Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout205-079Abandoned
10/7/2023
JSB
RBDMS JSB 110323
By Grace Christianson at 2:11 pm, Oct 20, 2023
GxDSR-11/16/23
Digitally signed by Torin
Roschinger (4662)
DN: cn=Torin Roschinger (4662),
ou=Users
Date: 2023.10.20 13:33:23 -08'00'
Torin
Roschinger
(4662)Drilling Manager
10/20/23
Monty M
Myers
ACTIVITYDATE SUMMARY
8/21/2023
T/I/O= 2440/2460/0/9 (Assist Slickline) TFS U-3, Pumped 112 bbls crude to load the
IA. ***Job Conitnued on 8-22-23***
8/21/2023
***WELL S/I ON ARRIVAL***(sidetrack)
DRIFT TBG w/ 20' x 3.70" DMY WHIPSTOCK, UNABLE TO PASS 9445' SLM
DRIFT TBG TO CIBP @ 9755' MD w/ 10' x 2.75" DMY GUN
LOGGED RCH 40 ARM CALIPER f/ 9750' SLM - SURFACE
SET 4-1/2" WHIDDON CATCHER @ 8808' MD
PULLED BK-OGLV AT ST# 3 (5,731' md) & BK-LGLV AT ST# 4 (3,312' md)
SET BK-DGLV AT ST# 4 (3,312' md)
T-BIRD LOADED IA W/ 112 BBLS CRUDE
SET BK-DGLV AT ST# 3 (5,731' md)
***CONTINUE ON 8/22/23 WSR***
8/22/2023
***Job Continued from 8-21-23***
Pumped ~2.5 bbls down IA for MIT-IA ***PASS*** @2685 psi, 1st 15 min IA lost (50
psi), 2nd 15 min IA lost (15 psi) total loss of (65 psi) in 30 minute test.
Bled back ~3 bbls on the IA
FWHP= 2420/225/0 SL still on well upon departure.
8/22/2023
***CONTINUED FROM 8/21/23 WSR*** (Sidetrack)
T-BIRD PERFORMED PASSING MIT-IA TO 2500 psi
PULLED EMPTY 4-1/2" WHIDDON AT 8,808' MD
***WELL S/I ON DEPARTURE***
10/1/2023
CTU 9 - 1.75" CT - .156" wt - 15962' Job Scope = Mill XN Nipple (LH Tools)
Start Travel/Ticket 16:30 to 06-20A. MU BOT LH Milling Assembly. 3.800" Mill and
String Reamer. Gauge Ring 3.800" GO, 3.790" NO GO prior RIH.
***Continue to 10/2/23***
10/2/2023
CTU 9 - 1.75" CT - .156" wt - 15962' Job Scope = Mill XN Nipple (LH Tools)
RIH with BOT LH Milling Assembly. 3.800" Mill XN Nipple @ 8808'. Gauge mill and
string reamer @ surface. Both are considerably undergauge. Reamer = 3.73"
GO/3.72" NOGO Mill = 3.72" GO/3.71" NOGO. M/U new 3.80" no-go, 3.81" go mill
and string reamer. RIH and drift through xn multiple times. POOH, LD BOT millng
BHA. Mill and String Reamer no change in gauge after POOH. Diesel FP 38 bbls
still in tubing from previous run. RDMO
***Job Complete***
10/4/2023
T/I/O=VAC/250/0. RD Upper Tree. RU CDR Tree, Kill Line & 4 to 7 crossover. Torque
to API specs. PT Against MV. 300 psi low & 5000 psi High (PASSED). ***JOB
COMPLETE***. RDMO. Final Whp's= VAC/250/0.
Daily Report of Well Operations
PBU 06-20A
Activity Date Ops Summary
10/5/2023 Complete moving rig over 06-20. Sat down 07:00. Work through rig up checklists. LTT master and swab. Both leaking. Grease crew serviced. LTT passed to
3500#. Wells Support RU tiger tank and pressure tested hardline. NU MPD line. Nipple up BOPE. Clear rig floor. Ream coil. Install coil connector. Test Gas Alarms.
All passed. Pull test 50k, good. M/U BHI upper quick w/ no floats. M/U nozzle get on well. Fill reel MeOH followed by fresh water. Returns at tiger tank pump
remaining MeOH out of CT. Purge CT riser w/ air to TT then returns inside. Push slack forward 3.4 bpm / 4200 psi for 1 reel volume. Skid inj back remove nozzle.
PT inner reel iron and UQC to 6800 psi, good. Inspect packoffs. Flush and fluid pack all surface lines. Test BOPs as per Hilcorp and AOGCC regulations. All tests
250 / 3500 psi. Test witness waived by AOGCC Inspector Kam Stjohn. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind / Shear, R2, BL2, C15 - Pass.
Test 3 - Annular (2-3/8"), TIW1, B1, B4 - F/P on B4. Test 4 - Upper 2-3/8" Pipe / Slip, TIW2, B2, B3 Pass. Test 5 - Lower 2-3/8" Pipe / Slip, C5, C6, C8, TV2 Pass.
Test 6 - Choke A, Choke C Pass.
10/6/2023 Test 7 - C1, C4, TV1 Pass. Test 8 - 3" Pipe / Slip, C2, C3, Pass. Accumulator Draw down. Rig down testing equipment. Install drilling risers and QTS. BHI install
floats. Stab on Injector. Reverse. Test floats and riser to 3500#. Good test. Circulate Freshwater to calibrate micromotions. Load reel with 1% SL KCL. Load MPD
line with methanol spear. 350 psi. Rate in: 3.5 to 4 bpm @ 1700- 1800 psi. Pump 215 bbls. Come offline. Let pressure fall off. Pump across top to tiger tank. Flow
check well. 12 bph loss rate. PJSM. Make up BHA#1 NSAK packer whipstock. Verify ball valves open / EDC open. Make up injector. Test QTS. RIH w/ BHA #1.
Rate: 0.82 bpm in, 1.2 bpm out. Circ pressure: 139 psi. Mud Weight: 8.37 ppg in, 8.36 ppg out. Stop at 6000' MD. Check torque on reel saddle clamps. Gamma ray
not working. Troubleshoot. Log. Scale. PU to 8380' Log tie in. Log GR from 8380' correct -8'. Log CCL from 8700' to 9450' bit depth. Log GR again near set depth
correct -3'. BHI CCL matches program CCL, no correction needed. RIH to bit depth 9374.19' P/U to 41k. Leaves TOWS 9359.96'. Close EDC pressure up setting
tool shears at 2200 psi. Set 5k down hold for 1 min, solid. Whipstock set 0R orientation TOWS 9359.96'. P/U Open EDC. Circ well to mud still on slight losses 2.9 /
2.6 bpm. Good 10 min no-flow on bottom. POOH. At surface, Good 10 min no-flow. L/D BHA #1 - Whipstock setting tools. M/U BHA #2 - Window mill and reamer.
Both 3.81" Go / 3.80" NoGo. RIH BHA #2. Log tie-in from 8550' correct -20'. Close EDC, dry tag whipstock 9360'. P/U 50k go to 2.8 bpm. Mill 3.80" window from
9360.3'. 2.65 / 2.50 bpm In / Out. MW 8.72 / 8.74 ppg, ECD = 9.86 ppg. Pcirc 3400 - 3450 psi.
10/7/2023 Mill 3.80" window from 9360.3' to 9367.3. 2.65 / 2.50 bpm In / Out. MW 8.69 / 8.71 ppg, ECD = 9.90 ppg. Pcirc 3400 - 3450 psi. Appears we exited. Mill additional
foot to get string reamer out. Mill rathole from 9367.3 to 9377'. Perform reaming passes. Dry drift. Clean. P/U open EDC. Good 10 min no-flow. POOH 3.5 bpm /
3400 psi. Good 10 min no-flow at surface. Lift inj inspect CT 40' above CTC - Good. Skid inj back L/D BHA #2 - Window mill. Mill 3.80" Go / 3.79" NoGo. Reamer
3.81" Go / 3.80" NoGo. M/U nozzle jet stack. M/U BHA #3 - Build section. RIH BHA #3. Tie-in from 9290' correct -19'. Close EDC. Pass window no issues. Go to
min rate tag end of rathole 9376'. Get up wt + 2' go to 2.9 bpm. Drill 4.25" build from 9377'. Pcirc 3250 - 3400 psi, Window ECD = 9.90#. MW 8.68 / 8.73 ppg. 2.9 /
2.7 bpm. 9420' 5 bbls lo/hi vis. 100' wiper from 9530' clean up/down 49k / 25k. Drill 4.25" build from 9530'. Pcirc 3180 - 3500 psi, Window ECD = 9.97#. MW 8.67
/ 8.80 ppg. Flow 2.9 / 2.7 bpm.
10/7/2023Spud Date:
Well Name:
Field:
County/State:
PBE 06-20B
Prudhoe Bay East
Hilcorp Energy Company Composite Report
, Alaska
50-029-20799-02-00API #:
Drilling Manager
08/14/23
Monty M
Myers
By Grace Christianson at 12:12 pm, Aug 14, 2023
323-457
* BOPE test to 3500 psi.
* Variance to 20 AAC 25.112(i) approved for alternate plug placement
when production liner placed and cemented in place.
MGR16AUG23 SFD 8/22/2023 DSR-8/14/23
10-407
GCW 08/22/2023JLC 8/23/2023
08/23/23
Brett W.
Huber, Sr.
Digitally signed by
Brett W. Huber, Sr.
Date: 2023.08.23
09:21:00 -08'00'
RBDMS JBS 082423
To: Alaska Oil & Gas Conservation Commission
From: Trevor Hyatt
Drilling Engineer
Date: August 11, 2023
Re: PBU 06-20B Sundry Request
Sundry approval is requested to set a whipstock and mill the window in 06-20A, as part of the
pre-rig for drilling and completing of the proposed 06-20B CTD lateral.
Proposed plan for 06-20B Producer:
Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2" packer
whipstock. Coil will mill XN-nipple and a single string 3.80" window + 10' of formation out of the 4-1/2" liner pre-rig.
If unable to set the whipstock or mill the window, for scheduling reasons, the rig will perform that work.
See 06-20B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the
Nabors CDR2 rig. The rig will move in, test BOPE and kill the well. If unbale to mill window pre-rig, the rig will
perform that work. The well will kick off drilling in Zone 4 Ivishak and land in Zone 2. The lateral will continue in
Zone 4, 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner,
cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This
completion will completely isolate and abandon the parent Ivishak perfs.
This Sundry covers plugging the existing Ivishak perforations via the packer whipstock, liner cement job or liner
top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)).
Pre-Rig Work - (Estimated to start September 2023):
1. Slickline: Dummy WS drift and Caliper
a. Drift and Caliper past whipstock setting location
2. Fullbore: MIT
a. MIT-IA to 2,500 psi
3. E-line: Set 4-1/2” packer whipstock
a. Top of window at 9,360’ MD (top of whipstock = pinch point)
b. Oriented 0° ROHS (High Side)
4. Service Coil: Mill Window (mill with rig if needed)
a. Mill XN nipple at 8,808’ MD to 3.80”
b. Mill Window
I. MIRU Service Coil Window Milling Surface Kit
II. Give AOGCC 24hr notice prior to BOPE test
III. Test BOPE to 3500 psi. MASP with gas (0.10 psi/ft) to surface is 2,460 psi
IV. Mill 3.80” window plus 10’ of rat hole
V. Single string window exit out of 4-1/2” liner
5. Valve Shop: Pre-CTD Tree Work as necessary
Rig Work:
Reference PBU 06-20B PTD submitted in concert with this request for full details.
General work scope of Rig work:
1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 2,460psi
a. Give AOGCC 24hr notice prior to BOPE test
2. Mill Window (only if not done pre-rig)
3. Drill Build and Lateral
4. Run and Cement Liner*
5. RPM log and Perforate (only if not done post-rig)
6. Freeze Protect and RDMO
7. Set LTP* (if needed), RPM log and perforate post rig
* Approved alternate plug placement per 20 AAC 25.112(i)
pyppg(p
completion will completely isolate and abandon the parent Ivishak perfs.
Sundry 323-457
PTD 223-0XX
The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling
operation.
Window Milling Fluids Program:
A min EMW of 8.4 ppg KCL. KCl will be used as the primary working fluid and viscous gel sweeps will be
used as necessary to keep the hole clean.
The well will be freeze protected with a non-freezable fluid (typically a 60/40 methanol/water mixture) prior
to service coil’s departure.
Additionally, all BHA’s will be lubricated and there is no plan to “open hole” a BHA.
Disposal:
All Class l & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4.
Fluids >1% hydrocarbons or flammables must go to GNI.
Fluids >15% solids by volume must go to GNI.
Hole Size:
The window and 10’ of formation will be milled/drilled with a 3.80” OD mill.
Well Control:
BOP diagram is attached.
AOGCC will be given at least 24-hour notice prior to performing a BOPE function pressure test so that a
representative of the commission can witness the test.
Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and at least
3,500 psi.
BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System)
and will provide the results to the commission in an approved format within five days of test completion.
BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals
thereafter.
20 AAC 25.036 (c)(4)(C) requires that a BOPE assembly must include “a firewall to shield accumulators and
primary controls”. A variance is requested based on the result of the joint hazop with the AOGCC. For our
operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit,
and the accumulators are located on the backside of the Operations Cabin (opposite side from the well).
These are approximately 70' from the well.
Hazards:
PBU DS-06 is an H2S pad.
o The highest recorded H2S well on the pad was from 06-09 (395 ppm) in 1987.
o The last recorded H2S on 06-20A is 14 ppm taken 11/24/2021.
Reservoir Pressure:
The estimated reservoir pressure is expected to be 3,336 psi at 8,800’ TVD (7.3 ppg equivalent).
Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,460 psi (from estimated
reservoir pressure).
Reservoir pressure will be controlled with a closed circulating system and choke for backpressure to
maintain overbalance to the formation.
Trevor Hyatt CC: Well File
Drilling Engineer Joseph Lastufka
907-223-3087
Coiled Tubing BOPs
Well Date
Quick Test Sub to Otis -1.1 ft
Top of 7" Otis 0.0 ft
Distances from top of riser
Excluding quick-test sub
Top of Annular 2.75 ft
C L Annular 3.40 ft
Bottom Annular 4.75 ft
CL Blind/Shears 6.09 ft
CL 2.0" Pipe / Slips 6.95 ft B3 B4
B1 B2
Kill Line Choke Line
CL 2-3/8" Pipe / Slip 9.54 ft
CL 2.0" Pipe / Slips 10.40 ft
TV1 TV2
T1 T2
Flow Tee
Master
Master
LDS
IA
OA
LDS
Ground Level
3" LP hose open ended to Flowline
CDR2-AC BOP Schematic
CDR2 Rig's Drip Pan
Fill Line from HF2
Normally Disconnected
3" HP hose to Micromotion
Hydril 7 1/16"
Annular
Blind/Shear
2-3/8" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2-3/8" Pipe/Slips
3.0" Pipe / Slip
Operator Name:2.
Development Exploratory
Service
5
Permit to Drill Number:205-079
6.50-029-20799-01-00
PRUDHOE BAY, PRUDHOE OIL
Hilcorp North Slope, LLC 5.
Well Name and Number:8.
10.Field/Pools:
Well Class Before Work4.
Present Well Condition Summary:11.
Total Depth: measured feet
feet
Plugs measured feet
feet
Effective Depth: measured feet
feet
Packer measured feet
feettrue vertical true vertical
11393
9755
8889
8764
none
9755 , 9950
8098
Casing: Length: Size: MD: TVD: Burst: Collapse:
Conductor 81 20" 27 - 108 27 - 108 1490 470
Surface 2477 13-3/8" 26 - 2503 26 - 2503 5380 2670
Intermediate 9222 9-5/8" 24 - 9246 24 - 8550 10910 11500
Intermediate 8918 7" 24 - 8942 24 - 8266 7240 5410
Liner 321 7" 8952 - 9273 8276 - 8575 8160 7020
Perforation Depth: Measured depth: 9377 - 11288
feet
True vertical depth:8668 - 8993 feet
Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 21 - 8820
8764 8098Packers and SSSV (type, measured and
true vertical depth)
4-1/2" Baker S-3 Perm Packer
Liner 2584 4-1/2" 8809 - 11393 8141 - 8994 7780 6350
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
67412454257109
2627761 1981
27808
1018 799
Representative Daily Average Production or Injection Data
Prior to well operation:
Subsequent to operation:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name:
Contact Email:
Ryan Thompson
Ryan.Thompson@hilcorp.com
Authorized Name:Bo York
Authorized Title:
Authorized Signature with Date:Contact Phone:907.564.5280
Treatment descriptions including volumes used and final pressure:
13.
Operations Manager
Operations Performed1.
Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing
GSTOR WINJ WAG GINJ SUSP SPLUG
16. Well Status after work:Oil 5 Gas
Exploratory Development 5 Stratigraphic
15. Well Class after work:
Service
WDSPL
14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283)
Daily Report of Well Operations
Copies of Logs and Surveys Run
true vertical measured8994
Sundry Number or N/A if C.O. Exempt:
n/a
no SSSV
Junk
Packer
Printed and Electronic Fracture Stimulation Data
5
Operations shutdown
Change Approved Program
Senior Pet Engineer:Senior Res. Engineer:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Suspend 5Perforate Other Stimulate Alter Casing
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well
3.Address: 3800 Centerpoint Dr, Suite
1400, Anchorage, AK 99503
7.Property Designation (Lease Number):ADL 028311 PBU 06-20A
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
Stratigraphic
Other:
API Number:
Form 10-404 Revised 03/2020 Submit Within 30 days of Operations
21 -8151
By Samantha Carlisle at 10:17 am, Apr 15, 2021
Digitally signed by Bo York
DN: cn=Bo York, c=US, o=HIlcorp
Alaska LLC, ou=Alaska North
Slope, email=byork@hilcorp.com
Date: 2021.04.14 11:54:45 -08'00'
Bo York
DSR-4/15/21 RBDMS HEW 4/15/2021 SFD 4/19/2021MGR30JUL2021
ACTIVITYDATE SUMMARY
3/18/2021
***WELL S/I ON ARRIVAL***(perforating)
RAN 20' x 3-3/8" DUMMY GUN (max od = 3.65", oal = 24.3') w/ 3.70" CENT & SD
9,457' SLM (19* dogleg)
RAN CIPB DRIFT (3.61" BARBELL CENT) TO 9,820' SLM (no issues)
SET 4-1/2" WHIDDON ON XN @ 8,808' MD
PULLED & SET BK-OGLV IN ST#3 @ 5,731' MD (no visible damage)
PULLED & SET BK-LGLV IN ST#4 @ 3,312' MD (no visible damage)
PULLED WHIDDON FROM XN @ 8,808' MD
*bled ia from 2100psi to 1700psi in 40 minutes*
*tbg fluid level ~9,100'*
***WELL S/I ON DEPARTURE***
3/19/2021
T/I/O/OO = 2170/1700/0/0. Temp = SI. TBG FL (E-Line request). ALP = 2000 psi,
SI @ CV. TBG FL @ 8530' (130 bbls).
SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 17:40
3/20/2021
...Well shut in on arrival...(HES EL - Plug and Perf Z4)
SET NORTHERN SOLUTIONS 4-1/2" CIBP AT 9755'.
PERFORATE 9,377' - 9,397' WITH 20' x 3-1/8" GEODYNAMIC BASIX 22.7G, RDX,
6 SPF, 60 DEG PHASING, API ENTRANCE HOLE = 0.42", API RP 43
PENETRATION = 46.01"
***Job Complete.*** Well shut in on departure. DSO notified.
Daily Report of Well Operations
PBU 06-20A
Samuel Gebert Hilcorp Alaska, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 777-8337
Fax: 907 777-8510
E-mail: sam.gebert@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510
Received By: Date:
DATE: 12/21/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
DATA TRANSMITTAL
PBU 06-20A (PTD 205-079)
PLUG SET RECORD 12/03/2020
Please include current contact information if different from above.
Received by the AOGCC 12/22/2020
PTD: 2050790
E-Set: 34452
Abby Bell 12/23/2020
Operator Name:2.
Development Exploratory
Service
5
Permit to Drill Number:205-079
6.50-029-20799-01-00
PRUDHOE BAY, PRUDHOE OIL
Hilcorp North Slope, LLC 5.
Well Name and Number:8.
10.Field/Pools:
Well Class Before Work4.
Present Well Condition Summary:11.
Total Depth: measured feet
feet
Plugs measured feet
feet
Effective Depth: measured feet
feet
Packer measured feet
feettrue vertical true vertical
11393
9950
8957
8764
none
9950
8098
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 81 20" 27 - 108 27 - 108 1490 470
Surface 2477 13-3/8" 26 - 2503 26 - 2503 5380 2670
Intermediate 8918 7" 24 - 8942 24 - 8266 7240 5410
Production
Perforation Depth: Measured depth:
feet
True vertical depth: feet
Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 21 - 8820 20 - 8151
8764 8098Packers and SSSV (type, measured and
true vertical depth)
4-1/2" Baker S-3 Perm Packer
Liner 321 7" 8952 - 9273 8276 - 8575 8160 7020
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
667160610724144
393527907 1263
15051
156 668
Representative Daily Average Production or Injection Data
Prior to well operation:
Subsequent to operation:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name:
Contact Email:
Ryan Thompson
Ryan.Thompson@hilcorp.com
Authorized Name:Bo York
Authorized Title:
Authorized Signature with Date:Contact Phone:(907) 564- 5280
Treatment descriptions including volumes used and final pressure:
13.
Operations Manager
Operations Performed1.
Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing
GSTOR WINJ WAG GINJ SUSP SPLUG
16. Well Status after work:Oil 5 Gas
Exploratory Development 5 Stratigraphic
15. Well Class after work:
Service
WDSPL
14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283)
Daily Report of Well Operations
Copies of Logs and Surveys Run
true vertical measured8994
Sundry Number or N/A if C.O. Exempt:
n/a
no SSSV
Junk
Packer
Printed and Electronic Fracture Stimulation Data
5
Operations shutdown
Change Approved Program
Senior Pet Engineer:Senior Res. Engineer:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Suspend Perforate Other Stimulate Alter Casing
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well
3.Address: 3800 Centerpoint Dr, Suite
1400, Anchorage, AK 99503
7.Property Designation (Lease Number):ADL 028311 PBU 06-20A
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
Stratigraphic
Other:
API Number:
Form 10-404 Revised 03/2020 Submit Within 30 days of Operations
9853 - 11288
8922 - 8993
By Samantha Carlisle at 9:25 am, Dec 14, 2020
Digitally signed by Bo York
DN: cn=Bo York, c=US, o=HIlcorp
Alaska LLC, ou=Alaska North
Slope, email=byork@hilcorp.com
Date: 2020.12.12 17:04:03 -09'00'
Bo York
SFD 12/16/2020DSR-12/14/2020 RBDMS HEW 12/14/2020
MGR17FEB2021
ACTIVITYDATE SUMMARY
12/2/2020
Freeze protect FL with 112 bbls of crude and load TBG with 181 bbls crude for E-line.
Hang tags, notify DSO upon departure.
12/5/2020
***WELL S/I ON ARRIVAL*** (HES E-Line Drift & CIBP)
DRIFT W/ 3.70" WRP DUMMY TO 9,971' MD (no issues).
SET 4-1/2" NORTHERN SOLUTIONS CIBP AT 9950' MD.
ALL LOGS CORRELATED TO SLB RST LOG DATED 17-FEB-2011.
***JOB COMPLETE ON 05-DEC-2020***
Daily Report of Well Operations
PBU 06-20A
STATE OF ALASKA
. 0 LASKA OIL AND GAS CONSERVATION COMMIS
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed
Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑
Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: 0
2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-079
3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0
AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20799-01-00
7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number: PBU 06-20A
9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:
PRUDHOE BAY,PRUDHOE OIL
11.Present Well Condition Summary: RECEIVED
Total Depth: measured 11393 feet Plugs measured feet
true vertical 8994 feet Junkmeasured feet JUN 0 8
2017 O 17
Effective Depth: measured 11307 feet Packer measured 8764 feet /
true vertical 8993 feet Packer true vertical 8098 feet AOG CC
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 82 20"91.5#1440 27-108 27-108 1490 470
Surface 2477 13-3/8"72#L-80 26-2503 26-2503 4930 2670
Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Production
Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Perforation Depth: Measured depth: 9853-9863 feet feet 9885-9895 feet 11020-11140 feet 11258-11288 feet
True vertical depth: 8922-8926 feet feet 8934-8937 feet 9016-9004 feet 8994-8993 feet
Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 21 -8820 21 -8151
Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8764 8098
true vertical depth)
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
SCANNED JUL 2 4 2D 17
Treatment descriptions including volumes used and final pressure:
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 81 200 3045 1536 574
Subsequent to operation: 112 5291 5955 1475 369
14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0
Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas ❑ WDSPL 0
Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
N/A
Authorized Name: Odom,Kristine Contact Name: Odom,Kristine
Authorized Title: DS 06&13 PE Contact Email: Kristine.Odom@bp.com
Authorized Signature: YC 'j� Date: Contact Phone: (907)564-5365
Form 10-404 Revised 04/2017 ' T/— 71 -{ /��y/T67 R B D MS "" JUN 1 3 2017 Submit Original Only
• •
Alaska Oil and Gas Conservation Commission
333 West Seventh Avenue RECEIVED
Anchorage, AK 99501-3572
JUN 0 8 2017
RE: BP Exploration (Alaska), Inc. AOGCC
Report of Sundry Well Operations Summary
June 7, 2017
To Whom it May Concern:
Attached please find the Report of Sundry Well Operations for adding of Perforations for
Well 06-20A, PTD # 205-079.
Sincerely,
BP Exploration (Alaska) Inc.
P.O. Box 196612
Anchorage, AK 99519-6612
Attachment: Form 10-404
BP Exploration (Alaska), Inc.
P.O. Box 196612 Anchorage,AK 99519-6612
• •
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TREE= 4-1/16"FMC GEN 3 •
41VVH_LI EAD= 4-1/16"FMC S NOTES: ***WELL ANGLE>70°@ 9966'
ACTUATOR= AXELSON 06-20A `*'4-1/2"CHROME TBG***
OKB.ELEV= 74'
BF.ELEV= 40' ;. •
•KOP= 9277 ►4
Max Angle= 96"@ 11146' •i ►i
Datum MD= 9685' 0 I ,. 2202' H4-1/2"HES X NP,D=3.813"
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e 14
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♦.• ► ►4
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•� ►� 4 3312 3289 21 KGB2 DOME BK 16 07/25/15
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►jI 3 5731 5402 30 KGB2 SO BK 28 07/25/15
•� ►� 2 7643 7080 26 KGB2 DW BK 0 07/25/15
Minimum ID = 3.725" @ 8808' 0 ki1 8675 8016 22 KGB2 DMY BK 0 06/25/05
4-1/2" HES XN NIP % .
►/ ' • 8743' H4-1/2"HES X NP,D=3.813"
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► U4-112"TBG,12.6#,13CR-80, — 8820' 8809' H D7x 5"BKRZXPLTP, =4.430"
t4
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A►1 f /oi
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�i 1 ♦ ►♦4"•
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RECEIVED
• STATE OF ALASKA •
ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 9 2010
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed G
CC
Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0
Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0
Plug for Redrill El Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: 0
2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 205-079
3. Address: P.O.Box 196612 Anchorage, Development ® Exploratory 0
AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20799-01-00
7. Property Designation(Lease Number): ADL 0028311 8. Well Name and Number: PRUDHOE BAY UNIT 06-20A
9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:
PRUDHOE BAY,PRUDHOE OIL
11.Present Well Condition Summary:
Total Depth: measured 11393 feet Plugs measured feet
true vertical 8994 feet Junk measured feet
Effective Depth: measured 11308 feet Packer measured 8764 feet
true vertical 8993 feet Packer true vertical 8098 feet
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 82 20"91.5#H-40 27-108 27-108 1490 470
Surface 2477 13-3/8"72#L-80 26-2503 26-2503 4930 2670
Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Production
Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Perforation Depth: Measured depth: 11020 11140 feet 11258-11288 feet
True vertical depth: 9016-9004 feet feet 8994-8993 feet
Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 21 -8820 21 -8151
Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 8764 8098
true vertical depth)
12.Stimulation or cement squeeze summary:
Intervals treated(measured):
Treatment descriptions including volumes used and final pressure: SCANNED CI 017,
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 73 2777 6393 1449 315
Subsequent to operation: 66 6304 5873 1446 372
14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations Ed Exploratory ❑ Development ® Service ❑ Stratigraphic 0
Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I71 Gas 0 WDSPL 0
Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP 0 SPLUG 0
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
N/A
Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com
Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer
Signature C
lV�l 1 RtGi9N6A2L Date 12/29/16
Form 10-404 Revised 5/2015"1 fir VV77-- 3/2-5'/1 RBDMSL'- JAS L 5 2017 Submit Original Only
• •
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06-20A SAFETY'NOTES: ***WELL ANGLE>70°@ 9966'
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OKB.ELEV= 74'
BF ELEV= 40' 4
KOP= 9272' j
RECEINOD • -0 -.0-79
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"! l
BAKER JUL '07 201b PRINT DISTRIBUTION LIST
HUGHES AOGCC Please sign and return one copy of this transmittal form to:
COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska)Inc.
Petrotechnical Data Center,LR2-1 DATA LOGGED
WELL NAME 6-20A 900 E. Benson Blvd. 'TA/2w(R
Anchorage,Alaska 99508 M.K.BENDER
FIELD Prudhoe Bay Unit to acknowledge receipt of this data.
COUNTY North Slope Borough LOG TYPE RPM:PNC3D-CO
BHI DISTRICT Alaska ---
LOG DATE May 10,2016
AUTHORIZED BY Paul Canizares
EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE July 3,2016
Revision
STATUS Final Replacement: No Details:
Rev. Requested by:
COMPANY FIELD/ FINAL CD/DVD FINAL
ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX PRELIM (as,dlis,PDF,META, SURVEY REPORT
LOGS LOGS
CGM,Final Surveys) (Compass)
PERSON ATTENTION #OF PRINTS 8 UI-THIN 15 #OF COPIES #OF COPIES #OF COPIES
4 4 4 4 4 4 4 •
-
1 BP North Slope. 0 0 0 0 0
EOA,PBOC,PRB-20(Office 109)
D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker
900 E.Benson Blvd.
Anchorage,Alaska 99508
2 ConocoPhillips Alaska Inc. 0 1 1 0 0
Attn:Ricky Elgarico
ATO 3-344
700 G Street
Anchorage,AK 99510
3 ExxonMobil,Alaska 0 1 1 I 1 0 I 0
Attn:Lynda M.Yaskell and/or Lisa Boggs
3201 C Street,Suite 505
Anchorage,AK 99503
4 State of Alaska -AOGCC 0 I 1 I 1 0 0
Attn:Makana Bender
333 W.7th Ave,Suite 100
Anchorage,Alaska 99501
5 DNR-Division of Oil&Gas *** 0 1 1 1 0 0
Attn:James Hyun
550 West 7th Avenue,Suite 802
Anchorage,Alaska 99501
***Stamp"confidential"on all material deliver to DNR
6 BP Exploration(Alaska)Inc. 0 1 0 I 0 0 0
Petrotechnical Data Center,LR2-1
900 E.Benson Blvd.
Anchorage,Alaska 99508 g:41-\\:-1
Attn:David liter
TOTALS FOR THIS PAGE: 0 4 4 0 0
TOTALS FOR ALL PAGES: 0 4 4 0 0
· .
Image Project Well History File Cover Page
XHVZE
This page identifies those items that were not scanned during the initial production scanning phase.
They are available in the original file, may be scanned during a special rescan activity or are viewable
by direct inspection of the file.
c2 05- 0 r¡ç¡ Well History File Identifier
Production Scanning
Stage 1 Page Count from Scanned File: 22- (Count does ,ncludeyer sheet)
Page Count Matches Number in Scanning Preparation: V YES
BY ~ Date7JJ-7!07
Stage 1 If NO in stage 1, page(s) discrepancies were found: YES
Organizing (done)
o Two-sided 1111/111111 """11
RESCAN
~olor Items:
o Greyscale Items:
DIGITAL DATA
~iskettes, No. )
o Other, NolType:
o Poor Quality Originals:
o Other:
NOTES:
BY: ~
Date'f/a-7/07
I I
Date 7/~7/07
:l
Project Proofing
BY: CMaria ~
Scanning Preparation
BY:
Date:
BY:
Maria
Date:
Scanning is complete at this point unless rescanning is required.
o Rescan Needed 11/1111111111111111
OVERSIZED (Scannable)
o Maps:
o Other Items Scannable by
a Large Scanner
OVERSIZED (Non-Scannable)
o Logs of various kinds:
o Other::
mP
Is~lllllIlllIli 11111 Mf
/s/
11I/1111/11/11 ,,1/1
NO
I~ ~p
NO
/s/
11111111111I1111111
ReScanned
BY:
Maria
Date:
/s/
Comments about this file:
"IIIIIIIIII~ 11111
Quality Checked
11I1111111111111111
10/6/2005 Well History File Cover Page.doc
143Gt_ 06- 00A_
Regg, James B (DOA) p% 20S-D 710
From: Murphy, Gerald L [MurphyGL@bp.com] i 2�
Sent: Friday, December 21, 2012 7:45 AM
To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops
Lead; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team
Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB
East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Glasheen, Sean
Cc: AK, D &C DHD Well Integrity Engineer; AK, D &C Well Integrity Coordinator; Holt, Ryan P;
Climer, Laurie A
Subject: OPERABLE: 06 -20A (PTD #2050790) Tubing Integrity Restored
All, ✓
Producer 06 -20A (PTD #2050790) passed a TIFL on 12/20/2012 after replacing the screened orifice gas lift valve with a
dummy gas lift valve. The passing test indicates the presence of two competent barriers in the wellbore. The well is
reclassi ie d s Operable. -
Please call if you have any questions.
Thank you,
APR 3. 3. 2.0
Gerald Murphy
SCANNED
BP Alaska - Well Integrity Coordinator
Ioba ge is
I Organt2at?or
WIC Office: 907.659.5102
WIC Email: AKDCWeIIIntegritvCoordinator@ BP.com
From: AK, D &C Well Integrity Coordinator
Sent: Tuesday, December 04, 2012 9:31 PM
To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 P Ops Lead; AK, OPS FS3 DS
Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operat'. s Team Lead; Cismoski, Doug A;
Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt E. d r; AK, OPS PCC EOC TL; G GPB FS3
Drillsites; Glasheen, Sean
Cc: AK, D &C DHD Well Integrity Engineer
Subject: UNDER EVALUATION: 06 -20A (PTD #2050790) Sustained -sing Pressure on IA Above MOASP
All,
Producer 06 -20A (PTD #2050790) has confirmed su . ined casing pressure on the IA above MOASP. The
tubing /IA /OA /OOA pressures were equal to 2250 2230/0/0 on 12/01/2012. A failing TIFL was performed confirming a
lack of competent barriers. At this time, the ell is reclassified as Under Evaluation and may remain online while further
diagnostics are performed.
Plan Forward:
1. Slickline: Change out orifi gas lift valve
2. Downhole Diagnostics: • -rform TIFL
1
■
03/24/11
Seger NO. 5709
Alaska Data 8 Consulting Services Company: State of Alaska
2525 Gambell Street, Suite 400 Alaska Oil 8 Gas Cons Comm
Anchorage, AK 99503 -2838 Attn: Christine Shartzer
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Well Job B Log Description Date BL Color CD
01 -20 BBSK -00054 PRODUCTION PROFILE rnajri01111MIIMIIII 11110 ' - MS* 1
09-46 BMSA -00006 PRODUCTION PROFILE . 1 bCk ' - - 1
14 -05A BBKA -00090 PRODUCTION PROFILE fr '
12 -30 BBSK -00055 IU k,k L 7.7 e 1
D -22C BCRD -00086 � % 5 ' _, • + 1 1
09-02 BBSK -00052 h:TaL1.,A0.37 ,,a 11R fi entsrmoimism • _ t 1
��i C ' , �•
09-41 BBSK -00053 PRODUCTION PROFILE ^ y `�F '
15-05A BCRD -00084 L�. l . ' `. - �ralar 1 i
H -15 BCRD -00083 USIT — C. 02/11/11 d, - '1 1 1
F -35 BG4H -00037 PRODUCTION PROFILE O Y 1 02/22/11 1 . o . , 1
•
Z -31 BJOH -00009 INJECTION PROFILE tJ f, 02/12/11 1 -. •l, , • 1
06 -16 BCRD -00090 IJ:bls]1fs91,. L;rsil.VMM 1 15! � - •+ 1
X-17 BJOH -00008 �j ' ' - 3 1
H -20 BBSK -00051 . 02!13111 1 - • , 1 ,
06 -20A BNWP -00003 • 02/17/11 1 • . lc 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc. Alaska Data & Consulting Services
Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400
900 E. Benson Blvd. Anchorage, AK 99503 -2838
•
5 - ,
. MAR 9.5 20l
kV ,
i ,,
�, ism
{ i
tiff, ,
• •
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
January 1, 2010
by
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7th Avenue
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB DS 06
Dear Mr. Maunder,
~.o ~ °a9a
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS
06 that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10-404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Anna Dube,
at 659-5102.
Sincerely,
Torin Roschinger
BPXA, Well Integrity Coordinator
• •
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
DS-06
Date: 12/10/09
Well Name
PTD #
API #
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
inhibitor/
sealant date
ft bbls ft na al
os-o1 1750490 50029201720000 NA Sealed NA
06-02 1770780 50029202820000 NA Sealed NA
o6-o3A 1951520 50029201860100 NA Sealed NA
o6-oaA 2001020 50029201790100 NA Sealed NA
O6-o5 1780200 50029202980000 NA Sealed NA
06-066 2050980 50029202010200 NA Sealed NA
06-07 1780210 50029202990000 NA Sealed NA
o6-o8A 1951950 50029203000100 NA Sealed NA
os-o9 1790730 50o292oaoooooo NA Sealed NA
06-1oA 1981960 50029204020100 NA Sealed NA
06-11 1791100 50029204280000 NA Sealed NA
06-12A 1920640 50029204560100 NA 0.5 NA 3.40 10/6/2009
06-13A 2061020 50029204570100 NA Sealed NA
06-146 2090120 50029204580200 NA Sealed NA
06-15 1800320 50029204590000 NA Sealed NA
06-16 1800330 50029204600000 NA Sealed NA
os-18A 2090630 50029207670100 NA 0.3 NA 1.70 11/5/2009
06-19A 2081020 50029207910100 NA 1.5 NA 6.80 10/4/2009
06-20A 2050790 50029207990100 NA 1 NA 5.10 10/4/2009
06-21B 2080990 50029208020200 NA 6 NA 42.50 12/14/2009
06-22A 1930570 50029208060100 NA 1.5 NA 5.10 10/4/2009
06-23C 2080920 50029208080300 NA 4.6 NA 30.60 10/6/2009
os-24A 2000960 50029208220100 NA Sealed NA
~ r- Jl~
DATA SUBMITTAL COMPL1ANCE REPORT
7/2/2007
Permit to Drill 2050790
Well Name/No. PRUDHOE BAY UNIT 06-20A
Operator BP EXPLORATION (ALASKA) INC
MD 11393"""- TVD 8994 -- Completion Date 6/25/2005
Completion Status 1-01L
Current Status 1-01L
-------.-----
._---_.~
REQUIRED INFORMATION
Ft~ 50-!2~-~~~ >-
UIC N
Mud Log No
Samples No
Directional su~e~~
-----_._---~-----~.
DATA INFORMATION
Types Electric or Other Logs Run: MWD DIR / GR / RES / DEN / NEU
Well Log Information:
Electr
Digital Dataset
Med/Frmt Number
D Asc
(data taken from Logs Portion of Master Well Data Maint
LIS Veri, GR, FET, ROP,
NCNT, DRHO, RHOB
w/Graphics txt and PDF
LIS Veri, GR, FET, ROP,
NCNT,DRHO,RHOB
LIS Veri, GR, FET, ROP,
NCNT, DRHO, RHOB
w/Graphics txt and PDF
Redo!
9251 11333 Open 6/25/2007 LIS Veri, GR, FET, ROP,
NCNT,DRHO,RHOB
Redo!
Log Log Run Interval OHI
Scale Media No Start Stop CH Received
9190 11393 7/29/2005
9251 11343 Open 6/25/2007
9251 11343 Open 6/25/2007
9251 11333 Open 6/25/2007
Name
Directional Survey
C Lis
15237 Induction/Resistivity
15237 LIS Verification
C Lis
15239 Induction/Resistivity
15239 LIS Verification
Well Cores/Samples Information:
Name
Interval
Start Stop
Sample
Set
Number Comments
Sent
Received
ADDITIONAL INFORMATION
Well Cored? y~
Chips Received? ~
Daily History Received?
&N
0/N
Formation Tops
Analysis
Received?
~
--
Comments
--
Comments:
Permit to Drill 2050790
MD 11393
TVD 8994
-~"~--
Compliance Reviewed By:
DATA SUBMITTAL COMPLIANCE REPORT
7/2/2007
Well Name/No. PRUDHOE BAY UNIT 06-20A
Operator BP EXPLORATION (ALASKA) INC
Completion Date 6/25/2005
Completion Status 1-01L
Current Status 1-01L
~
Date:
API No. 50-029-20799-01-00
UIC N
I /JJ; ~/
e
e
e
e
WELL LOG TRANS MITT AL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West ih Avenue, Suite 100
Anchorage, Alaska 99501
June 21,2007
RE: MWD Formation Evaluation Logs: 06-20A Redo
AK-MW-3753522
1 LDWG formatted CD rom with verification listing.
API#: 50-029-20799-01
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry Drilling Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
;F, b'iE\J
Date: JUI\1 2, 1 l007
. SÏQI:\
i113s\<a Oil & Gas COOS. C<)ffiI1\1S
t\lltJ\f,(¡)(ß
BP Exploration (Alaska) Inc.
Petrotechnical Data Center MB33
900 E. Benson Blvd.
Anchorage, Alaska 99508
Signed:
{liL--
o~
6Jð6-~~ 15~
e
.
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.: Librarian
333 West ill Avenue, Suite 100
Anchorage, Alaska 99501
June 7, 2007
RE: MWD Formation Evaluation Logs: 06-20A
AK-MW-3753522
1 LDWG formatted CD rom with verification listing.
API#: 50-029-20799-01
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Sperry Drilling Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
BP Exploration (Alaska) Inc.
Petrotechnical Data Center MB33
900 E. Benson Blvd.
Anchorage, Alaska 99508
RECE~VE[p
Signed:
r2ft
Date!UN 2 1 Z007
lilaska Oil & Gas Cons. Commission
An(;hor~Je
c!)D5"'- DtL)
-p=. I ':)-d'3 "'::ì
. STATE OF ALASKA .. RECEIVED
ALASKA AND GAS CONSERVATION COM~ION JUl 2005
WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2 fi
Alaska Oil & Gas Cons. Commissiolì
AnchnrRtlp
1a. Well Status: a Oil OGas o Plugged o Abandoned o Suspended o WAG 1b. Well Class:
20AAC 25.105 20AAC 25.110 a Development o Exploratory
OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service
2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number
BP Exploration (Alaska) Inc. 6/25/2005 205-079
3. Address: 6. Date Spudded 13. API Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 6/18/2005 50-029-20799-01-00
4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number:
Surface: 6/22/2005 PBU 06-20A
349' FSL, 934' FEL, SEC. 02, T10N, R14E, UM 8. KB Elevation (ft): 15. Field / Pool(s):
Top of Productive Horizon:
569' FSL, 2603' FWL, SEC. 01, nON, R14E, UM 63.8' Prudhoe Bay Field / Prudhoe Bay
Total Depth: 9. Plug Back Depth (MD+ TVD) Pool
1416' FSL, 3425' FWL, SEC. 01, T10N, R14E, UM 11308 + 8993 Ft
4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+ TVD) 16. Property Designation:
Surface: x- 686053 y- 5940949 Zone- ASP4 11393 + 8994 Ft ADL 028311
---~-- --_.~- ----- 11. Depth where SSSV set 17. Land Use Permit:
TPI: x- 689584 y- 5941258 Zone- ASP4
~.._~- (Nipple) 2200' MD
Total Depth: x- 690384 y- 5942125 Zone- ASP4
19. Water depth, if offshore 20. Thickness of Permafrost
18. Directional Survey aYes ONo N/ A MSL 1900' (Approx.)
21. Logs Run: ~t c> r a.),\.;cl òvJ C¡z /3 ~ /<6S 75 -r~
MWD DIR / GR / RES / DEN / NEU
22. CASING, LINER AND CEMENTING RECORD /
.~~~~G ..... SETTING EPTH MD . SETf"I/'jGEP'rt-ttíID HOLE ·i AMOUNT
Wor.PERFT. GR,¡!.DE .·IOPi· . ~OTTOM lOP I tjOTTOM SIZE . vEIIn",,, "'.'''' . PULLED
20" 91.5# H-40 Surface 80' Surface 80' 30" 2205 # Poleset
13-3/8" 72# L-80 Surface 2509' Surface 2509' 17-1/2" 2155 sx Fondu, 400 sx Permafrost 'C'
9-5/8" 47# L-80 Surface 9252' Surface 8556' 12-1/4" 500 sx Class 'G', 300 sx PF 'C'
7" 29# L-80 Surface 9273' Surface 8575' 8-1/2" 325 sx 'G', 430 sx 'G', 126 sx 'G'
4-1/2" 11.6# L-80 8809' 11393' 8141' 8994' 6" 301 sx Class 'G'
23. Perforations open to Production (MD + rvD of Top and 24. OJ )f3ING
Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD)
2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 8818' 8762'
MD rvD MD TVD
11020' - 11140' 9016' - 9004' 25. p"ÇID, vEMENI ...ET¢1·
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protect w/ 75 Bbls of Diesel
26. PRODUCTION TEST
Date First Production: Method of Operation (Flowing, Gas Lift, etc.):
July 11, 2005 Gas Lift
Date of Test Hours Tested PRODUCTION FOR Oil-Bel GAs-McF WATER-Bel CHOKE SIZE GAS-Oil RATIO
7/22/2005 5.4 TEST PERIOD .. 557 2,234 701 84.29 4,013
Flow Tubing Casing Pressure CALCULATED .. Oil-Bel GAs-McF WATER-Bel Oil GRAVITY-API (CORR)
Press. 300 1,000 24-HoUR RATE 2,475 9,931 3,114
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". R8DMS BFL JUL 2 8 2005
f"_.'''' ·'·'7:··"··--¡
I 0'''''''' CT"" ,
None ~
. I~ ....
!:
I VE '""' ï'\ , f"'\ 1 ~ 1 ^ I GF'
i .-
Form 10-4b7 Revised 12/2003 CONTINUED ON REVER~I~ , \.J ~ 1 \J ï\ L-
28. GEOLOGIC MARKERS
NAME MD
Shublik A 9304'
Shublik B 9324'
Shublik C 9346'
Sadlerochit 9382'
Top CGL 9702'
Base CGL 9903'
Zone 2 B / 23SB 10201'
29.
RMATION TESTS
Include and briefly summarize test results. List intervals tested,
TVD and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
8604' None
8622'
8641'
8672'
8871'
8940'
9001'
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed
Terrie Hubble
Title
Technical Assistant Date 0
Prepared By Name/Number: Terrie Hubble, 564-4628
Drilling Engineer: Ken Allen, 564-4366
PBU 06-20A
Well Number
205-079
Permit No. / A roval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in
Alaska.
ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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
6/18/2005
9,300.0 (ft)
8.40 (ppg)
803 (psi)
FIT
8,605.0 (ft)
4,558 (psi)
Printed: 6/27/2005 11:14:31 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRILLING I
NABORS 2ES
Start:
Rig Release:
Rig Number:
6/8/2005
6/25/2005
Spud Date: 8/12/1982
End:
6/8/2005 22:00 - 00:00 2.00 MOB P PRE Prepare to move to D.S. #6 well # 20A. Rig was released @
22:00 hrs 6/8/2005. Move pits away from sub base. Bridle up.
Move camp & shop to D.S # 6.
6/9/2005 00:00 - 17:30 17.50 MOB P PRE Move shop & camp from U-Pad to D.S. # 20. PJSM, Lay
derrick over. Pull sub base off well & stage @ end of pad.
Clean location. Move sub to D.S. # 6.
17:30 - 19:30 2.00 MOB P PRE Lay herculite. spot & level sub on well DS # 6-20A. Berm sub.
19:30 - 22:00 2.50 MOB P PRE PJSM. Raise derrick, bridle down, R/U floor.
22:00 - 00:00 2.00 MOB P PRE Lay herculite & spot pits, hook up lines, R/U.
6/10/2005 00:00 - 03:00 3.00 MOB P PRE Spot mud pits, tanks, shop & out buildings. R/U top drive.
[Install new brake bands on drawworks.] Take on seawater.
PSCL
03:00 - 03:30 0.50 WHSUR P DECOMP Rig accepted on well 06-20 @ 03:00 hrs 6/10/2005. Hold
prespud meeting with drill crew & WSL.
03:30 - 06:00 2.50 WHSUR P DECOMP Rig up circ lines to tree. Install secondary annulus valve. R/U
DSM lubricator & pull back pressure valve. R/U & test circ lines
on tree.
06:00 - 10:00 4.00 WHSUR P DECOMP Line up on annulus and reverse diesel freeze protect from
tubing. Line up on tubing and pump 45 bbl soap pill, circ out
diesel freeze protect from annulus. Displace well to clean 8.5
ppg seawater, pump @ 6 bpm @ 620 psi. Monitor well.
10:00 - 11 :00 1.00 WHSUR P DECOMP Dry rod FMC BPV into hanger, test from below to 1000 psi, OK.
Open accuator valve.
11 :00 - 11 :30 0.50 WHSUR P DECOMP Blow down & rig down circ lines in cellar.
11 :30 - 13:30 2.00 WHSUR P DECOMP Nipple down tree & adaptor flange
13:30 - 16:30 3.00 BOPSU P DECOMP N/U 135/8" x 5000 psi BOPE.
16:30 - 00:00 7.50 BOPSU P DECOMP Fill BOP stack & choke, test BOP to 250 low & 3500 psi high
test. Witness of test waived by Chuck Scheve with AOGCC.
Test witnessed by WSL J.M. Willingham. Blanking plug
leaking, pull plug, rebuild & install, continue test.
6/11/2005 00:00 - 00:30 0.50 BOPSU P DECOMP Complete BOP test. R/D test equipment.
00:30 - 01 :00 0.50 PULL P DECOMP Pull hanger blanking plug & UD blanking plug running tool.
01 :00 - 02:00 1.00 PULL P DECOMP R/U DSM lubricator & pull TWC.
02:00 - 04:00 2.00 PULL P DECOMP M/U double spear on drill pipe, engage 5.5" tubing. BOLDS.
Pull hanger to rig floor.
04:00 - 05:00 1.00 PULL P DECOMP UD hanger & double spear fishing tools.
05:00 - 06:30 1.50 PULL P DECOMP CBU. Pump @ 300 gpm @ 500 psi. RIU Schlumberger
spooling unit for control & chemical injection lines. Hold PJSM
on hazards of corrossion inhibitor left in chemical injection line.
06:30 - 10:30 4.00 PULL P DECOMP POH with 5.5" tubing from 8903', spool up control lines to
SSSV.
10:30 - 11 :30 1.00 PULL P DECOMP Change out control lines spoolers.
11 :30 - 00:00 12.50 PULL P DECOMP POH with 5.5" 17 #, LTC tubing, spooling up 3/8" chemical
injection line. Recovered all of the injection line, 201 jts of
tubing, 1 Cameo SSSV valve, 8 GLM & 1 chemical injection
mandrel, 211 clamps & 22 stainless steel bands. Clear & clean
rig floor.
6/12/2005 00:00 - 00:30 0.50 PULL P DECOMP Clear & clean rig floor after laying down 5.5" tubing.
00:30 - 02:30 2.00 PULL P DECOMP R/U to test BOPE, set test plug & test annular preventor, top &
bottom pipe rams, dart & safety valve to 250 low & 3500 psi
high test. Used 4" test joint. Test witnessed by WSL James
Willingham. Set wear ring.
02:30 - 04:30 2.00 PULL P DECOMP P/U 9 5/8" packer milling BHA w/PRT, 3 boot baskets,bumper
Printed: 6/27/2005 11 :14:36 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRILLING I
NABORS 2ES
Start:
Rig Release:
Rig Number:
6/8/2005
6/25/2005
Spud Date: 8/12/1982
End:
6/12/2005 02:30 . 04:30 2.00 PULL P DECOMP jar, oil jar, pump out sub, 9 D.C.s & accelerator jars.
04:30 . 10:00 5.50 PULL P DECOMP RIH P/U drill pipe to 8890', top of 9 5/8" packer.
10:00 - 13:00 3.00 PULL P DECOMP Mill 9 5/8" AVA PPB packer. Pump @ 250 gpm @ 600 psi, 90
rpm, 5-6K torque, 5-8K WOB. Observed flow increase.
13:00 - 14:30 1.50 PULL P DECOMP Shut well in. SICP = 40 psi, SIDDP = 20 psi, 1 bbl pit gain. Circ
kick [packer gas] out holding 200 psi back pressure @ 3
bpm/400 psi. Open choke & check flow. Open annular
preventor as per WSL. Monitor well. Circ @ 6 bpm/600 psi.
14:30 - 17:00 2.50 PULL P DECOMP Mill 9 5/8" packer, push packer to top of 7" liner @ 8937'.
17:00·18:30 1.50 PULL P DECOMP Pump sweep & CBU @ 12 bpm/2000 psi. Observe well. Adjust
brakes, remove top drive blower hose, install air slips.
18:30 - 22:30 4.00 PULL P DECOMP POH with fish from 8937' to 348'. UWT = 185K, DWT = 145K.
22:30 - 00:00 1.50 PULL P DECOMP Handle BHA, UD accelerator jars, 6 DCs, jars, bumper sub &
boot baskets, clean baskets.
6/13/2005 00:00 - 02:00 2.00 PULL P DECOMP POH UD 9 5/8" packer, 2 jts of tail pipe, "XN" nipple, pup &
WLEG. Boot baskets full. UD fishing tools. Clear & clean rig
floor.
02:00 " 05:00 3.00 DHB P DECOMP PJSM. R/U Schlumberger Wire Line Service. Run # 1, 6.0"
GR/JB, CCL, Gamma Ray. Tools stopped @ 9050' (+-100'
inside 7" liner). POH.
05:00 - 08:00 3.00 DHB P DECOMP P/U 5.9" GR/JB CCL & Gamma Ray. RIH. Tools stopped @
8990'. POH.
08:00 - 10:30 2.50 CLEAN P DECOMP P/U PFCS-GR/CCL, RIH to 9050 & log up. POH R/D wire line.
10:30 - 11 :30 1.00 CLEAN P DECOMP RIH W/drill collars, POH & UD collars. UD bumper sub & jars.
Clear floor of all 6 1/4" BHA tools.
11 :30 - 13:30 2.00 CLEAN P DECOMP PJSM. P/U 515/16" flat bottom mill, 7" casing scraper, 12 ea
4.75" drill collars & XO = 405'.
13:30 - 15:00 1 .50 CLEAN P DECOMP RIH P/U 2335' of drill pipe.
15:00 - 16:30 1 .50 CLEAN P DECOMP Cut & slip 75" drill line. Inspect & adjust brakes.
16:30 - 17:00 0.50 CLEAN P DECOMP Service top drive & crown.
17:00 - 20:00 3.00 CLEAN P DECOMP RIH from 2740' to 8893', tag 7" liner top @ 8936'. Wash & work
liner top. RIH to 9545', wash down & tag cement @ 9590'.
UWT = 185K, DWT = 160K, RWT = 170K. Torque = 4/5K @
30 rpm.
20:00 - 21 :30 1 .50 CLEAN P DECOMP Pump high vis sweep, CBU @ 525 gpm/2100 psi, packer
rubber in returns. Monitor well, install air slips, blow down top
drive.
21 :30 - 00:00 2.50 CLEAN P DECOMP POH from 9590' for USIT log.
6/14/2005 00:00 - 01 :00 1.00 CLEAN P DECOMP POH from 3302' with mill, boot baskets & 7" casing scraper.
01 :00 - 02:00 1.00 CLEAN P DECOMP Stand back drill collars. UD 7" casing scraper assy. & clear rig
floor.
No recovery from boot baskets.
02:00 - 06:00 4.00 EVAL P DECOMP PJSM. R/U Schlumberger Wire Line Service. P/U USIT log &
RIH. Log up from 3500'.
06:00 . 09:00 3.00 EV AL P DECOMP Run # 2, RIH with 5.9" GR/JB GR/CCL to 9602', POH.
09:00 - 16:00 7.00 DHB P DECOMP Run # 3, RIH with EZSV bridge plug & set @ 9296', POH.
(Perform top job on 20" x 133/8" annulus. Fill 8' void with 15.7
ppg cement up to landing ring.)
Close blind rams & test EZSV & casing to 3500 psi, OK.
Run # 4, RIH with FasDrill plug & set @ 8954', POH & rig down
SWS
16:00 - 17:30 1.50 CLEAN P DECOMP PJSM. P/U 9 5/8" casing scraper & 6.76" O.D. polish mill BHA
Printed: 6/27/2005 11: 14:36 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRILLING I
NABORS 2ES
Start: 6/8/2005
Rig Release: 6/25/2005
Rig Number:
Spud Date: 8/12/1982
End:
6/14/2005 16:00 - 17:30 1.50 CLEAN P DECOMP to 412'.
17:30 - 21:00 3.50 CLEAN P DECOMP RIH from 412' to 8900'.
21 :00 - 21 :30 0.50 CLEAN P DECOMP Break eire, wash & rotate to liner top @ 8936', work polish mill
through tie back sleeve.
21 :30 - 22:30 1.00 CLEAN P DECOMP Pump high vis sweep @ 12.4 bpm/1680 psi.
22:30 - 00:00 1.50 CLEAN P DECOMP POH from 8936'.
6/15/2005 00:00 - 02:00 2.00 CLEAN P DECOMP POH with tie back sleeve polish mill from 6552' to 412'.
02:00 - 03:30 1.50 CLEAN P DECOMP Rack back drill collars, UD polish mill assy. Clear rig floor.
03:30 - 07:00 3.50 PULL P DECOMP Pull wear ring. MIU pack-off pulling tool & "J" into pack-off.
Heat well head with steam & pull pack-off to rig floor. Install
new pack-off, RILDS & test to 5000 psi.
07:00 - 07:30 0.50 DHB P DECOMP Test casing to 3500 psi for 30 min, OK.
07:30 - 17:00 9.50 CASE P TIEB1 PJSM. R/U casing tools, PIU muleshoe with liner tie-back
no-go & 2 float collars. RIH with 7" 26#, L-80 Buttress to 5858'.
Torque to 8000 ft. lb.
17:00 - 23:30 6.50 CASE P TIEB1 RIU torque turn equipment & RIH with 7",26#, TCII pipe, tag
liner tie-back sleeve with no-go @ 8942' & set down 15K
weight.
23:30 - 00:00 0.50 CASE P TIEB1 RID 125 ton YC elevators, change out bails & RIU 250 ton
elevators & PIU sling. R/U stabbing board and prepare to P/U
landing joint.
6/16/2005 00:00 - 01 :00 1.00 CASE P TIEB1 Change bails & casing elevators to 250 ton.
01 :00 - 01 :30 0.50 CASE P TIEB1 M/U landing joint, slack off and stab muleshoe into top of liner
tie-back sleeve @ 8942', set 15K weight down.
01 :30 - 02:00 0.50 CASE P TIEB1 PJSM W/drill crew & Schlumbergercement crew. RIU cement
head & circ lines, break circ.
02:00 - 04:30 2.50 CASE P TIEB1 Cement 7" liner tie-back. Pump 5 bbl H20, test lines to 3500
psi. Pump 40 bbl high vis pill, 104 bbl diesel freeze protect.
Release bottom plug, pump 138 bbl class "G" 13.5 ppg lead
cement followed by 27 bbl class "G" 15.8 ppg tail cement.
Release top plug and kick out with 5 bbl H20. Switch to rig
pumps, close annular preventor and open annulus valve for
taking returns to slop tank and displace @ 10 bpm with 342
bbl of seawater, bump plug with 3000 psi. Had 40 bbl diesel
returns. HWT = 245K, SWT = 208K.
04:30 - 05:30 1.00 CASE P TIEB1 RID cementers, blow down lines, drain stack and suck fluid out
of landing joint.
05:30 - 06:30 1.00 CASE P TIEB1 NID BOPE, raise stack.
06:30 - 07:30 1.00 CASE P TIEB1 Pull 250K on 7" casing, set slips on pipe & run in lock downs.
07:30 - 09:00 1.50 CASE P TIEB1 R/U casing cutter & cut pipe, UD cut joint, dress 7" stub.
09:00 - 10:30 1.50 CASE P TIEB1 Install new 13 5/8" x 5000 psi tubing spool & test pack off to
4300 psi.
10:30 - 13:30 3.00 CASE P TIEB1 Nipple up BOPE. Install secondary annulus valve on on new
tubing spool. Install wear ring & mouse hole.
13:30 - 14:00 0.50 CASE P TIEB1 Close blind rams & test casing & wellhead to 250/3500 psi, OK.
Hold test for 10 min.
14:00 - 16:00 2.00 CASE P TIEB1 MIU 6.062 milling assy. Boot baskets, string mill, jars, 12
D.C.s, 21 HWDP to 1052'.
16:00 - 19:00 3.00 CASE P TIEB1 RIH from 1052', fill pipe @ 3000' intervals. Tag cement @
8870'.
19:00 - 23:00 4.00 CASE P TIEB1 Wash & ream cement from 8870', drill plugs & float equipment
from 8922'. HWT = 195K, DWT = 140K, RWT = 165K. Torque
= 8K @ 60/80 rpm. WOB = 5/10. Pump @ 250 gpm/900 psi.
Printed: 6/27/2005 11 :14:36 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRILLING I
NABORS 2ES
Start: 6/8/2005
Rig Release: 6/25/2005
Rig Number:
Spud Date: 8/12/1982
End:
6/16/2005 19:00 - 23:00 4.00 CASE P TIEB1 Tag & drill out FasDrill plug @ 8951'. RIH, tag EZSV @ 9291'.
23:00 - 23:30 0.50 CASE P TIEB1 Close pipe rams, open kill line. Pressure up to 3500 psi and
test casing for 30 min, OK.
6/17/2005 00:00 - 00:30 0.50 CASE P TIEB1 Test 7" casing to 3500 psi for 30 min, OK.
00:30 - 01 :30 1.00 CASE P TIEB1 Displace well to 8.4 ppg FloPro mud, pump @ 12 bpm.
01 :30 - 02:30 1.00 CASE P TIEB1 Cut & slip drill line.
02:30 - 05:30 3.00 CASE P TIEB1 Pump dry job, POH with clean out assy from 9100' to 1052', to
PIU whipstock assy.
05:30 - 07:00 1.50 CASE P TIEB1 Rack back HWDP & drill collars, UD jars, bumper sub, boot
baskets & watermellon mill. No recovery in boot baskets. Clear
rig floor.
07:00 - 11 :00 4.00 STWHIP P WEXIT PJSM. P/U MWD & upload. MIU mills & scribe. P/U whipstock
& 1 stand of drill collars. Surface test MWD. RIH with drill
collars & HWDP. (Trip speed = 38 feet per min.)
11 :00 - 18:00 7.00 STWHIP P WEXIT RIH from 1122' to 8235'. (Trip speed = 38 feet per min.)
18:00 - 18:30 0.50 STWHIP P WEXIT Orient whipstock 65 degrees left of high side.Tag EZSV plug @
9296'. Set anchor, shear running bolt.
18:30 - 21 :30 3.00 STWHIP P WEXIT Mill window from 9273' to 9286'. HWT = 175K, DWT = 155K,
RWT = 165K. Torque off bottom = 4/5K amps. Torque on =
5/8K amps. Pump @ 235 gpm @ 1325 psi. TOW @ 9273',
BOW @ 9286'.
21 :30 - 00:00 2.50 STWHIP P WEXIT Drill new formation to 9298'
6/18/2005 00:00 - 00:30 0.50 STWHIP P WEXIT Drill new formation with casing mill from 9298' to 9300'. Pump
@ 235 gpm @ 1380 psi.
00:30 - 02:00 1.50 STWHIP P WEXIT Ream/work window. Pump Super Sweep, CBU. Good returns
in sweep. Total of 85 Ibs of metal cuttings recovered.
02:00 - 02:30 0.50 STWHIP P WEXIT Pull into casing. Perform FIT to 10.2 ppg EMW. 803 psi @
8594' TVD. Pump dry job. Remove top drive blower hose.
02:30 - 05:30 3.00 STWHIP P WEXIT POH from 9300' to 1121' for directional BHA.
05:30 - 07:30 2.00 STWHIP P WEXIT Stand back HWDP, UD window mills, clear rig floor.
07:30 - 08:30 1.00 STWHIP P WEXIT Service wear ring, flush BOPE and all surface equipment of
metal cuttings. Function rams.
08:30 - 10:00 1.50 STWHIP P WEXIT PJSM. MIU directional BHA, to 360', PIU 1 stand of drill pipe.
Shallow test MWD tools, 250 gpm @ 900 psi.
10:00 - 11 :30 1.50 STWHIP P WEXIT Adjust drawworks brakes.
11 :30 - 15:00 3.50 STWHIP P WEXIT RIH from 453' to 9220'. Fill pipe @ 3000' intervals.
15:00 - 15:30 0.50 STWHIP P WEXIT Service top drive.
15:30 - 16:30 1.00 STWHIP P WEXIT Orient @ 9220', slide through window, wash & ream from 9290'
to 9300'.
16:30 - 00:00 7.50 DRILL P PROD1 Drill new hole from 9300' to 9470'. ART = .61 hrs, AST = 5.52
hrs. HWT = 170K, DWT = 145K, RWT = 155K. Torque off
bottom = 4K, torque on = 6K.Pump @ 270 gpm @ 2050 psi.
6/19/2005 00:00 - 00:00 24.00 DRILL P PROD1 Drill directionally from 9470' to 10187'. HWT = 175K, SWT =
145K, RWT = 160K. Torque off bottom = 5-6K, on bottom =
6-8K. AST = 5.53, ART = 3.85. Losing mud @ 6 bph. Mix
CaC03.
6/20/2005 00:00 - 08:00 8.00 DRILL P PROD1 Directionally drill 6" hole from 10187' to 10438'.
08:00 - 09:00 1.00 DRILL P PROD1 Circulate, spot 50 bbl 25 ppb LCM pill. Pump @ 270 gpm @
1950 psi. Monitor well, static.
09:00 - 09:30 0.50 DRILL P PROD1 POH from 10438' to 9273', hole in good shape.
09:30 - 10:30 1.00 DRILL P PROD1 Observe well, 15 min static loss rate @ 4 bph. Drop dart &
open circ sub. Pump dry job. Remove top drive blower hose.
10:30 - 13:30 3.00 DRILL P PROD1 POH from 9237' to BHA @ 360'.
Printed: 6/27/2005 11:14:36 AM
legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRilLING I
NABORS 2ES
Start:
Rig Release:
Rig Number:
6/8/2005
6/25/2005
Spud Date: 8/12/1982
End:
6/20/2005 13:30 - 14:30 1.00 DRILL P PROD1 Stand back HWDP & drill collars. UD MWD & break bit.
14:30 - 17:00 2.50 DRILL P PROD1 M/U bit, change bend on mud motor to 1.5 degree. Orient. UD
HOC, upload MWD, shallow test. PJSM, load CTNISLD (nuke
tools). RIH with BHA to 386'.
17:00 - 19:00 2.00 DRILL P PROD1 PIU 15 joints of drill pipe, RIH to 4680'.
19:00 - 19:30 0.50 DRILL P PROD1 Service top drive.
19:30 - 22:00 2.50 DRILL P PROD1 RIH from 4680' to 9250'. Orient & pass through window from
9273' to 9286'. RIH to 9720'. Hook up top drive blower hose.
22:00 - 00:00 2.00 DRILL P PROD1 MADD pass from 9720' to 9945'. Pump @ 270 gpm @ 1875
psi, RPM = 30. Make MADD pass @ 200' per hour.
6/21/2005 00:00 - 02:00 2.00 DRILL P PROD1 MADD pass from 9945' to 10190'. RIH to 10395', Make MADD
pass from 10395' to bottom @ 10438'. Pump @ 270 gpm @
1875 psi, make pass @ 200 fph.
02:00 - 00:00 22.00 DRILL P PROD1 Drill directionally from 10438' to 11285'. AST 7.13 hrs, ART
9.11 hrs. UP 175K, DWN 135K, ROT 155K. Pump 270 gpm I
2150 psi. TQ 6K off btm, 8K on btm. Mud loss 5 to 10 bblsl hr
drilling.
6/22/2005 00:00 - 02:30 2.50 DRILL P PROD1 Dir Drill f/11285' to 11,393' TD, 8994'TVD. AST 0.42 hrs, ART
0.68 hrs Mud loss 5 bph.
02:30 - 03:00 0.50 DRILL P PROD1 Circ hole clean for wiper trip - pump high vis sweep around.
Monitor well
03:00 - 03:30 0.50 DRILL P PROD1 POOH to 10191'. No problems.
03:30 - 04:30 1.00 DRILL P PROD1 Mas Pass log f/1 01 00' to 10000'. RT 200 fph 270 gpm.1950
psi, 40 RPM
04:30 - 05:00 0.50 DRILL P PROD1 POOH f/10184' to 9273'. No problems. Clear floor.
05:00 - 06:00 1.00 DRILL P PROD1 Cut drilling line. Adjust brakes.
06:00 - 06:30 0.50 DRILL P PROD1 Service top drive. Lubricate rig.
06:30 - 07:30 1.00 DRILL P PROD1 RIH to 11393'. No problems.
07:30 - 09:30 2.00 DRILL P PROD1 Pump high vis sweep around - CBU. Spot 80 bbls liner running
pill. Monitor well.
09:30 - 10:30 1.00 DRILL P PROD1 POOH to 9272'. No problems. Dropp rabitt. Monitor well..
Remove blower hose.
10:30 - 13:30 3.00 DRILL P PROD1 POOH to run 4.5" liner.
13:30 - 16:30 3.00 DRILL P PROD1 LD BHA - down load LWD's. Clear floor.
16:30 - 17:00 0.50 CASE P RUNPRD RU to run 4.5" liner. PJSM.
17:00 - 20:00 3.00 CASE P RUNPRD RIH wI 63 jts 4.5" liner. MU liner hanger I packer- 55K.
20:00 - 20:30 0.50 CASE P RUNPRD Circ liner volume. Liner Wt. - 55k.
20:30 - 23:00 2.50 CASE P RUNPRD RIH slow wI 4.5" liner on DP to 9225'. Fill every 10 stands.
23:00 - 00:00 1.00 CASE P RUNPRD Circ pipe volume @ top of window - 200gpm @ 850 psi.
6/23/2005 00:00 - 01 :30 1.50 CASE P RUNPRD RIH wI 4.5" liner to 11,372'. UP 115K, DW 135k
01 :30 - 03:30 2.00 CASE P RUNPRD MU cementing head. Break circ. Wash liner to bottom @
11393'. Stage pumps up to 5 bpm 11150 psi. Recipicate pipe &
cond mud & hole for cement job. 175K up 150K dn. PJSM.
Batch up cement. PJSM.
03:30 - 04:30 1.00 CEMT P RUNPRD Dowell cement 4.5" liner. Tested lines to 4500 psi. Pumped 15
bbls CW100 @ 8.3 ppg, 25 bbls Mudpush-2 @ 9.5 ppg, 62.7
bbls cement @ 15.8 ppg. Washed out pump and lines.
Displaced wI 121 bbls (50 bbls perf pill) mud @ 5 bpm. Full
returns. Recipicated pipe. Bumped plug to 4,000 psi. CIP @
0430 hrs. .
04:30 - 05:00 0.50 CEMT P RUNPRD Set liner hanger wI shoe @ 11393'. Floats held. Released
Printed: 6/27/2005 11:14:36 AM
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
06-20
06-20
REENTER+COMPLETE
NABORS ALASKA DRILLING I
NABORS 2ES
Start: 6/8/2005
Rig Release: 6/25/2005
Rig Number:
Spud Date: 8/12/1982
End:
6/23/2005 04:30 - 05:00 0.50 CEMT P RUNPRD running tool. Set liner top packer wI 40k. Pressure to 1000 psi
and pulled out of liner. CBU @ 12 bpm - 2500 psi. Circ out 18
bbls good cmt.
05:00 - 06:30 1.50 CEMT RUNPRD Displace well to 8.4 ppg SW - 10 bpm I 2500 psi.
06:30 - 07:00 0.50 CEMT RUNPRD RD cmt head.
07:00 - 10:30 3.50 CEMT RUNPRD POOH LD running tool. Clear rig floor.
10:30 - 11 :30 1.00 CEMT RUNPRD PJSM. Test 4.5" liner to 3500 psi for 30 min. Held.
11 :30 - 12:00 0.50 PERFO OTHCMP RU handling tools for perf guns.
12:00 - 12:30 0.50 PERFO OTHCMP PU 27/8" perf gun and firing head.
12:30 - 13:00 0.50 PERFO OTHCMP Change handling tools for 2 7/8" DP
13:00 - 14:30 1.50 PERFO OTHCMP RIH PU 27/8" DP.
14:30 - 15:30 1.00 PERFO RREP OTHCMP Repair reostat on dwks.
15:30 - 17:00 1.50 PERFO OTHCMP RIH PU 2 7/8" DP to 2557'.
17:00 - 17:30 0.50 PERFO OTHCMP Change out handling tools.
17:30 - 21 :30 4.00 PERFO OTHCMP RIH wI perf guns on 4" DP. Tagged up at 11307' PBTD. Pulled
5jts DP and spotted bottom shot @ 11140'.
21 :30 - 22:30 1.00 OTHCMP PJSM. Perf f/11140' -11020' - broke circ I closed pipe rams.
Press up as per Schlumberger. Guns fires. Fluid level fell 5'.
22:30 - 23:00 OTHCMP Pulled 2 stands. Observed well 5 min - static. Pump dry job.
23:00 - 00:00 OTHCMP POOH wI perf guns laying down DP..
6/24/2005 00:00 - 04:30 OTHCMP POOH wI perf guns laying down 4.5" DP.
04:30 - 07:00 OTHCMP Change handling tools. POOH laying down 2 7/8" DP.
07:00 - 08:30 OTHCMP LD perf guns. All guns fired.
08:30 - 11 :30 OTHCMP MU Mule shoe sub. RIH to 3000' wI 4" DP. POOH LD DP
11 :30 - 13:00 RUNCMP Pulled wear ring. MU landing jt. Remove saver sub. Rig up to
run 4.5" chrome tubing.
13:00 - 17:30 4.50 RUNCMP PU tail pipe & packer - Run 4.5" chrome tubing to 3632'.
17:30 - 18:00 0.50 RUNCMP Service top drive Iluricate rig.
18:00 - 00:00 6.00 RUNCMP RIH wI Packer PU 4.5" chrome tubing to 8228'.
6/25/2005 00:00 - 01 :00 1.00 RUNCMP RIH PU 4.5" chrome tubing. Tagged up in liner tie back sleeve
@ 8820'.
01 :00 - 02:00 TUBHGR Space out tubing wI WLEG 6' inside tie back sleeve. Make up
tubing hanger. Land tubing. 125K UP, 110 K DN
02:00 - 03:00 1.00 WHSUR P TUBHGR RILDS. RU circ lines. Test to 1000 psi.
03:00 - 04:30 1.50 WHSUR P TUBHGR Reverse circ - displace well wI clean SW. Inhibited SW from
top GLM to Packer. 3 BPM @ 220 psi.
04:30 - 05:30 1.00 WHSUR P TUBHGR Drop 1 7/8" ball & rod. Pressure to 3,500 psi. Set PKR @
8764'. Test tbg to 3,500 psi for 30 min. Held. Bleed pressure to
1500 psi.
05:30 - 06:30 1.00 WHSUR P TUBHGR Pressure Annulus to 3,500 psi. Test csg I Packer to 3500 psi
for 30 min. Held. Bleed off tbg press I Sheared DCK, installed
TWCV in hanger. Test from below to 1,000 psi.
06:30 - 12:00 5.50 BOPSU P WHDTRE ND BOP stack. NU tree & adaptor flange. Test adaptor flange,
tbg head, and hanger to 5,000 psi. Held.
12:00 - 12:30 0.50 WHSUR P WHDTRE Test tree to 5,000 psi.
12:30 - 13:30 1.00 WHSUR P WHDTRE RU lubricator. Pulled TWCV. RD lubricator.
13:30 - 16:00 2.50 WHSUR P WHDTRE Freeze protect tbg I annulus. Little red pumped 75 bbls diesel
down annulus. U- Tube.
16:00 - 16:30 0.50 WHSUR P WHDTRE Dry rod BPV. Test from below to 1,000 psi.
16:30 - 17:00 0.50 WHSUR P WHDTRE Remove annulus valve. Secure cellar. Rig released @ 1700
hrs~.
Ç;, idS (()GOç
~
Printed: 6/27/2005 11:14:36AM
06-20A
-2,202' HES 4-1/2" X Nipplê
-2,500' Top pf Cement
7" LNR, 26#, L-80, TC11 Top -3,008'
7" LNR, 26#, L-80, BTC-Mod
4-1/2" TBG, 12.6#, 13Cr-80, Vam TOP
Est Top 7"x4-1/2" ZXP &HGR -8,809'
-8,743' HES 4-1/2" X Nipple iD
-8,763 BKR 7" x 4-1/2" BKR PKR
-8,786' 4-1/2" X Nipple
-8,807' HES 4-1/2"
-8,820' 4-1/2" WLEG
4-1/2" LNR, 11.6#,
Top of 7" HES EZSV -9,303'
-9,500' Top of Cement Plug
.
Halliburton
Global
.
Field: Prudhoe Bay
North Slope
UNITED STATES
Map System:US State Plane Coordinate System 1927
Geo Datum: NAD27 (Clarke 1866)
Sys Datum: Mean Sea Level
Map Zone:
Coordinate System:
Geomagnetic Model:
Alaska, Zone 4
Well Centre
bggm2005
Well: 06-20 Slot Name:
06-20
Well Position: +N/-S -964.55 ft Northing: 5940949.59 ft Latitude:
+E/-W 1354.88 ft Easting: 686052.90 ft Longitude:
Position Uncertainty: 0.00 ft
70 14 37.041 N
148 29 49.834 W
Wellpath: 06-20A Drilled From: 06-20
500292079901 Tie-on Depth: 9190.30 ft
Current Datum: 06-20A: Height 64.30 ft Above System Datum: Mean Sea Level
Magnetic Data: 6/16/2005 Declination: 24.95 deg
Field Strength: 57607 nT Mag Dip Angle: 80.87 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
29.00 0.00 0.00 76.24
Survey Program for Definitive Wellpath
Date: 7/13/2005 Validated: Yes Version: 5
Actual From To Survey Toolcode Tool Name
ft ft
1490.30 1490.30 Blind Tool (1490.30-1490.30) (0) BLIND Blind drilling
1490.90 9975.30 1 : Camera based gyro multisho (1490.30-9!J]eH3I}1~O-MS Camera based gyro mulfishot
9975.90 11327.87 06-20A (9273.00-11327.87) MWD+IFR+MS MWD + IFR + Multi Station
Survey
29.00 0.00 0.00 29.00 -35.30 0.00 0.00 5940949.59 686052.90 TIE LINE
1490.30 0.00 0.00 1490.30 1426.00 0.00 0.00 5940949.59 686052.90 BLIND
1590.30 0.25 167.00 1590.30 1526.00 -0.21 0.05 5940949.38 686052.95 CB-GYRO-MS
1690.30 0.25 221.00 1690.30 1626.00 -0.59 -0.04 5940949.00 686052.87 CB-GYRO-MS
1790.30 0.25 135.00 1790.30 1726.00 -0.91 -0.03 5940948.68 686052.89 CB-GYRO-MS
1890.30 0.00 180.00 1890.30 1826.00 -1.06 0.12 5940948.53 686053.05 CB-GYRO-MS
1990.30 0.50 112.00 1990.30 1926.00 -1.23 0.52 5940948.38 686053.46 CB-GYRO-MS
2090.30 0.25 157.00 2090.29 2025.99 -1.59 1.01 5940948.02 686053.95 CB-GYRO-MS
2190.30 0.25 111.00 2190.29 2125.99 -1.87 1.30 5940947.75 686054.25 CB-GYRO-MS
2290.30 0.50 136.00 2290.29 2225.99 -2.26 1.81 5940947.37 686054.77 CB-GYRO-MS
2390.30 0.25 110.00 2390.29 2325.99 -2.65 2.32 5940947.00 686055.28 CB-GYRO-MS
2490.30 1.75 124.00 2490.27 2425.97 -3.58 3.79 5940946.11 686056.78 CB-GYRO-MS
2590.30 3.00 98.00 2590.19 2525.89 -4.80 7.65 5940944.98 686060.66 CB-GYRO-MS
2690.30 6.75 86.00 2689.81 2625.51 -4.75 16.10 5940945.24 686069.12 CB-GYRO-MS
2790.30 8.75 84.00 2788.89 2724.59 -3.55 29.53 5940946.77 686082.51 CB-GYRO-MS
2890.30 10.75 79.00 2887.44 2823.14 -0.97 46.25 5940949.76 686099.16 CB-GYRO-MS
2990.30 16.00 75.00 2984.70 2920.40 4.38 68.74 5940955.66 686121.50 CB-GYRO-MS
3090.30 18.00 77.00 3080.33 3016.03 11.42 97.11 5940963.41 686149.69 CB-GYRO-MS
3190.30 19.75 79.00 3174.95 3110.65 18.12 128.75 5940970.88 686181.16 CB-GYRO-MS
3290.30 21.00 88.00 3268.71 3204.41 21.97 163.25 5940975.58 686215.55 CB-GYRO-MS
3390.30 22.50 92.00 3361.59 3297.29 21.93 200.29 5940976.46 686252.57 CB-GYRO-MS
3490.30 23.50 85.00 3453.66 3389.36 23.00 239.28 5940978.49 686291.52 CB-GYRO-MS
3590.30 25.50 83.00 3544.65 3480.35 27.36 280.51 5940983.87 686332.63 CB-GYRO-MS
3690.30 28.00 85.00 3633.95 3569.65 32.03 325.27 5940989.64 686377.26 CB-GYRO-MS
3790.30 30.00 87.00 3721.41 3657.11 35.39 373.63 5940994.19 686425.52 CB-GYRO-MS
3890.30 30.50 87.00 3807.79 3743.49 38.02 423.93 5940998.06 686475.74 CB-GYRO-MS
3990.30 30.75 87.00 3893.84 3829.54 40.69 474.81 5941001.98 686526.53 CB-GYRO-MS
4090.30 30.25 86.00 3980.00 3915.70 43.78 525.46 5941006.33 686577.09 CB-GYRO-MS
.
Halliburton
Global
.
4190.30 30.25 86.00 4066.39 4002.09 47.30 575.72 5941011.08 686627.24 CB-GYRO-MS
4290.30 30.25 86.00 4152.77 4088.47 50.81 625.97 5941015.84 686677.39 CB-GYRO-MS
4390.30 30.25 86.00 4239.15 4174.85 54.33 676.23 5941020.59 686727.54 CB-GYRO-MS
4490.30 30.25 86.00 4325.54 4261.24 57.84 726.48 5941025.34 686777.69 CB-GYRO-MS
4590.30 30.00 88.00 4412.03 4347.73 60.47 776.59 5941029.21 686827.72 CB-GYRO-MS
4690.30 30.00 88.00 4498.64 4434.34 62.22 826.56 5941032.18 686877.63 CB-GYRO-MS
4790.30 29.75 90.00 4585.35 4521.05 63.09 876.36 5941034.29 686927.38 CB-GYRO-MS
4890.30 29.75 90.00 4672.17 4607.87 63.09 925.98 5941035.51 686976.99 CB-GYRO-MS
4990.30 30.00 90.00 4758.88 4694.58 63.09 975.79 5941036.74 687026.78 CB-GYRO-MS
5090.30 29.75 90.00 4845.59 4781.29 63.09 1025.60 5941037.97 687076.57 CB-GYRO-MS
5190.30 29.25 90.00 4932.63 4868.33 63.09 1074.85 5941039.19 687125.80 CB-GYRO-MS
5290.30 29.25 92.00 5019.88 4955.58 62.24 1123.70 5941039.54 687174.65 CB-GYRO-MS
5390.30 29.75 92.00 5106.91 5042.61 60.52 1172.91 5941039.04 687223.89 CB-GYRO-MS
5490.30 30.00 92.00 5193.63 5129.33 58.78 1222.69 5941038.53 687273.69 CB-GYRO-MS
5590.30 30.00 92.00 5280.23 5215.93 57.03 1272.66 5941038.02 687323.69 CB-GYRO-MS
5690.30 30.00 92.00 5366.83 5302.53 55.29 1322.63 5941037.50 687373.68 CB-GYRO-MS
5790.30 30.00 92.00 5453.43 5389.13 53.54 1372.60 5941036.99 687423.67 CB-GYRO-MS
5890.30 30.25 92.00 5539.93 5475.63 51.79 1422.76 5941036.48 687473.86 CB-GYRO-MS
5990.30 30.25 92.00 5626.31 5562.01 50.03 1473.10 5941035.97 687524.23 CB-GYRO-MS
6090.30 30.00 92.00 5712.80 5648.50 48.28 1523.26 5941035.45 687574.41 CB-GYRO-MS
6190.30 30.00 92.00 5799.41 5735.11 46.54 1573.23 5941034.94 687624.41 CB-GYRO-MS
6290.30 29.75 92.00 5886.12 5821.82 44.80 1623.01 5941034.43 687674.21 CB-GYRO-MS
6390.30 30.00 92.00 5972.83 5908.53 43.06 1672.79 5941033.92 687724.02 CB-GYRO-MS
6490.30 29.25 92.00 6059.76 5995.46 41.34 1722.19 5941033.42 687773.44 CB-GYRO-MS
6590.30 29.25 92.00 6147.01 6082.71 39.63 1771.02 5941032.92 687822.30 CB-GYRO-MS
6690.30 29.00 92.00 6234.36 6170.06 37.93 1819.67 5941032.42 687870.97 CB-GYRO-MS
6790.30 29.00 92.00 6321.82 6257.52 36.24 1868.12 5941031.93 687919.44 CB-GYRO-MS
6890.30 28.50 91.00 6409.50 6345.20 34.98 1916.20 5941031.85 687967.54 CB-GYRO-MS
6990.30 28.00 91.00 6497.59 6433.29 34.15 1963.52 5941032.19 688014.86 CB-GYRO-MS
7090.30 28.00 91.00 6585.88 6521.58 33.33 2010.46 5941032.53 688061.81 CB-GYRO-MS
7190.30 27.75 91.00 6674.28 6609.98 32.52 2057.21 5941032.87 688108.56 CB-GYRO-MS
7290.30 27.00 91.00 6763.08 6698.78 31.71 2103.18 5941033.20 688154.53 CB-GYRO-MS
7390.30 26.25 91.00 6852.47 6788.17 30.93 2147.99 5941033.53 688199.34 CB-GYRO-MS
7490.30 25.75 91.00 6942.35 6878.05 30.17 2191.82 5941033.85 688243.18 CB-GYRO-MS
7590.30 25.50 91.00 7032.52 6968.22 29.41 2235.06 5941034.16 688286.42 CB-GYRO-MS
7690.30 25.50 93.00 7122.78 7058.48 27.91 2278.08 5941033.72 688329.46 CB-GYRO-MS
7790.30 25.75 94.00 7212.94 7148.64 25.27 2321.25 5941032.14 688372.68 CB-GYRO-MS
7890.30 26.00 95.00 7302.92 7238.62 21.84 2364.75 5941029.79 688416.25 CB-GYRO-MS
7990.30 26.00 95.00 7392.80 7328.50 18.02 2408.42 5941027.05 688460.00 CB-GYRO-MS
8090.30 26.00 95.00 7482.68 7418.38 14.20 2452.09 5941024.31 688503.75 CB-GYRO-MS
8190.30 25.75 100.00 7572.66 7508.36 8.52 2495.33 5941019.70 688547.10 CB-GYRO-MS
8290.30 25.50 101.00 7662.83 7598.53 0.64 2537.85 5941012.87 688589.81 CB-GYRO-MS
8390.30 24.25 101.00 7753.55 7689.25 -7.39 2579.14 5941005.86 688631.28 CB-GYRO-MS
8490.30 23.75 102.00 7844.90 7780.60 -15.49 2619.00 5940998.75 688671.32 CB-GYRO-MS
8590.30 22.25 103.00 7936.95 7872.65 -23.94 2657.14 5940991.24 688709.66 CB-GYRO-MS
8690.30 21.75 106.00 8029.67 7965.37 -33.31 2693.40 5940982.78 688746.14 CB-GYRO-MS
8790.30 20.25 107.00 8123.03 8058.73 -43.47 2727.76 5940973.46 688780.74 CB-GYRO-MS
8890.30 19.25 109.00 8217.14 8152.84 -53.90 2759.90 5940963.83 688813.12 CB-GYRO-MS
8990.30 19.75 114.00 8311.41 8247.11 -66.14 2790.92 5940952.36 688844.44 CB-GYRO-MS
9090.30 21.00 118.00 8405.16 8340.86 -81 .43 2822.18 5940937.85 688876.06 CB-GYRO-MS
9190.30 21.75 122.00 8498.29 8433.99 -99.66 2853.72 5940920.41 688908.04 CB-GYRO-MS
9273.00 21.96 122.84 8575.04 8510.74 -116.16 2879.71 5940904.55 688934.42 MWD+IFR+MS
.
Halliburton
Global
.
9310.27 24.53 114.57 8609.29 8544.99 -123.16 2892.60 5940897.87 688947.49 MWD+IFR+MS
9341.70 28.23 105.62 8637.46 8573.16 -127.88 2905.70 5940893.48 688960.70 MWD+IFR+MS
9372.09 32.02 98.85 8663.75 8599.45 -131.06 2920.60 5940890.67 688975.66 MWD+IFR+MS
9404.22 35.50 97.06 8690.45 8626.15 -133.51 2938.28 5940888.65 688993.40 MWD+IFR+MS
9434.69 37.37 89.88 8714.98 8650.68 -134.58 2956.31 5940888.03 689011.46 MWD+IFR+MS
9465.83 41.20 82.66 8739.09 8674.79 -133.25 2975.95 5940889.84 689031.06 MWD+IFR+MS
9496.96 44.91 78.32 8761.84 8697.54 -129.71 2996.90 5940893.89 689051.90 MWD+IFR+MS
9527.72 48.11 75.51 8783.01 8718.71 -124.65 3018.62 5940899.49 689073.50 MWD+IFR+MS
9558.90 52.71 72.50 8802.87 8738.57 -118.01 3041.70 5940906.70 689096.41 MWD+IFR+MS
9589.79 56.91 69.81 8820.67 8756.37 -109.85 3065.58 5940915.45 689120.07 MWD+IFR+MS
9619.81 60.53 67.15 8836.26 8771.96 -100.43 3089.44 5940925.45 689143.69 MWD+IFR+MS
9654.44 64.21 63.21 8852.32 8788.02 -87.54 3117.26 5940939.03 689171.19 MWD+IFR+MS
9686.40 66.99 57.69 8865.53 8801.23 -73.18 3142.56 5940954.00 689196.12 MWD+IFR+MS
9716.10 69.05 53.57 8876.65 8812.35 -57.63 3165.28 5940970.11 689218.45 MWD+IFR+MS
9748.30 71.21 52.34 8887.60 8823.30 -39.39 3189.45 5940988.94 689242.16 MWD+IFR+MS
9809.85 70.43 51.91 8907.82 8843.52 -3.70 3235.34 5941025.75 689287.15 MWD+IFR+MS
9872.12 69.65 52.53 8929.07 8864.77 32.16 3281.60 5941062.74 689332.50 MWD+IFR+MS
9903.78 69.07 52.36 8940.23 8875.93 50.22 3305.08 5941081.37 689355.54 MWD+IFR+MS
9934.73 69.06 52.74 8951.29 8886.99 67.80 3328.03 5941099.51 689378.04 MWD+IFR+MS
9966.39 71.48 54.04 8961.98 8897.68 85.57 3351.95 5941117.86 689401.52 MWD+IFR+MS
9997.82 72.84 54.11 8971.61 8907.31 103.12 3376.18 5941136.00 689425.30 MWD+IFR+MS
10027.96 75.03 53.59 8979.95 8915.65 120.20 3399.57 5941153.66 689448.26 MWD+IFR+MS
10060.47 78.25 53.47 8987.46 8923.16 139.00 3425.00 5941173.08 689473.22 MWD+IFR+MS
10091.38 81.39 54.05 8992.92 8928.62 156.98 3449.53 5941191.66 689497.30 MWD+IFR+MS
10123.57 85.18 54.39 8996.69 8932.39 .175.67 3475.46 5941210.98 689522.76 MWD+IFR+MS
10157.38 87.41 54.07 8998.87 8934.57 195.39 3502.84 5941231.37 689549.63 MWD+IFR+MS
10185.48 86.85 54.05 9000.28 8935.98 211.87 3525.56 5941248.40 689571.94 MWD+IFR+MS
10278.74 88.83 55.01 9003.79 8939.49 265.94 3601.45 5941304.33 689646.47 MWD+IFR+MS
10372.19 86.54 54.20 9007.57 8943.27 320.02 3677.56 5941360.26 689721.22 MWD+IFR+MS
10491.52 87.96 50.67 9013.29 8948.99 392.67 3772.03 5941435.22 689813.86 MWD+IFR+MS
10586.40 89.81 47.23 9015.14 8950.84 454.96 3843.55 5941499.25 689883.82 MWD+IFR+MS
10679.39 88.89 44.43 9016.20 8951.90 519.74 3910.24 5941565.66 689948.88 MWD+IFR+MS
10773.06 87.41 45.29 9019.22 8954.92 586.10 3976.27 5941633.62 690013.25 MWD+IFR+MS
10866.52 89.20 45.15 9021.98 8957.68 651.90 4042.58 5941701.04 690077.91 MWD+IFR+MS
10959.15 93.46 43.78 9019.84 8955.54 717.98 4107.43 5941768.68 690141.11 MWD+IFR+MS
11052.87 95.31 40.88 9012.67 8948.37 787.05 4170.35 5941839.28 690202.30 MWD+IFR+MS
11146.17 95.62 36.90 9003.78 8939.48 859.32 4228.65 5941912.97 690258.80 MWD+IFR+MS
11238.82 94.45 32.91 8995.64 8931.34 934.99 4281.45 5941989.92 690309.71 MWD+IFR+MS
11327.87 89.01 29.66 8992.96 8928.66 1011.02 4327.64 5942067.06 690354.01 MWD+IFR+MS
11393.00 89.01 29.66 8994.08 8929.78 1067.61 4359.87 5942124.42 690384.82 PROJECTED to TD
.
.
AOGCC
Helen Warman
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
DEFINITIVE
Re: Distribution of Survey Data for Well 6-20A
Dear Dear Sir/Madam:
Enclosed is one disk with the *.PTT and *.PDF files.
Tie-on Survey:
Window / Kickoff Survey:
Projected Survey:
9,190.30 I MD
9,273.00 I MD
11,393.00' MD
(if applicable)
PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO
CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND
RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE
ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Carl Ulrich
6900 Arctic Blvd.
Anchorage, AK 99518 1/ I/·J / / (/
Date ]1 ~ç Signed I t~ ÚtúJJ
Please call me at 273-3545 if you have any questions or concerns.
Regards,
Carl Ulrich
Survey Manager
Attachment(s)
17 -Jul-05
;{ ð r- (Jlq pJ,
Vi·. r.' 1M lr f? r
... ,1 ,t!, III?
QV IJ LrlJ u !.b
.
(ñ1f6
¡.lill·. IU.: I ~ ,
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....
.
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¡it
,IiJ \
!J\j
FRANK H. MURKOWSKI, GOVERNOR
AI,ASIiA. ORAND GAS
CONSERVATION COMMISSION
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAJ< (907)276-7542
Bill Isaacson
Senior Drilling Engineer
BP Exploration (Alaska) Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
Re: Prudhoe Bay 06-20A
BP Exploration (Alaska) Inc.
Permit No: 205-079
Surface Location: 349' FSL, 934' FEL, SEC. 02, TI0N, RI4E, UM
Bottomhole Location: 999' FSL, 3190' FWL, SEe. 01, TI0N, RI4E, UM
Dear Mr. Isaacson:
Enclosed is the approved application for permit to redrill the above development well.
This permit to redrill does not exempt you from obtaining additional permits or approvals
required by law from other governmental agencies, and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
Commission reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure
to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or a Commission order, or the terms and conditions of this permit may
result in the revocation or suspension of the permit. Please provide at least twenty-four (24)
hours notice for a representative of the Commissio 0 'tness any required test. Contact the
Commission's petroleum field inspector at (907) 65 -36 (pager).
DATED this -Sday of May, 2005
cc: Department of Fish & Game, Habitat Section wlo encl.
Department of Environmental Conservation wlo encl.
..
~ fA '5'7),'~ ~_:. .~~t;1~ ~ ~1 /..0 ())
ALAS.OIL AND ~~~~g~s~~.J:~ON AMISSIO~E~.:~ ·:·O~ 0
PERMIT TO DRILL MA 2 L
( 20 AAC 25.005 L A.laska Oil & Cml$. Gmnmisslon
'*
1 a. Type of work o Drill II Redrill rb. Current Well Class 0 Exploratory II DevelopmentÞCn~Utèltiple Zone
ORe-Entry o Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone
2. Operator Name: 5. Bond: 1m Blanket o Single Well 11. Well Name and Number:" ozI. /
BP Exploration (Alaska) Inc. Bond No. 2S100302630-277 PBU 06-20A "5 / 0$"
3. Address: 6. Proposed Depth: 12. Field / Pool(s):
P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11028 rvD 9048 Prudhoe Bay Field / Prudhoe Bay
4a. Location of Well (Governmental Section): 7. Property Designation: Pool
Surface: ADL 028311
349' NSL, 934' WEL, SEC. 02, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date:
Top of Productive Horizon: /
486' NSL, 2515' EWL, SEC. 01, T10N, R14E, UM June 1, 2005
Total Depth: 9. Acres in Property: 14. Distance to Nearest Property:
999' NSL, 3190' EWL, SEC. 01, T10N, R14E, UM 2560 31,850'
4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool
Surface: X-686053 Y-5940949 Zone- ASP4 (Height above GL): 63.8 feet 06-07 is 1161' away at 11014' MD
16. Deviated Wells: Kickoff Depth: 9283 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.03;>
Maximum Hole Angle: 87 deQrees Downhole: 3250 Surface: 2370
18. casing Program: Specifications Setting Depth Qu~ntity of cement
Size TOD . Bottom c.1.or sacks\
Hole Casino Weiaht Grade CouDlina Lenath MD rvD MD rvD lincludino staoe data)
N/A 7" 26# L-80 TCII/ BTC-M 8949' Surface Surface 8949' 8273' 460 sx Class 'G', 353 sx Class 'G' ;"
6" 4-1/2" 11.6# L-80 LTC 2180' 8849' 8179' 11029' 9050' 250 sx Class 'G' /
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill ANDRe-entry Operations)
Total Depth MD (ft): Total Depth rvD (ft): I Plugs (measured): 1 Effective Depth MD (ft):1 Effective Depth rvD (ft): I Junk (measured):
9985 9228 9788 9788 9048 None
Casing Length Size Cement Volume MD rvD
r 80' 20" :>205# Poleset 80' 80'
2509' 13-3/8" 2155 sx Fondu, 400 sx Permafrost 'C' 2509' 2509'
9252 9-5/8" 500 sx Class 'G', 300 sx Permafrost 'C' 9252' 8556'
Production
UnAr 1028' 7" 325 sx Class 'G' 8949' - 9977' 8273' - 9221'
Perforation Depth MD (ft): 9750' - 9793' [perfOration Depth rvD (ft): 9014' - 9053'
20. Attachments 1m Filing Fee, $100 o BOP Sketch 1m Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis
1m Property Plat o Diverter Sketch o Seabed Report 1m Drilling Fluid Program 1m 20 MC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken Allen, 564-4366
Printed Name Bill Isaacson Title Senior Drilling Engineer
1 k. 1 Date s/'i-/oS Prepared By Name/Number.
Sionature - Phone 564-5521 Terrie Hubble, 564-4628
Commission Use Only
Permit To Drill .1 API Number: I Permit APprova~ ~ -I See cover letter for
Number: 20:5 - 079 50- 029-20799-01-00 Date: 'Sí;).3 () ç- other requirements
Mud Log Required [J Yes ~No
Other: ·T.e c; t- Hydroge~ Measures Jgyes iJ No Directional Survey Required 'j8Yes ! ì No
~ 00 p'l.
~¿ jtú1 ¡ APPROVED BY Date 5í~-s / O~
ADcrove ; . THE COMMISSION
Form 10-401 ~d 06~OV ê "-- ~bmit 111 Duplicate
~
.
.
Planned Well Summary
Well 06-20A Sidetrack I I Target I Zone 2B
horizontal
Objective
I AFE Number: PBD 4P2379 I I API Number: 50-029-20799-01
Surface Northin Eastin Offsets TRS
Location 5,940,949.59 686,052.90 4930.2' FNL I 934.9' FEL 10N,14E,2 /
Target Northin Eastin Offsets TRS
Location 5,941 ,173 689,498 4793' FNL/2765' FEL 10N,14E,1
Bottom Northin Offsets TRS /
Location 5,941,702 4281' FNL I 2089' FEL 10N,14E,1
Planned KOP:
Planned S ud:
9,283' md
06/01/05
Planned TD:
Planned TVD:
11,028' md
9,048'
1 Rig:
1 Nabors 2ES I
I GL:
135.3'
I RTE:
163.8'
Directional ProQram
/
Maximum Hole Inclination:
LOQQinQ ProQram
Cased Hole:
o en Hole:
Required Sensors I Service
Real time MWD Dir/GR/RES/DEN/NEU throughout the interval all in real-time
mode. DEN/NEU can be picked up on the second run and a MAD performed
over the build section BEFORE drilling the lateral. MAD pass should be
performed real-time by pulling out of the hole to avoid sidetracking with the
um s on. Two sam Ie catchers will be re uired at com an man call out.
None lanned
None lanned
Hole Section:
6" production:
06-20A Permit to Drill - Version 1.0
Page 1
~
.
.
Mud ProQram
Hole Section I operation: Set Whip stock I mill window in 7"
Type Density (ppg) PV YP LSRV APIFL pH
FloPro SF 8.4 - 8.5 8-15 30-36 > 30,000 4-6 9.0- 9.5
Hole Section I operation: Drilling 6" production interval
Type Density lPpè) PV YP LSRV API FL pH
FloPro SF 8.4 ¡ 8.qI 8-15 22 - 28 > 25,000 4-6 9.0- 9.5
'--Y.
CasinQ I TubinQ PrOQram
Hole CasingfTubing Wt. Gr~e Conn~tion Length Top Bottom
Size Size md I tvd md I tvd
7" Tie- 7" 26.0# L-80 TC-II 3,000' Surface 3,000' /2,995'
Back
7" Tie- 7" 26.0# L-80 BTC-M 5,949' 3,000' /2,995' 8,949' / 8,273'
Back
6" 4-1/2" 11.6# L-80 LTC 2,180' 8,849'/ 8,179' 11,029'/9,050'
Tubina 4-1 /2" 12.6# 13Cr-80 V AM TOP 8,849' Surface 8,849'/8,179'
Slurry Design Basis:
Fluids Sequence I Volume:
BHST:
BHCT:
Slurry Design Basis:
Fluids Sequence I Volume:
BHST:
BHCT:
CementinQ PrOQram
7",26#, L-80, TC-II x BTC-M Tie-back
Lead slurry: ~ of 9-5/8" x 7" annulus. '5 4't I WG
Tail slurry: 1,000' of 9-5/8" x 7" annulus, plus 50' of 7", 26# shoe track, plus
11' of 7" ID below float collar to FasDrill lu .
Pre-Flush None Planned
S acer 20bbls MudPUSH I
Lead Slur 147bbls / 828 ft
Tail Slur 75bbl / 423 ft /
1820
1200
4-1/2", 11.6#, L-80, LTC solid production liner
Lead slurry: none planned
Tail slurry: 1,745' of 4-1/2" X 6" annulus with 40% excess, plus 80' of 4-1/2",
11.6# shoe track, plus 434' of 7" X 4-1/2" liner lap, plus 200' of 7" X 4" drill
i e annulus.
Pre-Flush
S acer
Lead Slur
Tail Slur
1920
1300
Cement wíll be batch mixed before pumping
06-20A Permit to Drill - Version 1.0
Page 2
"
.
Test
7" liner & Tie-back to surface
Production casin window
.
Casina I Formation Intearitv Testina
Test Point
Test Type
30 min recorded
FIT
Test pressure
si surface
EMW
/
Well Control
Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an
annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE
and drilling fluid system schematics are currently on file with the AOGCC.
Well Interval:
Maximum antici ated BHP:
Maximum surface ressure:
Calculated kick tolerance:
Planned BOPE test ressure:
Planned com letion fluid:
Planned BOPE test pressure:
BOPE configuration for 7" Tie-
Back liner"
Annular In"ection:
Cuttings Handling:
Disposal
No annular injection in this well.
Cuttings generated from drilling operations are to be hauled to the Grind and Inject
station at OS-04. An metal cuttin s should be sent to the North Slo e Borou h.
All drilling and completion fluids and other Class II wastes are to be hauled to OS-04
for in'ection. All Class I wastes are to be hauled to Pad 3 for dis osal.
Fluid Handling:
Formation
KOP in Sa
TSHA
TSAD
TCGL
BCGL
23SB
To MHOIHOT
Planned MD ft
9283
9295
9373
9655
9823
10068
10919
TD Criteria:
GeoloclÏc Proanosis
TVDss ft
-8581
-8531
-8602
-8791
-8858
-8991
-8978
Comments
H drocarbon bearin
si
/
TD Criteria
Drill to TO of plan. Wellplan will not be extended due to the Eastern, Southern and
Northern boundaries bein hardlines.
06-20A Permit to Drill - Version 1.0
Page 3
.
.
Fault ProQnosis
Formation Est. MD SSTVD Throw
where encounter Intersect Intersect Est. Throw Direction Uncertainty
the Fault
Fault #1 - Zone -9,600 -8,829 15-25 Down to W +/- 100' MD
4A
Fault #2 - -9,873 -8,877 <10 Down to E +/-100' MD
Possible Zone 2C The proposed 06-20A well is expected to cross Fault #1 in Zone 4. A second small fault (Fault #2) has been
mapped at BSAD level but appears to die out up section and may not to cut the BCGL. The well mayor may
not see this fault. If the well does encounter Fault #2 it will probably be in Zone 2C.
The proposed 06-20A well lies in a moderate risk province of the field for lost circulation at faults as
documented by the WURD team and the risk of loss circulation events should be average. The nearest lost
circulation event was 2, 100 feet to the NW in 06-05. This and other nearby events are detailed below:
Loss Circulation Events
Well Type Loss (bbl) MD SSTVD Formation Fault?
06-05 rig 75 9972 9243 Below BSAD Poss (cementing)
06-08 rig 60 11379 9283 Below BSAD (cementing)
06-04 rig 200 8657 8334 Above SAG RlVER-LCU (casing)
Qperations SUmmary
Pre-Ria Work:
1. Rig up slickline. Drift 5-1/2" tubing to 5-1/2" x 4-1/2" crossover. Drift 4-1/2" tubing through WLEG. Tag
and record PBTD below WLEG.
2. Purge Chemical Injection line.
3. Fluid pack the tubing and inner annulus.
4. P&A perfs in 7" liner from the PBTD (-9,788') to -9,500' MD. RIH with coil to PBTD. Lay in 16 bbls of
cement to -9,365' MD. Obtain Squeeze with 5 additional bbls. Wash down to confirm TOC @ 9,500'.
POH with coil.
a. Cement Calculations:
. 7" liner = 9,788' - 9,500' or 288' (-11 BBLS)
. Squeeze an additional 5 BBLS for a total cement volume of 16 BBLS
5. Rig up slickline, drift 5-1/2" and 4-1/2" tubing. Tag TOC. Pull Dummy GLV from Man¡@8,681'.
6. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi f ~ inutes.
7. Circulate the well to sea water through the deepest GLM. Freeze protect the IA an bing with diesel
to -2,200'.
8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000
psi. Function all lock-down screws. Repair or replace as needed.
9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well.
10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover
form.
Ria Operations:
1. MIRU Nabors 2ES
2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC.
3. Nipple down tree. Nipple up and test BOPE. Pull TWC.
4. Pull 5-1/2" tubing and seals from PPB packer. Spool up SSSV and Chemical injection lines.
06-20A Permit to Drill - Version 1.0
Page 4
·'
.
5. PU packer milling assembly with PRT. RIH picking up 4" DP. Mill packer and POOH with packer and
Tail Pipe assembly.
6. RU e-line. Run Gauge Ring 1 Junk basket and Gamma Ray tool for 7",29# casing with CCL to TOC
plug. Log Gamma Ray from TOC to 8,500' MD.
7. RIH with USIT and log from 3,500' to surface.
8. RIH with 7" CIBP on e-line. Set CIBP at -9,303 to avoid cutting a casing collar during window milling
operations. Ensure KOP is below TSAG from previous Gamma Ray log.
9. RIH with HES FasDrill bridge plug and set l' below bottom of 7" tieback -8,960'. RD e-line.
1 O. PU 9-5/8" casing scraper and 7.5" tieback dressing assembly on DP. RIH and dress 7" tieback
receptacle. Close rams and pressure test the 9-5/8" casing, 7" liner and plug. If PT fails POOH and
PU RTTS to find leak. If there is a leak a contingency plan will be sent to the rig.
11. POOH - 5 stands. PU a 9-5/8" RTTS and hang off below the well head.
12. ND BOPE. Install a new spool for 7" tieback. NU and test BOPE.
13. POOH with RTTS, remaining DP and BHA. .
14. RU and run 7" Tie-back liner to surface. Top 3,000' of 7" will have premium threads. Cement will be /"
brought up to -2,500' MD. Remainder of 9-5/8" by 7" annulus will be freeze protected to surface.
15. Perform top job on the 13-3/8" casing off the critical path.
16. PU 6" milling assembly. RIH and clean out plugs and cement. Drift remaining 7" to top of CIBP
-9,303'. T~<;' \ 0 - 40 I WI? Jr(}\jA- { .
17. U 7" Baker bottom frip whipstock assemblY¡. R1H, orient whipstock and set on CIBP.
18. Swap over to 8.4 ppg FloPro SF milling fluid.
19. Mill a 6" window in 7" liner at -9,283' MD plus 20' past middle of window. Perform FIT. POOH. /"
20. MU 6" BHA with Dir/GR/RES/ABI on 4" DP and RIH to window.
21. Drill the 6" production interval building to horizontal, targeting Zone 2 Ivishak. POOH. MU 6" BHA with
Dir/GR/RES/DEN/NEU/ABI and drill ahead to an estimated TD of 11,048' MD. /
22. Run and cement a 4-1/2" solid liner throughout the 6" wellbore and back into the 7" liner. The 4-1/2" /
liner top should be a minimum of 100' above the bottom of the 7" tie-back previously installed. Set
liner top packer and displace well to clean seawater above the liner top. NOTE: A perf píll wíll be left in
the 4-112" liner.
23. RIH with DPC perf guns, Perf intervals to be determined from LWD logs. Plan to perforate/
overbalance. POOH, LD DP and perf guns.
24. Run the 4-1/2",12.6#, 13Cr80 completion tying into the 4-1/2" liner top.
25. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each.
26. Set and test TWC.
27. ND BOPE. NU and test the tree to 5,000 psi. /
28. Freeze protect the IA and Tubing to -2,200' and secure the well.
29. RDMO.
Post-Ria Work:
1. Install wellhouse and flowlines.
2. MIRU slickline. Pull the ball and rod 1 RHC plug from 'XN' nipple below the new production packer.
3. Install gas lift valves.
06-20A Permit to Drill - Version 1.0
Page 5
.
.
Job 1: Move In I RiCl Up I Test BOPE
Reference RP
.:. "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP.
.:. "Hydrogen Sulfide" SOP.
.:. "ADW Rig Move" RP.
Issues and Potential Hazards
"'y BOP test interval during this phase is 7 days.
"'y When moving from previous well to Drill Site 06 note the condition of the road over the Little Put
River. In June of 2000 N-2ES did have some difficulties with a move over that area of the Road.
Consider double matting when moving over the Little Put River.
"'y No wells will require shut-in for the rig move onto 06-20. However, 06-21 is about 25' to the North
and 06-19 is about 25' to the South of 06-20. 06-19 and 06-21 are the closest surface neighboring
wells. Wells 06-19 ad 06-21 are currently producing. Care should be taken while moving onto the
well. Spotters should be employed at all times.
"'y The 06-20 well bore will be secured with the following barriers:
.:. Note on barriers during MIRU procedures:
· Tubing - Tested Cement plug (P&A perfs), Kill weight fluid and a BPV.
· IA - Tested Cement plug (P&A perfs), Kill weight fluid and the annular
valve.
· OA - Kill weight fluid, tested Annulus and annular valve.
.:. Note on barriers during ND Tree I NU BOP Procedures
· Tubing - Tested Cement plug (P&A perfs), Kill weight fluid and a TWC.
· IA - Tested Cement plug (P&A perfs), Kill weight fluid and the annular
valve.
· OA - Kill weight fluid, tested Annulus and annular valve
"'y Prior to pulling the tree, verify there is a static column of seawater to surface and that no
pressure exists.
Drill Site 06 J!!l!l.I!.e considered as an H2S site. Standard Operating Procedures for H2S precautions
should be followed at all times. Recent H2S data from the pad is as follows:
Well Name H2S Readin Date
#1 Closest SHL with H2S Readin 06-20 15 m 03/05/02
#2 Closest SHL with H2S Readin 06-21A 35 m 12/01/01
#1 Closest BHL with H2S Readin 06-13 250 m 01/09/04
#2 Closest BHL with H2S Readin 06-19 20 m 08/16/04
Max Recorded H2S Readin on the Pad 06-13 250 m 01/09/04
Drill site 06 is a hi h level H2S drill site. Use extra caution while workin .
/'
/
~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud.
06-20A Permit to Drill - Version 1.0
Page 6
.
.
Job 2: De-complete Well
Reference RP
.:. "De-completions' RP
Issues and Potential Hazards
~ BOP test interval during this phase is 7 days.
~ Monitor the well to ensure the fluid column remains static prior to pulling the completion.
~ Note and record required PU weight to pull tubing from polish bore at cut point (-8,949').
~ Have all wellhead and completion equipment NORM-tested, following retrieval.
~ The existing wellhead is a "FMC Gen III" design completed in 1990. It has 9-5/8" intermediate
casing set on a mandrel hanger and packoff. The current completion is a 5-1/2" (Listed as 5-3/4"
RH ACME running threads) hanger. The bottom threads should be L TC-M. Have a spear on
location as a contingency to pull the Hanger to the floor.
~ There is a 5-1/2" Bal-O SSSV Landing Nipple at 2202' with 2, W' encapsulated control lines run to
surface. The current tubing tally states there are 22 steel bands securing these control lines.
~ There is a Chemical Injection mandrel at 8,754' with 1,3/8" non-encapsulated treater line run to
surface. The current tubing tally states there are 192 regular 5-1/2" Res. Tech clamps and 19
modified 5-1/2 Res. Tech clamps for a total of 211 clamps securing this line.
.:. Ensure the pre-rig purging of this line has been completed before pulling the
tubing hanger to the floor.
~ The current 9-5/8" x 5-1 /2" AVA PPB packer will be milled until free and retrieved along with the
tail pipe assembly. Note: Be prepared for any trapped pressure (gas) below the packer.
.:. The kick off will be just below (-5') the TSAG at -9,283' md.
~ A 7" tie-back will be stung into the current 7" liner and brought back to surface. Cement will be
brought up to -2,500'. The top 3,000' of 7" will be premium threads. The rest of the 7" tie-back will
be the BTC-M connection.
06-20A Permit to Drill - Version 1.0
Page 7
.
.
Job 3: Run Whip Stock
Reference RP
.:. "Whipstock Sidetracf(' RP.
.:. "Leak-off and Formation Integrity Tests" SOP
Issues and Potential Hazards
» BOP test interval during this phase is 7 days until the window is milled into formation.
Once the window is milled the 14 day test cycle starts and continues until the rig moves off
the well.
» A 7" whip stock will be run and set in the existing 7" 29# liner. A 6" window will then be milled in
the 7" 26# liner.
» According to the volumes pumped, there should be cement behind the 7" casing at the sidetrack
point.
» There were GEMCO Stand off Bands run on each joint of 7" liner. Note: There is a chance we
will mill through one of these when milling the window.
» The window will be cut in the existing 7" liner into the Sag River formation. Ensure entire wellbore
has been circulated to 8.4ppg mud before milling commences.
» Ivishak formation pressure expected to be -7.1 ppg. The 8.4 - 8.5 ppg FloPro mud will be -640
psi over balanced. Differential sticking will be a concern. Ensure the BHA is moving whenever
possible while in the open hole.
» Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill
to remove metal debris created from the milling process. Ditch magnets should be used
throughout job.
» Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove
metal debris that may have settled out in these areas. Ensure BOP equipment is operable.
Job 7: Drill 6" Production Hole Interval
Reference RP
.:. "Leak-off and Formation Integrity Tests" SOP
.:. "Prudhoe Bay Directional Guidelines" RP
.:. "Lubricants for Torque and Drag Managemenf' RP
Issues and Potential Hazards
» The 06-20A wellbore crosses 1 known fault and possibly a 2nd. Lost circulation risk should is low
in this area. A detailed list of faulting issues is listed on page 4 of this program.
» Differential sticking is a concern. The 8.4 - 8.6 ppg mud will be -640 psi over balanced to the
Ivishak formations. Minimize the time the pipe is left stationary while in open hole (making
connections, surveying, etc).
» Tie the MWD Gamma Ray log back into parent well bore log in the wellsite geologist possession.
A 200' MAD pass above the window is usually sufficient.
06-20A Permit to Drill - Version 1.0
Page 8
.
.
Job 9: Run 4-1/2" Production Liner
Reference RP
.:. "Modified Conventional Liner Cementing" RP
.:. Schlumberger Cement Program.
Issues and Potential Hazards
)- The completion design is to run a 4-1/2", 11.6#, L-80 LTC solid liner throughout the production
interval.
)- Differential sticking is possible. The 8.4 - 8.6 ppg Flo-Pro will be -640 psi over balanced to the
Ivishak formations. Minimize the time the pipe is left stationary while running the liner.
)- Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable
down weight, as per Baker representative.
)- Sufficient 4-1/2" liner will be run to extend -100' above the bottom of the 7" tie-back (est -8,849').
)- A Hi-Vis perforation pill will be spotted in the 4-1/2" liner as per MIDF recommendations.
Phase 10: DPC Perforate
Planned Phase Time
32 hou rs
Planned Phase Cost
$227,045
Reference RP
.:. "Drill Pipe Conveyed Perforating" RP
Issues and Potential Hazards
)- The well will be DPC perforated overbalanced, after running and cementing the 4-1/2 liner.
Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all
responsibilities are understood. Only essential personnel should be present on the rig floor while
making up DPC guns.
)- Expect to lose fluid to the formation after perforating. Have ample seawater on location and be
prepared with LCM if necessary.
06-20A Permit to Drill - Version 1.0
Page 9
.
.
Job 12: Run 4-%" 13Cr-80 Completion
Reference RP
.:. "Completion Design and Running" RP
.:. "Handling and Running 13 Chrome" RP
.:. "Casing and Tubing connections" RP
Issues and Potential Hazards
);> Diesel will be used to freeze protect the well to 2200'. The diesel flash point is 1000 F. Diesel
vapor pressure is - 0.1 psia at 1000 F.
);> The completion, as designed, will be to run a 4-1/2",12.6#, 13Cr-80, VAM TOP production tubing
string, stinging into the 4-1/2" production liner tieback sleeve.
Take all the normal precautions while running the VAM TOP 13Cr-80 tubing: clean
threads if contaminated, use a stabbing guide, single joint compensator, properly
dope and hand-start each pin. Use Jet Lube Seal Guard thread compound and
torque turn each connection. Tubing should arrive on location with the proper
thread dope. Confirm type of thread compound prior to RIH.
Job 13: ND/NU/Release RiQ
Planned Phase Time
12 hours
Planned Phase Cost
$41,089
Reference RP
.:. "ADW Rig Move" RP.
.:. "Freeze Protecting an Inner Annulus" RP.
Issues and Potential Hazards
);> No wells will require shut-in for the rig move onto 06-20. However, 06-21 is about 25' to the North
and 06-19 is about 25' to the South of 06-20. 06-19 and 06-21 are the closest surface neighboring
wells. Wells 06-19 ad 06-21 are currently producing. Care should be taken while moving onto the
well. Spotters should be employed at all times.
);> Note on Barriers during the ND BOP I NU Tree procedures:
· Tubing - Kill weight fluid on a RHC plug with ball & rod and a TWC.
· IA - Kill weight fluid, tested annulus and annular valve.
· OA - Kill weight fluid, tested annulus and annular valve.
);> Note on Barriers during the RDMO procedures:
· Tubing - Kill weight fluid on a RHC plug with ball & rod and a BPV.
· IA - Kill weight fluid, tested annulus and annular valve.
· OA - Kill weight fluid, tested annulus and annular valve.
06-20A Permit to Drill - Version 1.0
Page 10
TREE =
WELLHEAD =
ACTUATOR =
KB. ELEV =
BF. ELEV =
KOP=
Max Angle =
Datum MD =
Datum TVD =
FMC GEN 3
FMC
AXELSON
74'
.
06-20
Current
A:-rv NOTES: ***SURFACE CSG LEAK. OPERATING
~S; MAX lAP = 2000 PSI, MAX OAP = 100 PSI
(12/05/03 WAlVER)***
2900'
31 @ 4000'
9597'
8800' SS
Down squeeze CMT
w/Arctic Pak
.
2202' - 5-1/2" CAM BALO SSSV NIP I
Minimum ID = 3.725" @ 9014'
4-1/2" OTIS XN NIPPLE
ST MD TVD DEV
1 3015 3009 1
2 4947 4723 1
3 6070 5696 2
4 6985 6494 9
5 7650 7087 18
6 8166 7552 17
7 8486 7842 17
8 8681 8022
PORT DATE
o 07/29/04
o 07/29/04
o
o
o
o
o
o
113-3/8" CSG, 72#, L-80, ID = 12.347" I
-15-1/2" AVA LOC SEAL ASSY I
8903' - 9-5/8" X 5-1/2" A V A PPB PKR
15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I
TOPOF 4-1/2" TBG-PC: I
TOPOF7" LNR I
8928'
--15-1/2" X 4-1/2" XO I
9014'
- 4-1/2" OTIS XN NIP, ID = 3.72" I
14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958"
19-5/8" CSG, 47#, L-80. ID = 8.681" I
9026'
9016'
- 4-1/2"BKRS/OSUB I
- 4-1/2" TBG TAIL I
H ELMDTT LOGGED 12/21/90 I
PERFORA TION SUMMARY
REF LOG: BHCS ON 08/22/82
ANGLEATTOPPERF: 24 @ 9720'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DA TE
3-1/8" 4 09720 - 09760 S 12/12/90
3-3/8" 4 09738 - 09758 S 06/08/95
3-3/8" 6 09750 - 09754 0 03/03/97
3-3/8" 4 09754 - 09764 0 08/31/96
3-3/8" 4 09758 - 09763 S 06/08/95
3-3/8" 2 09760 - 09764 0 07/05/96
3-3/8" 4 09763 - 09764 S 06/08/95
3-3/8" 6 09780 - 09793 S 12/12/90
3-3/8" 4 09780 - 09793 0 01/21/90
9788' HSANDTOPTAG (11/21/03) I
I PBTD I
I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I
DATE
08/26182
12/13/90
09/12/01
02109103
08/19/03
10/14/03
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNlTP CORRECTIONS
ATDITP DELETE WANER SAFETY NO
CMOITLP PERF ANGLE CORRECTION
JCMlTLH GL V C/O
DATE
11/25/03
12/29/03
03/14/04
07/29/04
04/08/05
REV BY COMMENTS
JLJITLH TAG SAND TOP (FILL)
JLAlPAG WANER SAFETY NOTE
DA V ITLH GL V C/O
RWLlTLP GL V C/O
KWA Pre-rig for Rotary Sidetrack
PRUDHOE BA Y UNIT
WELL: 06-20
PERMIT No: '1821240
API No: 50-029-20799-00
SEe 2, T10N, R14E, 3101.13' FEL & 5203.73' FNL
BP Exploration (Alaska)
Pre-Rig
~ NOTES: ***SURFACE CSG LEAK. OPERATING
~~S; MAX lAP = 2000 PSI, MAX OAP = 100 PSI
(12/05/03 WAlVER)***
TREE =
WB..LHEAD =
ACTUATOR =
KB. B..EV =
BF. B..EV =
KOP=
Max Angle =
Datum MD =
Datum TVD =
FMC GEN 3
FMC
AXB..SON
74'
.
06-20
2900'
31 @ 4000'
9597'
8800' SS
Down squeeze CMT
w/Arctic Pak
.
2202' ,,5-1/2" CAM BALO SSSV NIP I
Minimum ID = 3.725" @ 9014'
4-1/2" OTIS XN NIPPLE
ST MD TVD DEV
1 3015 3009 1
2 4947 4723 1
3 6070 5696 2
4 6985 6494 9
5 7650 7087 18
6 8166 7552 17
7 8486 7842 17
8 8681 8022
PORT DATE
o 07/29/04
o 07/29/04
o
o
o
o
o
o
113-3/8" CSG, 72#, L-80, ID = 12.347" I
,,5-1/2" AVA LOC SEAL ASSY I
8903' "9-5/8" X 5-1/2" AVA PPB PKR
15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I
TOPOF 4-1/2" TBG-PC I
I TOP OF 7" LNR I
8928'
-15-1/2" X 4-112" XO I
9014'
-14-1/2" OTIS XN NIP, ID = 3.72" I
14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958"
19-5/8" CSG, 47#, L-80, ID = 8.681" I
9026'
9016'
., 4-1/2" BKR S/O SUB I
-14-1/2" TBG TAIL I
H B..MD TT LOGGED 12/21/90 I
PERFORA TION SUMMARY
REF LOG: BHCS ON 08/22/82
ANGLE AT TOP ÆRF: 24 @ 9720'
Note: Refer to A'oduction DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz OA TE
3-1/8" 4 09720 - 09760 S 12/12/90
3-3/8" 4 09738 - 09758 S 06/08/95
3-3/8" 6 09750 - 09754 0 03/03/97
3-3/8" 4 09754 - 09764 0 08/31/96
3-3/8" 4 09758 - 09763 S 06/08/95
3-3/8" 2 09760 - 09764 0 07/05/96
3-3/8" 4 09763 - 09764 S 06/08/95
3-3/8" 6 09780 - 09793 S 12/12/90
3-3/8" 4 09780 - 09793 0 01/21/90
9788' -1 SAND TOP TAG (11/21/03) I
17" LNR, 29#, L-80, .0371 bpf, ID = 6.184"
DATE
08/26182
12/13/90
09/12/01
02/09103
08/19/03
10/14/03
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNITP CORRECTIONS
ATDITP DB..ETEWAIVERSAFEfY NO
CMOITLP ÆRF ANGLE CORRECTION
JCM'TLH GL V C/O
DATE
11/25/03
12/29103
03/14/04
07/29/04
04/08/05
REV BY COMMENTS
JLJITLH TAG SAND TOP (FILL)
JLA/PAG WAIVER SAFETY NOTE
DA V ITLH GL V C/O
RWLITLP GL V C/O
KWA A'e-rig for Rotary Sidetrack
ffiUDHOE BA Y UNIT
WB..L: 06-20
ÆRMIT No: '1821240
API No: 50-029-20799-00
SEC 2, T10N, R14E, 3101.13' FB.. & 5203.73' FNL
BP Exploration (Alaska)
TREE =
WaLHEAD =
ACTUATOR =
KB. aEV =
BF. aEV =
KOP=
Max Angle =
Datum MD =
Datum TVD =
FMC GEN 3
FMC
AXaSON
74'
.
06-20
Decomplete 1
~ NOTES: ***SURFACE CSG LEAK. OPERATING
m~S; MAX lAP = 2000 PSI, MAX OAP = 100 PSI
(12/05/03 WAlVER)***
2900'
31 @ 4000'
9597'
8800' SS
Down squeeze CMT
wI Arctic Pak
113-3/8" CSG, 72#, L-80, ID = 12.347" I
Minimum ID = 3.725" @ 9014'
4-1/2" OTIS XN NIPPLE
PERFORA TION SUMMARY
REF LOG: BHCS ON 08/22/82
ANGLE AT TOP PERF: 24 @ 9720'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
3-1/8" 4 09720 - 09760 S 12/12/90
3-3/8" 4 09738 - 09758 S 06/08/95
3-3/8" 6 09750 - 09754 0 03/03/97
3-3/8" 4 09754 - 09764 0 08/31/96
3-3/8" 4 09758 - 09763 S 06/08/95
3-3/8" 2 09760 - 09764 0 07105/96
3-3/8" 4 09763 - 09764 S 06/08/95
3-3/8" 6 09780 - 09793 S 12/12/90
3-3/8" 4 09780 - 09793 0 01/21/90
8903' -19-5/8" X 5-1/2" A V A PPB PKR
15-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" I
TOPOF 4-1/2" TBG-PC I
8928' -15-112" X 4-1/2" XO I
9014' -14-112" OTIS XN NIP, ID = 3.72" I
14-1/2" TBG-PC, 12.6#, N-80, .0152 bpf, ID = 3.958"
19-518" CSG, 47#, L-80, ID = 8.681" I
9026'
9016'
-14-1/2" BKR S/O SUB I
-14-1/2" TBG TAIL I
H ELMD IT LOGGED 12/21/90 I
-9,500' Top of Cement Plug
9788' -iSANDTOPTAG (11/21/03) I
I PBTD I
17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I
DATE
08/26182
12/13190
09/12/01
02109103
08/19/03
10/14/03
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNlTP CORRECTIONS
A TDITP DaETE WAIVER SAFETY NO
CMOITLP PERF ANGLE CORRECTION
JCM'TLH GL V C/O
DATE
11/25/03
12/29/03
03/14/04
07/29/04
04/08/05
REV BY COMMENTS
JLJITLH TAG SAND TOP (FILL)
JLA/PAG WAIVER SAFETY NOTE
DA V ITLH GL V C/O
RWLITLP GL V C/O
KWA Pre-rig for Rotary Sidetrack
PRUDHOE BA Y UNIT
waL: 06-20
PERMIT No: ~821240
API No: 50-029-20799-00
SEC 2, T10N, R14E, 3101.13' FEL & 5203.73' FNL
BP Exploration (Alas ka)
TREE =
WELLHEAD =
ACTUATOR =
KB. ELEV =
BF. ELEV =
KOP=
Max Angle =
Datum MD =
Datum TVD =
FMC GEN 3
FMC
AXELSON
74'
.
06-20
Decomplete 2
113-3/8" CSG, 72#, L-80, ID = 12.347" I
2900'
31 @ 4000'
9597'
8800' SS
Down squeeze GMT
w/Arctic Pak
Minimum ID = 3.725" @ 9014'
4-1/2" OTIS XN NIPPLE
I TOP OF 4-1/2" TBG-PC H 8928'
TOPOF 7" LNR I
Top of 7" HES FasDrill -8,960'
19-5/8" CSG, 47#, L-80, ID = 8.681" I
Top of 7" HES EZSV -9,303'
I PBTD I
17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I
9977'
DATE
08/26/82
12/13/90
09/12/01
02/09/03
08/19/03
10/14/03
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNlTP CORRECTIONS
ATDITP DELEfEWAIVERSAFETY NO
CMOITLP ÆRF ANGLE CORRECTION
JCM!TLH GL V C/O
DATE
11/25/03
12/29/03
03/14/04
07/29/04
04/08/05
REV BY COMMENTS
JLJ/TLH TAG SAND TOP (FILL)
JLA/PAG WAIVER SAFETY NOTE
DA V ITLH GL V C/O
RWLlTLP GL V C/O
KWA Pre-rig for Rotary Sidetrack
PRUDHOE BA Y UNIT
WELL: 06-20
PERMIT No: '1821240
API No: 50-029-20799-00
SEC 2, T10N, R14E, 3101.13' FEL & 5203.73' FNL
~ NOTES: ***SURFACE CSG LEAK. OPERATING
~S; MAX lAP = 2000 PSI, MAX OAP = 100 PSI
(12/05/03 WAlVER)***
PERFORA TION SUMMARY
REF LOG: BHCS ON 08/22/82
ANGLE AT TOP ÆRF: 24 @ 9720'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERV AL Opn/Sqz DA TE
3-1/8" 4 09720 - 09760 S 12/12/90
3-3/8" 4 09738 - 09758 S 06/08/95
3-3/8" 6 09750 - 09754 0 03/03/97
3-3/8" 4 09754 - 09764 0 08/31/96
3-3/8" 4 09758 - 09763 S 06/08/95
3-3/8" 2 09760 - 09764 0 07105/96
3-3/8" 4 09763 - 09764 S 06/08/95
3-3/8" 6 09780 - 09793 S 12/12/90
3-3/8" 4 09780 - 09793 0 01/21/90
9788' -iSANDTOPTAG (11/21/03) I
BP Exploration (Alaska)
TREE =
l-EAD =
AGJUA. TOR =
KB. B..E:V =
BF. B..E:V =
KOP=
Max Angle =
D3tum J\¡[) =
[):rtum lVD =
.
06-20
2900'
31 @4000'
9597
8800' SS
113-3/8" CSG, 72#, L-80, ID= 12.347" I
Minimum ID = 3.725" @ 9014'
4-1/2" OTIS XN NIPPLE
19-5/8" CSG, 47#, L-80, ID = 8.681" I
Top of 7" HES EZSV -9,500'
I PBTD I
17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I
7" Tie-Back
~ NOTES: ***SURFACE CSG LEAK. OPERATING
~~; MAX lAP = 2000 PSI, MAX OAP = 100 PSI
(12/05/03 WAlVER)***
-2,500' Top of Cement
9788' -1 SAND TOP TAG (11/21/03) I
DATE
08126/82
12/13190
09/12/01
02/09/03
08/19/03
10/14/03
DATE
11/25/03
12/29/03
03/14/04
07/29/04
04/08/05
REV BY COMMENTS
JLJITLH TAG SAND TOP (FILL)
JLA/PAG WAIVER SAFETY NOTE
DA V ITLH GL V C/O
RWLlTLP GL V C/O
KWA 7" Tie-Back
PRUDHOE BA Y UNIT
WELL: 06-20
PERMIT No:
API No: 50-029-20799-00
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNlTP CORRECTIONS
ATDITP DELETE WAIVER SAFETY NO
CMOITLP ÆRF ANGLE CORRECTION
JCMlTLH GL V C/O
BP Exploration (Alaska)
.
.
06-20A
Proposed Completion
-2,200' HES 4-1/2" X Nipple 10 = 3.813"
113-3/8" CSG, 72#, L-80, ID = 12.347" I
-2,500' Top of Cement (
7" LNR, 26#, L-80, Yam Top -3,000'
7" LNR, 26#, L-80, BTC-Mod
4-1/2" TBG, 12.6#, 13Cr-80, Yam TOP
GAS LIFT MANDRELS
TYÆ VLV LATCH PORT DATE
dmy
dmy
dmy
dmy
ST MD
1
2
3
4
TVD DEV
3300
5400
7100
8130
Est Top 7"x4-1/2" ZXP & HGR -8,849'
-8,780' HES 4-1/2" X Nipple 10 = 3.813"
-8,800 BKR 7" x 4-1/2" BKR PKR
-8,820' HES 4-1/2" X Nipple 10 = 3.813"
-8,840' HES 4-1/2" XN Nipple 10 = 3.725"
-8,854' 4-1/2" WLEG
I 9-5/8" CSG, 47#, L-80, ID = 8.681" I
Top of Whipstock -9,283'
LNR, 11.6#, L-80, LTC
-11,028' TO '
-10,928'
Top of 7" HES EZSV -9,303'
~
-9,500' Top of Cement Plug
9788' -fSAND TOP TAG (11/21/03) I
I PBTD I
17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I
DATE
08/26182
12/13190
09/12/01
02/09/03
08/19/03
10/14/03
REV BY COMMENTS
ORIGINAL COM PLETION
LAST WORKOVER
RNlTP CORRECTIONS
ATDITP DELErEWAIVERSAFETY NOT
CMOITLP PERF ANGLE CORRECTION
JCMlTLH GL V C/O
REV BY COMMENTS
JLJ/TLH TAG SAND TOP (FILL)
JLA/PAG WAIVER SAFETY NOTE
DAVITLH GLV C/O
RWLITLP GL V C/O
t0NA 7" Tie-Back, WP05
PRUDHOE BAY UNIT
WELL: 06-20A
ÆRMIT No:
API No: 50-029-20799-01
DATE
11/25/03
12/29/03
03/14/04
07/29/04
05/16/05
BP Exploration (Alaska)
Phm: 06-20A wpOS (O( ()-20A\
're¡¡1eJ By' ¡JUS! 'JkmUser
Checked Oat
Dal
Dep1h Fm Dep1h To SUPicy,W!au
1027.(,! I 0(,..20/\'''1\05\'38 M\VD'JFR'MS
Targe'
06-20A TI
06-20A T2
N;JI S N<JI1!1!11g 3mm! SI
06-20
TARGET DETAILS
Name TVD +N/-S +E/-W Northing Easting Shape
T! Point
T2 Point
VSec
TFace
DLeg
SECTION DETAILS
MD c AZI TVD +N/-S +E/-W
21.98 8584.28
See
1
2
3
4
5
6
7
8
REFERENCE INFORMATION
FORMA nON TOP DETAILS
No. TVDPath MDPath Formation
1 8594.80 9294..16 TSHA
2 8665.80 9.172.95 TSAD
.1 8799.80 9547.88 42S8
4 8854.80 9654.90 TCGL
5 8921.80 982.1.49 BCGL
6 8990.80 10068..17 2.1SB
7 9041.80 109]9.07 Top MHO/HOT
a
DETAILS
No. TVD MD Name Size
9048. 027.00 4 II2' 4.500
4J24.46
4203.80
52.62
52.62
~
""
o
o
~
-"
ß. 8800
c¡
'"
"
E
>
"
"
!=
900
920
Plan: 06·20A wp05 (06-20i06-2ÜA)
Created By: Digital BusincssClient User Date: Sng;2(
Date:
La!iw.dc I,ongiwlk> S!O¡
7iY'14'37.04!N ¡4X&29'49)ß4'0.: NiA
DETAILS
WI
SURVEY PROGRAM
Jkp¡hFm Dcpthlo Piau
921B.OO I PJannc.d: O('-20A \Vp()~ V3g MW
- -
Name Eí-W NOJ1h
~94(j1
~J:'ERr:.NCE lNFORMA lION
I
Shape
Eastîng
Northing
S
-
TARGET DET AI
+E/-W
+N/-S
TVD
tl
Name
06-20A Fau
F
F
F
F
F
T
G
T:
Targe
06-20A T
VSee
2822,87
2828.76
3052.10
3240.19
3424.51
3475.90
4175.21
4263.54
TF ace
-69.06
0.00
-6.48
-71.51
0.00
0.00
DLeg
SECTION DETAILS
+E/-W
+N/-S
-67.48
34.47
138.3 I
71
-I
TVD
8584.28
8602.76
8854.33
8941.49
8991.80
8995.96
9042.30
9048.15
Azi
57.50
52.62
52.62
52.62
nc
MD
9283.00
9303.00
9653.72
9873.03
0078.86
See
J
2
3
4
5
6
7
8
Formation
Sìze
4.500
MDPath
No. TVDPath
I
2
3
4
5
6
7
06-20A T2
0.00
4203.80
-30
"'
'"
'"
~
:;-
~
~
:ð
~
o
co
.
Sperry-Sun
BP Planning Report
.
Company: BPAmoco Date: 5/18/2005 Time: 10:12:53 Page: 1
Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 06·20, True North
Site: PB DS 06 Vertical (TVD) Reference: 35.3.fo28.5 63.8
Well: 06-20 Section (VS) Reference: Well (0.00N,0.00E,80.40Azi)
Wellpath: 06-20A Survey Calculation Method: Minimum Curvature Db: Oracle
Plan: 06-20A wp05 Date Composed: 3/24/2005
Version: 38
Principal: Yes Tied-to: From: Definitive Path
Field: Prudhoe Bay
North Slope
UNITED STATES
Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004
Site: PB DS 06
TR-10-14
UNITED STATES: North Slope
Site Position: Northing: 5941880.59 ft Latitude: 70 14 46.529 N
From: Map Easting: 684674.88 ft Longitude: 148 30 29.224 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 1.40 deg
Well: 06-20 Slot Name:
06-20
Well Position: +N/-S -964.55 ft Northing: 5940949.59 ft Latitude: 70 14 37.041 N
+E/-W 1354.88 ft Easting : 686052.90 ft Longitude: 148 29 49.834 W
Position Uncertainty: 0.00 ft
Casing Points
MD TVD Diameter Hole Size Name
ft ft in in
11027.00 9048.12 4.500 6.000 4 1/2"
Formations
MD TVD Formations Lithology Dip Angle Dip Direction
ft ft deg deg
0.00 LCUITKNG 0.00 0.00
0.00 TSGR 0.00 0.00
9294.36 8594.80 TSHA 0.00 0.00
9372.95 8665.80 TSAD 0.00 0.00
9547.88 8799.80 42SB 0.00 0.00
9654.90 8854.80 TCGL 0.00 0.00
9823.49 8921.80 BCGL 0.00 0.00
10068.37 8990.80 23SB 0.00 0.00
10919.07 9041.80 Top MHO/HOT 0.00 0.00
Targets
Map Map <-- Latitude ---> <-- Longitude ->
Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec
Dip. Dir. ft ft ft ft ft
06-20A Fault1 8884.80 150.61 2829.85 5941170.00 688878.00 70 14 38.517 N 148 28 27.559 W
-Polygon 1 8884.80 150.61 2829.85 5941170.00 688878.00 70 14 38.517 N 148 28 27.559 W
-Polygon 2 8884.80 -106.95 3051.58 5940918.00 689106.00 70 14 35.983 N 148 28 21.116 W
-Polygon 3 8884.80 -279.10 3257.40 5940751.00 689316.00 70 14 34.289 N 148 28 15.134 W
-Polygon 4 8884.80 -106.95 3051.58 5940918.00 689106.00 70 14 35.983 N 148 28 21.116 W
-Plan out by 383.84 at 8884.80 -31.84 3167.55 5940995.95 689220.08 70 14 36.721 N 148 28 17.743 W
06-20A Fault2 8884.80 685.95 3067.15 5941711.00 689102.00 70 14 43.781 N 148 28 20.654 W
-Polygon 1 8884.80 685.95 3067.15 5941711.00 689102.00 70 14 43.781 N 148 28 20.654 W
-Polygon 2 8884.80 253.84 3308.58 5941285.00 689354.00 70 14 39.530 N 148 28 13.640 W
-Polygon 3 8884.80 252.72 3353.57 5941285.00 689399.00 70 14 39.519 N 148 28 12.332 W
-Polygon 4 8884.80 72.77 3349.12 5941105.00 689399.00 70 14 37.749 N 148 28 12.463 W
-Polygon 5 8884.80 -191.29 3266.57 5940839.00 689323.00 70 14 35.153 N 148 28 14.867 W
-Polygon 6 8884.80 72.77 3349.12 5941105.00 689399.00 70 14 37.749 N 148 28 12.463 W
-Polygon 7 8884.80 252.72 3353.57 5941285.00 689399.00 70 14 39.519 N 148 28 12.332 W
-Polygon 8 8884.80 253.84 3308.58 5941285.00 689354.00 70 14 39.530 N 148 28 13.640 W
-Plan out by 724.78 at 8884.80 -31.84 3167.55 5940995.95 689220.08 70 14 36.721 N 148 28 17.743 W
06-20A Fault4 8884.80 1111.46 4511.19 5942171.99 690535.00 70 14 47.959 N 148 27 38.660 W
-Polygon 1 8884.80 1015.66 3772.55 5942058.00 689799.00 70 14 47.021 N 148 28 0.139 W
Company:
Field:
Site:
Well:
Wellpatb:
Targets
BP Amoco
Prudhoe Bay
PB DS 06
06-20
06-20A
Name
Description
Dip. Dir.
-Polygon 2
-Polygon 3
-Polygon 4
-Plan out by 1764.22 at
06-20A Fault3
-Polygon 1
-Polygon 2
-Plan out by 1764.22 at
06-20A Fault5
-Polygon 1
-Polygon 2
-Polygon 3
-Polygon 4
-Plan out by 793.70 at
06-20A Fault6
-Polygon 1
-Polygon 2
-Plan out by 250.31 at
06-20A T1
-Plan hit target
06-20A Geo Poly
-Polygon 1
-Polygon 2
-Polygon 3
-Polygon 4
-Polygon 5
-Polygon 6
-Polygon 7
-Polygon 8
-Polygon 9
-Polygon 10
-Polygon 11
-Polygon 12
-Polygon 13
-Polygon 14
-Polygon 15
-Plan out by 550.84 at
06-20A T2
Plan Section Information
MD
ft
9283.00
9303.00
9653.72
9873.03
10078.86
10135.90
10927.61
11027.61
Incl
deg
21.98
22.98
66.58
66.58
85.00
86.64
86.64
86.64
Azim
deg
122.93
117.23
59.56
59.56
57.50
52.62
52.62
52.62
.
TVD
ft
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8884.80
8991.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
8992.80
9042.30
TVD
ft
8584.28
8602.76
8854.33
8941.49
8991.80
8995.96
9042.30
9048.15
.
Sperry-Sun
BP Planning Report
+N/-S
ft
1064.55
1311.01
1064.55
-31.84
1111.46
1111.46
246.45
-31.84
755.06
755.06
669.81
775.72
669.81
-31.84
-167.04
-167.04
-98.35
-31.84
138.31
339.85
339.85
79.40
-24.38
6.02
205.40
458.95
803.57
930.47
839.73
726.55
648.86
536.87
578.24
420.62
339.85
144.75
650.65
+N/-S
ft
-118.29
-122.11
-67.48
34.47
138.31
170.88
650.65
711.25
Date: 5/18/2005 Time: 10:12:53 Page: 2
Co-ordinate(NE) Reference: Well: 06-20, True North
Vertical (TVD) Reference: 35.3+28.563.8
Section (VS) Reference: Well (0.00N,0.OOE,80.40Azi)
Survey Calculation Metbod: Minimum Curvature Db: Oracle
+EI-W
ft
4101.88
4573.13
4101.88
3167.55
4511.19
4511.19
4660.89
3167.55
3063.86
3063.86
3558.94
3766.63
3558.94
3167.55
3378.21
3378.21
3959.12
3167.55
3449.78
2944.57
2944.57
3040.17
3353.73
3864.66
4459.80
4401.04
4340.52
4305.64
4010.29
3975.49
3880.54
3635.68
3256.56
2914.55
2944.57
3459.70
4124.46
Map
Nortbing
ft
5942114.99
5942372.99
5942114.99
5940995.95
5942171.99
5942171.99
5941310.99
5940995.95
5941780.00
5941780.00
5941707.00
5941818.00
5941707.00
5940995.95
5940866.00
5940866.00
5940949.00
5940995.95
5941173.00
5941362.00
5941362.00
5941104.00
5941008.00
5941051.00
5941265.00
5941517.00
5941860.00
5941986.00
5941888.00
5941774.00
5941694.00
5941576.00
5941608.00
5941442.00
5941362.00
5941179.68
5941701.81
Map
Easting
ft
690127.00
690592.00
690127.00
689220.08
690535.00
690535.00
690706.00
689220.08
689097.00
689097.00
689594.00
689799.00
689594.00
689220.08
689434.00
689434.00
690013.00
689220.08
689498.00
688988.00
688988.00
689090.00
689406.00
689916.00
690506.00
690441.00
690372.00
690334.00
690041.00
690009.00
689916.00
689674.00
689294.00
688956.00
688988.00
689507.76
690159.80
<-- Latitude -->
Deg Min Sec
70 14 47.500 N
70 14 49.921 N
70 14 47.500 N
70 14 36.721 N
70 14 47.959 N
70 14 47.959 N
70 14 39.451 N
70 14 36.721 N
70 14 44.461 N
70 14 44.461 N
70 14 43.620 N
70 14 44.661 N
70 14 43.620 N
70 14 36.721 N
70 14 35.391 N
70 14 35.391 N
70 14 36.064 N
70 14 36.721 N
70 14 38.394 N
70 14 40.378 N
70 14 40.378 N
70 14 37.816 N
70 14 36.794 N
70 14 37.090 N
70 14 39.048 N
70 14 41.542 N
70 14 44.932 N
70 14 46.180 N
70 14 45.289 N
70 14 44.176 N
70 14 43.413 N
70 14 42.312 N
70 14 42.721 N
70 1441.172 N
70 14 40.378 N
70 14 38.457 N
70 14 43.429 N
+E/-W
ft
2883.00
2889.62
3106.90
3280.41
3449.78
3496.39
4124.46
4203.80
DLS Build Turn
deg/1000 deg/1000 deg/100ft
0.00 0.00 0.00
12.00 5.01 -28.53
16.00 12.43 -16.44
0.00 0.00 0.00
9.00 8.95 -1.00
9.00 2.88 -8.55
0.00 0.00 0.00
0.00 0.00 0.00
TFO Target
deg
0.00
-68.00
-69.06
0.00
-6.48 06-20A T1
-71.51
0.00 06-20A T2
0.00
<-- Longitude -->
Deg Min Sec
148 27 50.562 W
148 27 36.855 W
148 27 50.562 W
148 28 17.743 W
148 27 38.660 W
148 27 38.660 W
148 27 34.323 W
148 28 17.743 W
148 28 20.749 W
148 28 20.749 W
148 28 6.355 W
148 28 0.315 W
148 28 6.355 W
148 28 17.743 W
148 28 11.621 W
148 28 11.621 W
148 27 54.731 W
148 28 17.743 W
148 28 9.536 W
148 28 24.222 W
148 28 24.222 W
148 28 21.445 W
148 28 12.331 W
148 27 57.476 W
148 27 40.170 W
148 27 41.874 W
148 27 43.628 W
148 27 44.640 W
148 27 53.229 W
148 27 54.243 W
148 27 57.005 W
148 28 4.125 W
148 28 15.148 W
148 28 25.094 W
148 28 24.222 W
148 28 9.247 W
148 27 49.912 W
.
Sperry-Sun
BP Planning Report
.
Company: BPAmoco Date: 5/18/2005 Time: 10:12:53 Page: 3
Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 06.20, True North
Site: PB DS 06 Vertical (TVD) Reference: 35.3+28.5 63.8
Well: 06-20 Section (VS) Reference: Well (0.00N,O.00E,80.40Azi)
Wellpath: 06-20A Survey Calculation Method: Minimum Curvature Db: Oracle
Survey
MD Inel Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Cornrne t
ft deg deg ft ft ft ft deg/1000 ft ft
9283.00 21.98 122.93 8584.28 8520.48 -118.29 2883.00 0.00 5940902.50 688937.77 Start Dir 12/10
9294.36 22.53 119.63 8594.80 8531.00 -120.52 2886.68 12.00 5940900.36 688941.50 TSHA
9300.00 22.82 118.05 8600.00 8536.20 -121.57 2888.58 12.00 5940899.36 688943.43 MWD+IFR+MS
9303.00 22.98 117.23 8602.76 8538.96 -122.11 2889.62 12.00 5940898.84 688944.48 Start Dir 16/10
9372.95 28.83 95.15 8665.80 8602.00 -129.90 2918.65 16.00 5940891.78 688973.69 TSAD
9400.00 31.82 88.93 8689.15 8625.35 -130.35 2932.29 16.00 5940891.66 688987.33 MWD+IFR+MS
9500.00 44.62 73.18 8767.74 8703.94 -119.63 2992.66 16.00 5940903.87 689047.41 MWD+IFR+MS
9547.88 51.28 68.09 8799.80 8736.00 -107.78 3026.13 16.00 5940916.54 689080.58 42SB
9600.00 58.75 63.55 8829.67 8765.87 -90.24 3065.01 16.00 5940935.04 689119.02 MWD+IFR+MS
9653.72 66.58 59.56 8854.33 8790.53 -67.48 3106.90 16.00 5940958.82 689160.33 End Dir : 9653
9654.90 66.58 59.56 8854.80 8791.00 -66.93 3107.83 0.00 5940959.39 689161.25 TCGL
9700.00 66.58 59.56 8872.72 8808.92 -45.97 3143.51 0.00 5940981.23 689196.40 MWD+IFR+MS
9730.39 66.58 59.56 8884.80 8821.00 -31.84 3167.55 0.00 5940995.95 689220.08 06-20A Fault1
9800.00 66.58 59.56 8912.47 8848.67 0.52 3222.63 0.00 5941029.65 689274.34 MWD+IFR+MS
9823.49 66.58 59.56 8921.80 8858.00 11.44 3241.21 0.00 5941041.03 689292.65 BCGL
9873.03 66.58 59.56 8941.49 8877.69 34.47 3280.41 0.00 5941065.02 689331.26 Start Dir 9/100
9900.00 68.99 59.27 8951.68 8887.88 47.18 3301.90 9.00 5941078.25 689352.43 MWD+IFR+MS
10000.00 77.94 58.25 8980.11 8916.31 96.86 3383.77 9.00 5941129.93 689433.05 MWD+IFR+MS
10068.37 84.06 57.60 8990.80 8927.00 132.70 3440.96 9.00 5941167.18 689489.33 23SB
10078.86 85.00 57.50 8991.80 8928.00 138.31 3449.78 9.00 5941173.00 689498.00 06-20A T1
10100.00 85.61 55.69 8993.53 8929.73 149.91 3467.36 9.00 5941185.02 689515.30 MWD+IFR+MS
10135.90 86.64 52.62 8995.96 8932.16 170.88 3496.39 9.00 5941206.70 689543.80 End Dir : 1013
10200.00 86.64 52.62 8999.71 8935.91 209.72 3547.25 0.00 5941246.79 689593.67 MWD+IFR+MS
10300.00 86.64 52.62 9005.56 8941.76 270.32 3626.58 0.00 5941309.33 689671.48 MWD+IFR+MS
10400.00 86.64 52.62 9011.42 8947.62 330.92 3705.91 0.00 5941371.86 689749.29 MWD+IFR+MS
10500.00 86.64 52.62 9017.27 8953.47 391.52 3785.24 0.00 5941434.40 689827.09 MWD+IFR+MS
10600.00 86.64 52.62 9023.12 8959.32 452.12 3864.57 0.00 5941496.93 689904.90 MWD+IFR+MS
10700.00 86.64 52.62 9028.98 8965.18 512.72 3943.90 0.00 5941559.47 689982.70 MWD+IFR+MS
10800.00 86.64 52.62 9034.83 8971.03 573.32 4023.23 0.00 5941622.01 690060.51 MWD+IFR+MS
10900.00 86.64 52.62 9040.68 8976.88 633.92 4102.56 0.00 5941684.54 690138.32 MWD+IFR+MS
10919.07 86.64 52.62 9041.80 8978.00 645.48 4117.69 0.00 5941696.47 690153.15 Top MHO/HOT
10927.61 86.64 52.62 9042.30 8978.50 650.65 4124.46 0.00 5941701.81 690159.80 06-20A T2
11000.00 86.64 52.62 9046.54 8982.74 694.52 4181.89 0.00 5941747.08 690216.12 MWD+IFR+MS
11027.00 86.64 52.62 9048.12 8984.32 710.88 4203.31 0.00 5941763.96 690237.13 41/2"
11027.61 86.64 52.62 9048.15 8984.35 711.25 4203.80 0.00 5941764.34 690237.60 MWD+IFR+MS
80
75
38
o
13
WEU, DETAfLS
('OMPANY DETA!J,S
ANTI-COLLISION SETTINGS
25.00
11027.61
PJan: 06-20A \vµ05
D<:p¡h Fm Ikp¡h Tn SUI\;<:yi1'lml
niB.oj) j 1H17.fd Planned: 06-10A wpÜ~ V3X
MW!J,¡FR,MS
Nam<: 'N,"-$ NDrthmg E¡~,ling LltÍludc L<>ugÜud<: Slot
BPAUJo'-'o
06-20 ·',1645:- n:'4,xg :,940<)4'i59 6X60:'i2.90 7WI4':nJ!41N !4)\,,29'4<).8:\4W N'A
SIJRVEY ¡>ROGHAM
['"o1
WEJJ_PATH Dr,TAILS
From Colour ToMD 06-10A
0 500 06-20
500 1000 92KUJO
1000 1500 Rig
!{¢f.DalUm 6:,)Wii
1500 2000 nj'jgiu Orjgm Slmtillg
2000 2500 ,N':-S F/-W Ffi)m rvn
2500 3000 gOAl)" O.(JO (J.()(J :m.5o
3000 3500
3500 4000
4000 4500
4500 5000 LEGI,NJ)
5000 5500
5500 6000
6000 7000
7000 8000
8000 9000
9000 10000
10000 10500
0500 11000
000 11500
00 12000
3
270
90
o
3
SECTION DETAILS
TV!)
ULcg TFaæ
fargct
06-1(JAT!
06-20A T2
.
Sperry-Sun
Anticollision Report
.
Company: BPAmoco Date: 5/18/2005 Time: 10:20:00 Page: 1
Field: Prudhoe Bay
Reference Site: PB DS 06 Co-ordinate(NE) Reference: Well: 06-20, True North
Reference Well: 06-20 Vertical (TVD) Reference: 35.3+28.563.8
Reference Wellpath: 06-20A Db: Oracle
GLOBAL SCAN APPLIED: All wellpaths within 200'+ 10011000 ofreference - There are TIriiIIIŒ_ls in this fRtiI1cipal Plan & PLANNED PROGRAM
Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse
Depth Range: 9283.00 to 11027.61 ft Scan Method: Trav Cylinder North
Maximum Radius: 1299.91 ft Error Surface: Ellipse + Casing
Survey Program for Definitive Wellpath
Date: 3/24/2005 Validated: No Version: 0
Planned From To Survey Toolcode Tool Name
ft ft
1491.50 9283.00 1 : Camera based gyro multisho (1489.80-99~II(D)'(RO-MS Camera based gyro multishot
9283.00 11027.61 Planned: 06-20A wp05 V39 MWO+IFR+MS MWO + IFR + Multi Station
Casing Points
MD TVD Diameter Hole Size Name
ft ft in in
11027.00 9048.12 4.500 6.000 41/2"
Summary
<----------- Offset Wellpath --------> Reference Offset Ctr-Ctr No-Go Allowable
Site Well Wellpath MD MD Distance Area Deviation Warning
ft ft ft ft ft
PB DS 06 06-01 06-01 V1 Out of range
PB DS 06 06-02 06-02 V1 Out of range
PB DS 06 06-03 06-03 V1 Out of range
PB OS 06 06-03A 06-03A V1 Out of range
PB OS 06 06-04 06-04 V1 Out of range
PB OS 06 06-04 06-04A V1 0 Out of range
PB OS 06 06-05 06-05 V1 Out of range
PB OS 06 06-06 06-06 V1 Out of range
PB DS 06 06-06A 06-06A V1 Out of range
PB OS 06 06-06 Plan 06-06B VO Plan: 0 Out of range
PB DS 06 06-07 06-07 V1 11014.67 9875.00 1161.10 355.17 805.93 Pass: Major Risk
PB DS 06 06-08 06-08 V1 Out of range
PB DS 06 06-08A 06-08A V1 Out of range
PB OS 06 06-17 06-17V1 Out of range
PB DS 06 06-18 06-18 V1 Out of range
PB OS 06 06-19 06-19 V1 Out of range
PB OS 06 06-20 06-20 V1 9299.99 9300.00 0.31 No Reference Casings
PB OS 06 06-21 06-21 V3 Out of range
PB DS 06 06-21 06-21A V5 Out of range
PB DS 06 06-22 06-22 V1 Out of range
PB OS 06 06-22A 06-22A V1 Out of range
PB OS 06 06-23 06-23 V1 Out of range
PB DS 06 06-23 06-23A V1 Out of range
PB DS 06 06-23 06-23B V2 Out of range
PB DS 06 06-23 06-23BPB1 V1 Out of range
PB DS 06 06-24 06-24 V1 Out of range
PB DS 06 06-24 06-24A V1 Out of range
Site: PB DS 06
Well: 06-07 Rule Assigned: Major Risk
Wellpath: 06-07 V1 Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglHSDistance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft
10858.80 9038.27 9625.00 7783.72 94.50 220.43 66.50 13.87 1294.45 244.89 1049.57 Pass
10874.82 9039.21 9650.00 7801.22 94.51 221.45 67.09 14.47 1280.73 254.52 1026.21 Pass
10890.77 9040.14 9675.00 7818.80 94.52 222.47 67.70 15.08 1267.07 264.45 1002.62 Pass
10906.63 9041.07 9700.00 7836.44 94.53 223.48 68.33 15.70 1253.48 274.66 978.81 Pass
10922.41 9042.00 9725.00 7854.17 94.54 224.46 68.97 16.34 1239.96 285.16 954.81 Pass
10938.07 9042.91 9750.00 7871.95 94.55 225.44 69.62 17.00 1226.56 295.99 930.56 Pass
10953.63 9043.82 9775.00 7889.81 94.56 226.42 70.30 17.67 1213.26 307.17 906.09 Pass
10969.07 9044.73 9800.00 7907.73 94.56 227.40 70.99 18.37 1200.08 318.70 881.38 Pass
.
Sperry-Sun
Anticollision Report
.
Company: BPAmoco Date: 5/18/2005 Time: 10:20:00 Page: 2
Field: Prudhoe Bay
Reference Site: PB DS 06 Co-ordinate{NE) Reference: Well: 06-20, True North
Reference Well: 06-20 Vertical (TVD) Reference: 35.3+28.5 63.8
Reference Wellpath: 06-20A Db: Oracle
Site: PB DS 06
Well: 06-07 Rule Assigned: Major Risk
Wellpath: 06-07 V1 Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIHSDistance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft
10984.39 9045.62 9825.00 7925.74 94.57 228.34 71.70 19.08 1187.00 330.53 856.47 Pass
10999.59 9046.51 9850.00 7943.84 94.58 229.27 72.43 19.81 1174.01 342.69 831.32 Pass
11014.67 9047.40 9875.00 7962.05 94.59 230.21 73.18 20.55 1161.10 355.17 805.93 Pass
Site: PB DS 06
Well: 06-20 Rule Assigned: NOERRORS
Wellpath: 06-20 V1 Inter-Site Error: 0.00 ft
Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable
MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasinglHSDistance Area Deviation Warning
ft ft ft ft ft ft deg deg in ft ft ft
9299.99 8599.99 9300.00 8600.04 121.30 121.46 232.03 113.97 0.31 FAIL
9324.86 8622.78 9325.00 8623.19 122.12 122.70 228.71 119.40 2.03 No Reference Casings
9349.36 8644.91 9350.00 8646.31 122.67 123.67 226.51 124.96 5.49 No Reference Casings
9373.30 8666.10 9375.00 8669.40 122.90 124.32 225.04 129.98 10.63 No Reference Casings
9396.46 8686.14 9400.00 8692.46 122.84 124.69 223.87 134.19 17.39 No Reference Casings
9418.73 8704.87 9425.00 8715.47 122.52 124.79 222.78 137.55 25.64 No Reference Casings
9440.00 8722.22 9450.00 8738.42 121.98 124.65 221.77 140.25 35.28 No Reference Casings
9460.19 8738.13 9475.00 8761.32 121.26 124.30 220.82 142.42 46.21 No Reference Casings
9479.27 8752.63 9500.00 8784.17 120.42 123.80 219.94 144.18 58.33 No Reference Casings
9497.22 8765.75 9525.00 8807.01 119.47 123.17 219.20 145.68 71.60 No Reference Casings
9514.03 8777.56 9550.00 8829.84 118.42 122.44 218.55 146.97 85.91 No Reference Casings
9529.74 8788.14 9575.00 8852.68 117.36 121.66 217.98 148.08 101.17 No Reference Casings
9544.39 8797.61 9600.00 8875.52 116.26 120.83 217.45 149.02 117.28 No Reference Casings
9558.06 8806.07 9625.00 8898.37 115.17 119.97 216.98 149.85 134.15 No Reference Casings
9570.80 8813.62 9650.00 8921.23 114.10 119.11 216.56 150.57 151.69 No Reference Casings
9582.68 8820.37 9675.00 8944.10 113.05 118.26 216.17 151.20 169.83 No Reference Casings
9593.75 8826.39 9700.00 8966.98 112.03 117.43 215.80 151.75 188.51 No Reference Casings
9604.08 8831.78 9725.00 8989.87 111.06 116.63 215.46 152.24 207.69 No Reference Casings
9613.73 8836.59 9750.00 9012.75 110.11 115.85 215.13 152.66 227.30 No Reference Casings
9622.75 8840.91 9775.00 9035.63 109.22 115.11 214.82 153.04 247.31 No Reference Casings
9631.19 8844.78 9800.00 9058.51 108.36 114.41 214.53 153.36 267.68 No Reference Casings
9639.11 8848.27 9825.00 9081.39 107.55 113.74 214.24 153.65 288.35 No Reference Casings
9646.55 8851.42 9850.00 9104.25 106.78 113.11 213.97 153.91 309.29 No Reference Casings
9653.57 8854.27 9875.00 9127.10 106.04 112.52 213.70 154.13 330.48 No Reference Casings
9666.53 8859.42 9900.00 9149.94 106.03 112.78 213.72 154.16 351.77 No Reference Casings
9679.63 8864.63 9925.00 9172.78 106.03 113.06 213.74 154.18 373.06 No Reference Casings
9692.73 8869.84 9950.00 9195.62 106.03 113.35 213.75 154.19 394.35 No Reference Casings
9705.73 8875.00 9974.80 9218.27 106.03 113.64 213.77 154.21 415.48 No Reference Casings
/. /"'
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"
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--------
----
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN
THE STATE OF ALASKA AND THAT
THIS PLAT REPRESENTS A SURVEY
MADE BY ME OR UNDER MY DIRECT
SUPERVISION AND THAT ALL
DIMENSIONS AND OTHER DETAILS ARE
CORRECT AS OF MAY 13, 2005.
24.
.1
23.
.2
22.
.3
21.
.4
20-+-
.5
19.
.6
18.
.7
17.
.8
-------
NOTES:
1. DATE OF SURVEY: MAY 10, 2005.
2. REFERENCE FIELD BOOK: PB05-02, PG'S 47-51.
3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD 27.
4. GEODETIC COORDINATES ARE NAD-27.
5. DRILL SITE 6 AVERAGE SCALE FACTOR IS: 0.9999388.
6. HORIZONTAL CONTROL IS BASED ON DS-6 MONUMENTS 6C AND 6D.
7. VERTICAL CONTROL IS BASED ON MONUMENT 6D.
ELEVATIONS ARE BP EXPLORATION MEAN SEA LEVEL DATUM.
8. TOP OF BASE FLANGE ELEVATION IS 38.90.
LOCATED WITHIN PROTRACTED SECTION 2, T. 10 N., R. 14 E., UMIAT MERIDIAN, ALASKA
WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION
NO. COORDINA TES COORDINATES POSITION(DMS) POSITION(D.DD) ELEV. OFFSETS
6-20 Y=5,940,949.59 5 1225.26 70'14'37.041" 70.2436225' 35.3' 350' FSL
X= 686,052.90 E 1124.61 148'29' 49.834" 148.4971761' 935' FEL
o 5 12 0 ISSUED FOR AS-BUIL T INFORMA 110N
NO. DA 1E RE'IISlON
/// / rFn
LEGEND
... AS-BUILT WELL
. EXISTING WELL
~~, DRAWN: Obp
FENTlE
CHECKED:
RFA
DATE: 5/12/05
DRAWING: SHEET:
FRB05 DS6 01-00 EOA DRILL SITE 6
¡ ffi~~rnœD JOB NO:
SCALE: AS-BUILT WELL LOCATION
JMF RFA ENGlNEERSANDLANOSUfNEYQRS WELL 6-20 1 OF 1
801'IIÆST nREWEED LANE 1" = 300'
BY CHK ANOtOAAGE, AlASKA 9t5OJ
bs14495.dgn
TERRIE L HUBBLE
BP EXPLORATION AKINC
PO BOX 196612 MB 7-5
ANCHORAGE, AK 99519-6612
89-6/1252 200
"Mastercard Check"
DATE os..\9 -OS
~~~~~cc ,$j@':LARS
~(~~
.
First Nâtional Bank Alaska
Anchorage, AK 99501
MEMO C/.o ·'2...0ff
I: ~ 25 2000 bOI: ~ ~ ~ ...... b 2 2 7··' ~ 5 5 bU- 0 200
e
.
.
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME jOð¿¡ Ô b - 2t5/J
PTD# 20.5'-- 0 7?
CHECK WHAT ADD-ONS "CLUE"
APPLIES (OPTIONS)
MULTI The permit is for a new wellbore segment of
LATERAL existing well_,
Permit No, API No. .
(If API number Production should continue to be reported as
last two (2) digits a function of the original API number stated
are between 60-69) above.
PILOT HOLE In accordance with 20 AAC 25.005(t), all
(PH) records, data and logs acquired for the pilot
hole must be clearly differentiated in both
name (name on permit plus PH)
and API number (50 -
70/80) from records, data and logs acquired
for well (name on permit).
SPACING The permit is approved subject to full
EXCEPTION compliance with 20 AAC 25.055. Approval to
perforate and produce/inject is contingent
upon issuance of a conservation order
approving a spacing exception.
(Company Name) assumes
the liability of any protest to the spacing
exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the
SAMPLE Commission must be in no greater than 30'
sample intervals from below the permafrost
or from where samples are first caught and
10' sample intervals through target zones.
Rev: 04/01/05
C\jody\transm ittal_ checklist
.
.
o
o
Well bore seg
Annular Disposal
640150 Well Name: PRUDHOE SAY UNIT 06-20A _ Program DEV
-
INC nitial ClasslType DEV 11-01L GeoArea 890 Unit 11650_ On/Off Shore On
- -
Administration PeOTJit fee attachejj - - - - Yf3S - - - - - - - -- - - - - - - - - - - - - - -
2 _Leas~number _appropriate - - - - - - - - - Yf3$ - - - - - - - - - - - - - - - - -
3 _U_nlque we''-"-arn~ _arrd Ol!mb_er - -- - - - -- _ __ __ __ _ Y_e$ - - - - - - - - - ~ . - - - - - - - - . - - - - -
4 Wen Jocat~d lna clefinejj _ppol_ - - - - - - - - - Y~$ - - - - - - - - - - - - - - - - - - -
5 Well Jocated p,.oper _distance_ from driJling unit b_oundjlry_ - - - - - - - - - _ Yf3S - - - - - - - - - - - - - - - - - - - - --
6 WeJUocat~d prpper _dlstance_ from other wells_ _ _ _ _ _ _ - - _Y~$ - - - - - - - - - - - -
7 _Sutfjcientjlcreage_ayailable in_drilliog l.InJt _ _ _ - - - - - Y~s - - - - - - - -- - - - - - - - - - -
8 Jtd~viated, Js_ weJlbore platjncJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s - - - - - - - - -- - - - - - - - -
9 _Operator 01'11>, affected party _ _ _ _ _ _ _ _ - - - - - - - - - - Y~s - - - - - - - - - - - - - -
10 _Ope,.ator has_apprpprlate_bond lnJorce _ _ _ _ _ _ _ _ _ _ - - - -- _ _ _ _ _ _ _ _ Yf3S - - - - - - - - - - - - - - - - - - - - - - - - -
11 P~rmit c_ao be iS$l!ed without co_nservatiol'l order _ _ _ _ _ _ _ _ Yf3S - - - - -
Appr Date 12 P~(mitC<lo be iSSl!ed without aclministratille_apprpval _ _ _ _ _ _ _ Y~s - - - - - - - - - - - - - - - -
RPC 5/20/2005 13 Can permit be approved before 15-day wait Yes
14 WeJUocated within area an_d_strata jluthorized by.lojectipo Ord~( # (puUO# in_cpr:nrn~otsUFor_ NA - - - - - - - - -
15 _AJI wellsJlyit!1in_1l4J'uile_area_of (eyiew id~otlfied (Fpr servJCf3JI'{etl on1y>- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - - - - - - - - - - - - - - - -
16 Pre-producecl iojeçtor; jjuratioRof pre-p(oductionl~ss than_:3 months_ (For_ser:vÎce well onJy) _ _ NA - - - - - - - - - - - --
17 ACMP_ finding .of Con.si.steocy has been jssued_ for_ tbi$ pr_oiect_ _ _ _ ___NA - - - - - ~ ~ ~ - - ~ ~
Engineering 18 _C_oodu_ctor string_provided _ _ _ . ~ - - ~ ~ - - - ~ _ _ _NA ~ - - -
19 _SwfaCf3 _casing_ protects alLknown USOWs _ _ _ _ _ _ _ _ . _ ___ NA ~ - - ~ ~ - - - - - - - - - - - - - - - - ~ -
20 CMT vpl adequateJo circjJtate_o_n _cond_uctor. & surtcsg _ _ . _ - ~ - - .NA - - - ~ - - - - - - - - - ~ - - - -
21 _CMT vol. adequ_ateJo tie-in Jong _striog to_surf C&g_ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - ~ ~ - - - -
22 _CMTwill coyer_all koownpro_ductiye bori~Qn_s_ _ _ _ _ . _ _ _ _ _ _ _ Yf3S ~ - - - - -
23 _C_asiog de_signs ad_eQua_te fp( C,_T" B _&_ p-ermafrpsL _ _ _ _ _ _ . . - Y~s
24 _Ädequatetankage_or re_Ser:ve pit _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - _ _ _Yf3S . Nab_ofS_2_ES, . - - - - - -
25 JtaJe-d(iII" bas_a_ tO~03 for abandonme_nt be~o approved _ _ _ _ _ _ _ _ Y~s _ _ _ _ .5/12/20_05. _ ~ - - - - -
26 AdequateJIl{ellboreseparatjo_n_propose~t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yf3S - - - - - - - - - - - - - - - - - - - - - - - --
27 Jtdiverter rectuired, does it meet reguJations_ _ _ _ _ _ _ _ _ . _ _ _ _ _ NA _ _ _ . _ Sidetrack.. . _ _ _ _ _ _ _ _ . _ _ _
Appr Date 28 _Dril/iog fluid_program sc.hematic_& equipJisLadequate_ _ _ . . _ _ _ _ _ _ Yes . Max MW8_.5. PP9. _ . _ _ _ _ _ _ _
WGA 5/23/2005 29 _BOPEs,_dpthey meetreguJation _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ - . _Y~$ - - ~ - - - - - - - - - - - - - ~ -
30 _BOPE_pre.ss ratiog appropriate; test to(PLlt p$ig in_comments)_ _ . . . . _ _ _Yf3S . _ _ _ . Test tp_35QO_psi. _MSI' 23]0 psi._
31 _CJ1oke_manifold compJies w/APtRI'-5:3 (May 84>- _ _ _ _ _ _ _ . _ _ Yf3S - - - - ~ ~ - - - -
32 Work will PCC_U( withpuLoperationsbutdowR _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Y~s - - - - - - - --
33 Js preseoce of H2S gas_ probable. - - - - - ~ ~ - - ~ - Yf3S _ _ _ 250ppm_onpad.
34 MechanicatC9oclitloopf wells within ~OR yerified (fors_ervice w~1J only) _ _NA
Geology 35 .P~(mit C<lO be iSSl!ed wlo_ hydrogen_ s_ulfide measjJ(es . - - - ~ . _ _ No_ - - - - - -
36 _Qata_preseoted on pote_ntialpve.rpressur~ _zOl]e.s _ _ _ _ _ _ _ _ _NA
Appr Date 37 _S~i.smic_analysJs of shaJlow gas_zpoes_ . . _ _ _ _ _ _ _ _ _ _ _ _ _NA
- - ~ - - - - - - ~ ~
RPC 5/20/2005 38 Sf3abedconditipo survey (if Qff-sh_o(e) . _ _ _ . _ _ _ _NA
- - - -
39 _ Conta_ct namelp!1oneJor_weekly progress_reports [exploratpry _oolYl NA - - - - - -
Geologic Date: Engineering Date Date
Commissioner: Commissioner:
D'e; Sl <~}3 ~ S-~3-tJ.) S .- z.l ... OJ
.
.
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 infom1ation.
e
e
620A006222005SSN.txt
Sperry-sun Drilli~g.services
LIS Scan Utlllty
$Revision: 3 $
LisLib $Revision: 4 $
Tue Jun 05 11:05:00 2007
Reel Header
Service name. ........... .LISTPE
Date. . . . . . . . . . . . . . . . . . . . .07/06/05
Ori gi n. . . . . . . . . . . . . . . . . . . STS
Reel Name....... .........UNKNOWN
continuation Number......01
Previous Reel Name..... ..UNKNOWN
Comments..... .......... ..STS LIS writing Library. scientific Technical services
Tape Header
service name. ........... .LISTPE
Date.......... .......... .07/06/05
Ori gi n. . . . . . . . . . . . . . . . . . . STS
Tape Name....... .........UNKNOWN
Continuation Number......01
previous Tape Name..... ..UNKNOWN
Comments....... ......... .STS LIS writing Library. scientific Technical services
physi ca 1 E)F
Comment Re:ord
TAPE HEADE~
Prudhoe Bar (EOA)
MWD/MAD LO~S
#
WELL NAME:
I
API NUMBER':
OPERATOR:
LOGGING Cor"'PANY:
TAPE CREATION DATE:
#
JOB DATA
06-20A
500292079901
BP Exploration (Alaska) Inc.
sperry Drilling services
05-JUN-07
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 2
W-0003753522
A. SHANAHAN
J. RALL
MWD RUN 3
w-0003753522
N. WHITE
J. RALL
MAD RUN 3
w-0003753522
N. WHITE
J. RAI.L
#
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
2
10N
14E
4930
935
64.30
35.30
#
WELL CASING RECORD
page 1
c90~~) -0'1''1 11 ~5"~ ~
e
e
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
620A006222005SSN.txt
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6.000 7.000 9273.0
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED. THESE
DEPTHS ARE BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP
OF WHICH WAS AT 9273'
MD/8575'TVD,IN THE 6-20 WELLBORE. THE WHIPSTOCK WAS
POSITIONED, THE WINDOW
WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING
MWD RUN 1. SROP DATA
FOR THIS RUN ARE MERGED WITH MWD RUN 2 SROP DATA.
4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY
(DGR) , UTILIZING GEIGER-
MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE
RESISTIVITY-PHASE 4 (EWR4), AND
AT-BIT INCLINATION (ABI). MWD RUN 3 ALSO INCLUDED
STABILIZED LITHO-DENSITY
(SLD) , AND COMPENSATED THERMAL NEUTRON POROSITY
(CTN). MAD PASS POROSITY
DATA ACQUIRED OVER THE MWD RUN 2 INTERVALS
9715'MD-10191'MD AND 10395'MD-
10438'MD (BIT DEPTHS), WHILE RIH FOR MWD RUN 3, WERE
MERGED WITH RUN 3 MWD
DATA. MAD DGR AND EWR4 DATA ARE PRESENTED SEPARATELY.
5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED
TO A SCHLUMBERGER
GAMMA RAY LOG RUN IN 6-20 ON 22 AUGUST 1982. ALL LOG
HEADER DATA RETAIN
ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA
WERE PROVIDED BY DOUG
DORTCH (SAIC/BP) ON 16 APRIL 2007, AS AUTHORIZED BY
DOUG STONER (BP).
6. MWD RUNS 1-3 REPRESENT WELL 6-20A WITH API#
50-029-20799-01. THIS WELL
REACHED A TOTAL DEPTH (TD) OF 11393'MD/8994'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(EXTRA-SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP
RESISTIVITY.
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE
Page 2
e
e
620A006222005SSN.tXt
MATRIX, FIXED HOLE SIZE).
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT
BIN).
sc02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN).
SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW-COUNT BIN).
SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS.
SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR
DISTANCE.
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: 6"
MUD WEIGHT: 8.4 PPG
MUD SALINITY: 1550-4400 PPM CHLORIDES
FORMATION WATER SALINITY: 10,994 PPM CHLORIDES
FLUID DENSITY: 1.0 GjCM3
MATRIX DENSITY: 2.65 GjCM3
LITHOLOGY: SANDSTONE
$
File Header
service name.. ...... .....STSLIB.001
service sub Level Name...
version Number.......... .1.0.0
Date of Generation.......07j06j05
Maximum physical Record. .65535
File Type...... ..... .... .LO
Previous File Name.......STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
FET
RPS
RPM
RPX
RPD
ROP
NCNT
NPHI
FCNT
PEF
DRHO
RHOB
$
1
clipped curves; all bit runs merged.
.5000
START DEPTH
9251. 0
9272.0
9272.0
9272.0
9272.0
9272.0
9275.0
9630.0
9630.5
9630.5
9644.5
9644.5
9644.5
STOP DEPTH
11343 .0
11350.0
11350.0
11350.0
11350.0
11350.0
11394.0
11307.0
11307.0
11309.0
11322.5
11322.5
11322 .5
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
BASELINE DEPTH
9251.0
9255.5
GR
9249.5
9254.0
page 3
e
e
620A006222005SSN.txt
9264.5
9273.5
9275.0
9278.0
9282.5
11394.0
$
9262.0
9271. 5
9273.0
9276.0
9281.0
11392.5
#
MERGED DATA
PBU TOOL
MWD
MWD
$
SOURCE
CODE BIT RUN NO MERGE TOP MERGE BASE
2 9249.5 10438.0
3 10438.0 11392.5
MERGED MAIN PASS.
$
#
REMARKS:
#
Data Format specification Record
Data Record Type... ....... .... ....0
Data specification Block Type.....O
Log9in9 Direction....... ..........Down
optlcal log depth units...........Feet
Data Reference point. .............undefined
Frame spacing.... .... ........ .....60 .1IN
Max frames per record............ .undefined
Absent value... ........... ....... .-999
Depth uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum specification Block sub-type...O
Name service order units size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
FCNT MWD CNTS 4 1 68 4 2
NCNT MWD CNTS 4 1 68 8 3
RHOB MWD G/CM 4 1 68 12 4
DRHO MWD G/CM 4 1 68 16 5
RPD MWD OHMM 4 1 68 20 6
RPM MWD OHMM 4 1 68 24 7
RPS MWD OHMM 4 1 68 28 8
RPX MWD OHMM 4 1 68 32 9
FET MWD HOUR 4 1 68 36 10
GR MWD API 4 1 68 40 11
PEF MWD BARN 4 1 68 44 12
ROP MWD FT/H 4 1 68 48 13
NPHI MWD PU-S 4 1 68 52 14
Fi rst Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 9251 11394 10322 . 5 4287 9251 11394
FCNT MWD CNTS 426.85 1504.76 649.431 2952 9630.5 11309
NCNT MWD CNTS 23254.6 37839.8 28932.7 2949 9630 11307
RHOB MWD G/CM 2.131 2.807 2.2583 2950 9644.5 11322 . 5
DRHO MWD G/CM -0.037 0.391 0.0608803 2950 9644.5 11322 . 5
RPD MWD OHMM 0.77 1925.83 35.7312 4157 9272 11350
RPM MWD OHMM 0.86 2000 31.8528 4157 9272 11350
RPS MWD OHMM 0.64 1351.05 24.1145 4157 9272 11350
RPX MWD OHMM 0.55 1373.06 20.2927 4157 9272 113 50
FET MWD HOUR 0.5 50.56 2.43876 4157 9272 11350
GR MWD API 12.73 566.07 36.9504 4185 9251 11343
PEF MWD BARN 0.83 8.21 1.613 2950 9644.5 11322 . 5
ROP MWD FT/H 0.03 287.34 50.2296 4239 9275 11394
NPHI MWD PU-S 11. 07 32.18 23.9839 2948 9630.5 11307
page 4
e
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620A006222005SSN.txt
First Reading For Entire File... .......9251
Last Reading For Entire File.... ...... .11394
Fi 1 e Trai 1 er
service name.. ........ ...STSLIB.001
service sub Level Name...
version Number.. .........1.0.0
Date of Generation. ......07/06/05
Maximum physical Record. .65535
Fi 1 e Type...... . . . . . . . . . . LO
Next File Name... ........STSLIB.002
physical EOF
File Header
service name.. ..... ..... .STSLIB.002
service sub Level Name...
version Number... ........1.0.0
Date of Generation.......07/06/05
Maximum physical Record. .65535
File Type.... ......... ...LO
Previous File Name... ....STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MAD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
RPD
RPM
FET
RPS
RPX
RAT
$
2
clipped curves; all MAD runs merged using earliest passes.
.5000
START DEPTH
9667.5
9675.5
9675.5
9675.5
9675.5
9675.5
9719.0
STOP DEPTH
10391. 0
10397.5
10397.5
10397.5
10397.5
10397.5
10442.0
#
MERGED DATA SOURCE
PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE
MWD 3 1 9628.5 11392.5
$
#
REMARKS:
MERGED MAD PASS.
$
#
Data Format specification Record
Data Record Type. .................0
Data specification Block Type.....O
Logging Direction....... ..........Down
optlcal log depth units.......... . Feet
Data Reference point...... ........undefined
Frame spacing......... ............60 .1IN
Max frames per record....... .... ..undefined
Absent val ue. . . . . . . . . . . . . . . . . . . . . . -999
Page 5
e
e
620A006222005sSN.txt
Depth uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum specification Block sub-type...O
Name Service order units Size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
RPD MAD OHMM 4 1 68 4 2
RPM MAD OHMM 4 1 68 8 3
RPS MAD OHMM 4 1 68 12 4
RPX MAD OHMM 4 1 68 16 5
FET MAD HOUR 4 1 68 20 6
GR MAD API 4 1 68 24 7
RAT MAD FT/H 4 1 68 28 8
Fi rst Last
Name Service unit Min Max Mean Nsam Reading Reading
DEPT FT 9667.5 10442 10054.8 1550 9667.5 10442
RPD MAD OHMM 2.48 124.01 41.009 1037 9675.5 10397.5
RPM MAD OHMM 2.56 106 . 52 32.3347 1037 9675.5 10397.5
RPS MAD OHMM 2.92 175.33 26.4379 1037 9675.5 10397.5
RPX MAD OHMM 3.51 172.96 23.0677 1037 9675.5 10397.5
FET MAD HOUR 19.25 40.41 32.5417 1037 9675.5 10397.5
GR MAD API 12.75 94.7 24.5948 1039 9667.5 10391
RAT MAD FT/H 3.93 1232.08 175.301 1040 9719 10442
First Reading For Entire File......... .9667.5
Last Reading For Entire File.......... .10442
Fi 1 e Trail er
service name. ........... .STSLIB.002
Service Sub Level Name...
version Number.......... .1.0.0
Date of Generation...... .07/06/05
Maximum physical Record. .65535
File Type.... ........... .LO
Next File Name.......... .STSLIB.003
physical EOF
File Header
service name...... .......STSLIB.003
service sub Level Name...
version Number... .... ....1.0.0
Date of Generation.......07/06/05
Maximum physical Record..65535
Fi 1 e Type.... . . . . . . . . . . . . LO
previous File Name.......STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
3
header data for each bit run in separate files.
2
.5000
START DEPTH
STOP DEPTH
Page 6
e
e
GR
FET
RPS
RPM
RPX
RPD
ROP
$
9249.5
9270.0
9270.0
9270.0
9270.0
9270.0
9273.0
620A006222005sSN.txt
10386.5
10394.0
10394.0
10394.0
10394.0
10394.0
10438.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
Electromag Resis. 4
#
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (s):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format specification Record
Data Record Type... .... ...........0
Data specification Block Type.....O
Log~ing Direction................ . Down
optlcal log depth units... .... ....Feet
Data Reference Point.... ..........undefined
page 7
20-JUN-05
Insite
66.37
Memory
10438.0
9273.0
10438.0
24.5
87.4
TOOL NUMBER
64004
59475
6.000
9273.0
Flo pro SF
8.40
52.0
9.7
4500
11.6
1.100
.620
1.800
1.600
70.0
129.2
70.0
70.0
e
e
620A006222005SSN.txt
Frame spacing.. ............ ...... .60 .1IN
Max frames per record...... .......undefined
Absent value. ............ .........-999
Depth uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name service order units Size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
RPD MWD020 OHMM 4 1 68 4 2
RPM MWD020 OHMM 4 1 68 8 3
RPS MWD020 OHMM 4 1 68 12 4
RPX MWD020 OHMM 4 1 68 16 5
FET MWD020 HOUR 4 1 68 20 6
GR MWD020 API 4 1 68 24 7
ROP MWD020 FT/H 4 1 68 28 8
Fi rst Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 9249.5 10438 9843.75 2378 9249.5 10438
RPD MWD020 OHMM 0.77 1925.83 50.2761 2249 9270 10394
RPM MWD020 OHMM 0.86 2000 44.184 2249 9270 10394
RPS MWD020 OHMM 0.64 1351. 05 31. 5913 2249 9270 10394
RPX MWD020 OHMM 0.55 1373.06 25.8907 2249 9270 10394
FET MWD020 HOUR 0.89 50.56 2.85808 2249 9270 10394
GR MWD020 API 15.14 566.07 41. 8338 2275 9249.5 10386.5
ROP MWD020 FT /H 0.03 157.07 39.925 2331 9273 10438
First Reading For Entire File......... .9249.5
Last Reading For Entire File.......... .10438
File Trailer
service name............ .STSLIB.003
service sub Level Name...
version Number....... ....1.0.0
Date of Generation.......07/06/05
Maximum physical Record..65535
Fi 1 e Type. . . . . . . . . . . . . . . . LO
Next File Name..... ..... .STSLIB.004
physical EOF
File Header
service name... .... ......STSLIB.004
service sub Level Name...
version Number......... ..1.0.0
Date of Generation.... ...07/06/05
Maximum physical Record..65535
File Type............... .LO
previous File Name...... .STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
4
header data for each bit run in separate files.
3
.5000
Page 8
e
620A006222005SSN.txt
#
FILE SUMMARY
VENDOR TOOL CODE
NCNT
NPHI
FCNT
PEF
DRHO
RHOB
GR
RPX
RPS
FET
RPM
RPD
ROP
$
START DEPTH
9628.5
9629.0
9629.0
9643.0
9643.0
9643.0
10387.0
10394.5
10394.5
10394.5
10394.5
10394.5
10438.5
STOP DEPTH
11305. 5
11305.5
11307. 5
11321.0
11321. 0
11321. 0
11341. 5
11348.5
11348.5
11348. 5
11348. 5
11348.5
11392.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
SLD
CTN
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
#
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
page 9
e
22-JUN-05
Ins;te
66.37
Memory
11393.0
10438.0
11393.0
87.4
95.6
TOOL NUMBER
64004
149845
149845
149845
6.000
9273.0
Flo pro SF
8.40
52.0
8.4
2500
8.0
1. 100
.480
1.800
1.600
70.0
169.0
70.0
70.0
e
e
620A006222005SSN.txt
#
EWR FREQUENCY (HZ):
REMARKS:
$
#
Data Format specification Record
Data Record Type..................O
Data specification Block Type.....O
Log~ing Direction................ . Down
optlcal log depth units. ..........Feet
Data Reference point....... ..... ..undefined
Frame spacing.......... ...........60 .1IN
Max frames per record....... ..... . undefined
Absent value.......... ............-999
Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name service order units size Nsam Rep Code offset channel
DEPT FT 4 1 68 0 1
FCNT MWD030 CNTS 4 1 68 4 2
NCNT MWD030 CNTS 4 1 68 8 3
RHOB MWD030 G/CM 4 1 68 12 4
DRHO MWD030 G/CM 4 1 68 16 5
RPD MWD030 OHMM 4 1 68 20 6
RPM MWD030 OHMM 4 1 68 24 7
RPS MWD030 OHMM 4 1 68 28 8
RPX MWD030 OHMM 4 1 68 32 9
FET MWD030 HOUR 4 1 68 36 10
GR MWD030 API 4 1 68 40 11
PEF MWD030 BARN 4 1 68 44 12
ROP MWD030 FT/H 4 1 68 48 13
NPHI MWD030 pU-S 4 1 68 52 14
Fi rst Last
Name service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9628.5 11392.5 10510.5 3529 9628.5 11392.5
FCNT MWD030 CNTS 426.85 1504.76 649.431 2952 9629 11307. 5
NCNT MWD030 CNTS 23254.6 37839.8 28932.7 2949 9628.5 11305.5
RHOB MWD030 G/CM 2.131 2.807 2.2583 2950 9643 11321
DRHO MWD030 G/CM -0.037 0.391 0.0608803 2950 9643 11321
RPD MWD030 OHMM 2.84 53.83 18.5936 1909 10394.5 11348. 5
RPM MWD030 OHMM 2.34 49.94 17. 3124 1909 10394.5 11348.5
RPS MWD030 OHMM 2.27 50.75 15.2948 1909 10394.5 11348.5
RPX MWD030 OHMM 2.38 48.05 13 . 6881 1909 10394.5 11348. 5
FET MWD030 HOUR 0.5 19.57 1.97098 1909 10394.5 11348.5
GR MWD030 API 12.73 101.14 31.1401 1910 10387 11341. 5
PEF MWD030 BARN 0.83 8.21 1.613 2950 9643 11321
ROP MWD030 FT /H 0.83 287.34 62.7875 1909 10438.5 11392.5
NPHI MWD030 PU-S 11. 07 32.18 23.9839 2948 9629 11305.5
First Reading For Entire File.. ....... .9628.5
Last Reading For Entire File.......... .11392.5
File Trailer
service name.. ......... ..STSLIB.004
service sub Level Name...
version Number.... .......1.0.0
Date of Generation...... .07/06/05
Maximum physical Record..65535
page 10
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620A006222005sSN.txt
Fi 1 e Type. . . . . . . . . . . . . . . . LO
Next File Name. ........ ..STSLIB.005
physical EOF
File Header
Service name..... ........STSLIB.005
service Sub Level Name...
version Number...... .... .1.0.0
Date of Generation.......07/06/05
Maximum physical Record..65535
File Type....... .... .... .LO
previous File Name. ......STSLIB.004
comment Record
FILE HEADER
FILE NUMBER:
RAW MAD
Curves and log
DEPTH INCREMENT:
MAD RUN NUMBER:
MAD PASS NUMBER:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
RPS
FET
RPX
RPM
RAT
$
5
header data for each pass of each run in separate files.
.5000
3
1
START DEPTH
9666.0
9674.0
9674.0
9674.0
9674.0
9674.0
9717.5
STOP DEPTH
10389.5
10396.0
10396.0
10396.0
10396.0
10396.0
10440.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
22-JUN-05
Insite
66.37
Memory
10438.0
9715.0
10438.0
87.4
95.6
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
TOOL NUMBER
64004
149845
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.000
9273.0
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
Flo Pro SF
8.40
page 11
e
e
MUD! VISCOSITY (S):
MUD PH:
MuD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
~UD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
~UD CAKE AT MT:
620A006222005sSN.txt
52.0
8.4
2500
8.0
1.100
.480
1.800
1.600
70.0
169.0
70.0
70.0
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format specification Record
Data Record Type..................O
Data specification Block Type.....O
LogØing Direction........ .........Down
OptlcaJ log depth units... ........Feet
Data Reference Point........ ..... .undefined
Frame Spacing.... ................ .60 .1IN
Max frames per record.............undefined
Absent val ue. . . . . . . . . . . . . . . . . . . . . . -999
Depth uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name service order units Size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
RPD MADOn OHMM 4 1 68 4 2
RPM MAD031 OHMM 4 1 68 8 3
RPS MAD031 OHMM 4 1 68 12 4
RPX MADOn OHMM 4 1 68 16 5
FET MADOn HOUR 4 1 68 20 6
GR MAD031 API 4 1 68 24 7
RAT MADOn FT/H 4 1 68 28 8
Fi rst Last
Name service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9666 10440.5 10053.3 1550 9666 10440.5
RPD MADOn OHMM 2.48 124.01 41.009 1037 9674 10396
RPM MADOn OHMM 2.56 106.52 32.3347 1037 9674 10396
RPS MADOn OHMM 2.92 175.33 26.4379 1037 9674 10396
RPX MADOn OHMM 3.51 172.96 23.0677 1037 9674 10396
FET MADOH HOUR 19.25 40.41 32.5417 1037 9674 10396
GR MAD031 API 12.75 94.7 24.5948 1039 9666 10389.5
RAT MADOH FT /H 3.93 1232.08 175.301 1040 9717.5 10440.5
First ReaQing For Entire Fi1e..........9666
Last Reading For Entire File. ..........10440.5
Fi 1 e Trail er
Servicè name...... .......STSLIB.005
page 12
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620A006222005SSN.txt
service sub Level Name...
version Number... ........1.0.0
Date of Generation.......07/06/05
Maxim~m physical Record..65535
Fi 1 e Type....... . . . . . . . . . LO
Next Rile Name........ ...STSLIB.006
physical :EOF
Tape Trailer
service name.. ......... ..LISTPE
Date. ... . . . . . . . . . . . . . . . . . .07/06/05
ori gi 11. . . . . . . . . . . . . . . . . . . STS
Tape Name..... .... ...... . UNKNOWN
Continuation Number..... .01
Next Tape Name. ..........UNKNOWN
Comments........ .........STS LIS writing Library. scientific Technical services
Reel Trailer
serviqe name....... ... ...LISTPE
Date. .. . . . . . . . . . . . . . . . . . .07/06/05
ori gi n. . . . . . . . . . . . . . . . . . . STS
Reel Name.... ......... ...UNKNOWN
Continuation Number... ...01
Next Reel Name........ ...UNKNOWN
Comments..... ........... .STS LIS writing Library. scientific Technical services
physicalEOF
physicalEOF
End of LIS Fi 1 e
page 13
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0620A006222005SSN.txt
sperry-sun Drilli~g.services
LIS Scan ut,l,ty
$Revision: 3 $
LisLib $Revision: 4 $
Tue Jun 19 07:12:42 2007
Reel Header
service name... ..........LISTPE
Date. .. . . . . . . . . . . . . . . . . . . .07/06/19
ori gi n . . . . . . . . . . . . . . . . . . . STS
Reel Name.... ........... . UNKNOWN
Continuation Number..... .01
previÓus Reel Name...... . UNKNOWN
Comments................ .STS LIS writing Library. scientific Technical services
Tape Header
servièe name.. ..... ..... .LISTPE
Date.~........ ..... ..... .07/06/19
ori gi r\. . . . . . . . . . . . . . . . . . . STS
Tape Name... ............ . UNKNOWN
Continuation Number..... .01
previous Tape Name..... ..UNKNOWN
Comments.......... ...... .STS LIS writing Library. scientific Technical services
physicalEOF
Comment Record
TAPE HEADER
Prudhoe 6ay (EOA)
MWD/MAD 1,.0GS
#
WELL NAMf!:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
# .
JOB DATA
06-20A
500292079901
BP Exploration (Alaska) Inc.
sperry Drilling services
18-JUN-07
JOB NUMBER:
LOGGING ENGINEER:
OPERAtOR WITNESS:
MWD RUN 2
w-0003753522
A. SHANAHAN
J. RALL
MWD RUN 3
w-0003753522
N. WHITE
J. RALL
MAD RUN 3
w-0003753522
N. WHITE
J. RALL
#
SURFACE L.OCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KEL.LY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
2
10N
14E
4930
935
64.30
35.30
#
WELL CASING RECORD
page 1
PDtJ-oô? .. 1~-;;a'7
e
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1ST StRING
2ND StRING
3RD StRING
PRODUCTION STRING
0620A006222005sSN.txt
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6.000 7.000 9273.0
#
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE
NOTED. THESE
DEPTHS ARE BIT DEPTHS.
2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD).
3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP
OF WHICH WAS AT 9273'
MD/8575'TVD,IN THE 6-20 WELLBORE. THE WHIPSTOCK WAS
POSITIONED, THE WINDOW
WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING
MWD RUN 1. SROP DATA
FOR THIS RUN ARE MERGED WITH MWD RUN 2 SROP DATA.
4. MWD RUNS 2,3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY
(DGR), UTILIZING GEIGER-
MUELLER TUBE DETECTORS,ELECTROMAGNETIC WAVE
RESISTIVITY-PHASE 4 (EWR4), AND
AT-BIT INCLINATION (ABI). MWD RUN 3 ALSO INCLUDED
STABILIZED LITHO-DENSITY
(SLD), AND COMPENSATED THERMAL NEUTRON POROSITY
(CTN). MAD PASS POROSITY
DATA ACQUIRED OVER THE MWD RUN 2 INTERVALS
9715'MD-10191'MD AND 10395'MD-
10438'MD (BIT DEPTHS), WHILE RIH FOR MWD RUN 3, WERE
MERGED WITH RUN 3 MWD
DATA. MAD DGR AND EWR4 DATA ARE PRESENTED SEPARATELY.
5. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED
TO A SCHLUMBERGER GAMMA
RAY LOG RUN IN 6-20 ON 22 AUGUST 1982. SUBSEQUENTLY,
AN UPHOLE BULK-SHIFT OF
10' WAS APPLIED TO ACCOUNT FOR REFERENCE ELEVATION
DIFFERENCES BETWEEN RIGS.
ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH
REFERENCES. THESE PDC
DATA WERE PROVIDED BY DOUG DORTCH (SAIC/BP) ON 16
APRIL 2007, AS AUTHORIZED
BY DOUG STONER (BP). THIS LOG IS THE PDCL FOR 6-20A.
6. MWD RUNS 1-3 REPRESENT WELL 6-20A WITH API#
50-029-20799-01. THIS WELL
REACHED A TOTAL DEPTH (TD) OF 11393'MD/8994'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(EXTRA-SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW
SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
Page 2
e
e
0620A006222005SSN.txt
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP
RESISTIVITY.
TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE
MATRIX, FIXED HOLE SIZE).
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE.
CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE.
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT
BIN).
sc02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN).
SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW-COUNT BIN).
SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS.
SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR
DISTANCE.
PARAMETERS USED IN POROSITY LOG PROCESSING:
HOLE SIZE: 6"
MUD WEIGHT: 8.4 PPG
MUD SALINITY: 1550-4400 PPM CHLORIDES
FORMATION WATER SALINITY: 10,994 PPM CHLORIDES
FLUID DENSITY: 1.0 G/CM3
MATRIX DENSITY: 2.65 G/CM3
LITHOLOGY: SANDSTONE
$
File Header
service name.. ......... ..STSLIB.001
service sub Level Name...
version Number... .... ....1.0.0
Date of Generation...... .07/06/19
Maximum physical Record. .65535
Fi 1 e Type. . . . . . . . . . . . . . . . LO
Previous File Name.......STSLIB.OOO
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MWD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
RPS
RPM
RPD
RPX
FET
ROP
NCNT
NPHI
FCNT
PEF
DRHO
RHOB
$
1
clipped curves; all bit runs merged.
.5000
START DEPTH
9241.0
9262.0
9262.0
9262.0
9262.0
9262.0
9265.0
9620.0
9620.5
9620.5
9634.5
9634.5
9634.5
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
STOP DEPTH
11333.0
11340.0
11340.0
11340.0
11340.0
11340.0
11384.0
11297.0
11297.0
11299.0
11312.5
11312.5
11312.5
page 3
BASELINE DEPTH
9241.0
9245.5
9254.5
9263.5
9265.0
9268.0
9272.5
11384.0
$
#
MERGED DATA
PBU TOOL
MWD
MWD
$
e
e
---------
0620A006222005SSN.txt
EQUIVALENT UNSHIFTED DEPTH ---------
GR
9251. 0
9255.5
9264.5
9273.5
9275.0
9278.0
9282.5
11394.0
SOURCE
CODE BIT RUN NO MERGE TOP MERGE BASE
2 9249.5 10438.0
3 10438.0 11392.5
MERGED MAIN PASS.
$
#
REMARKS:
#
Data Format specification Record
Data Record Type..................O
Data Specification Block Type.....O
Log~ing Direction................ . Down
optlcal log depth units..... ..... .Feet
Data Reference Point... .... .......undefined
Frame spacing............ .........60 .1IN
Max frames per record..... ....... .undefined
Absent value.............. ....... .-999
Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum specification Block sub-type...O
Name Service order units size Nsam Rep Code offset channel
DEPT FT 4 1 68 0 1
FCNT MWD CNTS 4 1 68 4 2
NCNT MWD CNTS 4 1 68 8 3
RHOB MWD G/CM 4 1 68 12 4
DRHO MWD G/CM 4 1 68 16 5
RPD MWD OHMM 4 1 68 20 6
RPM MWD OHMM 4 1 68 24 7
RPS MWD OHMM 4 1 68 28 8
RPX MWD OHMM 4 1 68 32 9
FET MWD HOUR 4 1 68 36 10
GR MWD API 4 1 68 40 11
PEF MWD BARN 4 1 68 44 12
ROP MWD FT/H 4 1 68 48 13
NPHI MWD PU-S 4 1 68 52 14
Fi rst Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 9241 11384 10312. 5 4287 9241 11384
FCNT MWD CNTS 426.85 1504.76 649.431 2952 9620.5 11299
NCNT MWD CNTS 23254.6 37839.8 28932.7 2949 9620 11297
RHOB MWD G/CM 2.131 2.807 2.2583 2950 9634.5 11312 . 5
DRHO MWD G/CM -0.037 0.391 0.0608803 2950 9634.5 11312.5
RPD MWD OHMM 0.77 1925.83 35.7312 4157 9262 11340
RPM MWD OHMM 0.86 2000 31.8528 4157 9262 11340
RPS MWD OHMM 0.64 1351. 05 24.1145 4157 9262 11340
RPX MWD OHMM 0.55 1373.06 20.2927 4157 9262 11340
FET MWD HOUR 0.5 50.56 2.43876 4157 9262 11340
page 4
GR MWD
PEF MWD
ROP MWD
NPHI MWD
API
BARN
FT/H
PU-S
e
e
12.73
0.83
0.03
11. 07
0620A006222005SSN.txt
566.07 36.9504
8.21 1.613
287.34 50.2296
32.18 23.9839
4185
2950
4239
2948
9241
9634.5
9265
9620.5
11333
11312.5
11384
11297
First Reading For Entire File......... .9241
Last Reading For Entire File.......... .11384
Fi 1 e Trail er
service name... ......... .STSLIB.OOl
service sub Level Name...
version Number. ......... .1.0.0
Date of Generation. ..... .07/06/19
Maxim~m physical Record. .65535
Fi 1 e type.. . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.002
physical EOF
File Header
service name. ........... .STSLIB.002
service sub Level Name...
version Number.......... .1.0.0
Date of Generation...... .07/06/19
Maximwm physical Record. .65535
Fi 1 e Type.. . . . . . . . . . . . . . . LO
Previous File Name...... .STSLIB.OOl
Comment Record
FILE HEADER
FILE NUMBER:
EDITED MERGED MAD
Depth shifted and
DEPTH INCREMENT:
#
FILE SUMMARY
PBU TOOL CODE
GR
RPD
RPX
RPS
RPM
FET
RAT
$
2
clipped curves; all MAD runs merged uSlng earliest passes.
.5000
START DEPTH
9657.5
9665.5
9665.5
9665.5
9665.5
9665.5
9709.0
STOP DEPTH
10381. 0
10387.5
10387.5
10387.5
10387.5
10387.5
10432.0
#
MERGED DATA SOURCE
PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE
MWD 3 1 9666.0 10440.5
$
#
REMARKS: MERGED MAD PASS.
$
#
Data Format specification Record
Data Record Type..................O
Data Specification Block Type.....O
Log~ing Direction.. .............. . Down
optlcal log depth units.......... .Feet
page 5
e
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0620A006222005SSN.txt
Data Reference Point.. ............undefined
Frame spacing............ .........60 .1IN
Max frames per record.... ..... ....undefined
Absent val ue. . . . . . . . . . . . . . . . . . . . . . -999
Depth uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum specification Block sub-type...O
Name Service order Units size Nsam Rep code offset Channel
DEPT FT 4 1 68 0 1
RPD MAD OHMM 4 1 68 4 2
RPM MAD OHMM 4 1 68 8 3
RPS MAD OHMM 4 1 68 12 4
RPX MAD OHMM 4 1 68 16 5
FET MAD HOUR 4 1 68 20 6
GR MAD API 4 1 68 24 7
RAT MAD FT/H 4 1 68 28 8
Fi rst Last
Name Service unit Min Max Mean Nsam Reading Reading
DEPT FT 9657.5 10432 10044.8 1550 9657.5 10432
RPD MAD OHMM 2.48 124.01 41. 009 1037 9665.5 10387.5
RPM MAD OHMM 2.56 106.52 32.3347 1037 9665.5 10387.5
RPS MAD OHMM 2.92 175.33 26.4379 1037 9665.5 10387.5
RPX MAD OHMM 3.51 172.96 23.0677 1037 9665.5 10387.5
FET MAD HOUR 19.25 40.41 32.5417 1037 9665.5 10387.5
GR MAD API 12.75 94.7 24.5948 1039 9657.5 10381
RAT MAD FT/H 3.93 1232.08 175.301 1040 9709 10432
First Reading For Entire File......... .9657.5
Last Reading For Entire File... ....... .10432
Fi 1 e Trail er
service name..... .... ....STSLIB.002
service sub Level Name...
version Number......... ..1.0.0
Date of Generation...... .07/06/19
Maximum physical Record. .65535
Fi 1 e Type.. . . . . . . . . . . . . . . LO
Next File Name.......... .STSLIB.003
physical EOF
File Header
service name............ .STSLIB.003
service sub Level Name...
version Number.......... .1.0.0
Date of Generation.......07/06/19
Maximum physical Record..65535
File Type.... ..... ...... .LO
Previous File Name...... .STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
Page 6
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DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPS
FET
RPX
RPM
RPD
ROP
$
.5000
0620A006222005SSN.txt
START DEPTH
9249.5
9270.0
9270.0
9270.0
9270.0
9270.0
9273.0
STOP DEPTH
10386.5
10394.0
10394.0
10394.0
10394.0
10394.0
10438.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 Electromag Resis. 4
$
#
#
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (s):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format specification Record
Data Record Type...... ....... .....0
page 7
20-JUN-05
Insite
66.37
Memory
10438.0
9300.0
10438.0
24.5
87.4
TOOL NUMBER
64004
59475
6.000
9273.0
Flo Pro SF
8.40
52.0
9.7
4500
11.6
1.100
.620
1. 800
1.600
70.0
129.2
70.0
70.0
e
e
0620A006222005SSN.txt
Data specification Block Type. . . . .0
Log~ing Direction... ........ ..... . Down
optlcal log depth units.. .........Feet
Data Reference Point............. .undefined
Frame spacing... ...... ........... .60 .1IN
Max frames per record...... ...... .undefined
Absent value.... .... ............. .-999
Depth uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order units size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
RPD MWD020 OHMM 4 1 68 4 2
RPM MWD020 OHMM 4 1 68 8 3
RPS MWD020 OHMM 4 1 68 12 4
RPX MWD020 OHMM 4 1 68 16 5
FET MWD020 HOUR 4 1 68 20 6
GR MWD020 API 4 1 68 24 7
ROP MWD020 FT/H 4 1 68 28 8
Fi rst Last
Name Service unit Min Max Mean Nsam Reading Reading
DEPT FT 9249.5 10438 9843.75 2378 9249.5 10438
RPD MWD020 OHMM 0.77 1925.83 50.2761 2249 9270 10394
RPM MWD020 OHMM 0.86 2000 44.184 2249 9270 10394
RPS MWD020 OHMM 0.64 1351. 05 31. 5913 2249 9270 10394
RPX MWD020 OHMM 0.55 1373.06 25.8907 2249 9270 10394
FET MWD020 HOUR 0.89 50.56 2.85808 2249 9270 10394
GR MWD020 API 15.14 566.07 41. 8338 2275 9249.5 10386.5
ROP MWD020 FT/H 0.03 157.07 39.925 2331 9273 10438
First Reading For Entire File...... ....9249.5
Last Reading For Entire File.......... .10438
File Trailer
service name.. .......... .STSLIB.003
service sub Level Name...
version Number.......... .1.0.0
Date of Generation. ......07/06/19
Maximum physical Record..65535
File Type.... ........... .LO
Next File Name. ..........STSLIB.004
physical EOF
File Header
service name... ..........STSLIB.004
service sub Level Name...
version Number.......... .1.0.0
Date of Generation.......07/06/19
Maximum physical Record. .65535
Fi 1 e Type. . . . . . . . . . . . . . . . LO
previous File Name.. .... .STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
page 8
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0620A006222005sSN.txt
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
FILE SUMMARY
VENDOR TOOL CODE
NCNT
FCNT
NPHI
PEF
DRHO
RHOB
GR
RPS
RPM
FET
RPX
RPD
ROP
$
header data for each bit run in separate files.
3
.5000
START DEPTH
9628.5
9629.0
9629.0
9643.0
9643.0
9643.0
10387.0
10394.5
10394.5
10394.5
10394.5
10394.5
10438.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
SLD
CTN
$
STOP DEPTH
11305.5
11307. 5
11305.5
11321.0
11321. 0
11321. 0
11341. 5
11348.5
11348.5
11348.5
11348.5
11348.5
11392.5
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (s):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
#
NEUTRON TOOL
MATRIX:
page 9
22-JUN-05
Insite
66.37
Memory
11393.0
10438.0
11393.0
87.4
95.6
TOOL NUMBER
64004
149845
149845
149845
6.000
9273.0
Flo pro SF
8.40
52.0
8.4
2500
8.0
1.100
.480
1.800
1.600
70.0
169.0
70.0
70.0
e
e
0620A006222005sSN.txt
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format specification Record
Data Record Type.......... ..... ...0
Data specification Block Type.....O
Log~ing Direction....... ..........Down
optlcal log depth units...........Feet
Data Reference point.. ....... .....undefined
Frame spacing.. ................. ..60 .1IN
Max frames per record............ .undefined
Absent value.. ................... .-999
Depth uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name service Order units size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
FCNT MWD030 CNTS 4 1 68 4 2
NCNT MWD030 CNTS 4 1 68 8 3
RHOB MWD030 G/CM 4 1 68 12 4
DRHO MWD030 G/CM 4 1 68 16 5
RPD MWD030 OHMM 4 1 68 20 6
RPM MWD030 OHMM 4 1 68 24 7
RPS MWD030 OHMM 4 1 68 28 8
RPX MWD030 OHMM 4 1 68 32 9
FET MWD030 HOUR 4 1 68 36 10
GR MWD030 API 4 1 68 40 11
PEF MWD030 BARN 4 1 68 44 12
ROP MWD030 FT/H 4 1 68 48 13
NPHI MWD030 pU-S 4 1 68 52 14
Fi rst Last
Name service Unit Min Max Mean Nsam Reading Reading
DEPT FT 9628.5 11392.5 10510.5 3529 9628.5 11392.5
FCNT MWD030 CNTS 426.85 1504.76 649.431 2952 9629 11307. 5
NCNT MWD030 CNTS 23254.6 37839.8 28932.7 2949 9628.5 11305.5
RHOB MWD030 G/CM 2.131 2.807 2.2583 2950 9643 11321
DRHO MWD030 G/CM -0.037 0.391 0.0608803 2950 9643 11321
RPD MWD030 OHMM 2.84 53.83 18.5936 1909 10394.5 11348. 5
RPM MWD030 OHMM 2.34 49.94 17.3124 1909 10394.5 11348.5
RPS MWD030 OHMM 2.27 50.75 15.2948 1909 10394.5 11348.5
RPX MWD030 OHMM 2.38 48.05 13 . 6881 1909 10394.5 11348.5
FET MWD030 HOUR 0.5 19.57 1. 97098 1909 10394.5 11348. 5
GR MWD030 API 12.73 101. 14 31.1401 1910 10387 11341. 5
PEF MWD030 BARN 0.83 8.21 1.613 2950 9643 11321
ROP MWD030 FT/H 0.83 287.34 62.7875 1909 10438.5 11392.5
NPHI MWD030 pU-S 11. 07 32.18 23.9839 2948 9629 11305.5
First Reading For Entire File. ........ .9628.5
Last Reading For Entire File...........11392.5
File Trailer
service name..... ........STSLIB.004
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service sub Level Name...
Version Number. ..........1.0.0
Date of Generation...... .07/06/19
Maximum physical Record..65535
Fi 1 e Type.. . . . . . . . . . . . . . . LO
Next File Name......... ..STSLIB.005
physical EOF
File Header
service name. ........... .STSLIB.005
service sub Level Name...
version Number..... ..... .1.0.0
Date of Generation.... ...07/06/19
Maximum physical Record..65535
Fi 1 e Type.. . . . . . . . . . . . . . . LO
Previous File Name... ....STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER:
RAW MAD
Curves and log
DEPTH INCREMENT:
MAD RUN NUMBER:
MAD PASS NUMBER:
#
FILE SUMMARY
VENDOR TOOL CODE
GR
RPD
FET
RPX
RPM
RPS
RAT
$
5
header data for each pass of each run in separate files.
.5000
3
1
START DEPTH
9666.0
9674.0
9674.0
9674.0
9674.0
9674.0
9717.5
STOP DEPTH
10389.5
10396.0
10396.0
10396.0
10396.0
10396.0
10440.5
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
22-JUN-05
Insite
66.37
Memory
10438.0
9720.0
10438.0
87.4
95.6
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
TOOL NUMBER
64004
149845
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
6.000
9273.0
page 11
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#
0620A006222005SSN.txt
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
#
REMARKS:
$
#
Data Format specification Record
Data Record Type..................O
Data specification Block Type.....O
Log~ing Direction.. ........ ...... . Down
Optlcal log depth units......... ..Feet
Data Reference Point.... ..........Undefined
Frame spacing...... .............. .60 .1IN
Max frames per record........... ..undefined
Absent value............. ...... ...-999
Depth uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum specification Block sub-type...O
Flo Pro SF
8.40
52.0
8.4
2500
8.0
1.100
.480
1.800
1.600
70.0
169.0
70.0
70.0
Name service order units Size Nsam Rep code offset channel
DEPT FT 4 1 68 0 1
RPD MAD031 OHMM 4 1 68 4 2
RPM MADOn OHMM 4 1 68 8 3
RPS MADOn OHMM 4 1 68 12 4
RPX MAD031 OHMM 4 1 68 16 5
FET MADOn HOUR 4 1 68 20 6
GR MAD031 API 4 1 68 24 7
RAT MADOn FT/H 4 1 68 28 8
Fi rst Last
Name service unit Min Max Mean Nsam Reading Reading
DEPT FT 9666 10440.5 10053.3 1550 9666 10440.5
RPD MADOn OHMM 2.48 124.01 41.009 1037 9674 10396
RPM MAD031 OHMM 2.56 106.52 32.3347 1037 9674 10396
RPS MADOn OHMM 2.92 175.33 26.4379 1037 9674 10396
RPX MADOn OHMM 3.51 172.96 23.0677 1037 9674 10396
FET MADOn HOUR 19.25 40.41 32.5417 1037 9674 10396
GR MADOn API 12.75 94.7 24.5948 1039 9666 10389.5
RAT MADOn FT /H 3.93 1232.08 175.301 1040 9717.5 10440.5
First Reading For Entire File..........9666
Last Reading For Entire File.......... .10440.5
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File Trailer
service name... ......... .STSLIB.005
service sub Level Name...
version Number... ...... ..1.0.0
Date of Generation...... .07/06/19
Maximum physical Record. .65535
Fi 1 e Type.... . . . . . . . . . . . . LO
Next File Name......... ..STSLIB.006
physical EOF
Tape Trailer
service name.... .... .....LISTPE
Date.. ..... ............. .07/06/19
Ori gi n . . . . . . . . . . . . . . . . . . . STS
Tape Name..... ...........UNKNOWN
Continuation Number......01
Next Tape Name.......... . UNKNOWN
Comments..... ........... .STS LIS writing Library. scientific Technical services
Reel Trailer
Service name... ..........LISTPE
Date. . . . . . . . . . . . . . . . . . . . .07/06/19
Ori gi n. . . . . . . . . . . . . . . . . . . STS
Reel Name... ............ . UNKNOWN
Continuation Number......01
Next Reel Name.. ...... ...UNKNOWN
Comments................ .STS LIS writing Library. scientific Technical services
physical EOF
physical EOF
End of LIS Fi 1 e
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