-21-84
03-22-84
to 03-23-84
03 -24 -84
03-25-84
03-26-84
to 03-28-84
Drilled to 8084'
Navi-drill to 8191'
Dyna-drill to 8237'
Drilled to 8267'
Navi-drill to 8350'
Drilled to 9100'
Logging; ran DIL, CNL-LDT, NGT-GR, and SHDT
Ran 9-5/8" casing to 9095' and cemented with 1,850 sx Class
G cement
TST BOPE to 3000 psi
Pressure test 9-5/8" casing to 1500 psi for 30 minutes.
Drilled out shoe to 9130'. Cut Core #1 9130-9148 ft.
(Recovered 12 ft.)
Cut Core #2 9148-9176 ft. (Recovered 26 ft.)
Drilled to 9722' TD.
Logging; ran DIL, CNL-LDT, NGT-RG, and SHDT
Ran 7-inch liner 8985-9685 ft. and cemented with 210 sx
Class G cement
Drilled out cement and tested liner lap to +1500 psi. for
30 minutes. Displaced mud wi th water
Ran Gyro survey and CCL-GR
Ran Kobe hydraulic completion equipment with 4" tubing-
conveyed perforating guns.
APR
L. A. Darsow
District Superintendent
Amoco Production Company
Post Office Box 100779
Anchorage, Alaska 99510
907-272-8471
March 15, 1984
File- WEN-O75-WF
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Gentlemen:
Monthly Report of Operations
Middle Ground Shoal State 17595 Well Nos. 23 and 27,
Platform Baker Cook Inlet, Alaska
Attached in duplicate is State of Alaska Form 10-404, Monthly Report of
Drilling and Workover Operations, for the above referenced wells,
reporting February 1984 activities.
Very truly yours,
W. E. Nielsen
Supervi sor-i n-Charge
Attachment
PLE:seh
MAR i 5 1984
Alaska 0ii & Gas Cons. Commission,
Anchorage
'-~ ¥ , ~-, . STATE(Jr=ALASKA ,~,,_.
~ ALASKA "L AND GAS CONSERVATION C IMISSION .
MONTHLy REPORT OF DRILLING AND WORKOVER OPERATIONS/ -
1. Drilling welX~]] . Workover operation []
Middle Ground Shoal 17595 Well No. 23
2. Name of operator 7. Permit No.
Amoco Production Company 84-11
3. Address 8. APl Number
P. O. Box 100779, Anchorage, Alaska 99510 50- 733-20369
4. Location of Well 9. Unit or Lease Name
MGS State 17595
at surface
Leg 4, Slot 2, Middle Ground Shoal Platform
Baker, 1,986' FNL, 472' FWL, Sec. 31, T9N,
R12W, S.M,
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
79;4-' KB Al'Il 1_7595
For the'Month of February
,19
10. Well No.
23
11. Field and Pool
Lower Kenai C0ngl0merate
Middle Ground Sh0al Fiel
84
12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
S'pud date- 01/21/84.
Depth at end of -month - 7,951' MD
FOotage drilled - 4637'
See attachment
13. Casing Or liner run and quantities o~ cement, results of pressurs tests
.
_
Ran 13-3/8" casing to 3,589 MD and Cemented with 2,500 sx Class "G" cement.
-t'0P job from 202' KB to surface with 600 sx Class "G" cement.
Di
14. Coring resume and brief description
None
15. Logs run and depth where run
None
I 6. DST data, perforating data, shows of H2S, miscellaneous data
None
MAR 1 5 1984
ni~ ~ Gas Cons. Commissio~
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Anchorage
[~~/~r~l~I Supervisor-in-Charge 3/15/84
NO:l'E--Report on this form is required o ~ calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of ~he succeeding month, unless otherwise directed.
Form 10-404 Submit in duplicate
02-01-84
02 -01-84
to 02-02-84
02-02 -84
to 02-04-84
02-05-84
02 -06 -84
to 02-10-84
02-10-84
02-11-84
02-11-84
to 02-12-84
02-12-84
to 02-13-84
02-13-84
to 02-14-84
02-14-84
02-15-84
to 02-16-84
02-17-84
to 02-18-84
02-18-84
to 02-22-84
02-22-84
to 02-23-84
02-23-84
to 02-24-84
02-24-84
to 02-29-84
ATTACHMENT
Dyna-drilled from 3,314' to 3,373'
Drilled to 3,601'
Ran 13-3/8" casing to 3,589' and cemented with
3,100 sx Class "G" cement
TST BOPE to 3,000 psi x Hydril to 1,500 psi.
Drilled out shoe to 3,611' MD and ran leak-off-test
to 14 ppg equivalent mud weight
Drilled to 5,521'
Dyna-drill to 5,530'
Drilled to 5,640'
Dyna-drill to 5,794'
Drilled to 5,884'
Dyna-drill to 6,070'
Drilled to 6,209'
Dyna-drill to 6,432'
Drilled to 6,502'
Dyna-drill to 6,819'
Drilled to 6,896'
Dyna-drill to 6,994'
Drilled to 7,951'
MAR 1. t984
Ala~;ka Oil & Gas 6r.)r~s,
Anchorage
03-01-84
to 03-02-84
03 -02-84
to 03-04-84
03-04-84
03 -05 -84
03-06-84
03 -07 -84
to 03-13-84
03-13-84
to 03-14-84
Drilled to 8084'
Navi-drill to 8191'
Dyna-drill to 8237'
Drilled to 8267'
Navi-drill to 8350'
Drilled to 9100'
Logging; ran DIL, CNL-LDT, NGT-GR, and
SHDT
03-15-84
03-16-84
03-17-84
03-18-84
03-18-84
to 03-21-84
03-21-84
03-22 -84
to 03-23-84
03 -24-84
03-25-84
03 -26-84
to 03-28-84
Ran 9-5/8" casing to 9095' and cemented
with 1,850 sx Class G cement
TST BOPE to 3000 psi
Pressure test 9-5/8" casing to 1500 psi
for 30 minutes. Drilled out shoe to
9130'. Cut Core #1 9130-9148 feet.
(Recovered 12 feet).
Cut Core #2 9148-9176 feet. (Recovered
26 feet).
Drilled to 9722' TD.
Logging; ran DIL, CNL-LDT, NGT R G, and
SHDT
Ran 7-inch liner 8985-9685 feet and
cemented with 210 sx Class G cement
Drilled out cement and tested liner lap
to +1500 psi for 30 minutes. Displaced
mud with water
Ran Gyro survey and CCL-GR
Ran Kobe hydraulic completion equipment
with Baker 4" tubing conveyed
perforating guns
03-29-84
03-30-84
03 -31-84
04-01-84
to 04-06-84
04-07-84
Pump diesel from well to give an
estimated 1500 psi negative differential~
dropped bar to fire guns and perforated
692 feet (G-1 through G-5 zones).
Pumping
Released rig
Pumping and testing well; 268 BOPD, 8
BWPD, and 104 MCFD of gas
Completed oil well. Pumping 258 BOPD, 2
BWPD, and 100 MCFD of gas.
L. A. Darsow
District Superintendent
Amoco Production Company
Post Office Box 100779
Anchorage, Alaska 99510
907-272-8471
January 15, 1984
File' WEN-172-WF
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation
3001 Porcupine Drive
Anchorage, Alaska 99501
Commi s s i on
Gentlemen'
Monthly Report of Operations
Middle Ground Shoal State 17595 Well
Platform Baker Cook Inlet, Alaska
Nos. 23 and 27,
Attached in duplicate is State of
Drilling and Workover Operations,
reporting January 1984 activities.
Very truly yours,
Alaska Form 10-404, Monthly Report of
for the above referenced wells,
W. E. Nielsen
Supervi sar- i n-Charge
Attachment
PLE' seh
-" ~-',. STATE O~ ALASKA ~_.
/~,LASKA ~ ,L AND GAS CONSERVATION CC 'vllSSION
MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS
1. Drilling well ~] Workover operation []
Miaale Ground Shoal 17595 Well No. 23
2. Name of operator 7. Permit No.
Amoco Production Company 84-11
3. Address 8. APl Number
P. 0. Box 100779, Anchorage, Alaska,99510 50- 733-20369
4. Location of Well
at surface
Leg 4, Slot 2, Middle Ground Shoal Platform
Baker, 1,986' FNL, 472' FWL, Sec. 31, T9N,
R12W, S.M.
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No.
79.4' KB ADL 17595
9. Unit or Lease Name
MGS State 17595
10. Well No.
23
11. Field and Pool
Lower Kenai Conglomerate
Middle Ground Shoal Fiel
For the Month of January ,19__
84
'12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks
Spud date - 01/21/84
Depth at end of month - 3,314' MD
See attachment
13. Casing or liner run and quantities of cement, results of pressure tests
None
14. Coring resume and brief description
None
15. Logs run and depth where run
None
.1 6. DST data, perforating data, shows of H2S, miscellaneous data
None
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
[,k3 '~ Ixl~ ,,, ~},-,,,..,/_ ^,q Supervisor-In-Charge
SIGNED ~ ' , [~" ~' I~,~-..~"b~ I' A 1'~ TITLE DATE "
NOTE--Report on this form is required for v-_.. ar month, regardless of the status of operations, and must be filed in duplicate with the Alaska
Oil and Gas Conservation Commission by the 15th of~t)~e succeeding month, unless otherwise directed.
form 10404 Submit in duolicate
ATTACHMENT
01-17-84
to 01-21-84
01-22-84
01-22-84
to 01-23-84
01-23-84
01-23-84
01-23-84
01-24-84
01-25-84
to 01-26-84
01-26-84
to 01-27-84
01-27-84
to 01-28-84
01-2'8-84
to 01-29-84
01-29-84
to 01-30-84
01-30-84
01-30-84
to 01-31-84
01-31-84
Rigged up over Leg 4, Slot 2
Drilled out of conductor casing from 118' to 285'
Dyna-drilled from 285' to 331'
Drilled to 490'
Dyna-drilled from 490' to 533'
Drilled to 583'
Ran gyroscopic directional survey
Drilled to 1,447'
Dyna-drilled from 1,447' to 1,827'
Drilled to 2,479'
Dyna-drilled from 2,479' to 2,624'
Drilled to 2,815'
Dyna-drilled from 2,815' to 2,935'
Drilled to 3,241'
Dyna-drilled from 3,241' to 3,314'
Jantmry 18, !984
Mr. W. E. Nlelson.
Supervisor-in-charge
~anoco Production Company
P. O. Box 100779
Anchorage, Alaska 99510
Middle Ground Shoal 17595 No. 23
Amoco Production Company
Permit No. 84-11
Sur. Loc. 1986' , 472'F%~, See. 31, TgN, R12w, sM.
Btmuhole Loc. 3127'FFU~, 988'F~fL, Sec. 31, TgN, RI?].t, ~.
Dear Mr. Niels°n:
Enclosed is the approved application for permit to drill 'the
above referenced well.
If cOring is conducted, a one cubic inch chip from each foot of
recovered core. is requlrmd. Samples of well cuttings and a mud.
log are not reo~.uired. A continuous directional survey is
required as per 20 AAC 25.050(b)(5). If available, a tape
containing the digitized log information shall be submitted on
all logs for copying except experimental logs, velocity surveys
and al!procter sur~zeys.
Many rivers in Alaska and their drainage zystems have been
classified as important for the spawning or migration of
anadromous fish. Operations in these areas are subject to
AS !6.05.870 and the regulate.ohs promulg~_t,d thereunder (Title 5,
Alaska Administrative Code). Prior to commencing operations you
may be contacted by the ~Habitat Coordinator's Office, Department
of Fish and Game.
Pollution of any waters of the State is prohibited by AS 46,
Chapter 3, Article 7 and thm regulations promulgated thereunder
(Title t8, Alaska Administrative Code, Chapter 70) and by the
Federal I,Tater Pollution Control Act, as amended. Prior to
cor~mencing operations you may be contacted by a representative of
the Department of Environmental Conservation.
To aid us in scheduling field work, please notify this office 24
hours prior to co_~menclng installation of the blowout prevention
equipmenit so that a representative of the Commission may be
pre~ent to witness testing of the equipment before the surface
ca~i~g shoe i~ drilled. ~There a div~rter ~ystem ~ required,
plea~ also notify th~ office 24 hour~ prior to commencing
equipm~nt !n~tal!atlo~ so that the Commission may w~tnes~ testing
De.ore drililns below the shoe of the conductor p~.pe.
In the event of suspension or abandonment, please give this
office adequate advance notification so that we may have a
witnes~ present.
Very truly yourm,
C. V' Chatterton
Alaska Oil and Ga~ Consolation Comi~ion
b~
Enclosure
cc~ Department 'of Fish & Game, Habitat Sect~on w/o encl.
Department of Environmental Con~ervatlon w/o encl.
Bill Sheffield, Governor
ALASKA OIL AND GAS CONSERVATIOH COMMISSION
January 17, 1984
3001 PORCUPINE DRIVE
ANCHORAGE,ALASKA 99501 '-3'i 9 2
TELEPHONE (907) 279.--1433
ADMINISTRATIVE APPROVAL NO. 44.37
Re: The application of AMOCO PRODUCTION COMPANY to drill,
complete, and produce the Middle Ground Shoal 17595 Well
No. 23~in the MGS "G" Oil Pool in the Middle Ground Shoal
'Field.
Mr. Warren Nielsen
Supervi s or - in- charge
~noco Production Company
P. O. Box 100779
Anchorage, Alaska 99510
-Dear Mr. Nielsen:
The referenced application was received on January 13, 1984 and
stated that the drilling of the No. 23 well will recover
reserves from the west flank of the Ifiddle Ground Shoal Field.
The Alaska Oil and Gas Conservation Commission has studied the
evidence available and hereby authorizes the drilling,
completion, and producing of the referenced well pursuant to
Rule 6 of Conservation Order No. 44.
Yours very truly,
Harry W. Kugler
Commis s ioner
BY THE OFJDER OF THE COb~ISS!ON
be
~qO0. O0
~00.00
-3342.41
-344~.41
..
1358. 7'2P
1531.
1522. 34 S21WP
1518. ~I S~7WP
1106. 54 S88WP
1~6. 73 NSBWP
1540.07 S~iWP
1538. 08 S~WP
CHANQ~-
(W)ELLS
(M)ETHOD
(D)EPTHS OR INCREMENT
(O)UTPUT UNITS
(P)LOT
(S)TOP (DEFAULT)
RECEIVED
JAN 1~'1~84
AI~s~ Oil & Gas Cons. Commission
Anchorage
24
25
T
9
N
i
i
I
I
!
I
I
i
I
__/
i
I
I
I
I
I
I
I
I
I
I
I
!
!
I
I
-I
I
I
I
I
I
I
I
29
-9495
9
;
0 I
1000 ...................
2000 ..................
3000-
4-000 -
5000 ...............
6000 ...............
7000 ....................
8000-
9000-.
-1000
VERTICAL -SIDE- VIEW
FILE = 23NORM
V(ERTICA.L) S(ECTJO N)
155.55 D(EGREES,)
UNITS=FT
0 1000 -2000 5000 4000 5000 6000
STATE Of ALASKA -~, ':
ALAsKA~'AND GAS cONSERVATION C~lSSlOU
PERMIT TO DRILL
20 AAC 2!5.005
la. Type of work.
DRILL
REDRILL
DEEPEN
lb. Type of well ' EXPLORATORY []
DEVELOPMENT Gl L [~
DEVELOPMENT GAS [-I
SERVICE [] STRATIGRAPHIC []
SINGLE ZONE []
:
MULTIPLE ZONE []
2. Name of operator
Amoco. Production Company
3. Address
P. 0. Box 100779, 3.nchOrage, Alaska 99510
4. Location of weil at surface Leg 4, Slot 2, MGS Platform Baker ~
1986' FNL, 472 FHL Section 31. T9N. R12W. S.M.'
At top of proposed producing interva~ G-1 sand at-8230' subsea 2800' FNL
424' FWL. Section 31, T9,N, R12W, ~S.~,!; '
At total depth 3127 FNL, 988- FWL, -8o87 Subsea, Section 31, .
TgN, R12W, S;;M.
5. Elevation in feet (indicate KB, DF etc.} I 6. Lease designation and serial no.
79.4' KB I ADL 17595
12. Bond information (see 20 AAC 25.025) '
Type B1 anket Surety and/or number Surety - 874698
13. Distance and direction from nearest town 14. Distance to nearest property or lease line
20 miles NW of Kenai, AKm',es 2153 FSL of ADL 17595 feet
16. Proposed depth (MD & TVD) 17. Number of acres in lease
9600' MD, 8966'...:TVD . feet 5106
19. If deviated (see 20 AA(~ 25.050)': ' - 120. Anticipated pressures
KICK OFF POINT 1450 feet._] MAXIMUM HOL. E ANGLE 45 Gl (see 20 AAC 25.035 (c) (2~
- SiZE
Proposed Casing, Liner and Cem'~eenting Program
CASING AND LINER
SETTING DEPTH
9. Unit or lease name
Middle Ground Shoal Field.
10. Well number
23
1 1. Field and pool
i'Hiddle Ground Shoal Field
Lower Kenai Conglomerate
Amount $200,000
!5. Distance to nearest drilling or ¢ornoJeted
11 wenis 685' S 33N[u-'z ~o~)
8. Approximate spud date
01-18-84
753 psig@ 0; Surface
3785 psig@ 7000 ft, TD (TVD)
QUANTITY OF CEMENT
Hole I Casing
17.5 113. 375
I
12.25 19. 625
1
8.5 17
Weight
68#
61,54.5:. K-55
40,43.5 S-95
47.53.5 & N-80
29# N-80
Grade
ICoup,ingl Lengt-h
S-80 I Butt I
IButt I
IButt" I
IButt-' I 1250'
MD TOP TVD
3600' 0 I 0
I
I
8670' 0 , 0 8670 I 8309
I
I
8400 18120
MD BOTTOM TVD
3600 ~l 3560
I
I
9600 8966
(include stage data)
To surface, Class G
To cover 500' above
uppermost productive
To cover entire liner
22. Describe proposed program:
YE_F_ ~f/C~ Fo£ ~ /~
Amoco proposes to directionally drill Well No. 23 from Leg 4, Slot 2, Middle Ground
Shoal Platform Baker to a Lower Kenai Conglomerate G-1 target at 8230' SS, 2800' FNL,
425' FWL, Sec. 31, T9N, R12W, S.M. Total depth is estimated to be at 9600' MD, 8966'
TVD after adequate penetration of the G-5 zone. After log evaluations, zones of
interest will be perforated, and.the well placed on hydraulic lift. There are no
affected operators. A location plat and DOPE sketches are attached. NOTE: Casing
design safety factors of 1.125, 1.0 and 1.8 will be used for collapse, burs~n~
tensile strengths respectively Estimated maximum mud weight is 10.4 PPg'~[E~VE~
23. I hereby certify that the foregoing is true and correct to the best of my knowledge
The space below for CommisSion use
TITLE
Supervisor-in-Charge DATE
/ .... 7""""
Samples required
[]YES
Permit number
CONDITIONS OF APPROVAL
Mud Icg required I Directional Survey required APl number
EYES ,~O "-I ~-YES i-INO 50-- '~,~.,~- ~_~ .~(' f
Approval date
I SEF nnw~R LETTER FOR OTHER REQUIREMENTS
/ ....
January 18, 1984
,COMMISSl ONER DATE
by order of the Commission
Form 10-401
B
lone
_~one
Submit in triplicate
~-~___ ~ ~ ~
II
Li~tD
. .
.~'
~7~
'-t?
~RbOE
Ir'-
_5
. .
& T&
BTC-
- _-l-
.
Z~,..%"/ FWL
- ~2.3os. s.
!
Rrnl ~ =
/¢
= 121'10,'
/ I
3'0
LEGEND
31
OIL PRODUCER
WATER INJECTOR
PROPOSED LOCATION
OAS SUPPLY
R'ECEIVE.D.
,t~,N ~ ~ 1984'
Alaska 011 & Gas C~)ns bummtssior,
- ~
~ RI2~
· PI_!DOLE GROUND SHOAL
G-,1 STRUCTURE
C.l. · 500'
3O
.51
7 o.
31
· SEWL~G M'£.~.~C!~N , ALASKA
LEG :'"' ~
,,L. I LES NO ~
L&T 60~ 49' 45.73'' LA% 60049, 45.22"
LGraG 151°29' O0 95- LONG 151~ 29' 00.07"
Y : 2,498,059.8 Y = 2~498,014.48
X = 2~5, 255.O X = ~35~297. SO
FRC~ N.W caR. FROM N W. CaR.
J934' SOUTH B 1989' SOUTH &
54~' EAST 588' EAST
J. -
SCALE I"= I000'
LEG ;JO 3
LAT. 60° 4,9' 44.70"
LON3 ~51° 29' OI. 41"
Y : 2,497, 95.3.55
X : 235,250-EO
FROM N.W.
204I SOUTH
522 EAST
T9N .'51
T 8N
LEG NO 4
LAT. 50° 49' 45.25"
LC~'iG 15;° 29' 02.29"
Y= 2_,498:018.8E
X= 235, 187.73
F,fiO;,I N.W OCR.
1987 SOUTH ~
478' EAST
NOTE
The location of platform legs
was accomplished by using
U.S.C.~G.S. monuments Tad,
Boulder ~ and Cost, 19LM c~h-
trol points CET IO, and
Granite Point Native Hub~
and triangulation stations East
Foreland Light OfFset ~ and
Arness Dock.
32
CO0~ INLET CORRZCTIO,"I LIf'iE
CERTIFICATE OF SURVEYOR
I h=r3by
licensed
Alaska
sJrvey
that ,:.II
certify that I am properly registered and
to ¢'ra~.tice la,qd surveying in the State of
and that this plat represents a location
m:_'3d~, b), me or undr. r my supervisidn and
dimensions and other details are correct.
/
.
Dote
',.,i:~.~if:.::'F LOC, A'FIO:! SURVEY OF
!A FIRST O:--RD=R CONTROL POINT
"PA Fl" Oi"! PLA'FFOR;'.,I "B"
_ , -
SURVEYED FOR
· SU q'.,'EY E3 3Y
PAN A,*',,'I ER I C.q.,'-J PETROL. EU,":'I
PO _5.OX 779
F. M. L_I"DeEY,., ._ ~ ASSOC.
L,~.>~D SUR'/EYCRS ~'~ ClV!L
1415 ;7 i'JOPTHER:J LI,S'.-!TS BLVD.
~ ~' SHEET NO. OF'
,~.-¢~, Amoco Production Compa,~y r,~
ENGINEERING CHART ~P~N
.... ;' ..... :" : ' . ~ ; ; ~ ~ ~ ' I - ~, ~ "= i-~'' ; ~ ~ ~'-; ...... ~ ---~" .......,~ ~
_~ .~ . - . '- ,~ ' . . ..~ ·
.o
C
:~-.t*.. Amoco Production Compa,,y
ENGINEERING CHART
"-
................... ~ __~. . , ~ ....... ~_ ~ ........... ~ .-~-. ~.._ ~ .... ~._,..
.... , -~ . ;_ . . . - _~.
I ~"' 3DOD
· HYDRIL
· ANNUL,aR
~000
SHEET NO.
FILE
APPN
DATE
BY
~ ¢ I~OV.E
p,~ N I Fo
6,-/" z.,,~ )
Amoco Production Compaq,!
ENGINEERING CHART
SUBJECT
SHEET
FILE
OF
APPN
PLAN
'TOP-
VIEW FILE
UNITS- FT
= 2,SNORM
2000-
1500 -
1000 ..................... : .... : ..................................................................................................................
500 ................................................ ~ ......................... ' .... : ............................................................
' /
' ./'Z? ' 1~$'¢-' ~,~,Lx,
~.~~'~ ;. . - ..
- ~ : : -
_.. - .... ~;~__: ..................................... .~~ : ...............................................................................
: G~:~ : : - : : -
.................................... p ....... %;~ ........................... , ..................................................
/ "¢ -
-500 -
-1000-
-1500
000 -500 0 500 1000 1500 2000
WEST EAST
2500
RECEIVED
TRUE
VERTICAL
DEPTH
TRADITIONAL UNIT5
1954--01--10 11' ~7
/~¢o¢oS¢ I RADIUS OF CURVATURE METHOD Abs~
~0. l(23NORM ) TO(MgS7 - ) · .
NORTH EAST FROM NO. 1 FROM NO. 1
-SOUTH -WEST FT DIR. FT DIR.
JAN i 1984
Oil & Bas. Cons.
TO ( MOS7-SS
FROM NO. 1
F'r DIR.
0 0.00
200.00 -1986.00
400.00 -1986.00
0 600.00 -1986.00
800.00 -1986.00
1000.00 -1986.00
0 imoo. oo -ivo~.oo
1400.00 -1986.00
1600.00- -1986.77
~ 1800.00 -1989.82-
2000.00 -1995.31
2200.00 -2003.30
2600.00 -2022.75
2800.00 -2032.55
0 3000.00 -2042.34
3200.00 -2052.14
3400.00 -2061.93
~l~ 3800. O0 -~071. 7~
-3800.00 -2081.52
4000.00 -2091.31
0- 4200.00 -2101.11
4400.00 -2110.90
460u. 00
5000.00 -2140.28
5200.00 -2150.08
0., 5400.00 -2159.87
5600.00 -2174.38
5800.00 -2200.80
~i~: 6000.00 --2237.07
6200.00 -2278.64
6400.00 -2320.24
~ 6600.00 -2356.57
6800.00 -2383.33
O~.lt~D 7000.00 -~407. 42
7400.00
¢~ 7600.00 -2527.7,
0
~ 7800.00 -2586.84
~ 8000.00 -2658.25
'~8200.00 -2743. 53
~" --8400.00 -2842.40
8600.00 -2942.40
8800.00 -3042.41
~ 9000.00 -3142.41
9200.00 -3242.41
I
472.00
472.00
472.00
472.00
472.00
478.00
472.00
468.74
455.86
432.66
398.94
316.76
275.39
234.03
192.66
151.29
lO~
68.56
27.19
-14 18
-55 55
-96 92
--13~.~
-179.65
-221.02
-2~2.39
-302.18
-335.12
--356.76
--364.39
--356.89
--335.32
-302.45
-260.72
--~O~.i~
--137.07
-52.25
50.04
173 73
321 43
492 67
665 88
839 09
1012 31P
1185
9. ~ 541E D. 10 511E
15.20 S47E 5. 10 SI1E
21.25 S49E 5. 10 SIlE
27.34 S51E 15. 50 S!IW
39.35 S53E 37.26 S17W
54.75 S67E 59.88 S18W
86,26 S87E 17~.25 S20~
10~.65 S89E 257.43 S20M
130.71 S85E 342.37 S19~
152.99 S77E 418.9! S17M
180.40 S68E 485.45 S14W
263.29 SSOE 579.81S 7W
324.80 S~IE ~!3.54 S 4W
402.95 S34E ~39.43 S 1W
487. 10 S30E 681. 65 S 3E
586.59 S28E 685.65 S 6E
~9~.~9 5~E 7i0. 50 5 ~E
822. 13 S24E 737.2I SllE
952.37 S22E 768.64 S14E
1078.83 S21E 803.24 S17E
1.200.72 S21E 838.39 S19E
1325.39 S2IE 871.00 S21E
1617.74 S22E 935. 54 S25E
1771.35 S22E 9~5. 94 S26E
1~,~=. 79 S23E 9~7. 41 S~7~_ _
2061. 51 S23E 1025. 9~ S2?E
2142. 58 S24E .i04!. 25 S30E
~lO. 30 5~E iO~!. 7i 531E
2239.72 S25E 1030.39 S31E
2244.88 S25E 1009.3! S31E
2246.64 S25E 981.47 S31E
2246. 10 S24E 956. 56 S29E
2243. 59 S24E 925.30 S27E
2178. O1 S22E 82'7. 57 S21E
2!52.01 S20EP 7~4. 53 S17E
2090. 11 SiSEP ~73.~8 SIIE
2012. ~ SleEP 622.34 S 1E
1921.27 S!2EP 564. 51 S13W
Ib19.87 S ~EP 548.31 S3~W
I728. b3 S 3EP 572.73 SSOW
1651 '~ ~"P 685.
o~ S 82 S65W
1590.27 S 8WP 811.00 S75W
1546.67 S14WP ~=~
,~. 64 S83WP
14.86
20.52
26.19
36.70
49.03
62.85
73.14
80.67
115.63
136.71
163.97
202.03
251,43
316.71
483.30
583,74
820.93
951.75
1078.59
1200.70
1325.26
1617.01
1770.43
1921.66
2060.33
2141.07
2~0~.D6
2237.93
2243.00
2244.87
2244.55
2242.36
2197 75
2152 46
209~ 46
2015 49
1925 34
1825.93
1737.05
1662.!6
1603.23
1562.06
,
S43E
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S15WP
L. A. Darsow
District Superintendent
Amoco Production Company
Post Office Box 100779
Anchorage, Alaska 99510
907-272-8471
January 11, 1984
File: WEN-O62-WF
Mr. C. V. Chatterton, Chairman
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear Sir'
Application for Permit to Drill
Middle Ground Shoal 17595 Well No. 23
Platform Baker, Cook Inlet, Alaska
Attached in triplicate is a completed state of Alaska Form 10-401,
application for permit to drill for Middle Ground Shoal 17595 Well No.
23. We propose to directionally drill this well from Middle Ground
Shoal Platform Baker, utilizing Leg 4, Slot 2, to a target location at
the top of the Lower Kenai Conglomerate G-1 zone, -8230' subsea, 2,800'
FNL, 425' FWL, Section 31, T9N, R12W, Seward Meridian. This well is to
be completed as a producing well to recover reserves from the west flank
of the Middle Ground Shoal field.
Also attached is our company draft No. 243369 dated January 11, 1984 for
$100.00 to cover the filing fee. Two plats showing the location of the
well in relation to the Middle Ground Shoal structure and a Platform
Baker survey plat are attached, along with sketches of the BOP equipment
to be used.
Since this will be the sixth well completed in the Southwest quarter of
Section 31, we also wish to obtain an exception to the provisions of
Conservation Order No. 76 (dated September 12, 1969) of the Alaska Oil
and Gas Conservation Commission. The other wells completed in this
quarter section are:
MGS 17595 Well No 7 Producer
" " " No. 8RD- Injector
" " " No. 11 - Producer
" " " No. 15 - Producer
" " " No. 12S & 12L - Lease Line Injector
RECEIVED
Naska Oil & Gas Cons
AnChor~e
C. V. Chatterton
File: WEN-O62-WF
January 11, 1984
Page 2
Amoco also intends to omit the 20-inch casing string as done in the
previously completed Well No. 27. This well was successfully drilled to
the 13-3/8 inch casing point at 3,407' MD with no lost circulation or
high pressure water or hydrocarbons encountered. A 9.2 ppg mud was
used. Additionally, none of the wells drilled from Platform Baker have
encountered problems of this nature.
Drilling of the subject well is estimated to start on January 18,1 1984.
Please contact Kevin Smith in our Anchorage office if you have any
questions concerning this application.
Very truly yours,
W. E. Nielsen
Supervisor-in-Charge
Attachments
KLS/seh
Aiaska Oil & Gas Cons.
Anchora!~e
CHE,.K LIST FOR NEW WELL PERMITS
ITEM APPROVE DATE
(1) Fe.e [/?Z~-~- I-t~"~
/2 thru 8)
tW-tf
(10 and 11)
(4) C sg
'(12 thru 20)
(5) BOPE f//c77'/ I-Ib-
(21 thru 24)
(6) Add:
12.
13.
14.
15.
16.
17.
18.
19.
20.
Company ---~.~.,:
~k~ LeaSe & Well No.
.... YES NO
·
1. Is the permit fee attached ..........................................
2. Is well to be located in a defined pool .............................
3. Is well located proper distance from property line ..................
4. Is well located proper distance from other wells ....................
5. Is sufficient undedicated acreage available in this pool ............
deviated
·
6. Is well to be and is well bore plat included ............... ,~'/~f.
7. Is operator the only affected party ..................................
8. Can permit be approved before ten-day wait ..........................
9. Does operator have a bond in force ..................................
le.leeleeeee.
10. Is a conservation order needed ......................... .-'
11. Is administrative approval needed ·
,
Is conductor string provided .... ...................................
Is enough cement used to circulate on conductor and surface .........
Will cement tie in surface and intermediate or production strings ...
Will cement cover all known productive horizons ..................... ~-~
Will surface casing protect fresh water zones ......................:
Will all casing give adequate safety in collapse, tension and. burst..
Is this well to be kicked off from an existing~wellbore ..... .........
Is old wellbor.e abandonment procedure included on 10-403 ............
Is adequate well bore separation proposed ........................... /~//
21.
22.
23.
24.
Is a diverter system required ....................................... ~7'~
Are necessary diagrams of diverter and BOP equipment attached ....... ffz~
Does BOPE have sufficient pressure rating - Test to ~ f~ZP psig .. ~
Does the choke manifold comply w/API RP-53 (Feb.78) ..................
REMARKS
25.
Additional requirements .............................................
Additional Remarks: ~,~,,] J:.-.~.~ '~'". -J ~' ..'.:'
/
C)
,1
Geology: Engj~.eer ing:
WVA ~__ JKT~ HJH
JAL ~r~.--_.MTM
rev: 12/08/83
INITIAL GEO. UNIT ON/OFF
POOL CLASS STATUS AREA NO. SHORE
.,
Well Histo.ry 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 APPENDIXi
..
No 'special'effort has been made to chronologically
organize this category of information,
TAPE
V~RTF~CATTO~!
~ 010,~02 VERIWICATI~3N LTSTI~[G PAGE
REEL HEADER **
~VIC~ NAME :EDIT
TE :~4/05/~3
EL N4NE l ~69,33
NTINUATION ~
~NENTS :~Y.,,IBR~RY TAPE
** ~ECORD TYPE 137 **
FILF HE~DMR **
bE NAM~ .'EDIT ,00~
.TE ~
bE TYPE',
:~VTOUS F~h~ :
' I~FOR~ATI~M RECORDS
~ m ~Mncn PRODUCTION COMPANY
, ~ ~IDDE, E GROUND SHOAL
~G: ~2w
;WN:
;CT:
)U~: KENAT
'~Y: USa
I~NIT TYPE CATE SIZE CODE
mmmm ~mmm mm~ ~ ~m~m
000 000 024 065
000 000 012 065
000 000 019 06'5
000 000 004 065
000 000 002 065
000 000 002 065
000 000 006 065
000 000 006 065
000 000 004 065
m O10,H0~ VEDIFICATION LISTIMG PAGE 2
**********************************************************************************
SCHLUMBERGER *
ALASKA COMPUTING CENTER
***********************************************************************************
MP.aNY c A~OCO PDOD~JCTIO~ COmPaNY
LL c M~S ~7595
ELD = ~IDD5~ ~ROIJN'D SHOALS
lINTY = KENAI
ATF = .ALASK~
~# AT ACC =
IlID LOSS
TRIX SANDSTOME
DATE b3GGED: .],~ NAP ~4
KCJHRTNC,
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: 9.6 RMC T
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P OlO.HO,,.9. VEPIFiCAT,It]N I.,.IS?I'NG PA6E 3
DATE: LOGC, ED: 2'1, ~ 84
5" TO 9706'
=, 9.6~5" 8 9096' - BIT SIZE -- 8,.
NSITY = 9. L~/G R~ · 4,46 ~ 88 DF
SCOSITY =5 45
= 9.8 R~C -3.01 e 6, OF
UID LOSS =6 4. C3 RM AT BHT · ~.g43 ~ ~42 DF
TR~X SANDSTO~E
* DUAb INDUCTION ~PHERICAL(,,Y ~DCL~ED bOG (DI5) *
* ~7]1' TO 1554'..~E~GED ~ 9082'
* G~.D~L COVERS~T~E INTERVAL 9732' TO 902~' ONBY
* LITHO DENSITY COMPENSATED [,,0~ (bO~
~ 9725' T0,3549', ~ERGED e 9072
' 9725' TO 3549' ,~RGBD , 9072'
* ~ATU~At, Ga~a TOOL [~
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* POTA,VOL lS SCALED 0 TO ,10
~P OlO,HO~ VE.~IFICATIDN LTSTING PAGE 4
* PC1TA..MGT IS SCAt. ED 0 TO 10.0 ,
: DAT~ FORMAT RECLRD **
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?YPE SIZE .~PE C~D~ E,T,¥
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