Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout198-104THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Travis Smith
Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 05-17B
Permit to Drill Number: 198-104
Sundry Number: 320-091
Dear Mr. Smith:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www. o ogcc. al oska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
ssie L. Chmielowski
Commissioner
DATED this 12 day of March, 2020.
RBDMSZ--w MAR 1 6 2020
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
RECEIVED
CCD n C nnnn
tttlilown ❑
1. Type of Request: Abandon m • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ osr5/
1RJp/¢rJLoonte
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ {20a1pp p0ra gram ❑
V- v P❑
Plug for Redrill E] Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other
2. Operator Name: BP Exploration (Alaska), Inc
4. Current Well Class: .
Exploratory ❑ Development p
5. Permit to Drill Number: 198-104
3. Address: P.O. Box 196612 Anchorage, AK
99519-6612
Stratigraphic ❑ Service ❑
6. API Number: 50-029-20271-02-00
7, If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
B. Well Name and Number:
Will planned perforations require a spacing exception? Yes ❑ No 19
PBU 05-178
9. Property Designation (Lease Number):
10. Field/Pools:
ADL 028326 •
PRUDHOE BAY. PRUDHOE OIL
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft):
Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):
Plugs (MD): Junk (MD):
10270
8949 6874 6868
6874 6947
Casing
Length Size MD TVD
Burst Collapse
Conductor
73 20" 40-113 40-113
1530 520
Surface
2667 13-3/8" 40-2707 40-2707
4930 2670
Intermediate
7102 9-5/8" 38-7140 38-7123
6870 4760
Intermediate
7104 7" 1 36-7140 1 36-7123
1 72405410
Liner
1764 4-1/2" 6969-8733 6960-8689
8430 7500
Liner
3321 2-3/8" 6947-10268 6938-8649--F--
938-8649
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
8958-10240
8892 - 8949
4-1/2" 12.6# x 3-1/2" 9.2#
13Cf80
34-6990
Packers and SSSV Type: 4-1/2" Otis MHR Packer
Packers and SSSV MD (ft) and TVD (ft): 6931 /6923
No SSSV Installed
No SSSV Installed
12. Attachments: Proposal Summary Q Wellbore Schematic 0
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ® Service ❑
14. Estimated Date for Commencing Operations: April 1, 2020
•
15. Well Status after proposed work:
Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16. Verbal Approval: Date:
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned Q
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Smith, Travis T
be deviated from without priorwritten approval.
Contact Email: tmvis.smithl@bp.com
Authorized Name: Smith, Travis T
Contact Phone: +1 9075645412
Authorized Title: Engineer
Authorized Signature: Date: SIS
G
COMMISSION USE ONLY
Conditions of approval: No/tify mmission so that a representative may witness Sundry Number:
Plug Integrity ❑ Mechanical Integrity / a
IBOP Test Test Location Clearance
Other: 9> W"O+r' �
IBDMS
-f-' MAR 161020
Post Initial Injection MIT Req'd? Yes ❑ No
Spacing Exception Required? Yes ❑ No 13 Subsequent Form Required: {j �L-f Q✓
APPROVED BYTHE
Approved by: COMMISSIONER COMMISSION Date: ?0
2-J-2,0
,qv -r- q1q1;ii> ORIGINAL A&&P-cliti
Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval.
Submit Forth and
Attachments in Duplicate
05-17B P&A
Intervention Engineer
Travis Smith (907) 564-5412
Production Engineer
Finn Oestgaard (907) 564-5026
Expected start date:
April 1, 2020
Distinct Permeable Zones (DPZs):
DPZ1: 1,950'— 6,600' MD
DPZ2: Not Present
DPZ3: Top at 8,372' MD
History
05-17B was completed in 1978, and undergone sidetracking operations in 1992 and 1998. In 2002 it was
discovered to have leaking and collapsed tubing at approximately 2,343' MD. A plug was set to secure the
well, and reservoir engineering indicates the well has no future economic value. The following proposed work
would fully P&A the well.
Objective
Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and
install marker cap.
Procedural steps
DHD
1. Fill the SSSV control line with one control line volume of cement for isolation.
Wireline / Fullbore
1. Perform CMIT-TxIAxOA above tubing plug.
2. Drift the tubing from surface to 6,874' MD with a dummy 2.81" XX -plug.
3. If drift is successful, pull the tubing plug at 6,874' MD.
4. Perform CBL log of the 2-3/8" liner from 9,000' MD to the deployment sleeve at 6,947' MD. Send a
copy of the CBL log to AOGCC.
Note: If the CBL log finds a cement top high enough to provide an adequate barrier between DPZ1 and
DPZ3 on the backside of the 2-3/8" liner, the coiled tubing circulation squeeze later in this procedure will
be omitted. A revision to this proposal will be submitted if this is the case. Additionally, cement tops
and volumes in the following jobs may be adjusted depending on where the top of cement is found with
this CBL.
Fullbore
1. Perform injectivity tests in preparation for cement. Pump down the tubing to formation, injecting at
several pump rates. Record injection pressure at each rate. Following the injectivity test down the
tubing, pump in turn down the OA and IA, taking returns to formation through the TxIAxOA
communication. Pump down each annulus until fluid packed, and then shut-in.
2. Rig up to pump down the tubing to the perforations. Hold the IA and OA shut-in and fluid packed
throughout job to prevent annulus communication. Pump the following schedule to abandon the
perforations, leaving cement in the tubing with a designed TOC at approximately 8,500' MD.
• 10 bbls McOH
• 10 bbls freshwater spacer
• 10 bbls Class G cement per the design below
• 2 bbls freshwater spacer
• Foam spacer ball
• 84 bbls of diesel for displacement
Cement Type/weight:
Class G 15.8 ppg mixed per WSL. Field blend to
beequal to the lab DPQ +/- 0.1 Ppq
Slurry Temperature:
between 800 and 110°F
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive Strength:
2,000 psi in 48 hrs.
Thickening Time:
Minimum 5 hours
Wireline / Fullbore
1. Tag the TOC in the 2-3/8" liner. Notify AOGCC at least 24 -hours in advance for witness of tag and MIT.
2. Perform CMIT-TxIAxOA to 2,500 psi.
3. Perforate 2-3/8" liner immediately above TOC (exact depth will be determined by CBL above).
4. Set cement retainer in the liner in the center of the liner joint above the perforations.
5. Punch 3-1/2" tubing at approximately 6940' MD, just below the production packer.
Coiled Tubing
1. RIH with stinger and latch into cement retainer. While running in hole, open both the 7" x 9-5/8" OA and
the 4-1/2" x 7" IA in turn and circulate to tanks to ensure each is fluid packed to surface (communication
will be through known TxIAxOA leaks).
2. Pump through the cement retainer while taking returns from the 4-1/2" tubing to establish returns
between the two sets of circulation perforations. Pump the following to clean-up the annular space and
verify returns:
• 20 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
• 100 bbls brine
3. Circulate cement to the backside of the 2-3/8" liner with the following pump schedule. With 5 bbls of
cement through the retainer, un -sting from the retainer and lay in the rest of the cement in the tubing.
The TOC in the tubing should be at approximately the production packer at 6930' MD. Note: The
schedule shown here is assuming a TOC in behind the 2-3/8" liner at 7400' D. This pump schedule
will likely be revised based on the CBL.
• 2 bbls freshwater spacer
• 8 bbls Class G cement per the design below
• 2 bbls freshwater spacer
0 Coil volume of 9.8 ppg brine for displacement
Cement Type/weight:
Class G 15.8 ppg mixed per WSL. Field blend to
beequal to the lab ppg +/- 0.1 ppq
Slurry Temperature:
between 80°and 110 OF
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive Strength:
2,000 psi in 48 hrs.
Thickening Time:
Minimum 8 hours
Wirellne / Fullbore
1. Tag TOC in tubing.
2. Perforate at approximately 2,300' MD through 4-1/2" tubing and 7" casing.
3. Circulate to verify communication from the tubing to the OA (7" x 9-5/8"). Pump surfactant surface-to-
surface to clean up OA:
a 50 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
a 100 bbls 9.8 ppg brine
4. Close in the OA and begin circulation to the IA (4-1/2" x 7"). Pump surfactant surface-to-surface to
clean up OA:
a 30 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
80 bbls 9.8 ppg brine
Fullbore
1. Rig up to pump down the tubing and take returns from both the IA and the OA in turn. Begin pumping
taking returns from the OA with the IA shut-in. When cement is seen at the OA (cement should be to
surface with 78 bbls pumped), open the IA and shut-in the OA. After the displacement is pumped, shut-
in the IA and tubing. Designed TOC will be 1000' MD in the tubing:
a 5 bbls McOH
5 bbls freshwater spacer
a 150 bbls 15.8 ppg cement per design
a 2 bbls res water spacer
a Foam wiper ball
a 13 bbls 9.8 ppg brine
Cement Type/weight:
Class G 15.8 ppg mixed per WSL. Field blend to
beequal to lab ppg +/- 0.1 ppq
Slurry Temperature:
between 80°and 110 OF
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive Strength:
2,000 psi in 48 hrs.
Thickening Time:
Minimum 4 hours
Relay or E -Line
1. Tag TOC in tubing.
2. Perforate @ 750' MD through 4-1/2" tubing, 7" casing, and 9-5/8" casing.
Fullbore
1. Rig up to pump down the tubing and take returns from the OOA. Pump the following:
a 20 bbls hot diesel
8 bbls 9.8 ppg brine
Shut down for one hour to let diesel soak in OOA and loosen Arctic Pack
a 20 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
0 75 bbls 9.8 ppg brine
2. Once clean brine is consistently returned from the OOA indicating that all hydrocarbons have been
circulated out of the annuli, pump OOA and tubing cement plug as follows down tubing. Top of cement
will be at surface in both the OOA and the tubing.
• 5 bbls McOH
• 5 bbls freshwater spacer
• 75 bbls 15.8 ppg cement per design
Cement Type/weight:
Class G 15.8 ppg mixed per WSL. Field blend to
beequal to lab ppg +/- 0.1 ppg
Slurry Temperature:
between 80° and 110 OF
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive Strength:
2,000 psi in 48 hrs.
Thickening Time:
Minimum 4 hours
Special Projects
1. Excavate and cut-off all casings and wellhead 3' below original tundra level. Top job the 20" x 13-3/8"
annulus and all other annuli and tubing with cement as neded.
2. AOGCC witness cement tops in all annuli p►�}e o�o c u w e Ai- I Oe- A v` ca.) I C-KVI V[
3. Bead weld marker capon outermost casing string (20" Conductor) to read as follows:
BP Exploration Alaska, Inc.
05-17B
PTD # 198-104
API # 50-029-20271-02
p �' o 4-6 J o C U wt,e J IX- 4�ej ? L a 1-e t D L Ce-
05-17B SAFETY TBGB 4 1 CHROME LNR•"" 12" CHROME
700 @ 9059' AND 90° Q 9133'
2
• TBG, 1,2.64, 13-CWW 3007"
1bpr, D=3.958'
Minimum ID -1.00 @ 10237'
23/8" SEAL SUB O RING
R
DATE REV
PERFORATION SLIAMARY
ND
DEV
REF LOG: BWA ON 09719192
VLV
LATCH
ANGLE AT TOP PEW. 44 @ 8958'
DATE
Note: Refer to Production DB for historical pert data
SIZE
SPF
NTERVAL
Opn/Sgz
DATE
1-11!16"
4
8958- 8978
C
OM02+01
1-11/18"
4
9236-9744
C
08 11
1-11118"
4
9828-10240
C
OB121/98
Si
kq
ND
DEV
TYPE
VLV
LATCH
HnRr
DATE
1
3207
3207
1
F"
DMY
RK
0
iN20Y02
4994
4993
1
FM40
DMY
RK
0
1020/02
3
9404
0903
1
FMHD
DMV
RK
0
1020/02
4
8008
0084
10
FMq
DMV
RK
0
1020/02
kILOUTWIDOW 8733-8737"
PRUDHOE HAYNIT
WELL: M17B082290
PERMIT No:9901040
50029-20271-02102092
SEC 32, T11N, R15E 4571.79'FEL 03423.74FNL08/1803
ByENTS DATE REV BY COMMENTS
1970 kPLETDN092395 KSBlRH %%TTP SET 102202)
179 012220 JNOJMD AODEDO QI,REF,BFELEVBCON
0211002 RN/IPSAPINo:
WC
MHMAK
CMOfrrLCORRECTION
08227"5
TLN?JCION
BP ExpbmUm (Alaska)
PRIIDHOEBAYUNIT
WELL: Ob17B
PERMIT No: X5981040
APINo: 50-02&20771-02
SEC 32, T11N. RISE 4571.79' FEL 8 3423.74' FNL
DATE REV BY COMMENTS DATE I REV BY COMMENTS
1979 ORKi4AL COMPLETION 0823105 KSBNI.H XX TIP SET 1022.92
0927096 SIDETRACK (05-17a2 012220 JNL/JMD ADDED OKB, REF, BF ELEV & COW
9826-10,240 I
c
Io8/21'M
PRIIDHOEBAYUNIT
WELL: Ob17B
PERMIT No: X5981040
APINo: 50-02&20771-02
SEC 32, T11N. RISE 4571.79' FEL 8 3423.74' FNL
DATE REV BY COMMENTS DATE I REV BY COMMENTS
1979 ORKi4AL COMPLETION 0823105 KSBNI.H XX TIP SET 1022.92
0927096 SIDETRACK (05-17a2 012220 JNL/JMD ADDED OKB, REF, BF ELEV & COW
02/10102 RWTP CORRECTIONS
1020102 M GLV
08/18W3
CMO/RCFrL P PERF ANGLE
NGLE CORRECTION
SP Espbratbn (Abska)
0922105 TLKPJC KS CORRECTION
by
05-17B P&A
Intervention Engineer
Travis Smith (907) 564-5412
Production Engineer
Finn Oestgaard (907) 564-5026
Expected start date:
April 1, 2020
Distinct Permeable Zones (DPZs):
DPZ1: 1, 950' — 6,600' MD
DPZ2: Not Present
DPZ3: Top at 8,372' MD
History
05-17B was completed in 1978, and undergone sidetrac
discovered to have leaking and collapsed tubing at appn
well, and reservoir engineering indicates the well has no
would fully P&A the well. ---
operations in 1992 and 1998. In 2002 it was
ately 2,343' MD. A plug was set to secure the
'e economic value. The following proposed work
f'00 2w.�Oso
Objective
Place cement plugs in the wellbore. Excavate and c casings 3' below original tundra level and
install marker cap.
Procedural steps
DHD
1. Fill the SSSV control line with one contrqi1ine volume of cement for isolation.
Wireline / Fullbore
1. Perform CMIT-TxIAxOA above tubing lug.
2. Drift the tubing from surface to 6,874' MD with a dummy 2.81" XX -plug.
3. If drift is successful, pull the tubing p gat 6,874' MD.
4. Perform CBL log of the 2-3/8" liner f om 9,000' MD to the deployment sleeve at 6,947' MD.
Note: If the CBL log finds a cem
DPZ3 on the backside of the 2
be omitted. A revision to this pr(
and volumes in the following job
this CBL.
Fullbore
Perform injectivity tests in pr
several pump rates. Record
top high enough to provide an adequate barrier between DPZ1 and
" liner, the coiled tubing circulation squeeze later in this procedure will
)osal will be submitted if this is the case' Additionally, cement tops
may be adjusted depending on where the top of cement is found with
�- - m7
for cement. Pump down the tubing to formation, injecting at
pressure at each rate. Following the injectivity test down the
tubing, pump in turn down the OA and IA, taking returns to formation through the TxIAxOA
communication. Pump down each annulus until fluid packed, and then shut-in.
Rig up to pump down the tubing to the perforations. Hold the IA and OA shut-in and fluid packed
throughout job to prevent annulus communication. Pump the following schedule to abandon the
perforations, leaving cement in the tubing with a designed TOC at approximately 8, 0' MD.
• 10 bbls McOH
• 10 bbls freshwater spacer
• 10 bbls Class G cement per the design below e
• 2 bbls freshwater spacer Vr l
• Foam spacer ball Q
• 84 bbls of diesel for displacement
Cement Type/weight:
Class G 15.8 ppg mix3k per WSL. Field blend to
beequal to the lab p,6q +/- 0.1 ppg
Slurry Temperature:
between 80° and 1 0°F
Fluid Loss:
40-200cc (20-10 cc/30 min)
Compressive Strength:
2,000 psi in 48firs.
Thickening Time:
Minimum 5 h urs
Wireline / Fullbore
1. Tag the TOC in the 2-3/8" liner. tify AOG at least 24 -hours in advance for witness of tag and MIT.
2. Perform CM IT-TxIAxOA to 0 psi. Z.SC5 P >
3. Perforate 2-3/8" liner immediately above T C (exact depth will be determined by CBL above).
4. Set cement retainer in the liner in the cent T7
of the liner joint above the perforations.
5. Punch 3-1/2" tubing at approximately 69 ' MD, just below the production packer.
Coiled Tubing
1. RIH with stinger and latch into cen
the 4-1/2" x 7" IA in turn and circul;
will be through known TxIAxOA le-,
2. Pump through the cement retainer
between the two sets of circulation
verify returns: ,
• 20 bbls surfactant wash
• 100 bbls brine
3. Circulate cement to the back:
cement through the retainer, i
The TOC in the tubing should
schedule shown here is assui
will likely be revised based or
• 2 bbls freshwater sp
• 8 bbls Class G cern
• 2 bbls freshwater s c
• Coil volume of 9.8 Dc
)tainer. While running in hole, open both the 7" x 9-5/8" OA and
tanks to ensure each is fluid packed to surface (communication
taking returns from the 4-1/2" tubing to establish returns
rations. Pump the following to clean-up the annular space and
+ surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
7d of the 2-3/8" liner with the following pump schedule. With 5 bbls of
sting from the retainer and lay in the rest of the cement in the tubing.
e at approximately the production packer at 693.0'' MD. Note: The
ing a TOC in behind the 2-3/8" liner at 7400' Mug This pump schedule
the CBL.
per the design below 4- —
brine for displacement
Cement Type/weight:
Class G 15.8 ppg mixed per WSL. Field blend to
beequal to the lab ppg +/- 0.1 ppq
Slurry Temperature:
between 80° and 110°F
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive Strength:
2,000 psi in 48 hrs.
Thickening Time:
Minimum 8 hours
Wireline / Fullbore I
1. Perform MIT -T to 1,500 psi. Provide adequate notificati/umpsurfactarnt
fitness of MIT and tag.
2. Tag TOC in tubing.
3. Perforate at approximately 2,300' MD through 4-1/2" tubasing.
4. Circulate to verify communication from the tubing to the /8"). Pump surfactant surface-to-
surface to clean up OA:
• 50 bbls surfactant wash: freshwater + surfactant;F103 and 2 gal/mgal U067
• 100 bbls 9.8 ppg brine
5. Close in the OA and begin circulation to the IA (4-1/2" x urfactant surface-to-surface to
clean up OA:
• 30 bbls surfactant wash: freshwater + surfactant;F103 and 2 gal/mgal U067
• 80 bbls 9.8 ppg brine
Fullbore
1. Rig up to pump down the tubing and take returns
taking returns from the OA with the IA shut-in. W
surface with 78 bbls pumped), open the IA and sl -
in the IA and tubing. Designed TOC will be 1000'
• 5 bbls McOH
• 5 bbls freshwater spacer /
• 150 bbls 15.8 ppg cement per design
• 2 bbls freshwater spacer /
• Foam wiper ball
• 13 bbls 9.8 ppg brine
both the IA and the OA in turn. Begin pumping
cement is seen at the OA (cement should be to
in the OA. After the displacement is pumped, shut -
D in the tubing:
Cement Type/weight:
15.8 ppg mixed per WSL. Field blend to
l to lab
Slurry Temperature:
n 80° and 110°F
14200cc
Fluid Loss:
(20-100cc/30 min)
Compressive00
Strength:
0 psi in 48 hrs.
Thickening Time:
Minimum 4 hours
Relay or E -Line
1. Perform MIT -T to 1,500 psi. Pr ide adequate notification for AOGCC witness of MIT and tag.
2. Tag TOC in tubing.
3. Perforate @ 750' MD through -1/2" tubing, 7" casing, and 9-5/8" casing.
Fullbore
1. Rig up to pump down the tub" g and take returns from the OOA. Pump the following:
• 20 bbls hot diesel
• 8 bbls 9.8 ppg brine
• Shut down for one hour to let diesel soak in OOA and loosen Arctic Pack
• 20 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067
• 30 bbls 9.8 ppg brine
Once clean brine is consistently returned from the OOA indicating that all hydrocarbons have been
circulated out of the annuli, pump OOA and tubing cement plug as follows do tubing. Top of cement
will be at surface in both the OOA and the tubing.
• 5 bbls McOH
• 5 bbls freshwater spacer
• 30 bbls 15.8 ppg cement per design /% J
Cement Type/weight:
Class G 15.8 pg mixed per WSL. Field blend to
a ual to ab +/- 0.1 ppg
Slurry Temperature:
ECompressive
between ° and 110°F
M_
Fluid Loss:
40-200 (20-100cc/30 min)
Strength:
2,000 si in 48 hrs.
Thickening Time:
Mini um 4 hours
Special Projects
1. Excavate and cut-off all casings
annulus and all other annuli and
2. AOGCC witness cement tops in
3. Bead weld marker cap on outerr
BP Exploration Alaska, Inc.
05-17B
PTD # 198-104
API # 50-029-20271(n-02
1- [ _ M �a o)( o u
dd Wellhead 3' below original tundra level. Top job the 20" x 13-3/8"
Yng with cement asn ded.
annuli `2 k.,d 7o �(,,n„_.eJ b O _ •fes
;t casing string (20" Conductor) to read as follows:
TREE= GRAYGEN2
WELLHEAD= _
ACTUATOR=
GRAY
AXELSON
OKB. ELEV =
69•
REFELEV=
74'
BF. ELEV =
3626'
KOP=
6700'
McXA L=
97' 9186'
Datum MD =
8918'
Datum WO=
8800'SS
Current Stalrrs
I
ail"TBG, iz.s#. ,3-cR-10. 300r
.0152 bpf, 1)
Minimum ID = 1.00" @ 10237'
2-3/8" SEAL SUB O RING
SAFETY NOTE: '••3-12" 8 4-12" CHROME
TBG 8 4-12" CHROME LNR•••
70" @ 9058' AND 90" @ 8133'
ST NU
PERFORATION AMY
DEV TYPE
VLV
LATCH PORT
REF LOG: BHCA N
09/19/92
3207
1 FMiO
ANGLE AT TOP PERF: 44 @ 8958'
RK 0
Note: Refer to Production OB for historical pert data
WE
SPF
MERVAL
OprVSgz
I DATE
1-11/16"
4
8958-8978
C
04/02/01
1-11/16"
4
9236-9744
C
08/21/98
1-11/16"
4
9826-10240
C
08/21/98
SAFETY NOTE: '••3-12" 8 4-12" CHROME
TBG 8 4-12" CHROME LNR•••
70" @ 9058' AND 90" @ 8133'
ST NU
TVD
DEV TYPE
VLV
LATCH PORT
DATE
1 3207
3207
1 FMiO
DMY
RK 0
10/20/02
-12 4994
4993
1 FMiO
DMY
RK 0
10/20/02
3 6404
6403
1 FMRO
OM1'
RK 0
10/20/02
4 6666
6684
10 FMRO
DMV
RK 0
10/20/02
$$7$' ELMD Tr LOGGED ON 09/27!92
�
f
side 9-5/8':
0' MD
MLLOUr WDUOW8733'-8737'
DATE
REVBY COMMENTS I DATE
REV BY COMMENTS
,978
ORIGINAL COMPLEWN 0923/05
KSB/rLH XX TTP SET 1022/02
082298
SDETRACK 05-,7B 0122/20
JNUJMD ADDED OKB, REF, BF ELEV 8 COI
02/10/02
RMIV CORRECTIONS
1020/02
MHMAK GLV DO
08/18/03
CMO/1LP PERF ANGLE CORRECTION
0922105
RHIPJC KB CORRECTION
PRUDHOE BAY UNIT
WELL: 05-178
PERMIT140:9981040
API No: 50-029-20271-02
BP ExPion60n (Alaska)
1RFF= RRAYr] NO
WELLHEAD=
PERFORATION SIM�MA
ND
ELOKBELEV=
REF LOG: BHCA ON 09/1 /92
d74'
REF ELEV=__
ANGLE AT TOP PERF: 44 8958'
BF. ELEV =
_
36
SEE
6700A
k=
97° 9186'um
tKOP5
MD = _
8918'
m TVD-
8800'SS
120' COND, 94#
"0. In =19.124"
4.-11G 260 ..8R.80, 300T
052bD=3.0
TOC in 7" x 9-5/8":
4801' MD
Minimum ID =1.00" @ 10237'
2-3/8" SEAL SUB O RING
9.3#,
13 -CR -80,
05-17B
w
G
kef
SAFETY NOTES: "•3-12" 8 4-12" CHROME
TBG& 4-12" CHROME LNR"""
70° � 9059' AND 90° 091
9133'
DPZ1: 1,950' MD to 6,600' MD
L-1
ST
PERFORATION SIM�MA
ND
DEV
REF LOG: BHCA ON 09/1 /92
VLV
LATCH
ANGLE AT TOP PERF: 44 8958'
DATE
Note: Refer to Production DB for historical pert data
SEE
SPF
MH2VAL
Opn/Sg2
DATE
1-11/16"
4
8958 - 8978
C
04/02/01
1-11/16"
4
9236-9744
C
08/21/98
1-11116"
4
9826-10240
C
08/21/98
05-17B
w
G
kef
SAFETY NOTES: "•3-12" 8 4-12" CHROME
TBG& 4-12" CHROME LNR"""
70° � 9059' AND 90° 091
9133'
DPZ1: 1,950' MD to 6,600' MD
L-1
ST
MD
ND
DEV
TYPE
VLV
LATCH
POR!
DATE
I
3207
3207
1
R*0
DMY
RK
0
1020102
0922105
4994
4993
1
RwHo
uw
RK
0
10120/02
3
6404
8403
1
FM4D
DW
RK
0
10120/02
4
B688
6684
10
FM1D
DMV
RK
0
1020102
3 -
�NN 1E TOC outside 9-5/
DATE
REV BY COMMENTS DATEREV
BY COMMENTS
1978
K.
OR4AL COMPLETKIN 0923105
KSB/tLFI XX TTP SET(1022/02)
082298
SIDETRACK (05-17B 012220
JNL/JMD ADDED OKB, REF, BF ELEV 8 COI
02/10/02
RN/IP CORRECTIONS
1020102
MHMAK GLV C/0
08/18/03
CMOrrLP PERF ANGLE CORRECT DN
0922105
TLH/PJC KB CORRECTION
NP, D=
DPZ3: 8,372' MD to TD
PIPE)
1623]' PBTD - O RING SEAL SUB
PRUDHOE BAYUNrr
WELL: 05 -ITB
PERMIT No: ^1981040
APING: 50-029-20271-02
1N. R15E, 4571.79' FEL 8 342:
BP Exploradon (Alaska)
u
bp
)
)
...
,"'."1.
-......~ ~.~
~~- --:....-
~.~ ~.......
·'I'~~I\"
".
Terrie Hubble
Technical Assistant
GPB Drilling & Wells
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
---7 S...f ~1..April 2~ 2005
Alaska Oil & Gas Conservation Commission
333 West ih Avenue, Suite 100
Anchorage, Alaska 99501
· L../
~jlO
.\~
Reference:
Well Name Changes
Direct: (907) 564-4628
hubbletl@bp.com
~J.\NNEL NOV 0 f> 2005
To Whom It May Concern:
Please find attached a revised 10-407 for Prudhoe Bay Field, Well Number 15-17B,
Permit Number 198-104, API Number 50-029-20271-02. It was recently discovered
that the KB elevation was incorrectly reported as 61/ instead of 74'. I have updated
the Completion Report with this corrected information and am resubmitting it on the
latest Completion Report form.
Thank you very much for your assistance in this matter.
Sincerely,
~~~
Terrie Hubble
Distribution
Well Files
PDC
Performance Unit
IC{~-\DV(
) STATE OF ALASKA )
ALASKA Oil AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: III Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG
20AAC 25.105 20AAC 25.110
CASING, LINER AND CEMENTING RECORD
'CA$ING" , ..... ""'),1 :::""" S¡;r¡¡:II'IG,PEpr¡'t\IAt>,:,:~Em:INþ!'DEfltHrVQ"ßIciM;i'¡ .,!"",";'/,'.",':, "'1:,1 ,,',;i,' . " ",I,Afv19Üt\lT,','1
',,' ,"'. $IZ,E.<i , :' 'WT ~,eER"F'T;'I, '(~RiÄPE:;' ,.,1',1,08\,;:, BOTTOM r,,: ,I,': IO¡:;lIII:;:S;01'\QM ,','I..,~'S,lie': ".,~I:";I',·',,:¡I, ',i'li" C,EM~Nt'~G,'~~G,Q~plli,::I'¡I'::,', . "" RÚt[;ED:"'1
20" 94# H-40 Surface 115' Surface 115' 32" 284 sx Permafrost
13-3/8" 72# N-80 Surface 2702' Surface 2702' 17-1/2" 6100 sx Permafrost II
9-5/8" 47# N-80 / RS-95 Surface 7140' Surface 7123' 12-1/4" 1200 sx Class 'H', 300 sx Arcticset I
7" 26# L-80 Surface 7140' Surface 7123' 12-1/4" 450 sx Class 'G'
4-1/2" 12.6# 13Cr 6969' 8731' 6960' 8687' 6" 247 sx Class 'G'
2-3/8" 4.43# L-80 6940' 10263' 6932' 8949' 3" 82 sx LARC
23. Perforations open.to Production (MP + TVD of Top and 24):'; ,,!,:::,!¡:I';ill :,"i":;:""" '1",·,.,I';'I,tûè¡~G'RE:CO~D,r"
Bottom Interval, Size and Number; If none, state "none "):
1-11/16" Gun Diameter, 4 spf 1-11/16" Gun Diameter, 4 spf
MD TVD MD TVD
9236' - 9744' 8945' - 8940' 8958' - 8978' 8892' - 8906'
9826' - 10220' 8945' - 8949'
PRODUCTION TEST
Method of Operation (Flowing, Gas Lift, etc.):
Gas Lift
Oll-Bsl
o GINJ 0 WINJ 0 WDSPL No. of Completions
2. Operator Name:
BP Exploration (Alaska) Inc.
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612
4a. Location of Well (Governmental Section):
Surface:
1796' FNL, 13' FWL, SEC. 32, T11N, R15E, UM
Top of Productive Horizon:
2138' FNL, 224' FWL, SEC. 32, T11N, R15E, UM
Total Depth:
3425' FNL, 708' FWL, SEC. 32, T11 N, R15E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 697064 y- 5949647 Zone- ASP4
TPI: x- 697284 y- 5949310 Zone- ASP4
Total Depth: x- 697807 y- 5948036 Zone- ASP4
18. Directional Survey 0 Yes III No
21. Logs Run:
GR / CCL / CNL / Press / Temp & MWD
22.
26.
Date First Production:
August 26, 1998
Date of Test Hours Tested PRODUCTION FOR
8/28/98 4 TEST PERIOD -+
Flow Tubing Casing Pressure CALCULATED ........ Oll-Bsl
Press. 343 24-HoUR RATE""'" 330
SIZE DEPTH SET (MD)
4-1/2", 12.6#, 13Cr80 3007'
3-1/2",9.3#, 13Cr80 3007' - 6990'
25; ;.AÇ',6, FRÅ6,.ÙFi~,C$MEr"J1"SåµEÊzE;eTc:,
DEPTH INTERVAL (MO) AMOUNT & KIND OF MATERIAL USED
One Other
5. Date Comp., Susp., or Aband.
08/22/1998
6. Date Spudded
07/19/1998
7. Date T.D. Reached
08/18/1998
8. KB Elevation (ft):
74'
9. Plug Back Depth (MD+ TVD)
10237 + 8949
10. Total Depth (MD+TVD)
10270 + 8949
11. Depth where SSSV set
(Nipple) 2207' MD
19. Water depth, if offshore
N/A MSL
GAs-McF
W A TER-BSl
C:.EP· 6']
\,,1 ~. i~~
GAs-McF
1409
W A TER-Bsl
365
1b. Well Class:
III Development 0 Exploratory
o Stratigraphic 0 Service
12. Permit to Drill Number
198-104
13. API Number
50- 029-20271-02-00
14. Well Name and Number:
PBU 05-17B
15. Field / Pool(s):
Prudhoe Bay Field / Prudhoe Bay
Pool
Ft
Ft
16. Property Designation:
ADL 028326
17. Land Use Permit:
20. Thickness of Permafrost
1900' (Approx.)
PACKER SET (MD)
6930'
CHOKE SIZE
GAS-Oil RATIO
4270
Oil GRAVITY-API (CORR)
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary).
Submit core chips; if none, state "none".
None
Form 10-407 Revised 12/2003
RBDMS 8Ft 0 CT 1 (} 2005
CONTINUED ON REVERSE SIDE
.,.
r"28.
)
GEOLOGIC MARKERS
29.
)
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested,
and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
(From 05-17 A)
None
Sag River
8372'
8330'
Shublik
8410'
8368'
Sadlerochit
8474'
8432'
30. List of Attachments:
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed Tenie Hubble -1í7At.Ù>, ~
PBU 05-17B 198-104
Well Number
Title
Technical Assistant
Date
D9';z~ -O~~
Permit NO.1 Approval No.
INSTRUCTIONS
Prepared By Name/Number:
Drilling Engineer:
Terrie Hubble, 564-4628
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in
Alaska.
ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water
Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with
production from each pool completely segregated. Each segregated pool is a completion.
ITEM 4b: TPI (Top of Producing Interval).
ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
ITEM 20: True vertical thickness.
ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the
cementing tool.
ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in
item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval).
ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or
Other (explain).
ITEM 27: If no cores taken, indicate "None".
ITEM 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003
Submit Original Only
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X
Pull tubing _ Alter casing _ Repair well _ Other_
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
B P Exploration (Alaska), Inc. Development _X RKB 61 feet
3. Address Explorato~__ 7. Unit or Property name
P. O. Box 196612 Stratigraphic__
Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
1794' FNL, 5266' FEL, Sec. 32, T11 N, R15E, UM (asp's 697063, 5949647) 05-17B
At top of productive interval 9. Permit number / approval number
2178' FNL, 5026' FEL, Sec. 32, T11 N, R15E, UM (asp's 697315, 5949271) 198-104
At effective depth 10. APl number
50-029-20271-02
At total depth 11. Field / Pool
3424' FNL, 4572' FEL, Sec. 32, T11N, R15E, UM (asp's 697806, 5948036) Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured 10270 feet Plugs (measured) Tagged PBTD @ 10150' MD on 12/20/2000.
true vertical 8949 feet
Effective depth: measured 10150 feet Junk (measured)
true vertical 8950 feet
Casing Length Size Cemented Measured Depth True Vertical Depth
Conductor 1 15' 20" 284 Sx PF 1 15' 1 15'
Surface 2641' 13-3/8" 61oo Sx PF II 2702' 2702'
Production 7079' 9-5/8" 12oo Sx C~ass H & 3O0 Sx AS ~ 7140' 7123'
Liner 7079' 7" 45o sx G 7140' 7123'
Liner 1762' 4-1/2" 286 cubic ft Class G 8731' 8687'
Liner 3323' 2-3/8" 17.5 bbls of LARC 10263' 8949'
Perforation depth: measured 8958' - 8978'; 9236' - 9744'; 9826' - 10220'.
truevertica18891'-8905'; 8945'-8940'; 8945'-8949'.
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 130R-80 Tbg @ 3007' MD; 3-1/2", 9.3#, 136R-80 Tbg @ 6990' MD. APR 0 _6 2001
AJa~ka 0ii & ~as ~_;,:~ns.
~ackers & SSSV (type & measured depth) OTIS MHR PERMANENT PACKER @ 6930' MD.
~ ,3~I .... t..-
CAMCO BAL-O SV LANDING @ 2207' MD. ' ' -
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
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
Prior to well operation 102 3744 84 489
Subsequent to operation 513 7168 279 422
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed ?~ ~ ~~~-,%~ Title: DS 5 Surveillance Engineer Date April 5, 2001
Brian Carlson Prepared by Paul Rauf 564-5799
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
05-17B
DESCRIPTION OF WORK COMPLETED
PERFORATING OPERATIONS
Date
Event Summary
4/02/2001'
MIRU SWS Wireline Unit. PT'd equip to 3000 psi. Shut in well. RIH w/20' 1-9/16" PJ
Perforating gun 4 SPF, random orientation, standard phasing, & @ balanced press.
Performed tie-in w/GR. Positioned guns & shot the following add perforation:
8958' - 8978' MD (Zone lB) Reference Log: SWS MCNL 8/18/1998.
POOH w/guns - ASF (Note: it took 3 attempts to get guns to fire). RD Wireline Unit.
Placed well BOL.
Placed well BOL & obtained a well test.
Page 1
UG/ U~/ /'UU.L .L { ; O0 ll/%._Yk ~U I OU'~I' ~-U~
bp
April 5,2001
:t":O'°mm I '-!
F¢-o-mm I I
BP Exploration (Alazka) Inc.
9130 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, AK 99501
Fax 276-7542
Dear Commissioners:
Re: Pmdhoe-EOA, Pt. Mac, & Lisburne Well Work,
This listing is provided as required under the terms of Conservation Order No. 341C (Rule 14) &
Order No. 342. This is a list of well work tentatively scheduled for April 2 - 9, 2001:
Well
02-19
02-21
'O5~17B
06-21A
07-08A
11-22A
15-43
16-05Ai
18-04A
Work Planned-
ADD PERFORATION
ADD PERFORATION
ADD PERFORATION
CTE PERFORATION
CT REMOVE 2-3/8" GL COIL
ADD PERFORATION
SET crop w/CT
CT REPERFORATION / ACID STIMULATION
CT REMOVE 2-3/8" GL CO1L
18-13A CT SET CIBP FOR GSO
18-18A SET CIBP W/CT
Starting next week, I will be including WOA, Milne Pt, & Endicott wellwork. If additional data
or scheduling information is needed, please call me at 564-5799 or B-mail me at raufpc@bp.eom.
Sincerely,
Paul C. Rauf
Technical Assistant, BPXA
Alaska Drilling & Wells
' ' STATE OF ALASKA '~ -'
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operations shutdown_ Stimulate _X(Microbe) Plugging_ Perforate_
Pull tubing _ Alter casing _ Repair well _ Other_
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
BP Exploration (Alaska), Inc. Development~X RKB 61 feet
3. Address ExploratoW~ 7. Unit or Property name
P. O. Box 196612 Stratigraphic_
Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
1794' FNL, 5266' FEL, Sec. 32, T11N, R15E, UM 05-17B
At top of productive interval 9. Permit number / approval number
2178' FNL, 5026' FEL, Sec. 32, T11 N, R15E, UM 98-104
At effective depth 10. APl number
50-029-20271-02
At total depth 11. Field / Pool
3424' FNL, 4572' FEL, Sec. 32, T11 N, R15E, UM Prudhoe Bay Oil Pool
12. Present well condition summer
Total depth: measured 10270 feet Plugs (measured) Tagged PBTD @ 10150' MD (12/20/2000)
true vertical 8949 feet
Effective depth: measured 10150 feet Junk (measured)
true vertical 8950 feet
Casing Length Size Cemented Measured Depth True vertical Depth
Conductor 115' 20" 284 Sx PF 1 15' 115'
Surface 2641' 13-3/8" 6100 Sx PF II 2702' 2702'
Production 7079' 9-5/8" 12oo sx C~ass H & 3OO Sx AS ~ 7140' 7123'
Liner 7079' 7" 45o sx G 7140' '; 7123'
Liner 1762' 4-1/2" 286 cubic ft Class G 8731' 8687'
Liner 3323' 2-3/8" 17.5 bbls of LARC 10263' 8949'
Perforation depth: measured 9236' - 9744'; 9826' - 10220'.
true vertical 8945' - 8940'; 8945' - 8949'. V~,~ ¢~
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 3007' MD; 3-1/2", 9.3#, 130R-80 Tbg @ 6990' MD. ~'¢4/~) 0 1
4/aska oi/ ,~ 2551
~ackers & SSSV (type & measured depth) 7" x 4-1/2" OTIS MHR PERMANENT PACKER @ 6931' MD. ~c35 COl'is.
4-1/2" CAMCO BAL-O SV LANDING @ 2208' MD. AnChOred C°rnm/ss/on
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Iniection Data
OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 65 78 60 - 352
Subsequent to operation 116 5905 0 415
15. Attachments 16. Status of well classification as:
.:
Copies of Logs and Surveys run __
Daily Report of Well Operations ~X Oil __X Gas __ Suspended __ Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed '~~~---,~ ~--- .~~ Title DS 5 Surveillance Engineer Date 3/1/2001
Brian Carlson ' Prepared by Paul Rauf 564-5799
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
05-17B "-
DESCRIPTION OF WORK COMPLETED
MICROBE STIMULATION TREATMENT
Date
Event Summary
12/18/2000:
12/19/2000 -
1 2/21/2000:
RIH & drifted to 9060' SLM (HAW). TIFL passed.
Performed a Microbe Stimulation Treatment as follows: MIRU CTU. PT'd BOP. RIH w/
slimhole stinger w/nozzle to 10044' CTM - unable to work CT further. PUH to liner top &
loaded well w/2% KCL Water. Performed injectivity test - 1.9 bpm @ 900 psi WHP. RBIH
to 10150' & reciprocated a Microbe Fluid Treatment across the open perforation intervals
located @:
9236'- 9744' MD (Zone 1)
9826'- 10220' MD (Zone 1)
Jetted a total of 842 bbls of Microbe / 2% KCL Solution across perfs while maintaining 1400
psi WHP. POOH w/CT. FP'd well. Left top of Microbe mix @ -6950' CTM. RD CTU. Left
well shut in for minimum of 14 days for microbes to incubate.
Placed well BOL & obtained a well test.
MAR 0 Z. ?001
Alaska Off & Gas Cons. Commission
Anchorage
Well Compliance Report
File on Left side of folder
198-104-0
MD 10270 TVD 08949
Microfilm Roll ! -
PRUDHOE BAY UNIT 05-17B 50- 029-20271-02 BP EXPLORATION (ALASK
. A \ U~T~'~
Completion Date: /98 Completed Status: 1-OIL Current:
Roll 2 /
--
Name Interval
D 9119 ~ BH GR
L GR-MD /~,4~AL 8743-10270
Sent Received T/C/D
OH 3/22/99 3/24/99
OH 3/22/99 3/24/99
L GR-TVD ~AL 8596-8887.61
L MCNL ~ 6764-10201
R SRVY LSTNG ~700-10270.
T 8986 ~ SCHLUM MCNL
Daily Well Ops~/~-~_~_ - - ~-/p) ~/c?0°
Was the well cored? yes (~..
OH 3/22/99 3/24/99
CH 2 2/16/99 2/18/99 T ~ ~
OH 9/3/98 9/3/98
CH 2/16/99 2/18/99
Are Dry Ditch Samples Required? yes ~ ~nd Received? ~
Analysis Description R~23_v. ad.~-ye~-ff6 Sam~~'
Comments:
Tuesday, August 01,2000
Page 1 of 1
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Stimulate _X Plugging _ Perforate _
Pull tubing _ Alter casing _ Repair well _ Other_
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
ARCO Alaska, Inc. Development~X RKB 61 feet
3. Address Exploratory__ 7. Unit or Property name
P. O. Box 100360 Stratigraphic__
Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
1794' FNL, 5266' FEL, Sec. 32, T11N, R15E, UM 05-17B
At top of productive interval 9. Permit number / approval number
2178' FNL, 5026' FEL, Sec. 32, T11N, R15E, UM 98-104
At effective depth 10. APl number
3402' FNL, 4597' FEL, Sec. 32, T11 N, R15E, UM 50-029-20271-02
At total depth 11. Field / Pool
3424' FNL, 4572' FEL, Sec. 32, T11N, R15E, UM Prudhoe Bay Oil Pool
12. Present well condition summar
Total depth: measured 10270 feet Plugs (measured) Tagged PBTD @ 10234' MD (12/13/1998)
true vertical 8949 feet
Effective depth: measured 10234 feet Junk (measured)
true vertical 8949 feet
Casing Length Size Cemented Measured Depth True vertical Depth
Conductor 115' 20" 284 Sx PF 115' 115'
Surface 2641' 13-3/8" 61oo sx PF II 2702' 2702'
Production 7079' 9-5/8" 12oo Sx Class H & 3OO Sx AS I 7140' 7123'
Liner 7079' 7" 45o Sx G 7140' 7123'
Liner 1762' 4-1/2" 286 cubic fl[ Class G 8731' 8687'
Liner 3323' 2-3/8" 17.5 bbls of I_ARC 10263' 8949'
Perforation depth: measured 9236' - 9744'; 9826' - 10220'.
true vertica18945' - 8940'; 8945'-8949'. O~IGINA L ~-~ ~*~?,~i~ ~.~ ;~ ~:~i_~
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR-80 Tbg @ 3007' MD; 3-1/2", 9.3¢, 13CR-80 Tbg @ 6990' MD.
Packers & SSSV (type & measured depth) 7" x 4-1/2" OTIS MHR PERMANENT PACKER @ 6931' MD.
4-1/2" CAMCO BAL-O SV LANDING @ 2208' MD. ~"-;,=-~J(~. UJ~ ~¢',. (i~S U0~S, ¢,)0~'~Pf;(~i~;¢;¢;·
13. Stimulation or cement squeeze summary /A,qCi101'~¢jL:
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation (shut-in) -
Subsequent to operation (shut-in) -
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service
17. I hereby..¢ertify that the foregoing is true and correct to the best of my knowledge.
Sign% ~t~~'''-'~ ~~/~' "~'f' Title Arco Engineering Supervisor Date [~ ~v'[/~",/r'~f.~
~_--./Ci~ Ob¢~ C '"~-I PreparedbyPaulRauf263-4990
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
05-17B
DESCRIPTION OF WORK COMPLETED
CT MUD ACID STIMULATION
Date
Event Summary
11/11/1998 -
11/12/1998:
12/13/1998:
Performed a CT Mud Acid Stimulation to initiate production as follows: MIRU CTU. PT'd
equip to 4000 psi. RIH w BHA & milled Cement stringers / performed FCO to PBTD @
10225' MD. POOH. RIH w/CT to BTM & reciprocated a treatment across the open
perforations located @:
9236'- 9744' MD (Zone lB)
9826' - 10220' MD (Zone lB)
Pumped:
(a) 100 bbls of 2% NH4CL w/50 Ib/Mgal Citric Acid @ 1 bpm, followed by
(b) 55 bbls of 75% Diesel, 25% Xylene @ 1 bpm, followed by
(c) 150 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 1.5 bpm, followed by
(d) 150 bbls of 9% HCL - 1% HF, & 3% Acetic Acid @ 1.6 bpm, followed by
(e) 75 bbls of 12% HCL w/10% Xylene, & 3% Acetic Acid @ 1.6 bpm, followed by
(f) 170 bbls of 2% NH4CL w/50 Ib/Mgal Citric Acid, & 5% Mutual Solvent @ 1.1 bpm, followed by
(g) 30 bbls of 60/40 Methanol - Water @ 1 bpm, followed by
(h) shutdown.
POOH w/CT. RD.
MIRU CTU. PT' equip. RIH & tagged PBTD @ 10234' MD. Pumped 270 bbls of Hot Oil f/
700' to TD. Loaded well w/90 bbls of Hot Diesel. Made 4 passes jetting 50/50 Diesel/Xylene
into perfs. POOH. Left well for soak period. RD.
Currently the well is shut-in & future wellwork options are being evaluated.
State of Alaska
AOGCC, Lori Taylor
3001 Porcupine St.
Anchorage, AK 99501
Well Reference Data:
Well No: 05-17B
Field:
Count¥:
State:
Prudhoe Bay Unit API No:
North Slope
Alaska
03/22/99
5002 92 02 7102
BHI Job#: 99489
Enclosed is the following data as lasted below:
Log Type Bluelines
Navigamma
USMPR
m~R/MD'./MDP
TOTALS:
Log Type
Navigamma
USMPR
DPR/MDL/MDP
Bluelines
2" + 5" Measured Depth Logs
Folded Sepias Rolled Sepias
1
2" + 5" True Vertical Depth Logs
Folded Sepias Rolled Sepias
1
Mylar Film
LAS Disks :
Survey Listing ASCII Disks :
LIS Tape Image File Disks :
LIS Verification Report & Listings :
Depth Shift Monitor Plot :
Upon Receipt, Please sign and fax to: Baker Hughes INTEQ
Fax#: (907) 267-6621
AttnR~~land
Cons.
2/16/99
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
Al'tN: Sherrie
NO. 12332
Compan~ Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Prudhoe Bay
Floppy LIS
Well Job # Log Description Date BL Sepia Disk Tape
D.S. 5-10B -~"~ct ~:) 98425 RST 980528 I 1 1
D.S. 5-12 ~:,c~/._j 99046 RST 981216 1 1 1
D.S. 5-17B -~, ~'c1~,~ 99062 MCNL {PDC) 980818 ] 1 ]
D.S. 11-38A '~c~':~ 99048 MCNL BORAX 990105 1 1
D.S. 18-14A ~[~[ ~ 99051 RST-SIGMA 980630 1 ] I
SIGN DATE: I' ~;~£~.~ 'l ~ i'~(:,)
,Ala~ 0il & (~as Cons. C~'~i~i~'~
Please sign and return ohe._c, bpy of this transmittal to Sherrie at the above address or fax to (907) 562-65~1.~~ you.
I STATE OF ALASKA ..... ,
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1 Status of Well Classification of Service Well
Oil_X Gas__ Suspended_ Abandoned_ Service_
2 Name of Operator 7 Permit Number
ARCO Alaska, Inc. 98-104
3 Address 8 APl Number
P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20271-02
4 Location of well at surface '- ..',,.i.~.. :: :i i-: !~: ~ .,~.~,,.,~.~-,,~- 9 Unit or Lease Name
1796'SNL, 13'EWL, Sec32, T11N, R15E, UM "~..'.~: s ~ -.. .~,~ ! PRUDHOE BAY UNIT
At Top Producing interval
At Total Depth ~i_ _~2_~__,-' . . 11 Field and Pool
3426' FNL, 707' FWL, Sec 32, T11 N, R15E, UM. ' ..... PRUDHOE BAY FIELD
5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No.
61' RKB ADL 28326 PRUDHOE BAY OIL POOL
12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions
7/19/98: 8/18/98 8/22/98 N/A 1
17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost
10270' MD / 8949' TVD 10237' MD / 8949' TVD YES_X NO__ 2207' MD 1900' (approx)
22 Type Electric or Other Logs Run
GR/CCL/CNL/PressFFemp & MWD.
23 CASING, LINER AND CEMENTING RECORD
SETTING DEPTH
CASING SIZE WT. PER FT. GRADE TOP BOll'OM HOLE SIZE CEMENTING RECORD AMT PULLED
20" 94# H-40 Surl'ace 115' 32" 284 Sx PF
13-3/8" 72# N-80 Surface 2702' 17-1/2" 6100 Sx PF II
9-5/8" 47# N-80/RS-95 Surl'ace 7140' 12-1/4" 1200 Sx Class H & 300 Sx AS I
7" 26# L-80 Surface 7140' 12-1/4" 450 Sx Class G
4-1/2" 12.6# 13CF 6969' 8731' 6" 286 ft3 Class G
2-3/8" 4.43# L-80 6940' 10263' 3" 17.5 bbls 15.6 ppg LARC
24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD
interval, size and number) SIZE DEPTH SET MD PACKER MD
4-1/2" Tbg 3007' 6930'
9236' - 9744' MD; 8945' - 8940' TVD; @ 4 spf. i3-1/2" Tbg 6990'
9826' - 10220' MD; 8945' - 8949' TVD; @ 4 spf.
26 ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL MD AMT & KIND MATERIAL USED
~, PRODUCTION TEST0RiG NAL
Date First Production Method of Operation (Flowing, gas lift, etc.)
8/26/98 gas lift
Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE I GOR
8/28/98 4.0 TEST PERIOD__I 4270
Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr)
343 - 24 HOUR RATE _X 330 1409 365
28 CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips.
E EiVE
* This 10-407 is submitted as directed per the 10-401 form approved 7102198 (Permit # 98-104).
_~,laSKa 0il & Gas Cons.
Anchorage
Form 10-407 Submit in duplicate
Rev, 7-1-80 CONTINUED ON REVERSE SIDE
GEOLOGIC MARK[:RS FORMATION TESTS
NAME Include interval tested, pressure data, and fluids recovered and gravity,
MI:AS DEPTH TRUI: VER'D DEPTH GOR, and time of each phase.
Sag River 8372' 8381'
Shublik 8410' 8368'
Top Sadlerochit 8474' 8432'
(other pics)
3,1 LIST OF ATTACHMENTS
Summary of 5-17B CT Sidetrack Drilling Operations + Survey.
321 hereby cedify that the foregoing is true and correct to the best of my knowledge
S,gned ~./[~- '~' ~ Engineering Su~aervisor Date ~:~ '" ~ ] ~'~ ~'
Erin Oba
INSTRUCTIONS
Prepared by Paul Rauf 263-4990
General: This form is designed for submitting a complete and correct well completion report and Icg on
all types of lands and leases.
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.).
RECEIVED
Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing ~:; ~ ? ~ ~ '~998
and the location of the cementing tool. &taska 0it & 6as Cons. C0mmissi0.~
Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Anchorage
Gas Injection, Shut-In, Other-explain.
Item 28: If no cores taken, indicate "none".
Form 10-407 Rev. 7-1-80
-- ~ 5-17B
DESCRIPTION OF WORK COMPLETED
COILED TUBING SIDETRACK DRILLING OPERATIONS
7/19~98:
MIRU CTU. PT equip to 3500 psi. PT'd cement plug - passed. RIH w/BHA milled out XN nipple @ 6966' MD.
Tagged whipstock @ 8743' MD. Milled window f/8743' to 8749.9' w/freq motor stalls. POOH. Tested BOPE.
7/20/98:
RIH w/2.8" formation mill & tagged whipstock. Drilled ahead to 8754' MD. BHA became stuck in window while
POOH. Pumped Crude. Unable to free up BHA. Disconnected f/BHA & POOH w/CT. RIH w/fishing BHA &
tagged fish @ 8734'. Attempted unsuccessfully to fish BHA w/jars. Unlatched f/fish & POOH.
7/21/98:
RIH & latched fish. Successfully fished half of BHA from the hole w/jars & accelerators. Fish broke @ the
motor output shaft. Top of fish located @ 8747'. RD.
7/22/98 - 7/23/98:
MIRU CTU. PT equip. RIH w/fishing BHA. Attempted 4 times to fish milling assembly from the hole - all
attempts were unsuccessful. POOH. Freeze protected well. RD.
7/28/98 - 7129198:
MIRU CTU. RIH. Mill over output shaft (fish) @ 8753' w/burn over shoe. POOH. Went over top of fish about
4'. RIH & attempted to pull fish out of hole. No success. POOH. FP well w/Crude. RD CTU. RU SLU. RIH
w/2.5" LIB & 2.75" Cent. Obtained good picture of .85" circle of fish. RD.
7/30/98:
MIRU Wireline unit. RIH & planted 2.7" overshot w/1.25" grab on fish. Baited w/3-1/2" G fishing neck w/
extension. Bait & overshot was 41" in length. CCH. RD.
8/02/98:
MIRU CTU. PT equip to 4000 psi. RIH w/fishing assembly & tagged fish @ 8727'. Worked fish w/jars tripping
18 times & pulled free. POOH. Bait & overshot pulled off fish (pulled guts out of grapple). Fish still in hole.
8103198:
MIRU SLU. RIH & set 2-5/8" Whipstock. Top @ 8703' & bottom @ 8710' ELM. POOH. RD.
8104198:
MIRU CTU. RIH w/BHA & tagged top of whipstock @ 8749 CTM. Believed whipstock fell down hole. Milled to
8752.5 MD. Pumped Biozan sweep & POOH.
8/05/98:
RIH and milled f/8733' to 8743' MD. Pumped Biozan sweep. POOH. RD.
8/08~98 - 8/09/98:
MIRU CTU#4. Tested BOPE.
8/10/98:
RIH w/BHA & tagged whipstock @ 8735'. POOH. RIH w/BHA & set down @ 8733'. Milled window to 8736.5'.
Reamed & backreamed. POOH. Discovered motor broke off leaving fish in hole.
8/11/98:
RU WLU. RIH & successfully retrieved fish from wellbore w/overshoot. RD WLU. RIH w/BHA & dressed
window area. POOH. RIH w/bi-centered bit.
Page 1
.... 5-17B ......
DESCRIPTION OF WORK COMPLETED
COILED TUBING SIDETRACK DRILLING OPERATIONS
8/12/98:
Displaced well to FIo Pro. Performed LOT to EMW of 9.1 ppg. Drilled build section to 8900' MD. POOH.
8/13198:
RIH w/bi-centered bit. Drilled f/8896' to 8924'. POOH. RIH & drilled to 8981'. POOH. RIH & drilled to 9000'.
8/14/98:
Drilled ahead f/8990' to 9085' w/short trip to window. Ran MAD pass. POOH. RIH w/BHA & logged from
8600' to 9094' MD. Re-tied in depths & corrected top of window to 8731'. POOH.
8/15/98:
RIH w/bi-centered bit. Drilled to 9600' w/periodic short trips to window.
8/16/98:
Drilled to 9645'. PUH & displaced open hole to new FIo Pro. RBIH to BTM & drilled ahead to 9720'. Performed
extended step rate test. POOH w/BHA. Conducted BOPE test. RIH w/BHA.
8/17/98:
Drilled to 9826' MD. Shod trip to window to ream/backream interval from 8900' to 9250'. Added KCL to mud to
increase salinity to'stabilize shalely intervals. Drilled to 10208'.
8/18/98:
Drilled to TD @ 10270' MD. PUH to window. RBIH pumping Hi Vis FIo Pro sweep. POOH w/BHA. MU liner.
8/19~98:
RIH w/2-3/8" liner assembly. Landed liner. Cemented liner in place w/17.5 bbls of 15.6 ppg LARC. Unstung
from flapper valve & cleaned out contaminated cement w/Biozan to 10223'. POOH. RIH w/logging tools.
8/20/98:
Tagged PBTD @ 10214' MD. Ran memory CNL-GR-CCL-Pres-Temp logs f/10214' to 6782'. POOH w/tools.
Logs show PBTD @ 10190'. RIH w/BHA & milled cement to 10237'. Circulated Biozan to cleanout liner.
8/21/98:
RBIH to BTM & laid in new FIo Pro. POOH w/BHA. RIH w/perf guns & tagged PBTD located @ 10237'. Shot
902' of initial perforations located @:
9236'- 9744'MD (Z1B)
9826'- 10220' MD (Z1B)
Used 1-11/16" carriers & shot all perfs @ 4 SPF, overbalanced pressure, 0 degree phasing, & random
orientation. POOH w/guns. Noted all guns fired.
8/22/98:
FP well. RDMOL.
Placed well on initial production & obtained a valid well test.
Page 2
8100-
82oo-
8300
Q.. 8400
0 8500
-4---
(D 8600
8700
I
V 8aoo
89OO
9OOO
Slot · 5-1 7
1
Locotion · North Slope, Alosko
ARCO Alaska, Inc.
Structure · D.S. 5
Field · Prudhoe Boy
Tie on - 6.61 Inc, 8626.00 Md, 8521.73 Tvd, 4-10,69 Vs
Kick eft Point
17bhs
4
5-.~7ihs
East (feet) ->
1 O0 0 1 O0 200 300 400 500 600 700 800 900
I I I~ I I t I I I I I I I I I I
~Tie on - 8521.73 Tvd, 555.47 $, 222.71
oint
5-17bhs ~ ' I
'5-17ohs
5-17ohs
T.D. & End of Drop/Turn - 86.72 Inc, 10215.32 Md, 8905.00 Tvd, 1787.56 Vs
5-171hs
I I I I i -- I" I I I I I i I I f I I----'1' I I I [---r' t '1 I I I I I I I I I I I I I
300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1'100 1800 1900 2000 2100 2200
Vertical Section (feet) ->
Azimuth 159.68 with reference 0.00 N, 0.00 E from 5.-17
200
500
40O
500
6OQ
70O
8OO
9OO 0
000
1100
v
~200
1300
1400
t500
1600
1700
800
90O
ARCO Alaska, Inc.
D.S. 5
5-17B
5-17
Prudhoe Bay
North Slope, Alaska
SURVEY LISTING
by
Baker Hughes INTEQ
Your ref : 5-17B
Our ref : svy214
License :API 500292027102
Date printed : 31-Aug-98
Date created : 28-Aug-98
Last revised : 31-Aug-98
Field is centred on 708179.340,5930615.440,999.00000,N
Structure is centred on 696997.000~5951440.940,999.00000,N
Slot location is n70 15 59.800,w148 24 23.213
Slot Grid coordinates are N 5949646.600, E 697062.800
Slot local coordinates are 1795.55 S 18.81E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ARCO Alaska, Inc. SURVEY LISTING Page 1
D.S. 5,5-17B Your ref : 5-17B
Prudhoe Bay,North Slope, Alaska Last revised : 31-Aug-98
Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S
Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/lOOft Sect Easting Northing
8700.00 6.68 140.86 8595.23 362.09S 228.14E 0.12 418.78 697300.33 5949290.62
8721.77 6.70 141.01 8616.85 364.06S 229.74E 0.12 421.19 697301.98 5949288.70
8817.00 15.60 151.50 8710.20 379.66S 239.37E 9.55 439.16 697312.01 5949273.35
8843.00 22.20 147.00 8734.78 386.86S 243.71E 25.98 447.42 697316.54 5949266,27
8872.00 26.50 152.50 8761.20 397.20S 249.69E 16.75 459.19 697322.79 5949256.09
8903.00 34.50 146.30 8787.90 410.67S 257.77E 27.70 474.63 697331.22 5949242.84
8932.00 39.30 159.30 8811.12 426.13S 265.59E 31.52 4~1~84 697339.44 5949227,60
8971.00 45.70 155.70 8839.86 450.43S 275.71E 17.55 518.14 697350.19 5949203.57
9000.00 54.30 154.90 8858.48 470.59S 284.99E 29.73 540.27 697360.00 5949183.66
9025.00 60.40 157.30 8871.97 489.83S 293.50E 25.70 561.27 697369.01 5949164.65
9059.00 73.10 156.60 8885.36 518.51S 305.72E 37.40 592.40 697381.97 5949136.30
9091.00 84.10 160,80 8891.68 547.69S 317.07E 36.70 623.71 697394.08 5949107,43
9133.00 90.40 166.80 8893.69 587,94S 328.76E 20.70 665.52 697406.82 5949067,50
9159.00 93,70 169,60 8892.76 613.37S 334.07E 16.64 691.21 697412.79 5949042.22
9186.00 97.30 166.90 8890.18 639.67S 339.54E 16.64 717.77 697418.95 5949016,07
9216.00 96.80 173.80 8886.49 669.01S 344.53E 22.89 747.01 697424.70 5948986,88
9255.00 93.70 172,30 8882.92 707.55S 349.23E 8.82 784.79 697430.41 5948948.47
9282.00 91.90 170.00 8881.60 734.20S 353.38E 10.81 811.22 697435.25 5948921,95
9312.00 90.50 165.60 8880.97 763.50S 359.71E 15.39 840.90 697442.35 5948892,82
9344.00 89.40 162,20 8881.00 794.24S 368.59E 11.17 872.81 697452.03 5948862,32
9372.00 89.20 159.10 8881.34 820.66S 377.86E 11.09 900.80 697461.99 5948836.16
9403.00 89.60 155.60 8881.67 849.26S 389.80E 11.36 931.77 697474.67 5948807,88
9437,00 88.70 147,50 8882.17 879.13S 405.98E 23.97 965.40 697491.63 5948778,45
9464.00 90.80 153.20 8882.29 902.58S 419.33E 22.50 992.03 697505.59 5948755,36
9502.00 92.20 155.10 8881.30 936.76S 435.89E 6.21 1029.83 697523.04 5948721,62
9528.00 91.60 161.50 8880.43 960.89S 445.49E 24.71 1055.80 697533.27 5948697,75
9560.00 90.80 167.00 8879.76 991.67S 454.17E 17.36 1087.68 697542.75 5948667,21
9591.00 89.00 165,70 8879.82 1021.80S 461.49E 7.16 1118.47 697550.85 5948637,29
9619.00 92.00 163.60 8879.57 1048.79S 468.90E 13.08 1146.35 697558.96 5948610,50
9641.00 90.00 164,70 8879.19 1069.95S 474.91E 10.37 1168.28 697565.52 5948589,51
9668.00 89.00 174,50 8879.42 1096.47S 479.77E 36.48 1194.85 697571.08 5948563,12
9696.00 91.30 178,10 8879.35 1124.41S 481.58E 15.26 1221.67 697573.62 5948535,24
9730.00 89.40 181.70 8879.14 1158.40S 481.64E 11.97 1253.57 697574.57 5948501.27
9760.00 87.00 179,20 8880.09 1188.38S 481.40E 11.55 1281.60 697575.12 5948471.29
9789.00 85.30 175,00 8882.03 1217.27S 482.87E 15.59 1309.20 697577.34 5948442.45
9819.00 87.40 172.20 8883.94 1247.02S 486.20E 11.65 1338.25 697581.45 5948412,80
9849.00 89.40 172,30 8884.78 1276.73S 490.25E 6.67 1367.52 697586.27 5948383.21
9884.00 88.10 168.10 8885.55 1311.20S 496.20E 12.56 1401.92 697593.12 5948348,91
9918.00 88.30 163,70 8886.61 1344.16S 504.48E 12.95 1435.69 697602.26 5948316,18
9950.00 87.00 159.40 8887.93 1374.48S 514.59E 14.03 1467.64 697613.17 5948286.14
9982.00 87.50 157.00 8889.46 1404.15S 526.46E 7.65 1499.59 697625.81 5948256.79
10007.00 90.10 154,80 8889.99 1426.96S 536.67E 13.62 1524.53 697636.60 5948234.25
10036.00 91.30 152.20 8889.63 1452.91S 549.61E 9.87 1553.35 697650.22 5948208.65
10065.00 90.30 149,00 8889.23 1478.17S 563.84E 11.56 1581.98 697665.10 5948183,77
10094.00 89.90 145.20 8889.18 1502.52S 579.59E 13.18 1610.28 697681.48 5948159.85
10127.00 90.50 142.10 8889.06 1529.09S 599.15E 9.57 1641.99 697701.73 5948133.80
10164.00 89.80 137.70 8888.96 1557.39S 622.97E 12.04 1676.80 697726.29 5948106.14
10191.00 90.60 134.60 8888.87 1576.86S 641.67E 11.86 1701.55 697745.49 5948087.17
10235.00 91.30 131.40 8888.14 1606.85S 673.84E 7.44 1740.86 697778.43 5948058.02
10245.00 90.80 130.10 8887.96 1613.38S 681.42E 13.93 1749.61 697786.18 5948051.70
All
data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from 5-17 and TVD from Mean Sea Level - rkb 74ft.
Bottom hole distance is 1773.69 on azimuth 156.74 degrees from wellhead.
Vertical section is from wellhead on azimuth 159,68 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ARCO Alaska, Inc.
D.S. 505-17B
Prudhoe Bay,North Slope, Alaska
Measured Inclin Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N A T E S
SURVEY LISTING Page 2
Your ref : 5-178
Last revised : 31-Aug-98
Dogleg Vert G R I D C 0 0 R D S
Deg/100ft Sect Easting Northing
10270.00 90.80 130.10 8887.61 1629.48S 700.54E 0.00 1771.35 697805.71 5948036.10
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from 5-17 and TVD from Mean Sea Level - rkb 74ft.
Bottom hole distance is 1773.69 on azimuth 156.74 degrees from wellhead.
Vertical section is from wellhead on azimuth 159.68 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ARCO Alaska, Inc.
D.S. 5,5-17B
Prudhoe Bay,North Slope, Alaska
SURVEY LISTING Page 3
Your ref : 5-17B
Last revised : 31-Aug-98
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
5-17ehs 697810.000,5948020.000,999.00 8905.00 1645.37S 704.99E 29-Jun-98
5-17ihs 697595.000,5948510.000,999.00 8885.00 1149.88S 502.89E 29-Jun-98
5-17bhs 697380.000,5949000.000,999.00 8865.00 654.38S 300.80E 29-Jun-98
8100
8200
8300
EL 8400
Q)
ID 8500
.+-
Q) 8600
>.
-,i 8700
I
V 8soo
89OO
9OOO
ARCO Alaska, Inc.
Structure ' D.S. 5 SIo-[ .'.'.-' 5'~1~
Field · Prudhoe Bay Location · North Slope, Alaska
East (feet) ->
1 O0 0 1 O0 200 300 400 500 600 700 800 900
I I I / I I I I I I I I I I I I I I I
Tie on - 8521.73 Tvd, 355.47 S, 222.71 E
Kick off Point
5-17bhs
Tie on - 6.61 Inc, 8626.00 Md, 8521.73 Tvd, 4-10.69 Vs
Kick off Point
5._-147bhs
5-17ihs 5--17ehs
T.D. & End of Drop/Turn - 86.72 Inc, 10213.62 Md, 8905.00 Tvd, 1787.56 Vs
ORIGINAL
I5-- 17ihs
5-17ehs
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 I I I I I I t II
300 400 500 600 700 800 900 1000 1100 17.00 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200
Vertical Section (feet) ->
200
300
400
500
600
700
800
900 0
1000
1100
I
1200
1300
1400
t500
1600
1700
1800
Azimuth 159.68 with reference 0.00 N, 0.00 E from 5-17 '-19oo
ARCO Alaska, Inc.
D.S. 5
5-17B
5-17
Prudhoe Bay
North Slope, Alaska
SURVEY LISTING
by
Baker Hughes INTEQ
Your ref : 5-17B
Our ref : svy214
License :API 500292027102
Date printed : 31-Aug-98
Date created : 28-Aug-98
Last revised : 31-Aug-98
Field is centred on 708179.340~5930615.440,999.00000~N
Structure is centred on 696997.000,5951440.940,999.00000,N
Slot location is nTO 15 59.800,w148 24 23.213
Slot Grid coordinates are N 5949646.600, E 697062.800
Slot local coordinates are 1795.55 S 18.81E
Projection type: alaska - Zone 4, Spheroid: Clarke - 1866
Reference North is True North
ARCO Alaska, Inc. SURVEY LISTING Page 1
D.S. 5,5~178 Your ref : 5-17B
Prudhoe Bay,North Slope, Alaska Last revised : 31-Aug-98
Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R ! D C 0 0 R D S
Depth Degrees Degrees Depth C 0 0 R D ! N A T E S Deg/lOOft Sect Easting Northing
8700.00 6.68 140.86 8595.23 362.09S 228.14E 0.12 418.78 697300.33 5949290.62
8721.77 6.70 141.01 8616.85 364.06S 229.74E 0.12 421.19 697301.98 5949288.70
8817.00 15.60 151.50 8710.20 379.66S 239.37E 9.55 439.16 697312.01 5949273.35
8843.00 22.20 147.00 8734.78 386.86S 243.71E 25.98 447.42 697316.54 5949266.27
8872.00 26.50 152.50 8761.20 397.20S 249.69E 16.75 459.19 697322.79 5949256.09
8903.00 34.50 146.30 8787.90 410.67S 257.77E 27.70 474.63 697331.22 5949242.84
8932.00 39.30 159.30 ~I1.12 426.13S 265.59E 31.52 491.84 697339.44 5949227.60
8971.00 45.70 155.70 ~839.86 450.43S 275.71E 17.55 518.14 697350.19 5949203.57
9000.00 54.30 154.90 8858.48 470.59S 284.99E 29.73 540.27 697360.00 5949183.66
9025.00 60.40 157.30 8871.97 489.83S 293.50E 25.70 561.27 697369.01 5949164.65
9059.00 73.10 156.60 8885.36 518.51S 305.72E 37.40 592.40 697381.97 5949136.30
9091.00 84.10 160.80 8891.68 547.69S 317.07E 36.70 623.71 697394.08 5949107.43
9133.00 90.40 166.80 8893.69 587.94S 328.76E 20.70 665.52 697406.82 5949067.50
9159.00 93.70 169.60 8892.76 613.37S 334.07E 16.64 691.21 697412.79 5949042.22
9186.00 97.30 166.90 8890.18 639.67S 339.54E 16.64 717.77 697418.95 5949016.07
9216.00 96.80 173.80 8886.49 669.01S 344.53E 22.89 747.01 697424.70 5948986.88
9255,00 93.70 172.30 8882.92 707.55S 349.23E 8.82 784.79 697430.41 5948948.47
9282.00 91.90 170.00 8881.60 734.20S 353.38E 10.81 811.22 697435.25 5948921.95
9312.00 90.50 165.60 8880.97 763.50S 359.71E 15.39 840.90 697442.35 5948892.82
9344.00 89.40 162,20 8881.00 794.24S 368.59E 11.17 872.81 697452.03 5948862.32
9372.00 89.20 159.10 8881.34 820.66S 377.86E 11.09 900.80 697461.99 5948836.16
9403.00 89.60 155.60 8881.67 849.26S 389.80E 11.36 931.77 697474.67 5948807.88
9437.00 88.70 147.50 8882.17 879.13S 405.98E 23.97 965.40 697491.63 5948778.45
9464.00 90.80 153.20 8882.29 902.58S 419.33E 22.50 992.03 697505.59 5948755.36
9502.00 92.20 155.10 8881.30 936.76S 435.89E 6.21 1029.83 697523.04 5948721.62
9528.00 91.60 161.50 8880.43 960.89S 445,49E 24.71 1055.80 697533.27 5948697.75
9560.00 90.80 167.00 8879.76 991.67S 454.17E 17.36 1087.68 697542.75 5948667.21
9591.00 89.00 165.70 8879.82 1021.80S 461.49E 7.16 1118.47 697550.85 5948637.29
9619.00 92.00 163.60 8879.57 1048.79S 468.90E 13.08 1146.35 697558.96 5948610.50
9641.00 90.00 164.70 8879.19 1069,95S 474191E 10.37 1168.28 697565.52 5948589.51
9668.00 89.00 174.50 8879.42 1096.47S 479.77E 36.48 1194.85 697571.08 5948563.12
9696.00 91.30 178.10 8879.35 1124.41S 481.58E 15.26 1221.67 697573.62 5948535.24
9730.00 89.40 181.70 8879.14 1158.40S 481.64E 11.97 1253.57 697574.57 5948501.27
9760.00 87.00 179.20 8880.09 1188.38S 481.40E 11.55 1281.60 697575.12 5948471.29
9789.00 85.30 175.00 8882.03 1217.27S 482.87E 15.59 1309.20 697577.34 5948442.45
9819.00 87.40 172.20 8883.94 1247.02S 486.20E 11.65 1338.25 697581.45 5948412.80
9849.00 89.40 172.30 8884.78 1276.73S 490.25E 6.67 1367.52 697586.27 5948383.21
9884.00 88.10 168.10 8885.55 1311.20S 496.20E 12.56 1401.92 697593.12 5948348.91
9918.00 88.30 163.70 8886.61 1344.16S 504.48E 12.95 1435.69 697602.26 5948316.18
9950.00 87.00 159.40 8887.93 1374.48S 514.59E 14.03 1467.64 697613.17 5948286.14
9982.00 87.50 157.00 8889.46 1404.15S 526.46E 7.65 1499.59 697625.81 5948256.79
10007.00 90.10 154.80 8889.99 1426.96S 536.67E 13.62 1524.53 697636.60 5948234.25
10036.00 91.30 152.20 8889.63 1452.91S 549.61E 9.87 1553.35 697650.22 5948208.65
10065.00 90.30 149.00 8889,23 1478.17S 563.84E 11.56 1581.98 697665.10 5948183.77
10094.00 89.90 145.20 8889.18 1502.52S 579.59E 13.18 1610.28 697681.48 5948159.85
10127.00 90.50 142.10 8889.06 1529.09S 599.15E 9.57 1641.99 697701.73 5948133.80
10164.00 89.80 137.70 8888.96 1557.39S 622.97E 12.04 1676.80 697726.29 5948106.14
10191.00 90.60 134.60 8888.87 1576.86S 641.67E 11.86 1701.55 697745.49 5948087.17
10235.00 91.30 131.40 8888.14 1606.85S 673.84E 7.44 1740.86 697778.43 5948058.02
10245.00 90.80 130.10 8887.96 1613.38S 681.42E 13.93 1749.61 697786.18 5948051.70
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from 5-17 and TVD from Mean Sea Level - rkb 74ft,
Bottom hole distance is 1773.69 on azimuth 156.74 degrees from wellhead.
Vertical section is from wellhead on azimuth 159.68 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ARCO Alaskav Inc.
D.S. 5~5-17B
Prudhoe Bay,North Slope, Alaska
Measured Inclin Azimuth True Vert R E C T A N G U L A R
Depth Degrees Degrees Depth C 0 0 R D I N A T E S
SURVEY LISTING Page 2
Your ref : 5-17B
Last revised : 31-Aug-98
Dogleg Vert G R I D C 0 0 R D S
Deg/lOOft Sect Easting Northing
10270.00 90.80 130.10 8887.61 1629.48S 700.54E 0.00 1771.35 697805.71 5948036.10
All data in feet unless otherwise stated. Calculation uses minimum curvature method.
Coordinates from 5-17 and TVD from Mean Sea Level - rkb 74ft.
Bottom hole distance is 1773.69 on azimuth 156.74 degrees from wellhead.
Vertical section is from wellhead on azimuth 159.68 degrees.
Grid is alaska - Zone 4.
Grid coordinates in FEET and computed using the Clarke - 1866 spheroid
Presented by Baker Hughes INTEQ
ARCO Alaska, Inc.
D.S. 5,5-17B
Prudhoe Bay, North Slope, Alaska
SURVEY LISTING Page 3
Your ref : 5-17B
Last revised : 31-Aug-98
Targets associated with this wellpath
Target name Geographic Location T.V.D. Rectangular Coordinates Revised
5-17ehs 697810.000,5948020.000,999.00 8905.00 1645.37S 704.99E 29-Jun-98
5-17ihs 697595.000,5948510.000,999.00 8885.00 1149.88S 502.89E 29-Jun-98
5-17bhs 697380.000,5949000.000,999.00 8865.00 654.38S 300.80E 29-Jun-98
TONY KNOWLES, GOVERNOR
ALASKA OIL AND GAS
C ONSERVATI ON COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE. ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (~-K)7) 276-7542
July 1. 1998
Erin Oba
Engineering Supervisor
ARCO Alaska. Inc.
P O Box 100360
Anchorage, AK 99510-0360
Pmdhoe Bay Unit 5-7[ 7 B
ARCO Alaska. Inc.
Permit No. 98-104
Sur. Loc. i796'SNL. 13'EWLScc. 32. TllN. R15E. UM
Btmnhole Loc. 1838'FSL. 4569'FEE Scc. 32. T1 IN. RI5E. UM
Dcar Ms. Oba:
Enclosed is thc approvcd application for permit to rcdrill thc above rcfcrenccd well.
The permit to rcdrill docs not cxcmpt you from obtaining additional permits required bx.' law from
othcr govcrnmcntal agencies, and docs not authorize conducting drilling opcrations until all other
required pcrmitting dctcrminations arc made.
Bloxvout prevention equipment (BOPE) must bc tcstcd in accordance with 20 AAC 25 035.
Sufficient notice (approximately 24 hours) must be given to alloy,' a rcprcscntativc of ti'to
Cotnmission to xvitncss a test of BOPE installed prior to drilling ncxv hole. Notice ma,,' be givcn
by contacting the Commission pctrolculn field inspcctor on the North Slopc pager at (>59-3607.
Robcrt N. Christcnson. P.E.
Commissioner
BY ORDER OF TIlE COMMISSION
dlf/Enclosurcs
CC:
Dcpartmcnt of Fish &Gamc. Habitat Scction xv/o cncl.
Department of Environmcntal Conservation xv/o cncl.
STATE OF ALASKA
ALASI;<A-QIL AND GAS CONSERVATION
PERMIT TO DRILL
20 ~C 25.005
la. Type of Work Drill_ Redrill __X lb. Type of Well Exploratory_ Stratigraphic Test!'~tr~ '~ .....................Dev/e.~.~.~'l
Re-Entry__ Deepen _ Service _ Development Gas_ Single Zone ~ Multiple Zone _
2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. RKB 74'
3. Address 6. Property Designation
P.O. Box 100360 Prudhoe Bay Field
Anchorage, AK 99510-0360 ADL 028326 Prudhoe Bay Oil Pool
4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025)
1796' SNL, 13' EWL, Sec 32, T11N, R15E, UM
Prudhoe Bay Unit Statewide
At top of productive interval 8. Well number Number
2135' SNL, 225' EWL, Sec 32, T11N, R15E, UM 5-17B #U-630610
At total depth 9. Approximate spud date Amount
(Proposed)
1838' FSL, 4569' FEL, Sec 32, T11N, R15E, UM July, 1998 $200,000
12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
property line
I
No Close Approach 10242' MD / 8979' TVD
16. To be completed for deviated wells 17. Anticipated pressure (see 20 ,&AC 25,035(e)(2))
kickoff depth 8740' MD Maximum hole angle 88° Ma)dmum surface 2800 psig At total depth ('fVD) 8800'
18. Casing program Setting Depth
Size Specification Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
2-3/4" 2-3/8" 4.7 L-80 FL4S 3342' 6900' 6893' 10242' 8979' 10 bbls
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured 9115 feet Plugs(measured) PBTD Tagged @ 8977' MD (65/23/96)
true vertical 9070 feet
Eflective depth: measured 8977 feet Junk (measured)
true vertical 8933 feet
Casing Length Size Cemented Measured depth True Vertical depth
Conductor 115' 20" 284 Sx PF 115' 115'
Surface 2628' 13-3/8" 6100 Sx PF II 2702' 2702'
Production 7066' 9-5/8" 1200 Sx Cl H & 7140' 7050'
300 Sx AS I
Scab Liner 7066' 7" 450 Sx CIG 7140' 7050'
Liner 2118' 4-1/2" 286 cuft Cl G 9115' 9070'
Perioration depth: measured 8792' - 8796'; 8938' - 8950'; 8954' - 8976'
0 '
true vertical 8748' - 8752'; 8894' - 8906'; 8910' - 8932'
20. Attachments Filing fee __X Property plat _ BOP Sketch x Diverter Sketch _ Drilling program __X
Drilling fluid program __ Time vs depth plot _ Refraction analysis _ Seabed report _ 20 AAC 25.050 requirements _
21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions: Call Dan Kara @ 263-4837.
Sicned Engineering Supervisor Date
Commission Use Only Prepared(by Paul Rauf 263-4990
Permit Number L APInumber .~ Approvaldate..~ ,,~__~_.~ See cover letter for
~'~'-'//~:~ ~ 50- 0 ~_~C~_ ~...(:~.2_. '~/' --E:~ other requirements
Conditions of approval Samples required Yes ~k"No Mud Icg required' Yes
Hydrogen sulfide measures ~"Yes _ No Directional survey required ~Y'es _ No
Required working pressure for DOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M __X 3500 psi for CTU
Other:
ORIGINAL SIGNED BY
Robert N. Christenson by order of
Approved by Commissioner the commission Date
Form 10-401 Rev. 7-24-89 Submit in triplicate
DS 5-17B
CT Sidetrack and Completion
Intended Procedure
Objective:
Set whipstock. Plugback existing wellbore. Directionally drill a horizontal
well from the existing wellbore. Complete with 2-3/8" cemented
liner. Perforate appropriate intervals.
Intended Procedure:
Set top of whipstock @ ~8740'. Cement squeeze the current perforations
and leave top of cement @ -8740' md.
Mill window in 4-1/2" liner at 8740' md. Drill 10' of formation and
perform Leak off test to 9.4 ppg, 0.5 ppg above the highest anticipated
mud weight (8.9 ppg FloPro).
Directionally drill 2-3/4" x -1502' horizontal well to access Romeo
reserves.
· Run 2-3/8" slotted liner to TD, cement in place.
· Perforate, place on production.
May18,1998
DS 5-17B Proposed CT
Sidetrack Horizontal
4-1/2" x 3-1/2" Tubing
4-1/2" Camco SVLN @ 2207'
Packer @ 6930'
4-1/2" Liner Top @ 6997'
3-1/2" XN Nipple
@ 6977'
Cement top ...8740'
41/2" Liner Shoe @ 9115'
Top of 2-3/8"
Liner in TT
Window cut in 4-1/2"
liner at ~8740'
2-3/4" Open hole
Current perforations
cement squeezed
Initial Perfs
2-3/8" liner
TD @ ~
10,242'
Anadrill Schlumberger
Alaska District
1111 East 80th Avenue
Anchorage, AK 99518
(907) 349-4511 Fax 344-2160
DIRECTIONAL WELL PLAN for ARCO ALASKA INC
Well ......... : DS 05-17B (P3)
Field ........ : DS 05
Computation..: Minimum Curvature
Units ........ : FEET
Surface Lat..: 70.26661020 N
Surface Long.: 148.40644428 W
Legal Description
Surface ...... : 3484 FSL 5267 FEL S32 TllN R15E UM
Tie-in Survey: 3119 FSL 5038 FEL S32 TllN R15E UM
TGT1 (BSL)...: 2829 FSL 4970 FEL S32 TllN R15E UM
TGT2 (ESL)...: 1838 FSL 4569 FEL S32 TllN R15E UM
BHL .......... : 1838 FSL 4569 FEL 'S32 TllN R15E UM
LOCATIONS - ALASKA Zone: 4
X-Coord Y-Coord
697063.28 5949646.32
697302.46 5949288.42
697380.00 5949000.00
697810.00 5948020.00
697810.00 5948020.00
Prepared ..... : 13 May 1998
Vert sect az.: 159.69
KB elevation.: 74.00 ft
Magnetic Dcln: +28.285 (E)
Scale Factor.: 0.99994411
Convergence..: +1.50001666
STATION MEASURED INCLN DIRECTION
IDENTIFICATION DEPTH ANGLE AZIMUTH
TIE-IN SURVEY
KOP/CURVE 21.25/100
PROPOSED WELL PROFILE
VERTICAL-DEPTHS SECTION COORDINATES-FROM
TVD SUB-SEA DEPART WELLHEAD
======== ~======= ~========= ==========
8677.85 8603.85 421.17 364.06 S 229.74 E
8695.96 8621.96 423.19 365.72 S 231.08 E
8705.86 8631.86 424.48 366.81 S 231.85 E
8715.72 8641.72 426.14 368.27 S 232.69 E
8725.51 8651.51 428.15 370.09 S 233.59 E
8721.77 6.70 141.01
8740.00 6.74 141.08
8750.00 8.67 147.79
8760.00 10.67 152.03
8770.00 12.72 154.93
8780.00 14.78 157.04 8735.23 8661.23 430.52 372.26 S 234.55 E
8790.00 16.86 158.64 8744.85 8670.85 433.25 374.78 S 235.58 E
8800.00 18.95 159.90 8754.36 8680.36 436.32 377.66 S 236.67 E
8810.00 21.05 160.91 8763.76 8689.76 439.74 380.88 S 237.81 E
8820.00 23.15 161.75 8773.02 8699.02 443.50 384.45 S 239.01 E
8830.00 25.26 162.46 8782.14 8708.14 447.60 388.35 S 240.27 E
(Anadrill (c)98 0517BP3 3.2b.02 1:55 PM P)
ALASI~ ~o~e 4
697302.46 5949288.42
697303.84 5949286.79
697304.64 5949285.72
697305.52 5949284.29
697306.46 5949282.50
697307.48 5949280.35
697308.58 5949277.85
697309.74 5949275.01
697310.97 5949271.82
697312.26 5949268.28
697313.62 5949264.42
TOOL DL/
FACE 100
12R <TIE
28R 0.23
22R 21.25
18R 21.25
15R 21.25
13R 21.25
llR 21.25
10R 21.25
9R 21.25
8R 21.25
8R 21.25
DS 05-17B (P3) 13 May 1998 Page 2
PROPOSED WELL PROFILE
STATION
IDENTIFICATION
MEASURED INCLN DIRECTION VERTIC3%L-DEPTHS
DEPTH ANGLE AZIMUTH TVD SUB-SEA
8840.00 27.36 163.06 8791.11 8717.11
8850.00 29.47 163.58 8799.90 8725.90
8860.00 31.59 164.04 8808.52 8734.52
8870.00 33.70 164.45 8816.94 8742.94
8880.00 35.81 164.81 8825.15 8751.15
8890.00 37.93
8900.00 40.05
8910.00 42.16
8920.00 44.28
8930.00 46.40
8940.00 48.52
8950.00 50.64
8960.00 52.76
8970.00 54.88
8980.00 57.00
8990.00 59.12
9000.00 61.24
9010.00 63.36
9020.00 65.48
9030.00 67.60
9040.00 69.72
9050.00 71.84
9060.00 73.97
9070.00 76.09
9080.00 78.21
165.14 8833.15 8759.15
165.44 8840.92 8766.92
165.72 8848.46 8774.46
165.97 8855.74 8781.74
166.20 8862.77 8788.77
SECTION
DEPART
COORDINATES-FROM
WELLHEIkD
452.02 392.58 S 241.59 E
456.77 397.14 S 242.95 E
461.84 402.02 S 244.37 E
467.22 407.21 S 245.83 E
472.90 412.71 S 247.34 E
478.87 418.50 S 248.90 E
485.13 424.59 S 250.49 E
491.67 430.95 S 252.13 E
498.48 437.59 S 253.80 E
505.55 444.50 S 255.51 E
166.42 8869.53 8795.53 512.87 451.65 S 257.26 E
166.62 8876.02 8802.02 520.42 459.06 S 259.03 E
166.82 8882.21 8808.21 528.21 466.69 S 260.83 E
167.00 8888.12 8814.12 536.22 474.56 S 262.66 E
167.17 8893.72 8819.72 544.43 482.63 S 264.51 E
167.34 8899.01 8825.01 552.85 490.91 S 266.39 E
167.49 8903.98 8829.98 561.44 499.37 S 268.28 E
167.64 8908.63 8834.63 570.21 508.02 S 270.18 E
167.79 8912.95 8838.95 579.14 516.83 S 272.10 E
167.93 8916.93 8842.93 588.22 525.80 S 274.03 E
597.44 534.91 S 275.97 E
606.78 544.15 S 277.91 E
616.23 553.51 S 279.85 E
625.78 562.97 S 281.80 E
635.41 572.53 S 283.74 E
168.07 8920.57 8846.57
168.20 8923.86 8849.86
168.33 8926.80 8852,80
168.46 8929.38 8855.38
168.58 8931.60 8857.60
ALASKA Zone 4
X Y
697315.05 5949260.22
697316.53 5949255.70
697318.07 5949250.86
697319.67 5949245.71
697321.33 5949240.25
697323.03 5949234.50
697324.79 5949228.46
697326.59 5949222.14
697328.44 5949215.55
697330.33 5949208.69
697332.26 5949201.58
697334.23 5949194.23
697336.23 5949186.64
697338.26 5949178.83
697340.32 5949170.81
697342.41 5949162.58
697344.52 5949154.17
697346.65 5949145.58
697348.80 5949136.82
697350.96 5949127.90
697353.14 5949118.85
697355.32 5949109.66
697357.51 5949100.36
697359.70 5949090.95
697361.89 5949081.45
TOOL DL/
FACE 100
7R 21.25
7R 21.25
6R 21.25
6R 21.25
5R 21.25
5R 21.2
5R 21.2
'SR 21.2
5R 21.25
4R 21.25
4R 21.25
4R 21.25
4R 21.25
4R 21.25
3R 21.25
3R 21.25
3R 21,25
3R 21,25
3R 21.25
3R 21.25
9090.00 80.33
9100.00 82.45
9110.00 84.57
168.70 8933.47 8859.47 645.12 582.16 S 285.67 E
168.82 8934.96 8860.96 654.88 591.85 S 287.60 E
168.94 8936.09 8862.09 664.69 601.60 S 289.51 E
697364.08 5949071.87
697366.25 5949062.23
697368.42 5949052.53
3R 21.25
3R 21.25
3R 21.25
(Anadrill (c)98 0517BP3 3.2b.02 1:55 PM P)
DS 05-17B (P3) 13 May 1998. Page 3
STATION MEASURED INCLN
IDENTIFICATION DEPTM ANGLE
_
9120.00 86.70
END 21.25/100 CURVE 9122.30 87.18
CURVE 21.25/100 9160.70 87.18
CURVE 2.09/100 9163.88 87,86
TGT1 (BSL) 9163.88 87.86
MINMUM INCLINATION
9200.00 87,86
9300.00 87.85
9400.00 87.85
9433.36 87.85
9500.00 87.85
9600.00 87.85
9700.00 87.86
9800.00 87.87
9900.00 87.88
10000.00 87.90
10100.00 87.91
10200.00 87.93
TD 10241.81 87.94
TGT2 (ESL) 10241.81 87.94
PROPOSED WELL PROFILE
========= ==============2==
DIRECTION VERTICAL-DEPTHS
AZIMUTH TVD SUB-SEA
169.06 8936.85 8862.85
169.09 8936.98 8862.98
169.09 8938.86 8864.86
169.09 8939.00 8865.00
169.09 8939.00 8865.00
SECTION
DEPART
=====================
COORDINATES-FROM ALASKA Zone 4
WELLHEAdD X Y
168.33 8940.35 8866.35
166.24 8944.09 8870.09
164.15 8947.85 8873.85
163.45 8949.10 8875.10
162.06 8951,60 8877.60
674.53 611.39 S 291.41 E
676.80 613.65 S 291.85 E
714.63 651.31 S 299.11 E
717.77 654.43 S 299.71 E
717.77 654.43 S 299.71 E
753.42 689.82 S 306.77 E
852.46 787.30 S 328.76 E
951.93 883.90 S 354.30 E
985.18 915.92 S 363.60 E
1051.67 979.51 S 383.34 E
159.96 8955.35 8881.35 1151.57 1074.00 S 415,86 E
157.87 8959.09 8885.09 1251,49 1167.23 S 451.81 E
155.78 8962.82 8888.82 1351.29 1259.09 S 491.14 E
153.68 8966.53 8892.53 1450.84 1349.46 S 533.79 E
151.59 8970,21 8896.21 1550.01 1438.20 S 579,72 E
1648.66 1525.21 S 628.86 E
1746.67 1610.37 S 681,15 E
1787.44 1645.40 S 703,93 E
1787.44 1645.40 S 703,93 E
149.50 8973.87 8899.87
147.40 8977.50 8903.50
146.53 8979.00 8905.00
146.53 8979.00 8905.00
697370.58 5949042.80
697371.08 5949040.56
697379.32 5949003.10
697380.00 5949000.00
697380.00 5949000.00
TOOL DL/
FACE 100
====
3R 21.25
HS 21.25
HS 0.00
90L 21.25
90L 21.25
697387.99 5948964.80 90L 2.09
697412.52 5948867.94 90L 2.09
697440,57 5948772.04 90L 2.09
697450,71 5948740.28 90L 2.09
697472.11 5948677.23 90L 2.09
697507.09 5948583.63 90L 2,09
697545.46 5948491.38 90L 2,09
697587.18 5948400.58 90L 2.09
697632.18 5948311.37 90L 2.09
697680.42 5948223.87 90L 2,09
697731.82 5948138.18 89L 2,09
697786.31 5948054.42 89L 2,09
697810.00 5948020.00 2.09
697810.00 5948020.00 2,09
ANADRILL AKA-Dr'C
APPROVED
FOR PERMITTING
ONLY _
PLAN ._.
(Anadrill (c)98 0517BP3 3.2b.02 1:55 PM P)
ARCO ALASKA ][NC
IVERTICAL SECTION VIEW
Isec~i°nl a~: J59.69
ITVD Scale.: J inch = ~200 feet
IDep Scale.: ! inch = J2OO feet
IDrawn ..... : ~3 Nay J998
!
I JnadnJ]] Sch]umbemge~
Marker Identification MD BKB SECTN INCLN
A) TIE-IN SURVEY 8722 8678 421 6,70
. B) KOP/CURVE 21.25/t00 8740 8696 423 6.74
C) END 2t.25/100 CURVE 9122 8937 677 87.18
D) CURVE 21.25/100 g~6t 8939 715 87.
E) CURVE 2.09/100 9164 8939 718 87.86
F) TGT~ (8SL) 9t64 8939 7~8 87.86
G) MINMUM INCLINATION 9433 8949 985 87.85
H) TD 10242 8979 1787 87.94
I) TGT2 (ESL) 10242 8979 ~787 87.94
,
i FCR P~RMI'FTING
J ONLY ) i
, PLAN
r
ESL) (Potent) J j , I
0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800
~ Section Departure :
Marker Identification
A) TIE-IN SURVEY
B) KOP/CURVE 21.25/100
C) END 21.25/100 CURVE
D) CURVE 2~.25/100
E) CURVE 2.09/100
F) TGT1 (BSL)
G) MINMUM INCLINATION
HI TO
I) TGF2 (ESL)
ARCo
ALASKA INC
MD BKB SECTN INCLN
8722 8678 421 6.70
8740 8696 423 6.74
g122 8937 677 87.18
916! 8939 7~5 87.18
9164 8939 718 87.86
9164 8939 718 87.86
9433 8949 985 87.85
10242 8979 2787 87.94
10242 8979 ~787 87.94
A,NADRILL AKA-Dr'C
APPROVED
FOR P£RMITTING
ONLY
PLAN:/:/: .~ _
Anadr J ] ] Sch]umberger
DS 05-17B (P3)
VERTICAL SECTION VIEW
Section at' 159.69
TVD Scale.' 1 inch = 200 feet
Dep Scale.' ~ inch : 200 feet
Drawn · 13 May ~998
1
~ ~ TGT2 (I SL)(Poi
H
200 300 400 500 600 700 BO0 900 1000 1100 1200 1300 1400 1500 1600 1700 lB00 1900
Section Departure
(Anadr]11 (c)gB 0517BP3 3.2b.5 2:01 PM P)
it)
2000
ARCO ALASKA TNC
Marker Identification MD N/S E/W
A) TIE-IN SURVEY 8722 384 S 230 E
B) KOP/CURVE 21.25/100 8740 366 S 231
E
c~ ~NO ~.~U~oo cu,v~ g~ ~4 s ~
E
E) CURVE 2.0§/100 giB4 654 S 300 E
F) TGT1 (BSL) 9164 654 S 300 E
8) MINMUM INCLINATION 9433 916 S 354 E
H) TO 10242 1545 S 704 E
I) TGT2 (ESL) 10242 1645 S 704 E
DS 05-178 (!:)3)
PLAN VIEW
CLOSURE ..... : 1790 feet at Azimuth t56.84
DECLINATION.: +28.285 (E)
SCALE ....... : 1 inch = 300 feet
DRAWN ....... : 13 May 1998
AnadrJ ]] Schlumberger
, J I i ANa, DRILLj i AKA-D,-'C i
(ESL) fl~oint) I j
150 0 t50 300 450 600 750 gOO t050 1200 1350 1500 1650
<- I~EST ' EAST -> )
1800
1950
Mu, Tanks
60/40 ]
TrplxI
Ext.
Fuel
Shop
/~oilers
Water
Pump Rool
Fire
Ext.
Fire
Ext.
/~Pipe rac/
Dowell Drilling
Equipment
Trailer
Preferred Major Equipment Layout for CT Drilling
· -,, C T Drilling Wellhead Detail ~-
Methanol Injection
Otis 7" WLA
Quick Connect
Alignment Guide Flange
7-1/16", 5M Ram Type Dual
Gate BOPE
Flanged Fire Resistant
Kelly Hose to Dual HCR
Choke Manifold
Man
~ CT Injector Head
~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure
_
7" Riser
Annular BOP (Hydril),7-1/16" ID
5000 psi WP
Cutters or
Combination CuttedBlinds
Slip/Pipe Rams
Manual Valves Drilling spool 7-1/16", 5M
by 7-1/16", 5M
Manual over Hydraulic
Ram Type Dual Gate BOPE
7-1/16" ID with
Pipe/Slip Rams
Manual Master Valve
0.458' (5.5")
2" Pump-In
Hanger
Fire resistant Kelly Hose to
Flange by Hammer up 1/4 Turn
Valve on DS Hardline to Standpipe
manifold
ri
~[~9-5/8" Annulus
13-3/8" Annulus
· WELL PERMIT CHECKLIST COMPANY
FIELD & POOL ~//'~~/~ INIT CLASS ,~
WELL NAME
/ - ~..(// GEOL AREA ~::"~'~)
ADMINISTRATION
1. Permit fee attached ....................... Y
2. Lease number appropriate ................... Y
3. Unique well name and number ..................
Y
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
N
N
N
N
N
N
N
N
N
N
N
PROGRAM: exp [] dev [] redrll/~g,, serv [] wellbore seg El ann. disposal para req
UNIT# //~::~,~'~ ON/OFF SHORE
ENGINEERING
14. Conductor string provided ................... Y N
15. Surface casing protects all known USDWs ........... Y N/ :' c.,_
16. CMT vol adequate to circulate on conductor & surf csg ..... Y N
17. CMT vol adequate to tie-in long string to surf csg ........
/
18. CMT will cover all known productive horizons .......... ,,~
SN
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved... Y N
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate ..... ~N
25. BOPEs, do they meet regulation ...... ~.,~..~.,,:.,_,:, ..... (~ N
26. BOPE press rating appropriate; test to ,~, ~,, c./ psig.~)N
27. Choke manifold complies w/APl RP-53 (May 84) ........ N
28. Work will occur without operation shutdown ........... ~ N
29. Is presence of H2S gas probable ................. >N
REMARKS
GEOLOGY
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones .............
33. Seabed condition survey (if off-shore) ............ ,//. Y N
34. Contact name/phone for weekly.progress reports .... /.. Y N
l exploratory only] /
GEOL. O, GY: ENGINEERING: COMMISSION:
JDH~ RNC
co 6o
Comments/Instructions:
A:\GEN, Misc\FORMS\cheMist rev 05198
dlf:C:\msoffice\wordian\diana\checklist
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history, file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX. ,
No special effort has been made to-chronologically
organize this category of information.
* ALASKA COMPUTING CENTER *
. .
. ............................ .
....... SCHLtrMBERGER
. ............................ .
COMPANY NAME : ARCO ALASKA INC.
WELL NAME : DS 05-17B
FIELD NAME : PRUDHOE BAY
BOROUGH : NORTH SLOPE
STATE . ALASKA
API N-~4BER : 500292027102
REFERENCE NO : 99062
RECEIVED
:-%~ 1 8 1999
Oil & (~as Con_ ~. Oorr,.~ion
LIS Tape V~fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999
PAGE:
**** REEL HEADER ****
SERVICE NAME : EDIT
DATE : 99/02/10
ORIGIN : FLIC
REEL NAME : 99062
CONTINUATION # :
PREVIOUS REEL :
CO~94ENT · ARCO ALASKA, PRUDHOE BAY, DS 05-17B, API #50-029-20271-02
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE · 99/02/10
ORIGIN - FLIC
TAPE NAME . 99062
CONTINUATION # : 1
PREVIOUS TAPE :
CO~94ENT : ARCO ALASKA, PRUDHOE BAY, DS 05-17B, API #50-029-20271-02
TAPE HEADER
PR UDHOE BAY
CASED HOLE WIRELINE LOGS
WELL NAME: DS 05-17B
API NUMBER: 500292027102
OPERATOR: ARCO ALASKA INC.
LOGGING COMPANY: SCHLUMBERGER WELL SERVICES
TAPE CREATION DATE: 10 - FEB- 99
JOB NUMBER: 99062
LOGGING ENGINEER: SPENCER
OPERATOR WITNESS: SARBER
SURFACE LOCATION
SECTION: 32
TOWNSHIP: 1 iN
RANGE: 15E
FNL:
FSL: 1838
FEL: 4569
FWL :
ELEVATION(FT FROM MSL O)
KELLY BUSHING: 61. O0
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
OPEN HOLE CASING DRILLERS CASING
BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT)
1ST STRING 2. 375 10268.0 4.85
2ND STRING
3RD STRING
PRODUCTION STRING
CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH)
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
BASELINE CURVE FOR SHIFTS
LDWG TOOL CODE: BCS
LDWG CURVE CODE: GR
RUN NUMBER:
PASS NUMBER:
DATE LOGGED: 1978
LOGGING COMPANY: SCHLUMBERGER WELL SERVICES
BASELINE DEPTH
88888 0
7114 0
7108 5
7102 0
7097 5
7092 5
7086 0
7077 0
7073 5
7072 5
7071 5
7070.0
7069.0
7059.5
7059.0
7053.5
7051.5
7046.5
7045.5
7043.5
7042.0
7039.0
7033.5
7030.5
7024.0
7013.0
7006.0
6997.0
6995.0
6993 5
6992 0
6991 5
6990 5
6990 0
6986 0
6974 0
6971 5
6964 5
6962.0
6950.5
6948.5
6948.0
6945.5
6941.5
6936.0
.......... EQUIVALENT UNSHIFTED DEPTH ..........
GRCH CNT
88889.5 88889.5
7115.5 7115.5
7110.5 7110.5
7103.0 7103.0
7098.0 7098.0
7090.5 7090.5
7084.5 7084.5
7077.0 7077.0
7074.5 7074.5
7071.5
7070.5
7069.0
7061. 0
7052.5
7050.0
7046.0
7041.5
7039.5
7032.5
7028.0
7007.5
6997.0
6991.5
6989.0
6984.5
6974.0
6971.5
6963.5
6951.0
6946.0
6940.5
6935.5
7068.5
7056.5
7046.0
7043.0
7041.5
7035.5
7032.5
7028.0
7013.0
7007.5
6997.0
6994.5
6991.5
6989.0
6984.5
6974.0
6971.5
6966.5
6963.5
6951.0
6948.5
6946.0
6940.5
PAGE:
j
LIS Tape V$-'r~fication Listing
Schlumberger Alaska Computing Center
6934 0
6932 5
6930 5
6925 0
6922 0
6919 5
6917 0
6914 0
6906.0
6896.5
6895.5
6889.5
6888.5
6881.0
6880.0
6879.0
6867.0
6864.0
6860.0
6854.0
6847.5
6843.0
6839.0
6829.5
6825 5
6822 5
6811 0
6809 0
6804 0
6803 5
6798 0
6796 5
6791 0
6787 0
6786 5
6782.0
6780.5
6777.0
6773.5
6769.0
100.0
REMARKS:
6934.0
6931.5
6921.5
6918.5
6913.5
6907.5
6898.5
6888.5
6882.5
6870.0
6865.0
6860.5
6854.5
6846.5
6837.5
6824.5
6809.0
6803.0
6796.5
6789.5
6786.5
6783.0
6776.5
6772.5
103.5
6930.0
6925.0
6918.5
6907.5
6898.5
6888.5
6882.5
6880.5
6860.5
6854.5
6846.5
6839.5
6837.5
6829.0
6822.0
6808.0
6803.0
6796.5
6789.5
6786.5
6783.0
6776.5
oo 5
CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE MCNL
DATA AQUIRED ON ARCO ALASKA'S 05-17B WELL. THE DEPTH
SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BET~WEEN GRCH
PASS #1 AND THE BCS GANkqA RAY, ALSO PASS #1 NRAT AND
THE BCS GA24N_A RAY, CARRYING ALL MCNL CO~VES WITH THE
1TRAT SHIFTS. THE BCS GR IS THE PARENT 05-17 WELL.
THE MCNL CURVES ARE TIED TO THE PARENT HOLE DOr/~ TO
THE KOP AT 7120 ', CARRYING THE LAST SHIFT OVER THE
REMAINING LOGGED INTERVAL. THIS LOG IS THE PDC.
$
$
PAGE:
LIS Tape VerSification Listing
Schlumberger Alaska Computing Center
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 1
EDITED CURVES
Depth shifted and clipped curves for each pass in separate files.
PASS NUMBER: 1
DEPTH INCREMENT: 0.5000
FILE SUM24ARY
LDWG TOOL CODE START DEPTH STOP DEPTH
GRCH 10171.5 6769.5
CNT 10169.5 6765.5
$
CURVE SHIFT DATA - PASS TO PASS (FzEASURED DEPTH)
BASELINE CURVE FOR SHIFTS
LDWG CURVE CODE: CR
PASS NUMBER:
BASELINE DEPTH
$
.......... EQUIVALENT UNSHIFTEDDEPTH ..........
GRCH CNT
REMARKS: THIS FILE CONTAINS CASED HOLE MCNL MAIN PASS. THERE
ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA.
$
LIS FORMAT DATA
DATA FORMAT SPECIFICATION RECORD
SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 2~
4 66 i
LIS Tape V$~'fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999
PAGE: 5
TYPE REPR CODE VALUE
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 36
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE ~ CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT O0 000 O0 0 1 1 1 4 68 0000000000
GRCH CNT GAPI O0 000 O0 0 1 1 1 4 68 0000000000
NCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000
FCNT CNT CPS O0 000 O0 0 1 1 1 4 68 0000000000
NRAT CNT O0 000 O0 0 1 1 1 4 68 0000000000
CCL CNT V O0 000 O0 0 1 1 1 4 68 0000000000
GR BCS GAPI O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 10171.500 GRCH. CNT 134.569 NCNT. CNT -999.250 FCNT. CNT -999.250
NRAT. CNT -999.250 CCL.CNT -999.250 GR.BCS -999.250
DEPT. 2692.000 GRCH. CNT -999.250 NCNT. CNT -999.250 FCNT. CNT -999.250
NRAT. CNT -999.250 CCL.CNT -999.250 GR.BCS 33.100
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT . 001
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE
LIS Tape ~fication Listing
Schlumberger Alaska Computing Center
10 -FEB-1999 i~.?00
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE · FLIC
VERSION : O01CO1
DATE · 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NIIMBER: 2
EDITED CURVES
Depth shifted and clipped curves for each pass in separate files.
PASS NUMBER: 2
DEPTH INCREMENT: O. 5000
FILE SOWmlARY
LDWG TOOL CODE START DEPTH STOP DEPTH
GRCH 10181 . 0 9836.0
CNT 10176.0 9836.0
$
CO~RVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH)
BASELINE CURVE FOR SHIFTS
LDWG CURVE CODE: GRCH
PASS NUMBER: 1
.......... EQUIVALENT OWSHIFTEDDEPTH ..........
BASELINE DEPTH GRCH CNT
88888.0 88891.0 88890.0
10166.0 10169.0 10168.0
10162.5 10163.5
10157.5 10159.5
10152.0 10155.0
iO1SO.O 10151.0
10147.5 10148.0
10144.0 10145.5
10141.5 10142.5
10139.0 10141.0
10135.0 10137.5
10133.5 10137.5
10128.5 10133.5
10123.0 10125.5
10122.0 10122.5
10115.0 10117.5
10110.5 10111.0
10109.5 10i11.0
10103.0 10102.5
10101.0 10099.0
10098.0 10096.0
LIS Tape V~'~i'fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999
PAGE:
10093 5
10089 5
10083 5
10080 5
10077 0
10075 5
10074 0
10072 0
10065 5
10060 5
10050 5
10046 5
10044 5
10041 0
10038 0
10031 5
10021.0
10018.0
10016.5
10010.0
10007.0
10001.5
9993.0
9990.5
9981.0
9976.5
9975.0
9972.0
9961.5
9954.0
9950.5
9945.5
9944.5
9942.5
9939.0
9936.0
9934.5
9927.0
9925.5
9920.5
9918.5
9914.0
9910.5
9909.5
9908.0
9903.5
9903.0
9901.5
9898.0
9895.5
9894.5
9893.0
9891.0
9889.5
9885.0
10081.5
10075.0
10065.0
10031.0
10017.0
10008.5
10001.0
9990.5
9988.5
9980.0
9977.5
9975.0
9971.0
9959.5
9950.0
9945.5
9936.5
9924.0
9912.5
9910.5
9906.5
9901.5
9898.5
9897.0
9895.5
9891.0
10091.5
10089.0
10086.5
10080.0
10076.5
10073.5
10062.5
10052.0
10050.0
10047.0
10041.5
10039.0
10023.5
10021.0
10011.0
9996.0
9994.0
9975.0
9955.5
9946.5
9942.5
9938.5
9935.5
9926.0
9920.0
9918.5
9910.0
9905.5
9903.0
9896.0
9892.0
9887.0
LIS Tape V~fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999 iB~FO~O
PAGE:
9883.0 9884.5
9880.0 9881.5
9879.0 9880.5
9875.5 9878.5
9872.5 9876.0
9868.5 9870.0
9865.5 9866.0
9864.0 9865.5
9862.0 9863.5
9860.0 9862.0
9857.0 9858.5
9855.5 9856.5
9854.5 9857.0
9849.5 9850.5
9847.0 9847.0
9845.0 9845.5
9842.5 9845.0
9840.5 9842.5
9837.5 9839.5
100.0 102.0 102.0
R~KS: THIS FILE CONTAINS THEE CASED HOLE MCNL REPEAT PASS. THE
SHIFTS SHO~'~VABOVE REFLECT CORRELATIONS BE~gEEN GRCH
PASS #2 AND GRCH PASS #1, ALSO ArR~T PASS #2 AND N-RAT
PASS #1, CARRYING ALL MCNL CURVES WITH THE NRAT SHIFTS
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE ~ 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 24
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
il 66 42
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
LIS Tape ~fication Listing
Schlumberger Alaska Computing Center
1 O-FEB-1999 1'~'~.00
PAGE:
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE ~ NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX)
DEPT FT O0 000 O0 0 2 1 1 4 68 0000000000
GRCH CNT GAPI O0 000 O0 0 2 1 1 4 68 0000000000
NCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000
FCNT CNT CPS O0 000 O0 0 2 1 1 4 68 0000000000
NRAT CNT O0 000 O0 0 2 1 1 4 68 0000000000
CCL CNT V O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT. 10181.000 GRCH. CNT 119.448
NRAT. CNT -999.250 CCL.CNT -999.250
DEPT. 9836.000 GRCH. CNT 83.031
NRAT. CNT 9.464 CCL.CNT 87.990
NCNT. CNT -999.250 FCNT. CNT -999.250
NCNT. CNT 7095.863 FCNT. CA~f 481.267
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE
**** FILE HEADER ****
FILE NAME : EDIT .003
SERVICE · FLIC
VERSION : O01CO1
DATE · 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 3
AVERAGED CURVES
Compensated Neutron: Arithmetic average of edited passes for all curves.
LIS Tape V~-~--ification Listing
Schlumberger Alaska Computing Center
lO-FEB-1999 1~-~.'00
PAGE:
10
DEPTH INCREMENT O. 5000
PASSES INCLUDED IN AVERAGE
LDWG TOOL CODE PASS NUMBERS
CNT 1, 2,
$
REMARKS:
THIS FILE CONTAINS THE ARI~TIC AVERAGE OF THE
MAIN AND REPEAT PASSES. THE DATA WAS CLIPPED A~VD
DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 20
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 51
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NU?4B NUMB SiZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~.4 CODE (HEX)
DEPT FT O0 000 O0 0 3 1 2 4 68 0000000000
GRCH CNT GAPI O0 000 O0 0 3 i 1 4 68 0000000000
NCNT CNAV CPS O0 000 O0 0 3 1 1 4 68 0000000000
FCNT CNAV CPS DO 000 O0 0 3 ! 1 4 68 0000000000
NRAT CNAV O0 000 O0 0 3 1 i 4 68 0000000000
LIS Tape V~'~fication Listing
Schlumberger Alaska Computing Center
10 -FEB-1999
PAGE:
11
* * DA TA * *
DEPT. 10171. 500
NRAT. CNAV -999. 250
DEPT. 6769.500
NRAT. CNAV -999.250
GRCH. CNT
GRCH. CNT
134.569 NCNT . CNA V
52.118 NCNT. CNAV
-999.250 FCNT. CNAV
-999.250 FCNT. CNAV
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION · O01CO1
DATE · 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE . 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 4
RAW CURVES
Curves and log header data for each pass in separate files; raT~z background pass in last file
PASS NUMBER: 1
DEPTH INCREMENT: O. 1000
FILE SUNk/zARY
VENDOR TOOL CODE START DEPTH
MCNL 10202.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
STOP DEPTH
..........
6751.9
18-AUG-98
RELOO3iA
10230.0
10202.0
6766.0
LIS Tape V~fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999 1~0
PAGE: 12
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR):
DEPTH CONTROL USED (YES/NO):
10174.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
GR GAMMA RAY
MCNL MEMORY COMP NEUTRON
$
TOOL NUMBER
GR
MCNL
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT):
10268.0
BOREHOLE CONDITIONS
FLUID TYPE:
FLUID DENSITY (LB/G):
SURFACE TEMPERATURE (DEGF) :
BOTTOM HOLE TEMPERATURE (DEGF) :
FLUID SALINITY (PPM) :
FLUID LEVEL (FT) :
FLUID RATE AT WELLHEAD (BPM) :
WATER CUTS (PCT) :
GAS~OIL RATIO:
CHOKE (DEG) :
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL)
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
THERMAL
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT) :
BASE NORMALIZING WINDOW (FT) '.
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT RATE LOW SCALE (CPS): 0
FAR COUNT RATE HIGH SCALE (CPS): 2200
NEAR COUNT RATE LOW SCALE (CPS): 0
NEAR COUNT RATE HIGH SCALE (CPS): 32500
TOOL STANDOFF (IN):
REMARKS:
Depth correlated to ARCO PDC log faxed from town
when tool reached surface.
Tool had a lot of cement on it and in it when it
reached the surface.
The temperature output was not reliable on RIH after
18000 lbs. was satcked on the coil. (Temp showed
excessive increases and decreases on down logs).
This log shows only up logs and the temperature
did not definitively sho~¢ ~uomolies.
Cement in hole prevented ~ool from reaching expected TD.
LIS Tape V~fication Listing
Schlumberger Alaska Computing Center
10 -FEB- 1999 1~ 0
PAGE: 13
TD recorded on 1st tag = 10202 ft
TD recorded on 2nd tag = 10194 ft
Pressure data collected but not presented (per client
request)
THIS FILE CONTAINS THE RAW DATA FOR THE MAIN PASS.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
* * SET TYPE - 64EB * *
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 32
4 66 1
5 66
6 73
7 65
8 68 0.1
9 65 FT
11 66 32
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE AEAv~ NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT O0 000 O0 0 4 1 1 4 68 0000000000
CVEL PS1 F/HR O0 000 O0 0 4 1 1 4 68 0000000000
GR PS1 GAPI O0 000 O0 0 4 1 1 4 68 0000000000
NCNT PS1 CPS O0 000 O0 0 4 ! 1 4 68 0000000000
FCNT PS1 CPS O0 000 O0 0 4 1 1 4 68 0000000000
NRAT PS1 O0 000 O0 0 4 1 1 4 68 0000000000
CCLD PS1 V O0 000 O0 0 4 1 1 4 68 0000000000
MTEM PS1 DEGF O0 000 O0 0 4 1 1 4 68 0000000000
** DATA **
LIS Tape V~=ification Listing
Schlumberger Alaska Computing Center
lO-FEB-1999 IL~O
PAGE:
14
DEPT. 10202.451 CVEL.PS1
FCNT. PS1 -999.250 iVRAT. PS1
-999.250 GR.PS1
-999.250 CCLD.PS1
DEPT. 6752.050 CVEL.PS1 -999.250 GR.PS1
FCNT. PS1 -999.250 NRAT. PS1 -999.250 CCLD.PS1
-999.250 NCNT. PS1
-999.250 MTEM. PS!
-999.250 NCN~f. PS1
85.000 MTE~I. PS1
-999.250
-999.250
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE · 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 5
RAW CURVES
Curves and log header data for each pass in separate files; raw background pass in last file
PASS NUMBER: 2
DEPTH INCREMENT: O. 1000
FILE SUNR4ARY
VENDOR TOOL CODE START DEPTH
MCNL 10208.7
$
LOG HEADER DATA
DATE LOGGED:
SOFS~gARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT? :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
STOP DEPTH
9819.9
18-AUG-98
RELOO31A
10230.0
10202.0
6766.0
10174.0
LIS Tape V~'fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999
PAGE:
15
LOGGING SPEED (FPHR):
DEPTH CONTROL USED (YES/NO):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
GR G~ RAY
MCNL MEMORY COMP NEUTRON
$
TOOL NUMBER
GR
MCNL
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN)
DRILLERS CASING DEPTH (FT)
LOGGERS CASING DEPTH (FT)
10268.0
BOREHOLE CONDITIONS
FLUID TYPE:
FLUID DENSITY (LB/G) :
SURFACE TEMPERATURE (DEGF) :
BOTTOM HOLE TEMPERATURE (DEGF) :
FLUID SALINITY (PPM) :
FLUID LEVEL (FT) :
FLUID RATE AT WELLHEAD (BPM) :
WATER CUTS (PCT) :
GAS~OIL RATIO:
CHOKE (DEG) :
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
THERMAL
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT):
BASE NORMALIZING WINDOW (FT):
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT P~TE LOW SCALE (CPS): 0
FAR COUNT RATE HIGH SCALE (CPS): 2200
NEAR COO~IT RATE LOW SCALE (CPS): 0
NEAR COUNT RATE HIGH SCALE (CPS): 32500
TOOL STANDOFF (IN):
REMARKS:
Depth correlated to ARCO PDC log faxed from to~rn
when tool reached surface.
Tool had a lot of cement on it and in it when it
reached the surface.
The temperature output was not reliable on RIH after
18000 lbs. was satcked on the coil. (Temp showed
excessive increases and decreases on down logs).
This log shows only up logs and the ~emperature
did not definitively show anomolies.
Cement in hole prevented tool from reaching expected TD.
TD recorded on ist tag = 10202 ft
LIS Tape Verl-flcatlon Listing
Schlumberger Alaska Computing Center
1 O-FEB-1999
PAGE: 16
TD recorded on 2nd tag = 10194 ft
Pressure data collected but not presented (per client
request)
THIS FILE CONTAINS THE RAW DATA FOR THE REPEAT PASS.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 32
4 66 1
5 66
6 73
7 65
8 68 0.1
9 65 FT
11 66 32
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 !
** SET TYPE - CHAN **
NAME SERVUNIT SERVICE API API API API FILE NOWB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT O0 000 O0 0 5 I 1 4 68 0000000000
CVEL PS2 F/HR O0 000 O0 0 5 1 1 4 68 0000000000
GR PS2 GAPI O0 000 O0 0 5 1 1 4 68 0000000000
NCNT PS2 CPS O0 000 O0 0 5 i 1 4 68 0000000000
FCNT PS2 CPS O0 000 O0 0 5 1 1 4 68 0000000000
NRAT PS2 O0 000 O0 0 5 t 1 4 68 0000000000
CCLD PS2 V O0 000 O0 0 5 1 ! 4 68 0000000000
MTEM PS2 DEGF O0 000 O0 0 5 1 i 4 68 0000000000
** DATA **
LIS Tape Ve~£~fication Listing
Schlumberger Alaska Computing Center
lO-FEB-1999 l~.~JO
PAGE: 17
DEPT. 10208.658 CVEL.PS2
FCNT. PS2 -999.250 NP~T. PS2
DEPT. 9819.959 CVEL.PS2
FCNT. PS2 -999.250 NRAT. PS2
-999.250 GR.PS2
-999.250 CCLD. PS2
-999.250 GR.PS2
-999.250 CCLD. PS2
-999.250 NCNT. PS2
-999.250 MTEM. PS2
-999.250 NCNT. PS2
85.000 MTEM. PS2
-999.250
-999.250
-999.250
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION : O01CO1
DATE : 99/02/10
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 99/02/10
ORIGIN : FLIC
TAPE NAME : 99062
CONTINUATION # : 1
PREVIOUS TAPE :
COYk4ENT · ARCO ALASKA, PRUDHOE BAY, DS 05-17B, API #50-029-20271-02
**** REEL TRAILER ****
SERVICE NAME : EDIT
DATE : 99/02/10
ORIGIN : FLIC
REEL NAME : 99062
CONTINUATION # :
PREVIOUS REEL :
CObff4ENT : ARCO ALASF~, PRUDHOE BAY, DS 05-i7B, API #50-029-20271-02
Tape Subfile 1 is type: LIS
**** REEL HEADER
MWD
99/ 3/22
BHI
01
LIS Customer Format Tape
**** TAPE HEADER
MWD
99/ 3/22
99489
01
1 3/4" NaviGamma, Gamma Ray Data
LIS COMMENT RECORD(s):
~234567890~234567890~23456789~~23456789~~234567890~234567890~23456789~~23456789~
Remark File Version 1.000
gxtract File: Meader.tas
~Version Information
VERS. 1.20:
WRAP. NO:
~Well Information Block
~MNEM.UNIT Data Type Information
STRT. F 6765.0000: Starting Depth
STOP. F 10300.0000: Ending Depth
STEP. F 0.5000: Level Spacing
NULL. -999.2500: Absent Value
COMP. COMPANY: ARCO Alaska, Inc.
WELL. WELL: 05-17B
FLD . FIELD: Prudhoe Bay Unit
LOC . LOCATION: 1838' FSL
CNTY. CC~3NTY: North Slope
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 1 3/4" NaviGamma
REF . JOB REFERENCE: 99489
DATE. LOG DATE: 17 Aug 98
API . API NUMBER: 500292027102
CWLS log ASCII Standard -VERSION 1.20
One line per frame
~Parameter Information Block
~MNEM.UNIT Value Description
FL . 4569' MEL : Field Location
SECT. 32 : Section
TO~N.N liN : Township
RANG. 15E : Range
PDAT. M.S.L. : Permanent Datum
LMF . KB : Log Measured From
FAPD. FT 74 : Feet Above Perm. Datum
DMF . KB : Drilling Measured From
EKB .M 74' : Elevation Of Kelly Bushing
EDF .M N/A : Elevation Of Derrick Floor
EGL .M N/A : Elevation Of Ground Level
CASE. F 8700 : Casing Depth
OS2 . DIRECTIONAL : Other Services Line 2
~Remarks
(1) Ail depths are Measured Depths (MD) unless otherwise noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All Garm~a Ray data (GRAX) presented is realtime data.
(4) Well 05-17B is represented by runs 2, 3, 4, 6 and 7 which are
all Directional with Gamma Ray.
(5) Run 1 was used to dress the window and no new hole was logged.
RECEIVED
2 4 ]999
(6) Run 5 was used to relo~ from 8700' MD (8595' TVD) to 9096' MD
(8892' TVD) to obtain a tie-in depth with the original well.
(7)The well was kicked off from the wellbore of Well 05-17A
@ 8700' MD (8595' TVD) through a window cut in the liner.
(8)The break in the log from 9613' MD (8879' TVD) to 9621' MD
(8879' TVD) was due to depth adjustment applied after a tie-in.
(9) The interval from 10251' MD (8887' TVD) to 10270' MD (8887' TVD)
was not loqged due to sensor to bit offset.
(10) Well 05-17B was drilled to TD @ 10270' MD (8887' TVD) on Run 7.
(11) The Gamma Ray log has been depth shifted to match the Schlumberger
MCNL Gamma Ray logged on %8 August 1998.
(12) A Magnetic Declination correction of Z8.29 degrees has been
applied to the Directional Surveys.
-Mnemonics
-> SRAX = Gamma Ray MWD-API [MWD] (MWD-API units)
-> ROPS = Rate of Penetration (ft/hr)
-> TVD = True Vertical Depth (feet)
-Sensor Offsets
RUN GAMMA DIRECTIONAL
2 23.13 ft 28.16 ft
3 22.94 ft 27.97 ft
4 23.93 ft 28.96 ft
5 23.21 ft 28.24 ft
6 22.64 ft 27.67 ft
7 21.80 ft 26.80 ft
Tape Subfile: 1
73 records...
Minimum record length: 14 bytes
Maximum record length: 132 bytes
Tape Subfile 2 is type: LIS
**** FILE HEADER ****
MWD .001
1024
*** INFORMATION TABLE: CONS
MNEM VALU
LCC 150
CN ARCO Alaska, Inc.
WN 05-17B
FN Prudhoe Bay Unit
COON North Slope
STAT Alaska
LIS COMMENT RECORD(s):
~23456789~~234567890~234567890~234567890~234567890~23456789~~23456789~~234567890
{!!!!~!!!!!!!!!!!!! Remark File Version 1.000
1. The data presented here has been edited from the field raw data.
2. The data has been depth shifted to match the PDC supplied by ARCO
Alaska, Inc.
3. The PDC used is Schlumberger's MCNL Gamma Ray data, dated August 18, 1998.
INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM ODEP
1 GR GRAX 0.0
2 ROP
ROPS
FORMAT RECORD (TYPE~ 64)
Entry Type( 1) Size( 1) Repcode( 66)
Data record type is: 0
Entry Type( 2) Size( 1) Repcode(66)
Datum Specification Block Type is: 0
Entry Type( 3) Size( 2) Repcode(79)
Datum Frame Size is: 12 bytes
Entry Type( 4) Size( 1) R~pcode(66)
Logging direction is down (value= 255)
Entry Type( 5) Size( 1) Repcode(66)
Optical Log Depth Scale Units: Feet
Entry Type( 8) Size( 4) Repcode(68)
Frame spacing: 0.500000
Entry Type( 9) Size( 4) Repcode(65)
Frame spacing units: [~ ]
fndun c [F ] 1.00000000 3
Entry Type(11) Size( 4) Repcode( 68)
Number of frames per record is: 84
Entry Type(13) Size( 1) Repcode(66)
One depth per frame (value= 0)
Entry Type(16) Size( 1) Repcode(66)
Datum Specification Block Sub-type is:
Entry Block terminator.
Summary of entry types encountered:
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16
1 1 1 1 1 0 0 1 1 0 1 0 1 0 0 1
Rep Code Count Bytes
68 2 8
0.0
Sum: 2 8
fndun a [F ] 1.00000000
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size
1 GR MWD 68 1 API 4
2 ROP MWD 68 1 4
API API API API
Log Crv Crv
Length Typ Typ Cls Mod
4 99 995 99 1
4 99 995 99 1
* DATA RECORD (TYPE~ 0)
Total Data Records: 41
1014 BYTES *
Tape File Start Depth = 8590.000000
Tape File End Depth = 10274.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = Feet
**** FILE TRAILER ****
LIS representation code decoding summary:
Rep Code: 66 1 datum
Rep Code: 68 10111 datums
Rep Code: 79 2 datums
Tape Subfile: 2
48 records...
Minimum record length: 54 bytes
Maximum record length: 1014 bytes
Tape Subfile 3 is type: LIS
**** FILE HEADER ****
MWD .001
1024
*** INFORMATION TABLE: CONS
MNEM VALU
LCC 150
CN ARCO Alsaka, Inc.
~N 05-17B
FN Prudhoe Bay Unit
COON North Slope
STAT Alaska
LIS COMMENT RECORD(s):
~234567890~23456789~~23456789~~23456789~~23456789~~234567890~23456789~~~3456789~
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
1. The data presented here is the unedited field raw data.
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM ODEP
1 GRAX GRAX 0. O
2 ROPS ROPS 0.0
FORMAT RECORD (TYPE~ 64)
Entry Type( 1) Size( 1) Repcode(66)
Data record type is: 0
Entry Type( 2) Size( 1) Repcode(66)
Datum Specification Block Type is: 0
Entry Type( 3) Size( 2) Repcode(79)
Datum Frame Size is: 12 bytes
Entry Type( 4) Size( 1) Repcode(66)
Logging direction is down (value= 255)
Entry Type( 5) Size( 1) Repcode(66)
Optical Log Depth Scale Units: Feet
Entry Type( 8) Size( 4) Repcode(68)
Frame spacing: 0.500000
Entry Type( 9) Size( 4) Repcode(65)
Frame spacing units: [F ]
fndun c IF ] 1.00000000 3
Entry Type(11) Size( 4) Repcode(68)
Number of frames per record is: 84
Entry Type(13) Size( 1) Repcode(66)
One depth per frame (value= 0)
Entry Type(16) Size( 1) Repcode(66)
Datum Specification Block Sub-type is:
Entry Block terminator.
Summary of entry types encountered:
1 2 3 4 5
1 1 1 1 1
Rep Code Count
68 2
Sum: 2
fndun a [ F ]
7 8 9 10 11 12 13 14 15 16
0 1 1 0 1 0 1 0 0 1
Bytes 8
8 8
1. 00000000 3
FRAME SPACE = 0. 500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size
1 GRAX MWD 68 1 4
2 ROPS MWD 68 1 4
[]
* DATA RECORD (TYPE~ 0) 1014 BYTES *
Total Data Records: 41
Tape File Start Depth = 8587.000000
Tape File End Depth = 10273.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = Feet
**** FILE TRAILER ****
LIS representation code decoding summary:
Rep Code: 66 1 datum
Rep Code: 68 10123 datums
Rep Code: 79 2 datums
Tape Subfile: 3
48 records...
Minimum record length: 54 bytes
Maximum record length: 1014 bytes
Tape Subfile 4 is type: LIS
**** TAPE TRAILER ****
MWD
99/ 3/22
99489
01
API API API API
Log Crv Crv
Length Typ Typ Cls Mod
4 99 995 99 1
4 99 995 99 1
**** REEL TRAILER ****
MWD
99/ 3/22
BHI
01
Tape Subfile: 4 2 records...
Minimum record length: 132 byte~
Maximum record length: 132 bytes
End of execution: Mon 22 MAR 99 9:35a
Elapsed execution time = 1~26 seconds.
SYSTEM RETURN CODE = 0
Tape subfile 1 is type: LIS
[]
Tape Subfile 2 is type: LIS
GR
DEPTH -999.2500
8590.0000
8590.5000 _999.2500
8600.0000 24.4800
28.2290
8700.0000 124.5580
8800.0000 36.7200
8900.0000 73.4400
9000.0000
188.1900
9100.0000 164.4750
9200.0000
9300.0000 177.9420
76.5000
9400.0000
87.2100
9500.0000
68.8500
9600.0000
9700.0000 96.2910
9800.0000 131.6310
9900.0000 125.7150
10000.0000 88.7400
60.2160
10100.0000 155.2950
10200.0000
10274.0000 -999.2500
ROP
Tape File Start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth units
Tape Subfile 3 is type: LIS
GRAX
DEPTH -999. 2500
8587.0000
8587.5000 _999.2500
8600. 0000 26.7750
8700.0000 25.6840
8800. 0000 120. 8700
8900,0000 33. 6600
9000.0000 56.2200
9100. 0000 192.7800
9200.0000 148.4100
9300 0000 92.3870
· 75.0500
9400. 0000
9500. 0000 111. 9890
70.3800
9600- 0000
9700. 0000 91. 6980
9800. 0000 131. 6310
9900. 0000 127.1940
85.7820
10000- 0000 60- 9210
10100. 0000
10200- 0000 153. 0770
10273- 0000 -999.2500
Tape File start Depth
Tape File End Depth
Tape File Level Spacing
Tape File Depth units
[]
Tape Subfile 4 is type: LIS
_999.2500
_999.2500
_999.2500
_999.2500
32.7500
33.5000
12.9450
94.7000
69.2000
80.0000
76.5160
58.0000
75.7700
69.2000
29.0000
83.7000
52.0210
112.5000
133.3000
_999.2500
8590.000000
10274.000000
0.500000
Feet
ROPS
_999.2500
_999.2500
_999.2500
-999.2500
36.7000
49.3000
87.8000
76.9650
1B.O000
28.7000
63.1000
58.4450
15.0000
80.0000
29.0000
52.1000
50.0790
116.1000
124.1000
_999.2500
8587.000000
10273.000000
0.500000
Feet
RECEIVED
1999
A ska & Gas C<ms. e, om n
An or
