Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout202-229By James Brooks at 4:23 pm, Jan 31, 2023
Abandoned
1/7/2023
JSB
RBDMS JSB 020823
xG
DSR-2/8/23MGR28JULY2023
1.31.2023
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2023.01.31 15:57:54 -09'00'
Monty M
Myers
ACTIVITYDATE SUMMARY
12/12/2022
CTU#9 1.75" Coil 0.145 WT Job Scope: FCO/drift
Travel to L-pad, snow removal, MIRU CTU#9
***Job in Progress***
12/13/2022
CTU#9 1.75" Coil 0.145 WT Job Scope: FCO/drift
Continue rig up. MU FCO BHA. RIH and tag the prong 9135 ctmd. POOH. Pick up
YJ fishing assembly w/ 3-1/2" GS and bait sub fro prong. RIH and latch and pull the
prong 9136' ctmd. Seen WHP response. Prong recovered. RIH w/ YJ fishing
assembly and 3-1/2" GS. Tag plug 9,142' ctmd. Hit 10 light jar licks and popped free.
POOH. Plug recovered. Cut off YJ tools.
***Job in Progress***
12/14/2022
CTU#9 1.75" Coil 0.145WT Job Scope: FCO/drift
MU SLB FCO BHA, RIH and tag fill at 9346 CTM.. Perform FCO to 9420'. RIH dry
from 9300' and tag at 9417', POOH pumping 60/40 to FP coil and cap well. Break
off SLB tools and MU NS RIH to with WS drift. Dry tag at 9430 CTMD, POOH, freeze
protect with 38bbls diesel. L/D NS whipstock drift RDMO
***Job Complete***
12/17/2022
T/I/O=SI/0/0. Pre CDR. RD 4" comapion flow cross chemical blind. install Kill line
on companion.torque to spec. Remove 4" tree cap assembly. Install 4" tapped blind.
torque to spec. Install slip blind between WV and FL. torque to spec. PT tree
assembly. 500 low 5000 high. (Pass). RD A/L C-spool. install 2" tapped blind to WIA.
torqe to spec. install 2" tapped blind to break out spool torqe to spec. FWPs=SI/0/0.
***RDMO***
Daily Report of Well Operations
PBU L-112
Activity Date Ops Summary
1/5/2023 Rig accepted at 08:00. RU checklists. Safe in Rig. Open well up to gauge. 0 psi. Oil change on Koomey oil. Perform LTT on swab to 3500#. NU MPD line. Test gas
alarms. All pass. Nipple up BOPE. Change oil in Koomey unit. Re-plumb cement hardline. Verify test joint connections. Grease choke and stack valves. M/U nozzle,
M/U injector to well. Flush and fluid pack surface lines. Test BOPs as per PTD and Hilcorp guidelines. Test witness waived by AOGCC Inspector Kam StJohn. All
tests 250/3500 psi. Test 1: IRV, Stripper, C7, C9, C10, C11 - Pass. Test 2: Blind/Shears, R2, BL2, C15 - Pass. Slide injector back, insert test jt. Test 3: Annular (2"),
TIW1, B1, B4 - Pass. Test 4: Upper 2" Pipe/Slip, TIW2, B2, B3 - F/P on B2 grease then pass. Test 5: Lower 2" Pipe / Slip, C5, C6, C8, TV2 - Pass. Test 6: Choke
A, Choke C - Pass. Accumulator Drawdown. Test 7: C1, C4, TV1 - F/P on TV1, grease then pass. Test 8: 2-3/8" Pipe/Slip, C2, C3 - Pass. BOPE test complete
05:30.
1/6/2023 Remove test risers, Install drilling risers and QTS. Install weight bars in lubricators. Pressure test ODS PDL / MPD line / Drilling Risers to 3500#. Pressure test DS
PDL to 3500#. BHI install floats in UQC. Pressure test body to 3500#. Test Floats to 4500#. Good test. Stab injector on. Load coil with 1%KCL. Spot Methanol up to
T1/T2. PJSM for bullhead kill. Bullhead. 10 bbls Neet Methanol Catch fluid at about ~7 bbls away. 150 bbls 1% SL KCL w/ 0.6 Safelube. Circulate to tiger tank.
Bring inside. Losing 30 bph. PJSM, Establish hole fill. Make up BHA#1 MWD w/ nozzle. RIH with Nozzle BHA #1. Rate: 0.60 bpm in, 0.44 bpm out. Circ pressure:
265 psi. Mud Weight: 8.36 ppg in, 8.38 ppg out. Shut choke. Run to bottom. Log down for tie-in from 9070' to 9278 MD (formation) with -8' correction. Continue
logging down to tag. Wt ck at 9440' is 38k clean. Tag at 9446' 4k DWOB. Pick up to 9411' and flag pipe. P/U above perfs and break circulation. Pump 20 bbls hi-
vis, leave across and above perfs. Pump 1 x B/U to tiger tank 1.5 / 1.4 bpm. Bring returns to pits, 10 min flow check on bottom is good, no flow. POOH. Tag stripper,
10 min flow check is good no flow. Lift injector and slide back, pull BHA #1 remove nozzle. M/U mem CBL tools on CoilTrak. M/U injector. RIH BHA #2. Tie-in depth
from 9200 correct -11'. RIH to flag 9437' and line up to pump across top. Log up from 9437' to 9000' at 30 ft/min. RIH to 9437' and log repeat pass up 30 ft/min.
Stop at 9000' line up to pump down CT. POOH. Tag stripper, 10 min flow check is good, no flow. Lift injector off and slide back. Pull BHA #2 out, L/D mem CBL
tools and download data.
1/7/2023 Stand-by for download of data. Swap out DGS blind for DGS HOT. Make up and scribe NS 3-1/2" x 7" HEW whipstock. Make up injector. Test QTS. RIH with
Whipstock BHA #3. Rate: 0.50 bpm in, 0.57 bpm out. Circ pressure: 260 psi. Mud Weight: 8.38 ppg in, 8.23 ppg out. Lose communication with tools. Troubleshoot
surface. Surface good. Pooh. Pooh to troubleshoot comms. Rate: 1.55 bpm in, 0.93 bpm out. Circ pressure: 1260 psi. Mud Weight: 8.40 ppg in, 8.36 ppg out.
Come off line. Flow check. Well still losing. Troubleshoot communication issue with tools. Anchor pulled. Pump back till e-line stopped. Cut 100' of pipe. MU coil
connector. Pull test to 50K, Test to 4000#. Install stinger and nozzle. Pump slack forward for UQC. Movement heard immediately.
MU UQC w/ floats and test to 3500#. Pump forward at 3.5 bpm for 2 coil volumes. Fill well. Open swab. Flow check. M/U BHA #3, whipstock + setting tools. RIH
BHA #3, pump through open EDC. Set pump and slackoff trips tight for RIH with whipstock. Tie-in depth from 9200' correct -10.5'. Drift down to 9400', clear. Pick
up to 9200' log CCL to 9400'. Our CCL matches well plan CCL. RIH to 9394.72' leaves top WS at 9386' at 10L orientation. Get up wt back. Close EDC. Pressure up
and shear out setting tool 2700 psi. Set down 3.65k DWOB, no movement, good set. POOH pump 1.8 / 1.25 bpm. At surface, 10 min flow check is good, no flow.
Lift injector off and skid back. L/D BHA #4, whipstock and setting tools. M/U BHA #5, window mill + 2 jts CSH + CoilTrak. Mill 2.81/2.80 Go/NoGo Reamer 2.80/2.79
Go/NoGo. RIH BHA #5, window mill. Run past sliding sleeve slowly, nothing seen. Log tie-in from 9250' correct -12'. Close EDC, ease down and dry tag pinch point
at 9391.1'. Go to milling rate 1.85 / 1.49 bpm. Mill window from 9390.5' @ 10L. 2750 psi Free Spin. 8.39 / 8.39 ppg In/Out. ECD = 9.06 ppg.
1/8/2023 Milling window to 9393.52'. Free spin: 2750 psi, 1.85 bpm. Rate: 1.80 bpm in, 1.58 bpm out. Circ pressure: 2700 psi. Mud weight: 8.38 ppg in, 8.39 ppg out,
Window ECD: 9.20 ppg. WOB increasing. Forward progress in question. Pick off window clean. Milling window 9393.52' to 9394.24'. Free spin: 3330 psi, 1.82
bpm. Rate: 1.82 bpm in, 1.57 bpm out. Circ pressure: 3330 - 3700 psi. Mud weight: 8.40 ppg in, 8.40 ppg out, Window ECD: 9.27 ppg. WOB climbing up to 4.1K
PU to top of window. 1 fpm up / 1 fpm down. Milling window 9394.24' to 9394.4'. Free spin: 2880 psi, 1.85 bpm. Rate: 1.85 bpm in, 1.58 bpm out. Circ pressure:
2880 - psi. Mud weight: 8.38 ppg in, 8.39 ppg out, Window ECD: 9.29 ppg. Stalled and pickup. Establish parameters. Casing exit at 9394.4' MD. Continue milling
at 1 fph to get reamer out. Mill rathole to 9404' MD with 2.4K WOB at 14 fph. Milled last 5' with HiVis pill at bit. Perform reaming passes while pumping pill up for
sample. Rathole sample showed 95% fine grained KC3C. Swap from 8.7 ppg Powerpro. Completed reaming passes at 15 L and R of as milled. Clean passes. Dry
drifted window. Bobble at 9400' MD. Rih to 9405' Come online. Backream 1 fpm from TD through window. Come offline. Dry drift to TD without issue. Pull above
window. Open EDC and perform 10 min No Flow. Pooh. Rate: 2.0 bpm in, 1.18 bpm out. Circ pressure: 2943 psi. Mud weight: 8.79 ppg in, 8.81 ppg out. Flow
check. Well minimal losses. Lay down window milling BHA #5. Mill and reamer same gauge as when they went in. M/U nozzle, M/U injector. Jet stack. Change out
QTS valve bank. M/U BHA #6, build BHA. RIH, BHA #6. Pump 1.6 bpm through open EDC. Tie-in depth from 9200' correct -8'. Stop at 9350 close EDC. Pass
window 10L, 0 pump, 25 ft/min nothing seen. Tag 9406' get up wt + 2 ft start pumps 1.8 bpm. Drill 9406' to 9500'. 1.83 / 1.5 bpm @ 3600 psi free spin. 8.76 / 8.80
ppg In / Out. Window ECD = 10.53 ppg on open choke. Drill 9500' to 9550'. 1.83 / 1.71 bpm. 8.79 / 8.80 ppg In / Out. Window ECD = 10.60 ppg open choke. 9500'
5 bbls lo / hi vis, start adding black product to mud. Pull 100' wiper trip from 9550' up wt 38k clean up/down. Drill from 9550'. 1.83 / 1.75 bpm. 8.80 / 8.85 ppg In /
Out. Window ECD = 10.73 ppg open choke. 9605' pump 5 bbls lo / hi vis.
50-029-23129-01-00API #:
Well Name:
Field:
County/State:
PBW L-112A
Prudhoe Bay West
Hilcorp Energy Company Composite Report
, Alaska
1/8/2023Spud Date:
Kyle Wiseman Hilcorp Alaska, LLC
Geotechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: Kyle.Wiseman@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 01/11/2023
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20230111
Well API #PTD #Log Date Log
Company Log Type AOGCC
Eset#
PBU 05-30 50029222130000 191115 1/2/2023 HALLIBURTON RMT3D
PBU 15-07D 50029211660400 215158 12/29/2022 HALLIBURTON RMT3D
PBU K-20C 50029225550300 208049 1/2/2023 HALLIBURTON RBT
PBU L1-13 50029235630000 216003 1/4/2023 HALLIBURTON RMT3D
PBU Z-223 50029237200000 222080 12/22/2022 HALLIBURTON WFL-TMD3D-RMT3D
PBU L-112 50029231290000 202229 1/6/2023 READ MemoryRadialCementBondLog
Please include current contact information if different from above.
By Meredith Guhl at 3:24 pm, Jan 11, 2023
T37435
T37436
T37437
T37438
T37439
T37440PBU L-112 50029231290000 202229 1/6/2023 READ MemoryRadialCementBondLog
Meredith Guhl Digitally signed by Meredith Guhl
Date: 2023.01.11 15:32:54 -09'00'
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
*All BOPE reports are due to the agency within 5 days of testing*
Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov
Rig Owner:Rig No.:CDR2AC DATE:1/6/23
Rig Rep.:Rig Email:
Operator:
Operator Rep.:Op. Rep Email:
Well Name:PTD #2022290 Sundry #322-694
Operation:Drilling:Workover: X Explor.:
Test:Initial: X Weekly:Bi-Weekly:Other:
Rams:250/3500 Annular:250/3500 Valves:250/3500 MASP:1537
MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES:
Test Result/Type Test Result Quantity Test Result
Housekeeping P Well Sign P Upper Kelly 0 NA
Permit On Location P Hazard Sec.P Lower Kelly 0 NA
Standing Order Posted P Misc.NA Ball Type 2 P
Test Fluid Water Inside BOP 0 NA
FSV Misc 0 NA
BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm
Stripper 1 2"P Trip Tank P P
Annular Preventer 1 7 1/16" GK P Pit Level Indicators P P
#1 Rams 1 Blind / Shears P Flow Indicator P P
#2 Rams 1 2.0" Pipe / Slip P Meth Gas Detector P P
#3 Rams 1 2 3/8" Pipe / Slip P H2S Gas Detector P P
#4 Rams 1 2.0" Pipe / Slip P MS Misc 0 NA
#5 Rams 0 NA
#6 Rams 0 NA ACCUMULATOR SYSTEM:
Choke Ln. Valves 1 2-1/16"P Time/Pressure Test Result
HCR Valves 2 2-1/16"P System Pressure (psi)3000 P
Kill Line Valves 1 2-1/16"FP Pressure After Closure (psi)2200 P
Check Valve 0 NA 200 psi Attained (sec)20 P
BOP Misc 2 2.0" Piper FP Full Pressure Attained (sec)57 P
Blind Switch Covers:All stations Yes
CHOKE MANIFOLD:Bottle Precharge:1050 P
Quantity Test Result Nitgn. Bottles # & psi (Avg.):10@1960 P
No. Valves 12 P ACC Misc 0 NA
Manual Chokes 1 P
Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result
CH Misc 0 NA Annular Preventer 4 P
#1 Rams 5 P
Coiled Tubing Only:#2 Rams 4 P
Inside Reel valves 1 P #3 Rams 3 P
#4 Rams 3 P
Test Results #5 Rams 0 NA
#6 Rams 0 NA
Number of Failures:2 Test Time:5.0 HCR Choke 1 P
Repair or replacement of equipment will be made within days. HCR Kill 1 P
Remarks:
AOGCC Inspection
24 hr Notice Yes Date/Time 1/04/2023 17:42
Waived By
Test Start Date/Time:1/6/2023 0:30
(date)(time)Witness
Test Finish Date/Time:1/6/2023 5:30
BOPE Test Report
Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov
Kam StJohn
Nabors
F/P on manual kill line valve B2 and test valve TV1 on the BOP stack. Both valves were greased then passed.
R.Coyne / T.Henson
Hilcorp North Slope, LLC
J.Perl / T. Kavanagh
PBU L-112
Test Pressure (psi):
robert.coyne@nabors.com
alaskans-ctd-dsm@hilcorp.com
Form 10-424 (Revised 08/2022)2023-0106_BOP_Nabors_CDR2AC_PBU_L-112
J. Regg; 5/25/2023
12.8.2022
By Anne Prysunka at 8:40 am, Dec 09, 2022
322-694
Digitally signed by Monty M Myers
DN: cn=Monty M Myers, c=US,
o=Hilcorp Alaska, LLC, ou=Technical
Services - AK Drilling,
email=mmyers@hilcorp.com
Reason: I am approving this document
Date: 2022.12.08 16:24:16 -09'00'
Monty M
Myers
X
MGR14DEC22
Variance to 20 AAC 25.112(i) approved for alternate plug placement.
DSR-12/9/22
10-407
DLB 12/09/2022
BOPE test to 3500 psi.
GCW 12/15/22
Jessie L.
Chmielowski
Digitally signed by Jessie L.
Chmielowski
Date: 2022.12.15 09:14:56
-09'00'
RBDMS JSB 121522
To: Alaska Oil & Gas Conservation Commission
From: Sean McLaughlin
Drilling Engineer
Date: December 8, 2022
Re: PBU L-112 Sundry Request
Sundry approval is requested to set a whipstock and mill the window in L-112 as part of the
drilling and completion of the proposed L-112A CTD lateral.
Proposed plan for L-112A Producer:
Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. The well will also be screened
for conversion to an injector after about 3 months of production.
See L-112A 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. A 3-1/2"x7" HEW whipstock will be set with the
rig. A 2.80" window +10’ of formation will be milled out of the 7” casing. The well will kick off drilling and land in the
Kuparuk. The lateral will continue in the Kuparuk to TD. The proposed sidetrack will be completed with a 2-3/8” L-
80 solid liner and cemented in place. The well will be selectively perforated post rig (see future perf sundry). This
completion will completely isolate and abandon the parent Kuparuk perfs.
After the well has produced for approximately 3 month a separate Sundry will be filed for conversion to injection
service.
This Sundry covers plugging the existing perforations via the 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 in December 2022):
1. Eline: CBL of 7” casing below the tubing tail.
2. Slickline: Dummy WS drift
a. Drift past whipstock setting location
3. Fullbore: MIT-IA and MIT-T to 3,000 psi
4. Valve Shop: Pre-CTD Tree Work as necessary
Rig Work:
x Reference PBU L-112A PTD submitted in concert with this request for full details.
x General work scope of Rig work:
1. MIRU and Test BOPE - MASP with gas (0.10 psi/ft) to surface is 1,537psi
2. Set HEW (whipstock)
3. Mill Window
4. Drill Build and Lateral
5. Run and Cement Liner*
6. Freeze Protect and RDMO
7. Set LTP* (if needed) and perforate post rig
* Approved alternate plug placement per 20 AAC 25.112(i)
Sean McLaughlin CC: Well File
Drilling Engineer Joseph Lastufka
907-223-6784
Sundry 322-694
PTD
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
2.0" Pipe/Slips
2 3/8" Pipe/Slips
2 3/8" Pipe/Slips
7-1/16"
5k Mud
Cross
2.0" Pipe/Slips
2-3/8" Pipe /
Slip
HF
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From:Prysunka, Anne E (OGC)
To:Brooks, James S (OGC)
Subject:RE: Sundry 322-616
Date:Wednesday, November 23, 2022 11:30:18 AM
From: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>
Sent: Monday, November 21, 2022 11:09 AM
To: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>
Subject: RE: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
It need to be printed to a PDF and saved in the corresponding wells folder, logged out of
the log as rejected and “N/A” for the approval date, saved for James to process.
From: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>
Sent: Monday, November 21, 2022 11:08 AM
To: Carlisle, Samantha J (OGC) <samantha.carlisle@alaska.gov>
Subject: RE: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
Should this sundry be immediately deleted form the processing folder?
From: Chmielowski, Jessie L C (OGC) <jessie.chmielowski@alaska.gov>
Sent: Monday, November 21, 2022 11:06 AM
To: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>; Carlisle, Samantha J (OGC)
<samantha.carlisle@alaska.gov>
Subject: FW: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
See below. Sundry rejected.
Jessie Chmielowski
Commissioner
Alaska Oil and Gas Conservation Commission
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain
confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state
or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so
that the AOGCC is aware of the mistake in sending it to you, contact AOGCC at 907-793-1223 or
jessie.chmielowski@alaska.gov.
From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Sent: Monday, November 21, 2022 10:47 AM
To: Brodie Wages <David.Wages@hilcorp.com>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>;
CAUTION: This email originated from outside the State of Alaska mail system.
Do not click links or open attachments unless you recognize the sender and know
the content is safe.
Aras Worthington <aras.worthington@hilcorp.com>; Wallace, Chris D (OGC)
<chris.wallace@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Monty Myers
<mmyers@hilcorp.com>; Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>; Boyer, David L
(OGC) <david.boyer2@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>
Subject: RE: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
Brodie,
Unfortunately, the Alaska Oil and Gas Regulations do not allow for ‘exemptions’. I refer you to
20 AAC 25.540 Hearings if Hilcorp would request a waiver from: 20 AAC 25.030. Casing and
cementing (c)(7) for intermediate or production casing in a service well used for injection, a cement
quality log or other evaluation log approved by the commission must be run to demonstrate
isolation of the injected fluids to the approved interval.
PTD PBU L-112A is rejected.
Sundry request PBU L-112 #322-616 is rejected.
noun: exemption;
1. the process of freeing or state of being free from an obligation or liability imposed on others
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or
privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an
unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake
in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
From: Brodie Wages <David.Wages@hilcorp.com>
Sent: Tuesday, November 15, 2022 1:38 PM
To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>
Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Subject: RE: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
Hello Mel,
CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders.
Please see attached excemption for packer set depth as well as verbiage explaining cement
condition on the 7” production casing shoe.
David “Brodie” Wages
Ops Engineer
C: 713.380.9836
From: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Sent: Friday, October 28, 2022 10:36 AM
To: Brodie Wages <David.Wages@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Subject: Fwd: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
Brodie,
Any chance you can respond to Mel on this one?
Thanks!
Trevor Hyatt
907-223-3087
Begin forwarded message:
From: "Rixse, Melvin G (OGC)" <melvin.rixse@alaska.gov>
Date: October 27, 2022 at 7:08:41 AM HST
To: Trevor Hyatt <Trevor.Hyatt@hilcorp.com>
Cc: "Davies, Stephen F (OGC)" <steve.davies@alaska.gov>, "Roby, David S (OGC)"
<dave.roby@alaska.gov>, "Boyer, David L (OGC)" <david.boyer2@alaska.gov>
Subject: [EXTERNAL] PBU L-112A proposed injector from PBU L-112 existing producer PTD202-
229
Trevor,
I need clarification for this proposed side plan can. Please describe how your well design will
meet the following AOGCC regulations (in yellow) for a proposed injector that is planned to be
hydraulically fractured:
20 AAC 25.412 Casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and
storage
(b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates
pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that
injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface
injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the
perforations, unless the commission approves a different placement depth as the commission considers appropriate given the
thickness and depth of the confining zone.
(c) Before injection begins, a well must be pressure-tested to demonstrate the mechanical integrity of the tubing and packer
and of the casing immediately surrounding the injection tubing string. The casing must be tested at a surface pressure of 1,500
psig or at a surface pressure of 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater, but the
casing may not be subjected to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. The test
pressure must show stabilizing pressure and may not decline more than 10 percent within 30 minutes.
(d) The operator shall provide a cement quality log or other well data approved by the commission to demonstrate
isolation of the injected fluids to the approved interval.
(e) At least 24 hours notice of a pressure test required by (c) of this section must be given so that a representative of
the commission can witness the test
Please provide variance requests to (b) and (d) or provide justification why your design provides
equal to or greater assurance that WAG injection will be confined to the Borealis oil pool.
Mel Rixse
Senior Petroleum Engineer (PE)
Alaska Oil and Gas Conservation Commission
907-793-1231 Office
907-297-8474 Cell
CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas
Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or
privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an
unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake
in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov).
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby
notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please
immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete
this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the
onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility
is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
From: Brooks, James S (OGC) <james.brooks@alaska.gov>
Sent: Wednesday, November 23, 2022 11:14 AM
To: Prysunka, Anne E (OGC) <anne.prysunka@alaska.gov>
Subject: Sundry 322-616
Has no com signature.
thanx
James Brooks
research analyst II | alaska oIl and Gas conservatIon commIssIon
department of commerce, communIty and economIc development
907-793-1241|James.Brooks@alaska.Gov
Operator Name:2.
Exploratory Development
Service
5
Permit to Drill Number:202-229
6.API Number:50-029-23129-00-00
PRUDHOE BAY, BOREALIS OIL
Hilcorp North Slope, LLC 5.
Field/Pools:9.
Well Name and Number:
ADL 028239
Property Designation (Lease Number):10.
8.
PBU L-112
7.If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception?
Stratigraphic
Current Well Class:4.
Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well
Operations shutdown
Install Jet Pump
Op Shutdown
GAS
GSTOR WAG
SPLUG
Abandoned
Oil 5 WINJ
Exploratory Development 5Stratigraphic Service
WDSPL
12. Attachments:
PRESENT WELL CONDITION SUMMARY
9640
Effective Depth MD:
L-80
11.
9/1/2020
Commission Representative:
15.
Suspended
Contact Name: Brodie Wages
Contact Email: david.wages@hilcorp.com
Authorized Name: Stan Golis
Authorized Title:Operations Manager
Authorized Signature:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Yes No Spacing Exception Required?Subsequent Form Required:
Approved by:COMMISSIONER
APPROVED BYTHE
COMMISSION Date:
5OtherAlter Casing
Pull Tubing
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
COMMISSION USE ONLY
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
Detailed Operations Program
Packers and SSSV Type:
No SSSV Installed
Packers and SSSV MD (ft) and TVD (ft):
Perforation Depth MD (ft):Tubing Size:
Size
Total Depth MD (ft):Total Depth TVD(ft):
6958
Effective Depth TVD:Plugs (MD):Junk (MD):
Other Stimulate
Re-enter Susp Well
Suspend
Plug for Redrill
Perforate
Perforate New Pool
6468
No SSSV Installed
Date:
Well Status after proposed work:
16. Verbal Approval:
Change Approved Program
35 - 3109 35 - 2670
14. Estimated Date for Commencing Operations:
BOP Sketch
Surface - 110
Structural
7240
Proposal Summary 13. Well Class after proposed work:
3-1/2" Baker Premier Packer
9358 - 9382 6693 - 6716 4-1/2" x 3-1/2"9176
9529 6854 none none
Surface - 110 470
9-5/8"
7"
Contact Phone:713-380-9836
Date:
5410
80 149020"Conductor
3090
GINJ
5
Post Initial Injection MIT Req'd? Yes No
5
Comm.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Surface 3074'5750
Production 9580 32 - 9612 32 - 6932
Address:3800 Centerpoint Dr, Suite 1400,
Anchorage, AK 99503
3.
No 5Yes
Casing Length MD TVD Burst
Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):
Collapse
MPSP (psi):
Wellbore Schematic
Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng
Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval.
By Jody Colombie at 8:09 am, Jul 23, 2020
320-311
Digitally signed by Stan Golis
DN: cn=Stan Golis,
ou=Users
Date: 2020.07.23 07:27:16 -
08'00'
Stan Golis
DSR-7/23/2020
X
DLB 07/23/20
10-404
MGR23JUL20
Yeption Required?
Comm.
7/23/2020
dts 7/23/2020
JLC 7/23/2020
RBDMS HEW 7/24/2020
10-403 Sundry Application for Well PBU L-112 PTD# 202-229
Hilcorp Energy
Contacts:
Ops Engineer - David Wages: 713.380.9836
Ops Manager - Stan Golis: 907.564.5231
Expected State Date: 9-2020
Current Condition of Well: Oil Producer, Operable, Shut-In
Oil Rate: 300 bpd
Gas Rate: 500 mcfd
Water Rate: 12 bpd
Flowing Tubing Pressure: 300 psi
Shut-In Wellhead Pressure: 1780 psi
Reservoir Pressure 2200 psi
Program History and Objective(s):
L-112 has historically had major hydrate issues with on time less than 50%.
The objective is to convert this well from gas lift into a jet pumped well to increase its on-time by
warming it up.
Proposed Program:
1. Set catcher/ Pull LGLVs, dummy stations 4-2, Load IA, dummy station 1.
a. Option to use SS to load IA
2. MIT-IA to 3000 psi, chart test
3. Brush then open SS. Pump ~10 bbls crude to confirm open
4. Set jet pump insert with check valve (E+10) at 9094’. Pump 50 bbls of crude down the IA at 2
bpm to confirm we have a flow path. 50 bbl should be plenty to catch pressure and know we are
going through the jet pump.
*Submit charted MIT-IA with 10-404
10-403 Sundry Application for Well PBU L-112 PTD# 202-229
Hilcorp Energy
Current Wellbore Schematic:
10-403 Sundry Application for Well PBU L-112 PTD# 202-229
Hilcorp Energy
Proposed Wellbore Schematic:
~
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB-20
Post Office Box 196612
Anchorage, Alaska 99519-6612
August 14, 2009
-~ ~ ,
r '~ ~~i(~rJ
r r, ~~~~t,,, ~`: ~ '.
4'«~ e;:i'~~
~
bp
~~~~~~~~
Mr. Tom Maunder
Alaska Oil and Gas Conservation Commission
333 West 7'h Avenue
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB L-Pad
Dear Mr. Maunder,
0 C T 0 5 2~05
~IlasVc~ ~ii ~r Gas Cons. Com~ission
Anchorage
~Q~.~ ~-~-q
~ f 112~-
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L-
Pad 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 Mnulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10-404)
Date
L pad
8/13/2009
Well Name
PTD #
API #
Inipal to of cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Corrosion
inhibitor Corrosion
i~hibitor/ sealant
date
ft bbls ft na al
L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009
L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009
L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009
L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009
L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009
L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009
L-102 2020360 50029230710000 37' NA Need To Job? NA
L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009
L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009
L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009
L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009
L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009
L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009
L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009
L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009
L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009
L-112 2022290 50029231290000 NA 5.5 NA 51 6l27/2009
L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009
L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009
L-116 2011160 50029230250000 NA 5 NA 54.4 6l28/2009
L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009
1-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009
L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009
L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009
L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009
L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009
L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009
L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009
L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009
L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009
L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009
L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009
L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009
L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009
L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009
L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009
L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009
L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009
L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009
L-216 2040650 50029232060000 NA 1.3 NA 11.9 6f2fi/2009
L-217 2060750 50029233120000 late blockin conductor NA NA
L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009
L-219 2071480 50029233760000 suAace NA NA
~-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009
~-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009
L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009
~-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009
L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009
e
e
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marker.doc
/ l ("1 (/'\.. À.-ß~ \-
DATA SUBMITTAL COMPLIANCE REPORT
3n /2005
Permit to Drill 2022290
Well Name/No. PRUDHOE BAY UN BORE L-112
Operator BP EXPLORATION (ALASKA) INC
5, q¿ / J~^ (}-~ 3
API No. 50-029-23129-00-00
MD 9640
ìVD 6958
Completion Date 2/17/2003
Completion Status 1-01L
Current Status 1-01L
UIC N
REQUIRED INFORMATION
Mud Log Yes
Samples No
Directional Survey ~5
DATA INFORMATION
Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, PEX, BHC Sonic
Well Log Information:
(data taken from Logs Portion of Master Well Data Maint)
-- Log/ Electr
Data Digital Dataset Log Log Run Interval OH/ ~
;%~ Med/Fnnt Number Name Scale Media No Start Stop CH Received Comments
, : D D Lis (Á513 Induction/Resistivity 728 9600 Open 6/9/2004 MWD GR EWR4 CNP SLD
ROP
A Directional Survey Log is
required to be submitted.
This record automatically
created from Permit to Drill
Module on: 12/10/2002.
; Rpt Directional Survey 722 9640 Open 2/6/2003 :rr(::,;
LEf) D .:,...8frectional Survey 722 9640 Open 2/6/2003 ¡- .lF~
ft D c2ffectional Survey 722 9640 Open 2/6/2003 MWD
Rpt Directional Survey 722 9640 Open 2/6/2003 MWD
, Rpt Directional Survey 0 722 Open 2/6/2003 GYRO
~ D ~rectional Survey 0 722 Open 2/6/2003 GYRO
5P C ~24 See Notes 3080 9645 Open 2/7/2003 LDWG edit of openhole
data for mainlog and repeat
lòQ-- La-ensity 25 Blu 3095 9602 Open 2/7/2003
'~og c..f1íd uctio n/Res istivity 25 Blu 3109 9646 Open 2/7/2003
tJ.og yeutron 25 Blu 3095 9602 Open 2/7/2003
I ttOQ' Caliper log 2 Blu 3095 9602 Open 2/7/2003
~g t..8t>n ic 25 Blu 3109 9624 Open 217/2003
V-0g See Notes f(tl} 25 Blu 3095 9646 Open 217/2003 Triple combo Presentation
Platform Express
ifog See Notes 'ìVI'J 25 Blu 3095 9646 Open 2/7/2003 Triple combo Presentation
Platform Express
DATA SUBMITTAL COMPLIANCE REPORT
3n /2005
Permit to Drill 2022290
Well Name/No. PRUDHOE BAY UN BORE L-112
Operator BP EXPLORATION (ALASKA) INC
MD 9640 TVD 6958 Completion Date 2/17/2003 Completion Status 1-01L Current Status 1-01L
~ iLog- ,.-...... Pressure 5 Blu 9004 9453 Case 4/14/2003
Log -/T 5 Blu 9004 9453 Case 4/14/2003
~ emperature
Log l../ Casing collar locator 5 Blu 9004 9453 Case 4/14/2003
.-=-~- ~ c ~~I ~2795 R~tration JJl~ ~
771 9640 10/29/2004
-~-----
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? Y €)
Chips Received? .~
Daily History Received?
~N
WN
Formation Tops
Analysis
Received?
;t-I-N-
--- -----~-
Comments:
-~
Compliance Reviewed By:
Þ-a
Date:
3à ~,-~\'-
API No. 50-029-23129-00-00
UIC N
Static Bottom Hole
Pressure Survey PSP
Pressrr emp/GRlCCL
Static Bottom Hole
Pressure Survey PSP
Pressrremp/GRlCCL
Static Bottom Hole
Pressure Survey PSP
Pressrremp/GRlCCL
DGR/ROP/EWRlMWD/BA T
1\ ')
)
W:ELL LOG TRANSMITTAL
October 26, 2004
To: State of A.1aska
Alaska Oil and Gas Conservation Comm.
Attn.: Helen Warman
333 West 7th Avenue, Suite 100
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs: L-112,
L-112:
Digital Log Images:
50-029-23129-00
AK-MW- 2220900
1 CD Rot11
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE
TRANSMITTAL LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
Date: /~?ftl
.~/ .. ')_\Î'
vf~µ;~
~t?2 - 22 c¡r
JììCff
",
)
\
)
WELL LOG TRANSMITTAL
To: State of Alaska
Alaska Oil and Gas Conservation Comtn.
Attn.: Howard Okland
333 West 7th Avenue, Suite 100
~chorage,Alaska
June 07, 2004
RE: MWD Fonnation Evaluation Logs L-112,
AK-MW-22209
1 LDWG fonnatted Disc with verification listing.
API#: 50-029-23129-00
1*
1)Ç-/3
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL
LETTER TO THE ATTENTION OF:
Halliburton Energy Services
Attn: Rob Kalish
6900 Arctic Blvd.
Anchorage, Alaska 99518
BP Exploration (Alaska) Inc.
Petro-Technical Data Center LR2-1
900 E. Benson Blvd.
~chorage, Alaska 99508
Date: 9Ju.-.. J..M'"
1w (jiLJ
Signed:
~ Q~ - ¿)..;
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
FRAC
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
Operation shutdown_
Pull tubing _
2754' FNL,3875' FEL, Sec. 34, T12N, R11E,UM
At top of productive interval
1100' FNL, 4132' FEL, Sec. 33, T12N, R11 E, UM
At effective depth
1081' FNL, 4188' FEL, Sec. 33, T12N, R11E, UM
At total depth
1069'FNL,4223'FEL,Sec.33,T12N, R11E,UM
12. Present well condition summary
Total depth: measured
true vertical
Stimulate _X
Alter casing _
5. Type of Well:
Development _X
Exploratory_
Stratigraphic_
Service_
Plugging _ Perforate
Repair well_ Other
6. Datum elevation (DF or KB feet)
RKB 83 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
(asp's 583040, 597824~.. L-112
,9. Permit number / approval number
(asp's 577482, 5979840) 202-229
10. API number
(asp's 577390,5979870)
(asp's 577426,5979858)
9640 feet
6958 feet
Plugs (measured)
50-029-23129-00
11. Field / Pool
Prudhoe Bay Field I Borealis Pool
Effective depth: measured 9529 feet Junk (measured)
true vertical 6854 feet
Casing Length Size Cemented Measured Depth True Vertical Depth
Conductor 112' 20" 260 sx ArcticSet (Aprox) 144' 144'
Surface 2987' 9-5/8" 481 sx ArcticSet Lite III, 3019' 3072'
342 sx Class 'G'
Production 9580' 7" 143 bbls lead cmt, 154 9612' 6932'
sx Class 'G'.
Perforation depth:
measured Open Perfs 9358'-9382'
true vertical Open Perfs 6693'-6716'
.~ ~à I. ~ "". r'''''''i¡¡
li "l ¡"~~,, £1 ~'
.'t ~L:¡.' (~-....,t;,¡,;¡ ;~L:'.1:.pl
fklA. y nt,' 1"
¡ \, \,j
~il '~'~~::~}:tr~!:::,,c.::,.
Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 TBG @ 73'. 4-1/2" x 3-1/2" XO @ 73'. 3-1/2" 9.2# L-80 TBG' @ 9176'.
Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker Premier Packer @ 9118'.
3-1/2" HES X Nipple @ 2211' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure
Prior to well operation SHUT-IN
Subsequent to operation 03-05-2003
15. Attachments
Copies of Logs and Surveys run_
Daily Report of Well Operations _ Oil X Gas
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
A~ ~~ Totle' Tech'cal Assistant
DeWayne R. Schnorr
3082
~~~
5 2'nn:·"~
Form 10-404 Rev 06/15/88 ·
Tubinç¡ Pressure
1146
16. Status of well classification as:
138
392
Suspended _
Service
Date April 22, 2003
Prepared by DeWayne R. Schnorr 564-5174
ORIGINAL
~
SUBMIT IN DUPLICATE ~
)
)
L-112
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
02/19/2003 NEW WELL POST: STATIC BOTTOM HOLE PRESSURE SURVEY
02/22/2003 FRACTURING: FRACTURING
02/22/2003 FRACTU RI NG: FRACTU RI N G
02/23/2003 FRACTURING: FILL CLEAN OUT
02/28/2003 NEW WELL POST: GAS LIFT--FOR RATE
03/01/2003 FRACTURING: GAS LIFT--FOR RATE
03/02/2003 FRACTURING: HOT OIL TREATMENT
04/18/2003 TESTEVENT --- BOPD: 1,566, BWPD: 156, MCFPD: 3,033, AL RATE: 2,902
EVENT SUMMARY
02/19/03 PERFORMED SBHPS. TD TAGGED AT 9524'. STOP COUNTS TAKEN AT:
94531MD - 6700lSS PRESS = 3443 PSI, TEMP = 162.6 DEGF;
93461MD - 6600lSS PRESS = 3399 PSI, TEMP = 161.1 DEGF;
9240lMD - 6500lSS PRESS = 3355 PSI, TEMP = 157.3 DEGF;
IN LUB - WHP 589 PSI, WHT = 34.6 DEGF.
«< WELL LEFT SHUT-IN »>
02/22/03 HEAT DIESEL IN TRANSPORT. HOLD IA PRESSURE DURING FRAC.
02/22/03 FRACED ICI SAND PERFS 93581-93821 WITH 209.9K# OF 16/20 CLlTE USING
YF125LG SYSTEM. PLACED 206.9K# PROP BEHIND PIPE LEAVING 3200#
PROP IN CASING, EST. TOS = 93001. FLUSHED JOB WITH 72 BBLS, WELL
FREEZE PRETECTED TO 10001 WITH DIESEL. RECOVERED ALL TREESAVER '
CUPS, LOAD TO RECOVER IS 1600 BBLS. MAX TREATING PRESSURE --- 6467
PSI. AVERAGE TREATING PRESSURE --- 5555 PSI.
02/23/03 MIRU UNIT #8 FOR POST FRAC FCO. RIH WITH 2.25" DJN & 51 STINGER. JET
ICE FROM TREE TO 561. RIH WITH 2.25" JSN TO ESTIMATED TOS @ 9300'.
ONLINE WITH 1% KCL AND HEC SWEEPS. CLEAN DOWN TO 94351 (LEAVES
531 OF RATHOLE). STARTED LOSING RETURNS (75%) WITH HEAVY SAND TO
RETURN TANKS. POOH @ 800/0 STOPPING TO WASH JEWELRY. FREEZE
PROTECT TO 4000' WITH NEAT METHANOL. AT SURFACE --- WHP @ 800 PSI.
NOTIFY PAD OPERATOR OF STATUS --- SLlCKLlNE UP NEXT.
02/28/03 SET 3-1/2" X CATCHER @ 91261 SLM. PULLED DGLVIS FROM STA. # 1,2,& 4.
SET LGLVIS IN STA. # 4 & 2. RUNNING IN HOLE W/ S/O GLV.
03/01/03 SET LGLVIS IN GLM # 4 & 2. SET OGLV IN GLM # 1. PULL CS. «< WELL LEFT
SI»>
03/02/03 HOT OIL IA TO POP WELL THROUGH APC TEST SEPERATOR. PUMPED 5
BBLS OF METHANOL, 104 BBLS OF 190 DEGREE F DIESEL, 30 BBLS OF 80
DEGREE F METHANOL.
Page 1
)
)
.(
L-112
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
04/18/03 TESTEVENT --- BOPD: 1,566, BWPD: 156, MCFPD: 3,033, AL Rate: 2,902
FLUIDS PUMPED
BBLS
91 NEAT METHANOL
107 60/40 METHANOL WATER
327 DIESEL
373 1 % EXTRA SLICK KCL WATER
1775 FRESH WATER
60 3# HEC
2733 TOTAL
Page 2
)
)
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well r;:;~~~\ Classification of Service Well
1m Oil 0 Gas 0 Suspended 0 Abandoned 0 S~~Vice '. ~ $H \ .~~l .
2. Name of Operator r-ú,\:':';~ít~, ;, ..'};' 7. Permit Number
BP Exploration (Alaska) Inc. \ : )r~la.... ~\..:"./"".~.,.."'""'...,..;::'" ','71'" 202-229
3. Address \ ~-!:f:::"~~~,'~ \ 8. API Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 t, '¡jlP¿..._._~I~ 50-029-23129-00
4. Location of well at surface \,.:::::",:,"..,,,..-~~...,,_.. 9. Unit or Lease Name
2525' NSL, 3874' WEL, SEC. 34, T12N, R11E, UM X = 583040, Y = 5978244 Prudhoe Bay Unit
At top of productive interval
4175' NSL, 4117' WEL, SEC. 33, T12N, R11 E, UM X = 577496, Y = 5979835 10. Well Number
At total depth
4211' NSL, 4223' WEL, SEC. 33, T12N, R11 E, UM X = 577390, Y = 5979870
5 EI t· . f t (' d' t KB DF t) 6 L D· t· d S . I N 11. Field and Pool
. eva Ion In ee In Ica e , , e c. . ease eSlgna Ion an ena o. Prudhoe Bay Field / Prudhoe Bay Pool
KBE = 82.5' ADL 028239
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband.
1/1/2003 1/8/2003 2/17/2003
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey
9640 6958 FT 9529 6854 FT 1m Yes 0 No
22. Type Electric or Other Logs Run
MWD, GR, RES, DEN, NEU, PWD, PEX, BHe Sonic
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH HOLE
Top BOTTOM SIZE
Surface 110' 42"
35' 3109' 12-1/4"
32' 9612' 8-3/4"
23.
CASING
SIZE
WT. PER FT.
91.5#
40#
26#
GRADE
H-40
L-80
L-80
20"
9-5/8"
7"
24. Perforations open to Production (MD+ TVD of Top and
Bottom and interval, size and number)
2-1/2" Gun Diameter, 6 spf
MD TVD MD TVD
9358' - 9382' 6693' - 6716'
L·112
15. Water depth, if offshore 16. No. of Completions
NIA MSL One
20. Depth where SSSV set 21. Thickness of Permafrost
(Nipple) 2211' MD 1900' (Approx.)
CEMENTING RECORD
260 sx Arctic Set (Approx.)
479 sx Arctic Set Lite III, 360 sx IG'
358 sx Class 'G', 146 sx Class 'G'
AMOUNT PULLED
25. TUBING RECORD
SIZE DEPTH SET (MD) PACKER SET (MD)
4-1/2", 12.6#, L-80 73'
3-1/2",9.2#, L-80 73' - 9176' 9118'
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protected with 77 Bbls Diesel
9358' - 9382' Frac'd: Placed 206,900# 16/20 Carbolite
behind pipe
4000' Freeze Protected with MeOH
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
Gas Lift
27.
Date First Production
March 3, 2003
Date of Test Hours Tested
3/10/2003 4
PRODUCTION FOR
TEST PERIOD
OIL-BBL
1,337
OIL-BBL
Flow Tubing Casing Pressure CALCULATED
Press. 326 24-HoUR RATE
GAs-McF
64
GAs-McF
CHOKE SIZE
95°
OIL GRAVITY-API (CORR)
WATER-BBL
250
WATER-BBL
GAS-OIL RATIO
48
::>8. CORE DATA ¡"':~::,\~ )it¡p" . .~
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core Chig~ t .~ .~.~ \.J ,.~
No core samples were taken.
Form 10-407 Rev. 07-01-80
RBDMS 8Fl
:VI
I
"i
¡
(\0 I'. ~7
¿: uj
Þ:\~~¡.$~~3 Of!,& Gai:~ Gm]s. ComuÜ~¡síû\
Anchorage
GP
I
¡,; \ 1..' t·
MAR I 7
Submit In Duplicate
')
)
29.
Geologic Markers
30.
Formation Tests
Marker Name
Measured
Depth
True Vertical
Depth
Include interval tested, pressure data, all fluids recovered and
gravity, GOR, and time of each phase.
Ugnu 3396'
Ugnu M Sandstones 5404'
Schrader Bluff N Sandstones 5889'
Schrader Bluff 0 Sandstones 6116'
Base Schrader I Top Colville 6675'
HRZ 8878\
Kalubik 9130'
Kuparuk D 9313'
Kuparuk C 9358'
Kuparuk B 9511'
2828'
3930'
4188'
4314'
4634'
6247'
6479'
6651'
6693'
6842'
'ì
~
31. List of Attachments:
¿;~~at~ø, fD¡i~ & ~;)¡as,iG¡)~~S. V~¡'ø~~~¡~~â~Ou ì
Summary of Daily Drilling Reports and Post Rig Work, Surveys M~~l,i~¡¡j~~!~3
32. I ~erebY certi~y that the fO~Oing. is true and correct to the best of my knowledge
Signed Teme Hubble /f.QJ\MQ" ~ Title Technical Assistant Date 03- I ~ ...03
L -112 202-229 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Number Permit No. I Approval No. Drilling Engineer: James Franks, 564-4468
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation,
injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any
attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the
producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data
rertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the detaits of any multiple stage cementing and the location of the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Legal Name:
Common Name:
Test Date
1/4/2003
LOT
L-112
L-112
Test Type
Test Depth (TMD)
3,145.0 (ft)
BP.. E~Pl.ORAT(()N
Leak"Off.·TestSumrnêJry
Test Depth (TVD)
2,690.0 (ft)
AMW
9.70 (ppg)
SurfacéPresSlice Leak Off pressure(BHP)
475 (psi) 1,830 (psi)
Page1···.bf1
13.10 (ppg)
~
Printed: 1/14/2003 2:50:47 PM
)
)
Page 1 of 6
BP EXPLORATION
Op~rationsSl.lm mary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
12/31/2002
111/2003
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
From - To Hours Task Code NPT Phase
04:30 - 05:30 1.00 MOB P PRE
05:30 - 07:30 2.00 MOB P PRE
07:30 - 08:30 1.00 RIGU P PRE
08:30 - 12:00 3.50 RIGU P PRE
12:00 - 13:30 1.50 RIGU P PRE
13:30 - 15:00 1.50 RIGU P PRE
15:00 - 19:00 4.00 RIGU P PRE
19:00 - 21 :00 2.00 RIGU P PRE
21 :00 - 22:30 1.50 RIGU P PRE
22:30 - 23:00 0.50 RIGU P PRE
23:00 - 23:30 0.50 RIGU P PRE
23:30 - 00:00 0.50 RIGU P PRE
00:00 - 01 :00 1.00 DRILL P SURF
01 :00 - 02:00 1.00 DRILL P SURF
02:00 - 11 :00 9.00 DRILL P SURF
11 :00 - 12:00 1.00 DRILL P SURF
12:00 - 14:00 2.00 DRILL P SURF
14:00 - 15:00 1.00 DRILL P SURF
15:00 - 15:30 0.50 DRILL P SURF
15:30 - 16:00 0.50 DRILL P SURF
16:00 - 16:30 0.50 DRILL P SURF
16:30 - 00:00 7.50 DRILL P SURF
1/2/2003 00:00 - 04:00 4.00 DRILL P SURF
04:00 - 04:30 0.50 DRILL P SURF
04:30 - 05:30 1.00 DRILL P SURF
05:30 - 13:30 8.00 DRILL P SURF
13:30 - 15:00 1.50 DRILL P SURF
15:00 - 16:30 1.50 DRILL P SURF
16:30 - 17:30 1.00 DRILL P SURF
17:30 - 19:30 2.00 DRILL P SURF
19:30 - 21 :00 1.50 DRILL P SURF
21 :00 - 21 :30 0.50 DRILL P SURF
21 :30 - 22:00 0.50 DRILL P SURF
Start: 12/31/2002
Rig Release: 111212003
Rig Number: 14
Spud Date: 1/112003
End: 1/12/2003
Description of Oþerations
Hold PJSM prior to moving. Slide rig floor.
Move rig off L-02 & spot rig on L-112.
Slide Rig floor & R/U.
Held pre-spud mtg. RIG ACCEPTED @ 0830 HRS,
12/31/2002. N/U Diverter system.
NID riser & send to shop to have it extended 6". Remove end
of diverter line to retrieve riser.
P/U DP & load in pipe shed.
P/U DP 1 x1 & stand back in derrick.
N/U riser & reconnect diverter line. Hook up flow line & fill up
lines. tighted up turnbuckles.
M/U BHA #1 w/12 1/4" bit, motor & DCs.
Check & test Diverter Equip. Hold diverter drill. Diverter test
witnessing waived by John Crisp wI AOGCC.
R/U Gyro Equip & slickline equip.
Fill surface stack & check for leaks.
Spud well @ 0000 Hrs, 12/31/2002. Drill 12 1/4" hole from 112
to 160'. 120 SPM, 504 GPM, Bit RPMs 75, Pipe RPMs 45,
Torq 1.5K.ART 3 Hrs, AST 2.75 Hrs. ADT 5.75.
M/U stabilizer & DC on BHA. R/U & run Gyro.
Directionaly drill from 160 to 772'. surveying done wI GYRO
tools.
POOH to change bit & P/U MWD tools.
LID bit #1. P/U new bit. M/U BHA wI MWD equip.
Up load data to MWD.
Surface test MWD tools & adjust UBHO sub.
Hold PJSM. Load sources in MWD equip.
RIH to 772'.
Directionaly drill ahead from 772 to 1365'. 130 SPM, 550
GPM, PP on 1750 Psi, PP off 1440 Psi, Torq on 6K, Torq off
3K, WOB 35-45K, P/U 11 Ok, SIO 105K, ROT 11 OK. AST 4.5
Hrs, ART 1.25 Hrs. ADT 5.75 Hrs.
Directionaly drill from 1365 to 1886'. 150 SPM, 630 GPM, PP
2750 Psi, torq 6K, WOB 35-45K.
Circulate bottoms up.
POOH to 772' for wiper trip. No problems. RIH to bottom.
Directionaly drill from 1886 to 3125'.153 SPM, 643 GPM, PP
on 2650 Psi, PP off 2200 Psi, Torq on 5K, Torq off 2K, WOB
40K, P/U 135K, SIO 11 OK, ROT 120K. AST 6.99 Hrs, ART
3.04Hrs.
Pump weighted sweep. Circulate 2 bootoms up while rotating &
reciprocating. 85 RPMs, 153 SPM @ 2400 Psi. Torq 5K.
Make wiper trip to 750'. Had intermittent swabbing from app.
2,200 to 1,900. No backreaming or pumping required on TOH.
RIH. Stode up on ledge at 2180 attempt to work with no pump
or rotation---to no avaiL'. Washed & reamed down 2 stands @
130 SPM, 1900 Psi, 60 RPMs, Torq 5K. Con't to RIH & washed
last stand to bottom.
Pump weighted sweep. Circulate hole clean while rotating &
reciprocating & 650 GPM, 2350 Psi, 90 RPMs, Torq 5K.
Flow Check well. POOH to BHA.
Begin laying down BHA.
Hold PJSM. Remove nuke sources from MWD tools.
Printed: 1/14/2003 2:5053 PM
)
)
BPEXPLORA TION
Operati()n~ Summary Report
Page 2 of6
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
Start: 12/31/2002
Rig Release: 1/12/2003
Rig Number: 14
Spud Date: 1/1/2003
End: 1/12/2003
Date From - To Hours Task Code NPT Phase Description of Operations
1/2/2003 22:00 - 00:00 2.00 DRILL P SURF Down load data from MWD tools. Con't to LID BHA. Break and
grade bit.
1/3/2003 00:00 - 00:30 0.50 DRILL P SURF Clear & clean rig floor.
00:30 - 01 :30 1.00 CASE P SURF Hold PJSM. R/U equip to run 9 5/8" surface casing.
01 :30 - 05:00 3.50 CASE P SURF Run 74 jts 9 5/8" 40#, L-80 BTC casing. Had tight spots from
2362 to 2488'. Began washing down from from 2488 ro 2571'.
Con't to RIH to 2779'. Wash down from 2779 to 2863'. Ran
remainder in hole wlo washing. Break circulation @ TO & stage
up to cementing rates. No losses noted. Shoe @ 3109', Float
@3027', Tam collar @ 993'.
05:00 - 05:30 0.50 CASE P SURF M/U casing hanger & landing jt. Land casing. Set @ 3109' MD,
2670' TVD.
05:30 - 06:00 0.50 CASE P SURF Circulate & condition mud prior to cementing.
06:00 - 06:30 0.50 CASE P SURF RID Franks Tool & casing equip.
06:30 - 08:00 1.50 CEMT P SURF R/U cementing head & cementing equip. Con't to circulate &
condition mud. Hold PJSM.
08:00 - 11 :00 3.00 CEMT P SURF Pump 5 bbls of CW-1 00. Test lines to 3500 psi. Pump 10 bbls
CW-100 followed wi 75 bbls 10.5 ppg Mudpush. Drop bottom
plug. Mix & pump 365 bbls (481 sx) of lead Articset lite III
cement. Mixed @ 10.7 ppg. Yld 4.28 cuft/sx. Tailed in wi 75
bbls (342 sx) Class 'G', mixed @ 15.8 ppg, Yld 1.17 cuft/sx.
Dropped top plug & kicked out wi 5 bbls of water. Displaced
plug wi rig pump. Pumped 225 bbls of mud @ 9 BPM. Bumped
plug to 1390 psi, float held. CIP @ 1035 Hrs, 1/3/2003. Had 73
bbls of cement returns to surface. Hole stayed full.
Reciprocated pipe during job until 20 bbls. from bump.
11 :00 - 12:00 1.00 CEMT P SURF RID cementing equip. LID landing jt.
12:00 - 13:00 1.00 DIVRTR P SURF Flush out diverter & all lines. Clean clear rig floor.
13:00 - 15:00 2.00 DIVRTR P SURF Nipple down diverter & Blooey line.
15:00 - 16:30 1.50 WHSUR P PROD1 N/U Speed head & tbg spool. Test to 5000 psi for 10 min, OK.
16:30 - 19:00 2.50 BOPSUR P PROD1 N/U BOPE. R/U test equip & prepare to test BOPE.
19:00 - 00:00 5.00 BOPSUR P PROD1 Begin pressure testing BOPE. Test witnessed by Jeff Jones wi
AOGCC. tested choke manifold & valves, & upper pipe rams..
LP 250 psi, HP 4500 psi. Tested annular. LP 250 psi, HP 2500
psi. Lower variable pipe rams failed low test.
1/4/2003 00:00 - 01 :30 1.50 BOPSURP PROD1 Con't to pressure test BOPE. Test blind rams, LP 300 psi, HP
4500 psi. Change bottom pipe rams to 5" & test, LP 300 psi,
HP4500 psi. Test witnessed by Jeff Jones wi AOGCC. Had
faulty gauge on Koomey & several leaks. All equip has been
serviced & repaired. New gauge ordered for Koomey. Test
complete.
01 :30 - 02:00 0.50 BOPSUR P PROD1 RID test equip. Install wear bushing.
02:00 - 03:00 1.00 DRILL P PROD1 P/U bails & elevators.
03:00 - 07:30 4.50 DRILL P PROD1 P/U DP 1 x1, picked up 63 jts & stand back in derrick. P/U
additional 63 jts & stand back in derrick.
07:30 - 10:30 3.00 DRILL P PROD1 P/U BHA & jewelry from beaver slide. m/U bit, motor & MWD.
Orient & uplload data in MWD tools.
10:30 - 11 :00 0.50 DRILL P PROD1 Shallow test MWD & equip.
11 :00 - 11 :30 0.50 DRILL P PROD1 M/U Sonic & AlCal tools.
11 :30 - 12:00 0.50 DRILL P PROD1 Hold PJSM & load Radioactive sources in LWD tools.
12:00 - 12:30 0.50 DRILL P PROD1 P/U Remaining BHA & RIH.
12:30 - 15:00 2.50 DRILL P PROD1 P/U 5" DP from pipe shed & RIH. Rotate Bit & Stabs thru Tam
Port Collar @ 993'. Test casing to 1000 psi to insure Port
Printed: 1/14/2003 2:50:53 PM
) )
BP EXPLORATION Page 3 ot6
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
Start: 12/31/2002
Rig Release: 1/12/2003
Rig Number: 14
Spud Date: 1/1/2003
End: 1/12/2003
Date From - To Hours Task Code NPT Phase Description of Operations
1/4/2003 12:30 - 15:00 2.50 DRILL P PROD1 Collar is closed. Con't to P/U DP & RIH.
15:00 - 16:30 1.50 DRILL P PROD1 Cut & slip drilling line. Service top drive.
16:30 - 17:30 1.00 DRILL P PROD1 Test casing for 30 min to 3500 psi, OK. Charted same.
17:30 - 19:00 1.50 DRILL P PROD1 Tag up on cement fill @ 3015'. Float collar @ 3029'. Float
shoe @ 3109'. Drill out plugs & shoe track. Drill out rathole to
3125'. Drill 20' of new hole to 3145'.
19:00 - 20:00 1.00 DRILL P PROD1 Circulate & displace hole to new clean 9.7 ppg, 43 vis, LSND
mud.
20:00 - 20:30 0.50 DRILL P PROD1 Perform LOT @ 3145' MD, 2690' TVD. Leaked off @ 475 psi,
13.1 ppg EMW. Charted & recorded same. (12.6 ppg EMW
was required as per program) Calculated kick tolerance ===37
bbls.
20:30 - 00:00 3.50 DRILL P PROD1 Directionaly drill from 3145 to 3645'.152 SPM, 638 GPM, PP
on 2850 PSI, PP off 2650 PSI, Torq on 7K, Torq off 5K, Bit
RPMs 214, Pipe RPMs 90. WOB 5-10K, P/U 130K, SIO 100K,
ROT 115K. AST .8 Hrs, ART 2.5 Hrs. ADT 3.3 Hrs. No
Losses noted.
1/5/2003 00:00 - 02:30 2.50 DRILL P PROD1 Directionaly drill from 3645 to 3775'.152 SPM, 638 GPM, PP
on 2850 PSI, PP off 2650 PSI, Torq on 7K, Torq off 5K, Bit
RPMs 214, Pipe RPMs 90, WOB 5-10K. P/U 130K, SIO 100K,
ROT 115K. AST .2 Hr, ART 1 Hr, ADT 1.2 Hrs. Lost pulse
signal to MWD tool. Attempt to revive tool, cycle & work tool.
Clean pump suction screens & isolate pumps.Try multiple
pump rates. Unsuccessful.
02:30 - 03:00 0.50 DRILL N DFAL PROD1 CBU, Pump dry job. Line up on trip tank. Blow down lines &
top drive. Flow check.
03:00 - 05:30 2.50 DRILL N DFAL PROD1 POOH to casing shoe. Flow check. Con't to POOH to BHA.
05:30 - 06:00 0.50 DRILL N DFAL PROD1 POOH & stand back HWDP & Flex collars.
06:00 - 07:30 1.50 DRILL N DFAL PROD1 LID BHA & found small rocks in MWD pulsar valve. Remove
radioactive sources & down load data from MWD tool.
07:30 - 10:00 2.50 DRILL N DFAL PROD1 Change out pulsar in MWD. Pull up to bit & inspect same,
ingauge & Ok. Reload data in MWD tool. Hold PJSM & install
radioactive sources in MWD.
10:00 - 10:30 0.50 DRILL N DFAL PROD1 RIH wI Flex collars & HWDP.
10:30 - 12:00 1.50 DRILL N DFAL PROD1 RIH wI drill string. Rotate thru Tam collar @ 993'. Con't to RIH
to bottom.
12:00 - 00:00 12.00 DRILL P PROD1 Establish baseline values for ECD. Directionaly drill ahead from
3775 to 5660'. 150 SPM, 635 GPM, PP on 3150 PSI, PP off
2850 PSi, Torq on 10K, Torq off 9K, Bit RPMs 204, Pipe RPMs
90, WOB 10-15K. P/U 155K, SIO 112K, ROT 131K. AST 1.5
Hrs, ART4.75 Hrs. ADT 6.25 Hrs.
1/6/2003 00:00 - 05:30 5.50 DRILL P PROD1 Directionaly drill from 5660 to 6138'. 150 SPM, 630 GPM, PP
on 3200 PSI, PP off 3050 PSI, Torq on 10K, Torq off 9K, Bit
RPMs 200 Pipe RPMs 80 WOB 1 0-15K. P/U 162K, SIO 123K,
ROT 140K. AST 1 Hr, ART 2.75 Hrs, ADT 3.75 Hrs
05:30 - 06:30 1.00 DRILL N RREP PROD1 Lost pump #1. Cracked fluid end washed out. Stand 1 stand
back. Circulate bottoms up. Blow down lines & top drive. Flow
check well.
06:30 - 08:00 1.50 DRILL N RREP PROD1 POOH to casing shoe. Hole in good shape, no tight spots.
08:00 - 16:30 8.50 DRILL N RREP PROD1 Repair fluid end in pump #1. service top drive, drawworks & rig
equip. Test pump.
16:30 - 17:30 1.00 DRILL N RREP PROD1 Trip in hole to 6044'. Hole in good shape, no tight spots. Hole
I
Printed: 1/14/2003 2:50:53 PM
)
)
BP EXPLORATION
Operations Summary. Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
Start: 12/31/2002
Rig Release: 1112/2003
Rig Number: 14
Spud Date: 1/1/2003
End: 1/12/2003
Date From - To HoUrs Task Code NPT Phase Description of Operations
1/6/2003 16:30 - 17:30 1.00 DRILL N RREP PROD1 took 3 bbls of mud in 5 hrs while pump was being repaired.
17:30 - 18:30 1.00 DRILL N RREP PROD1 Wash & ream to bottom @ 6138'.128 SPM, PP 2450 PSI, 80
RPMs, Torq 10K, WOB 5K.
18:30 - 00:00 5.50 DRILL P PROD1 Directionaly drill ahead from 6138 to 6810'.152 SPM, 645
GPM, PP on 3550 PSI, PP off 3390 PSI, Torq on 11K, Torq off
10K, Bit RPMs 198, Pipe RPMs 80, WOB 5-15K.P/U 165K,
S/O 122K, ROT 145K. AST .25 Hrs, ART 4 Hrs, ADT 4.25 Hrs.
No mud losses noted to formation.
1/7/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional Drill Ahead From 6,810' To 8,460' - Weight On Bit
10K To 20K - With Pump Rate At 145 Strokes Or 614 GPM-
Off Bottom Pump Pressure At 3640 Psi. & On Bottom Pump
Pressure At 3920 Psi. - Top Drive RPM At 80 - Off Bottom
Torque At 13K On Bottom Torque At 16K - String Rotating
Weight At 168K - With Pump On Drag Up At 217K And Drag
Down At 138K
Formation Top TVD TVDSS
CM2 7177 4942 4859
CM1 8132 5622 5540
Actual Rotating Time At 17.63 Hours - Actual Slide Time At
1.41 Hours
1/8/2003 00:00 - 19:00 19.00 DRILL P PROD1 Directional Drill Ahead From 8460' To 9640'TD - Weight On Bit
10K To 20K - With Pump Rate At 145 Strokes Or 614 GPM-
Off Bottom Pump Pressure At 3450 Psi. & On Bottom Pump
Pressure At 3900 Psi. - Top Drive RPM At 80 - Off Bottom
Torque At 19K On Bottom Torque At 21 K - String Rotating
Weight At 190K - With Pump On Drag Up At 270K And Drag
Down At 145K- ART 13.4 AST 1.6
TKUP D-9313 md
Lcu/Kup B-9516 md
19:00 - 21 :00 2.00 DRILL P PROD1 Pump sweep, Circ to surface, and one more bottoms up with
614 gpm, 3450 psi, 100 rpms
21 :00 - 00:00 3.00 DRILL P PROD1 Flow check, Short tripping to csg shoe, SLM, @ 4414' at 2400
hrs
1/9/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Finish short trip to csg shoe, SLM, No problems
01 :00 - 02:15 1.25 DRILL P PROD1 Service rig, Slip and cut drilling line
02:15 - 04:30 2.25 DRILL P PROD1 Trip back to bottom, no problems, wash 90 ft no fill
04:30 - 06:30 2.00 DRILL P PROD1 Pump sweep, circ to surface with 614 gpm, 3450 psi, 100 rpms
06:30 - 10:30 4.00 DRILL P PROD1 Flow check, drop rabbit 2.25, tripping out, slm from 3041
10:30 - 11 :30 1.00 DRILL P PROD1 Stand back HWDP, 1 stand flex collars, Flush bha with h20
11:30-12:00 0.50 DRILL P PROD1 PJSM on Radioactive sources, remove sources
12:00 - 14:00 2.00 DRILL P PROD1 UD bha, down load MWD
14:00 - 15:30 1.50 EVAL P PROD1 PJSM, clear floor, rig up Schlumberger wireline service
15:30 - 21 :00 5.50 EVAL P PROD1 Rih w/ log tools, Platorm express w/borehole comp sonic
readings,res,porosity,den,gr,caliper,mud res and temp. from
9640 to 311 0
21 :00 - 21 :30 0.50 EVAL P PROD1 PJSM, rig down Schlumberger wireline service
21 :30 - 22:30 I 1.00 CASE P COMP Pickup bha #5, bit, S86EHVPX w/8/12, NB stab. flex dc., Drill
mill, flex de., 15 HWDP, jars, 5 HWDP
22:30 - 00:00 1.50 CASE P COMP Trip in to 4000', rotating bit across port collar @993'
1/10/2003 00:00 - 00:30 0.50 CASE P COMP Circ bottoms up @ 4,000',610 gpm, 1200 psi
Printed: 1/14/2003 2:50:53 PM
J
BP EXPLORATION
Operatio nsSu mmaryReport
PageS of 6
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
Start: 12/31/2002
Rig Release: 1/12/2003
Rig Number: 14
Spud Date: 1/1/2003
End: 1/12/2003
Date From - To Hours Task Code NPT Phase Description of Operations
1/10/2003 00:30 - 01 :30 1.00 CASE P COMP Tripping in to 7,000'
01 :30 - 02:30 1.00 CASE P COMP Circ bottoms up @ 7,000' wI 610 gpm 1450 psi
02:30 - 04:00 1.50 CASE P COMP Tripping to 9,430' hit bridge
04:00 - 04:30 0.50 CASE P COMP Wash and ream from 9430 to bottom with 610 gpm 1600 psi
04:30 - 07:30 3.00 CASE P COMP Pumped sweep. circ to surface, with full drilling rate 610 gals
min 1600 psi, 100 rpms, spot 300 bbl steel seal pill
07:30 - 13:30 6.00 CASE P COMP Flow check, laying down drill pipe
13:30 - 15:00 1.50 CASE P COMP LID Down bha
15:00 - 16:00 1.00 CASE P COMP Clear floor, Pull wear ring
16:00 - 17:00 1.00 CASE P COMP Rig up to run 7" 26# csg, Mobilize csg in pipe shed
17:00 - 21 :30 4.50 CASE P COMP PJSM, Picking up 7" 26 # csg to 2700'
21 :30 - 22:00 0.50 CASE P COMP Circ. bottoms up, no losses, max rate 5 bbls min.
22:00 - 00:00 2.00 CASE P COMP Picking up 7" 26 # csg to 4,000', circ csg @ 4,000' to 4,250' ,
circ @ 2.5 bbls running pipe 3 min per jt
1/11/2003 00:00 - 00:30 0.50 CASE P COMP Circ csg @ 4,250' to 4,350' , circ @ 2.5 bbls min. running pipe
3 min per jt , total pumped 40 bbls, no losses
00:30 - 03:00 2.50 CASE P COMP Picking up 7" 26 # csg to 6,500'
03:00 - 04:00 1.00 CASE P COMP Circ csg @ 6500' to 6700' , circ @ 2.5 bbls min. running pipe 5
min per jt , total pumped 67 bbls, no losses
04:00 - 06:00 2.00 CASE P COMP Picking up 7" 26 # csg to 8,000'
06:00 - 06:30 0.50 CASE P COMP Circ csg @ 8,000' to 8,200' , circ @ 2.5 bbls min. running pipe
5 min per jt , no losses, total pumped 40 bbls
06:30 - 09:00 2.50 CASE P COMP Picking up 7" 26 # csg to 9,611 broke circ @ 8422,8839,9252'
Wash last joint to bottom with franks tool. No adverse hole
conditons or fill during trip in hole with casing. Hole in good
shape. Rig down franks tool and P/U cement head. (Loading of
plugs witnessed by Co. Rep.)
09:00 - 11 :30 2.50 CASE P COMP Stage up pumps and Circ for cement job, w/8 bbls min, 900
psi, PJSM on cementing
11 :30 - 14:00 2.50 CASE P COMP Cement wI Dowell, pump 5 bbls CW-100 , tested lines to 3000,
pump 10 bbls CW-100, 75 bbls mud flush,drop bottom plug,
143 bbls 12# lead cement, 32 bbls 15.8 tail cement, wash up
cement lines to flowline.
Kick out top plug with rig and displace @ 8 bbls min. Pump
365 bbls of sea water, slowed pumps to 5 bpm with 10 bbls.
left. Bump plug with 2500 #, full returns thru out job.
Reciprocated pipe until 50 bbls. left til bump.
14:00 - 14:30 0.50 CASE P COMP Test csg to 3500 psi for 30 min. recorded on chart, good test.
Bleed pressure and check floats.
14:30 - 15:00 0.50 CASE P COMP Rig down cement head
15:00 - 15:30 0.50 CASE P COMP Install 7" pack of and test same to 5000 psi.
15:30 - 16:00 0.50 RUNCOIVP COMP Rig down csg tools and clear floor of all vendors excess
equipment.
16:00 - 17:30 1.50 RUNCOIVP COMP Rig up to run 3.5, 9.2 # 1-80 tubing with TC11 connection,
Mobilize Jewely, function blind rams. Torque turn all
connections using "Jet Lube" dope.
17:30 - 18:00 0.50 RUNCOIVP COMP PJSM on running tubing. (Cement had 600 PSI of compression
strength at 19:00 hours.) Pump down annulus and inject app. 2
bbls. Formation broke down at app. 420 PSI.
18:00 - 00:00 6.00 RUNCOIVP COMP Picking up 7" packer and tail pipe, picking up 3.5 9.2# 1-80
tubing. @ 4,350 @ 24:00 hrs
1/12/2003 00:00 - 09:00 9.00 RUNCOIVP COMP Picking up 3.5 9.2# L-80 TCII tubing to 9133'
09:00 - 09:30 0.50 RUNCOIVP COMP M/U Fmc hanger, Land tubing
Printed: 1/14/2003 2:50:53 PM
)
Page 6' of6
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
L-112
L-112
DRILL +COMPLETE
DOYON
DOYON 14
Start: 12/31/2002
Rig Release: 111212003
Rig Number: 14
Spud Date: 1/1/2003
End: 1/12/2003
Date From -To H 0 LJ rs Task Code NPT
1/12/2003 09:30 - 10:30 1.00 RUNCOrvP COMP
10:30 - 12:30 2.00 RUNCOrvP COMP
12:30 - 14:00 1.50 RUNCOrvP COMP
14:00 - 14:30 0.50 RUNCOrvP COMP
14:30 - 15:30 1.00 RUNCOrvP COMP
15:30 - 16:00 0.50 RUNCOrvP COMP
16:00 - 18:30 2.50 RUNCOrvP COMP
18:30 - 19:30 1.00 RUNCOrvP COMP
19:30 - 22:30 3.00 RUNCOrvP COMP
22:30 - 23:00 0.50 RUNCOrvP COMP
23:00 - 00:00 1.00 RUNCOrvP COMP
R/U to reverse circ tubing, PJSM
Reverse circ. while spotting corrosion inhibitor 3 bbls min 300
psi
Drop ball, set packer, test tubing for 30 min. with 3,500 psi,
bleed presure to 2,000 psi on tubing and test annulus to 3,500
psi for 30 min, bleed tubing pressure to zero and shear RP
valve
Establish circ tru RP valve, annular 3 bbls min. 500 psi, tubing
.5 bbls min 3,500
Rig down test equipment, install twc and test to 1000 psi
Change out bales, clear floor
Nipple down BOPS, Nipple up 4 118 tree and adapter, test to
5000 psi
R/U DSM, pull TWC and rig down
R/U hot oil unit and freeze protect well with 57 bbls. diesel
down annulus and 20 bbls down tubing
Install BPV, Secure well
RID circ lines fl freeze protect, clear cellar, police loc.
(rig release for rig move to MP S-19 @ 2400 hrs.1 112/2003)
Printed: 1/14/2003 2:50:53 PM
',)
)
Well:
Field:
API:
Permit:
Date
L-112
Prudhoe Bay Field / Borealis
50-029-23129-00
202-229
Accept:
Spud:
Release:
Rig:
12/31/02
01/01/03
01/12/03
Doyon 14
POST RIG WORK
01/27/03
PULLED BALL & ROD. PULLED RP SHEAR VLV FROM STA# 1. SET DGLV IN STA #1
01/28/03
MIT IA TO 3500 (PASSED) - PULL RHC PLUG BODY - DIT W/2 -1/2" DG WI SB TO 9512' SLM (PBTD 9529'
MD). WELL LEFT SI.
02/17/03
PERFORMED JEWELRY LOG FROM TD (9524') TO 8660'. TEMP LOG RUN FROM SURFACE. TT DETECTED
AT 9170', RA TAGS AT 9206' & 9447'. PERFORATED INTERVAL 9358'-9382' WITH 2.5" HSD GUN LOADED 6
SPF WITH POWERJET(DP) 2506 CHARGES ALTERNATING WITH POWERFLOW (BH) 2506 , 60 DEG
PHASING, RANDOM ORIENTATION. API PENETRATION 25.2"/4.8", ENTRANCE HOLE 0.32"10.66". WELL
LEFT SHUT IN, NOTIFIED DSO.
02/19/03
PERFORMED SBHPS. TD TAGGED AT 9524'. STOP COUNTS TAKEN AT:
9453'MD - 6700'SS PRESS = 3443 PSI, TEMP = 162.6 DEGF;
9346'MD - 6600'SS PRESS = 3399 PSI, TEMP = 161.1 DEGF;
9240'MD - 6500'SS PRESS = 3355 PSI, TEMP = 157.3 DEGF;
IN LUB - WHP 589 PSI, WHT = 34.6 DEGF.
WELL LEFT SHUT-IN.
02/22/03
HEAT DIESEL IN TRANSPORT. HOLD IA PRESSURE DURING FRAC. FRAC'D C SAND PERFS 9358'-82'
WITH 209.9 K# OF 16/20 CLlTE USING YF125LG SYSTEM. PLACED 206.9 K# PROP BEHIND PIPE LEAVING
3200# IN CSG, EST. TOS = 9300'. FLUSHED JOB WITH 72 BBLS, WELL FREEZE PROTECTED TO 1000'
WITH DIESEL. RECOVERED ALL TREESAVER CUPS, LOAD TO RECOVER IS 1600 BBLS. MAX TREAT - 6467
PSI, AVG TREAT - 5555 PSI.
02/23/03
POST FRAC FCO. RIH WI 2.25" DJN & 5' STINGER. JET ICE FROM TREE TO 56'. RIH WI 2.25" JSN TO
ESTIMATED TOS @ 9300'. ONLINE W/1% KCL & HEC SWEEPS. CLEAN DOWN TO 9435' (LEAVES 53' OF
RATHOLE). STARTED LOSING RETURNS (75%) WITH HEAVY SAND TO RETURN TANKS. POOH @ 80%
STOPPING TO WASH JEWELRY. FREEZE PROTECT TO 4000' WI NEAT METH. AT SURFACE - WHP @ 800
PSI. NOTIFY PAD OPER OF STATUS - SLlCKLlNE UP NEXT.
02/28/03
SET 3-112" X CATCHER @ 9126' SLM. PULLED DGLV'S FROM STA. # 1,2,& 4. SET LGLV'S IN STA. # 4 & 2
RUNNING IN HOLE WI SIO GLV.
03/01/03
SET LGLV'S IN GLM # 4 & 2. SET OGLV IN GLM # 1. PULL CS. WELL LEFT SI.
03/02103
HOT OIL IA TO POP WELL THROUGH APC TEST SEPERATOR. PUMP 5 BBLS OF METHANAL, 104 BBLS OF
1900 F DIESEL, 30 BBLS OF 800 F METHANAL.
)
)
J
cÌða~d9
28-Jan-03
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
Re: Distribution of Survey Data for Well L-112 Gyro
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey
Projected Survey:
'MD
'MD
(if applicable)
'MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
RECEIVED
FEB 05 2003
Alaaka ON & Gas Cons. CoIlll1l8ion
Ancfrthge
Sperry-Sun Drilling Services
North Slope Alaska
BPXA
PBU WOA L Pad
L-112 Gyro
--
Job No. AKF022209, Surveyed: 8 January, 2003
Survey Report
27 January, 2003
Your Ref: API 500292312900
Surface Coordinates: 5978244.24 N, 583040.40 E (70021' 01.9315" H, 149019'32.8636" W)
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4
.~
Surface Coordinates relative to Project H Reference: 978244.24 N, 83040.40 E (Grid)
Surface Coordinates relative to Structure: 94.94 N, 129.36 E (True)
Kelly Bushing: 82.04ft above Mean Sea Level
Elevation relative to Project V Reference: 82.04ft
Elevation relative to Structure: 82.04ft
sper"'......y-sul'l
DRILLING SERVices
A Halliburton Company
Survey Ref: svy11416
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112 Gyro
Your Ref: AP/500292312900
Job No. AKF022209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
0.00 0.000 0.000 -82.04 0.00 0.00 N 0.00 E 5978244.24 N 583040.40 E 0.00 Tolerable Gyro
93.00 0.350 325.000 10.96 93.00 0.23 N 0.16W 5978244.47 N 583040.23 E 0.376 0.22
186.00 0.350 288.000 103.96 186.00 0.55 N 0.60W 5978244.79 N 583039.80 E 0.239 0.73
275.00 0.750 225.000 192.95 274.99 0.23 N 1.27W 5978244.45 N 583039.13 E 0.751 1.28
365.00 1.300 221.000 282.94 364.98 0.96S 2.35W 5978243.25 N 583038.06 E 0.616 1.98
455.00 2.600 195.000 372.89 454.93 3.70 S 3.55W 5978240.50 N 583036.89 E 1.712 2.34 ~
540.00 4.200 181.000 457.74 539.78 8.68S 4.10W 5978235.52 N 583036.39 E 2.107 1.44
632.00 3.300 191.000 549.54 631.58 14.65 S 4.67W 5978229.54 N 583035.89 E 1.206 0.27
722.00 2.750 232.000 639.42 721.46 18.52 S 6.86W 5978225.65 N 583033.74 E 2.422 1.27
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US).
Vertical Section is from Well and calculated along an Azimuth of 286.660° (True).
Magnetic Declination at Surface is 25.682°(31-Dec-02)
Based upon Minimum Curvature type calculations, at a Measured Depth of 722.00ft.,
The Bottom Hole Displacement is 19.75ft., in the Direction of 200.33JD (True).
Survey tool program for L-112 Gvro
Fro m
Measured Vertical
Depth Depth
(ft) (ft)
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
'.----
0.00
0.00
722.00
721.46 Tolerable Gyro
27 January, 2003 - 16:50
Page 2 0'2
DrillQuest 3.03.02.004
)
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
)
qCb1 ,~acr
30-Jan-03
Re: Distribution of Survey Data for Well L-112
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey
Projected Survey:
'MD
'MD
(if applicable)
9,640.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
RECEIVED
FES 05 2003
Ala_ on & Gas Con" Co~
~ ,..¡y;,~,
Sperry-Sun Drilling Services
North Slope Alaska
BPXA
PBU_WOA L Pad
L-112
Job No. AKZZ22209. SUlVeyed: 8 January. 2003
Survey Report
27 January, 2003
Your Ref: API 500292312900
Surface Coordinates: 5978244.24 N. 583040.40 E (70021' 01.9315" N. 149019' 32.8636" W)
Grid Coordinate System: NAD27 Alaska State Planes. Zone 4
Surface Coordinates relative to Project H Reference: 978244.24 N. 83040.40 E (Grid)
Surface Coordinates relative to Structure: 94.94 H. 129.36 E (True)
Kelly Bushing: 82.04ft above Mean Sea Level
Elevation relative to Project V Reference: 82.04ft
Elevation relative to Structure: 82.04ft
sr-=-............y-s;ur-,
DRILLING SeRVices
A Halliburton Company
J, .. rm !'! ''Jf .~.. T·· Villi
- '- J ~}. .-
!IIE;.J ¡ i sm
-~....-
-
Survey Ref: svy11436
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112
Your Ref: API 500292312900
Job No. AKZZ22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft)
722.00 2.750 232.000 639.42 721.46 18.52 S 6.86W 5978225.65 N 583033.74 E 1.27 AK-6 BP.JFR-AK
766.48 3.240 266.690 683.85 765.89 19.25 S 8.96W 5978224.89 N 583031.65 E 4.149 3.07
860.45 3.840 283.710 777.64 859.68 18.66 S 14.67 W 5978225.42 N 583025.94 E 1.281 8.70
956.52 4.290 287.900 873.47 955.51 16.79 S 21.21 W 5978227.22 N 583019.37 E 0.561 15.51
1051.96 6.550 292.680 968.4 7 1050.51 13.59 S 29.63 W 5978230.32 N 583010.92 E 2.413 24.49
1147.63 12.620 299.400 1062.77 1144.81 6.35 S 43.79 W 5978237.40 N 582996.69 E 6.441 40.13
1243.77 16.860 301.040 1155.72 1237.76 6.00 N 64.89 W 5978249.52 N 582975.45 E 4.431 63.89
1340.21 16.250 298.500 1248.17 1330.21 19.65 N 88.73 W 5978262.90 N 582951.45 E 0.981 90.64
1436.01 17.830 288.610 1339.78 1421.82 30.73 N 114.42 W 5978273.70 N 582925.65 E 3.440 118.43
1531.05 19.850 284.270 1429.73 1511.77 39.35 N 143.85 W 5978281.99 N 582896.12 E 2.586 149.10
1626.73 23.030 285.230 1518.77 1600.81 48.27 N 177.66 W 5978290.54 N 582862.21 E 3.344 184.04
1722.44 22.980 285.680 1606.87 1688.91 58.24 N 213.71 W 5978300.11 N 582826.05 E 0.191 221 .44
1817.93 24.540 285.090 1694.27 1776.31 68.44 N 250.81 W 5978309.90 N 582788.85 E 1.653 259.90
1914.86 26.690 284.900 1781.66 1863.70 79.28 N 291.29 W 5978320.29 N 582748.25 E 2.220 301.79
2010.40 31.580 284.300 1865.09 1947.13 90.98 N 336.29 W 5978331.49 N 582703.12 E 5.127 348.26
2106.18 37.430 284.71 0 1943.99 2026.03 104.58 N 388.79 W 5978344.51 N 582650.47 E 6.113 402.45
2202.16 40.770 287.450 2018.47 2100.51 121.39 N 446.92 W 5978360.67 N 582592.16 E 3.917 462.96
2297.95 43.500 286.450 2089.49 2171.53 140.11 N 508.39 W 5978378.71 N 582530.49 E 2.935 527.22
2393.93 45.630 289.010 2157.88 2239.92 160.64 N 572.52 W 5978398.53 N 582466.14 E 2.903 594.54
2489.91 47.560 287.700 2223.83 2305.87 182.59 N 638.70 W 5978419.74 N 582399.72 E 2.242 664.23
2585.75 50.950 287.290 2286.37 2368.41 204.41 N 707.94 W 5978440.79 N 582330.24 E 3.552 736.83
2681.58 53.850 286.980 2344.84 2426.88 226.77 N 780.49 W 5978462.35 N 582257.44 E 3.037 812.74
2776.25 55.810 288.160 2399.37 2481.41 250.14 N 854.26 W 5978484.90 N 582183.42 E 2.307 890.11
2871.70 56.150 287.850 2452.77 2534.81 274.59 N 929.50 W 5978508.51 N 582107.92 E 0.446 969.20 -.
2968.41 54.290 288.210 2507.93 2589.97 299.17 N 1005.03 W 5978532.26 N 582032.12 E 1.947 1048.61
3058.29 55.870 286.310 2559.39 2641.43 321.03 N 1075.40 W 5978553.33 N 581961.51 E 2.469 1122.29
3189.93 57.060 284.350 2632.11 2714.15 350.02 N 1181.22 W 5978581.15 N 581855.37 E 1.535 1231.98
3287.46 56.680 284.150 2685.42 2767.46 370.13 N 1260.38 W 5978600.38 N 581776.00 E 0.426 1313.59
3383.41 56.160 284.300 2738.49 2820.53 389.77 N 1337.87 W 5978619.16 N 581698.30 E 0.557 1393.45
3477.27 55.650 285.390 2791.10 2873.14 409.68 N 1413.00 W 5978638.24 N 581622.95 E 1.105 1471.14
3572.91 57.480 285.460 2843.80 2925.84 430.91 N 1489.93 W 5978658.61 N 581545.78 E 1.914 1550.93
3668.14 58.500 286.900 2894.28 2976.32 453.41 N 1567.48 W 5978680.25 N 581467.99 E 1.671 1631.67
3764.95 56.380 286.180 2946.38 3028.42 476.65 N 1645.69 W 5978702.62 N 581389.53 E 2.278 1713.26
3861.90 56.360 286.750 3000.07 3082.11 499.53 N 1723.10 W 5978724.64 N 581311.87 E 0.490 1793.98
3957.25 56.170 286.720 3053.02 3135.06 522.36 N 1799.04 W 5978746.63 N 581235.68 E 0.201 1873.28
27 January, 2003 - 16:54 Page 20f5 DrillQuest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112
Your Ref: AP/500292312900
Job No. AKZZ22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
4052.80 55.870 286.970 3106.43 3188.47 545.32 N 1874.87 W 5978768.75 N 581159.60 E 0.382 1952.51
4148.37 55.240 287.330 3160.48 3242.52 568.56 N 1950.18 W 5978791.15 N 581084.04 E 0.729 2031.32
4244.72 55.260 287.230 3215.40 3297.44 592.07 N 2025.77 W 5978813.83 N 581008.19 E 0.088 2110.48
4339.50 54.920 287.410 3269.64 3351.68 615.21 N 2099.97 W 5978836.14 N 580933.74 E 0.391 2188.20
4435.91 56.770 286.350 3323.77 3405.81 638.37 N 2176.31 W 5978858.45 N 580857.15 E 2.124 2267.97
4532.24 56.840 286.570 3376.51 3458.55 . 661.21 N 2253.62 W 5978880.43 N 580779.59 E 0.204 2348.58 --
4628.43 56.380 286.730 3429.44 3511.48 684.22 N 2330.57 W 5978902.59 N 580702.39 E 0.498 2428.90
4723.18 56.190 286.320 3482.04 3564.08 706.64 N 2406.12 W 5978924.17 N 580626.59 E 0.412 2507.71
4818.96 55.930 287.490 3535.51 3617.55 729.74 N 2482.15 W 5978946.43 N 580550.32 E 1.049 2587.17
4913.89 56.860 287.290 3588.05 3670.09 753.37 N 2557.60 W 5978969.22 N 580474.61 E 0.995 2666.22
5011.79 57.040 287.300 3641 .45 3723.49 777.77 N 2635.95 W 5978992.75 N 580395.99 E 0.184 2748.28
5108.09 58.270 287.470 3692.97 3775.01 802.08 N 2713.59 W 5979016.20 N 580318.09 E 1.286 2829.63
5203.76 58.440 287.960 3743.16 3825.20 826.86 N 2791.17 W 5979040.12 N 580240.24 E 0.471 2911.06
5300.50 58.380 289.160 3793.84 3875.88 853.09 N 2869.29 W 5979065.48 N 580161.83 E 1.058 2993.42
5396.60 58.680 290.160 3844.01 3926.05 880.66 N 2946.47 W 5979092.20 N 580084.35 E 0.941 3075.27
5493.25 57.680 289.410 3894.97 3977.01 908.46 N 3023.75 W 5979119.14 N 580006.77 E 1.227 3157.27
5589.73 58.020 287.390 3946.31 4028.35 934.24 N 3101.25W 5979144.06 N 579928.99 E 1.807 3238.91
5684.94 58.450 285.920 3996.44 4078.48 957.44 N 3178.80 W 5979166.40 N 579851.18 E 1.388 3319.86
5779.67 56.960 286.450 4047.05 4129.09 979.76 N 3255.70 W 5979187.86 N 579774.04 E 1.642 3399.93
5875.39 57.320 286.860 4098.98 4181.02 1002.80 N 3332.73 W 5979210.05 N 579696.76 E 0.520 3480.33
5970.83 56.460 286.680 4151.12 4233.16 1025.87 N 3409.28 W 5979232.27 N 579619.97 E 0.915 3560.27
6066.59 56.240 284.440 4204.18 4286.22 1047.25 N 3486.06 W 5979252.80 N 579542.95 E 1.961 3639.96
6159.91 55.830 284.560 4256.32 4338.36 1066.63 N 3560.99 W 5979271.34 N 579467.81 E 0.452 3717.31
6253.08 55.860 284.670 4308.63 4390.67 1086.08 N 3635.60 W 5979289.97 N 579392.99 E 0.103 3794.36 ,,-.'
6349.00 55.210 284.710 4362.91 4444.95 1106.14 N 3712.10 W 5979309.17 N 579316.27 E 0.679 3873.39
6448.54 55.010 284.290 4419.85 4501.89 1126.58 N 3791.14 W 5979328.74 N 579237.01 E 0.400 3954.98
6544.93 54.450 283.720 4475.51 4557.55 1145.63 N 3867.50 W 5979346.94 N 579160.44 E 0.755 4033.59
6640.62 53.500 285.030 4531.79 4613.83 1164.84 N 3942.46 W 5979365.31 N 579085.27 E 1.487 4110.92
6736.95 52.740 285.340 4589.60 4671.64 1185.02 N 4016.83 W 5979384.67 N 579010.69 E 0.830 4187.95
6831.51 52.4 70 285.310 4647.02 4729.06 1204.87 N 4089.28 W 5979403.72 N 578938.02 E 0.287 4263.05
6927.36 52.050 286.190 4705.69 4787.73 1225.45 N 4162.23 W 5979423.49 N 578864.84 E 0.848 4338.84
7023.00 52.120 286.350 4764.46 4846.50 1246.58 N 4234.66 W 5979443.82 N 578792.18 E 0.151 4414.29
7119.46 51.780 288.220 4823.92 4905.96 1269.15 N 4307.19 W 5979465.58 N 578719.41 E 1.567 4490.24
7215.36 50.720 289.780 4883.95 4965.99 1293.49 N 4377.90 W 5979489.14 N 578648.44 E 1.683 4564.96
7311.73 48.880 288.4 70 4946.15 5028.19 1317.61 N 4447.43 W 5979512.49 N 578578.64 E 2.173 4638.49
27 January, 2003 - 16:54
Page 3 of 5
DrillQuest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112
Your Ref: API 500292312900
Job No. AKZZ22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
7405.73 47.580 287.670 5008.76 5090.80 1339.36 N 4514.08 W 5979533.50 N 578511.75 E 1.522 4708.58
7502.48 46.240 287.010 5074.86 5156.90 1360.43 N 4581.52 W 5979553.81 N 578444.09 E 1 .472 4779.22
7597.82 44.71 0 286.480 5141.71 5223.75 1380.01 N 4646.61 W 5979572.68 N 578378.79 E 1.653 4847.19
7693.43 43.600 285.830 5210.31 5292.35 1398.55 N 4710.58 W 5979590.50 N 578314.61 E 1 .254 4913.79
7788.89 42.050 285.490 5280.32 5362.36 1416.06 N 4773.05 W 5979607.32 N 578251.95 E 1.642 4978.67
7884.99 41.210 284.790 5352.15 5434.19 1432.74 N 4834.68 W 5979623.32 N 578190.14 E 0.999 5042.49 --
7981.36 40.780 286.060 5424.89 5506.93 1449.55 N 4895.62 W 5979639.45 N 578129.02 E 0.973 5105.69
8077.64 39.870 285.950 5498.29 5580.33 1466.73 N 4955.51 W 5979655.97 N 578068.95 E 0.948 5167.99
8173.25 38.560 287.480 5572.36 5654.40 1484.10 N 5013.40 W 5979672.70 N 578010.86 E 1.703 5228.43
8269.34 36.920 288.560 5648.35 5730.39 1502.29 N 5069.33 W 5979690.26 N 577954.74 E 1.840 5287.22
8364.45 35.300 289.830 5725.19 5807.23 1520.70 N 5122.26 W 5979708.09 N 577901.60 E 1.876 5343.22
8460.73 33.980 291.260 5804.40 5886.44 1539.90 N 5173.51 W 5979726.71 N 577850.15 E 1.610 5397.82
8555.50 32.310 289.000 5883.75 5965.79 1557.75 N 5222.14 W 5979744.02 N 577801.32 E 2.192 5449.53
8652.05 30.61 0 285.320 5966.11 6048.15 1572.65 N 5270.25 W 5979758.39 N 577753.04 E 2.656 5499.89
8747.56 28.780 286.390 6049.08 6131.12 1585.56 N 5315.77 W 5979770.79 N 577707.39 E 1.995 5547.20
8841.83 26.320 286.560 6132.65 6214.69 1597.92 N 5357.58 W 5979782.69 N 577665.44 E 2.611 5590.79
8938.51 24.140 286.640 6220.10 6302.14 1609.69 N 5397.07 W 5979794.03 N 577625.82 E 2.255 5632.00
9035.30 22.630 286.930 6308.94 6390.98 1620.78 N 5433.85 W 5979804.71 N 577588.92 E 1.565 5670.42
9132.61 21.200 287.010 6399.21 6481.25 1631.38 N 5468.59 W 5979814.92 N 577554.07 E 1.470 5706.73
9226.91 19.880 286.850 6487.52 6569.56 1641.02 N 5500.24 W 5979824.21 N 577522.32 E 1.401 5739.82
9325.11 19.370 288.390 6580.01 6662.05 1651.00 N 5531.67 W 5979833.84 N 577490.77 E 0.740 5772.79
9421.32 19.990 288.740 6670.60 6752.64 1661.31 N 5562.38 W 5979843.81 N 577459.95 E 0.656 5805.18
9516.71 20.320 288.230 6760.15 6842.19 1671.73 N 5593.56 W 5979853.88 N 577428.66 E 0.392 5838.03
9565.06 20.270 289.320 6805.50 6887.54 1677.13 N 5609.43 W 5979859.11 N 577412.73 E 0.789 5854.78 ' /
---
9640.00 20.270 289.320 6875.80 6957.84 1685.72 N 5633.93 W 5979867.42 N 577388.13 E 0.000 5880.72 Projected Survey
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US).
Vertical Section is from Well and calculated along an Azimuth of 286.660° (True).
Magnetic Declination at Surface is 25.681°(31-Dec-02)
Based upon Minimum Curvature type calculations, at a Measured Depth of 9640.00fl.,
The Bottom Hole Displacement is 5880.72ft., in the Direction of 286.658° (True).
27 January, 2003 - 16:54 Page 4 of5 DrilfQuest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112
Your Ref: API 500292312900
Job No. AKZZ22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
9640.00
6957.84
1685.72 N
5633.93 W
Projected Survey
._~.,
Survey tool program for L-112
Fro m
Measured Vertical
Depth Depth
(ft) (ft)
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
0.00
722.00
0.00
721.46
722.00
9640.00
721.46 Tolerable Gyro(L-112 Gyro)
6957.84 AK-6 BP _IFR-AK(L-112)
~'
27 January, 2003 - 16:54
Page 50f5
DrillQlJest 3.03.02.004
)
AOGCC
333 W. 7th Ave. Suite 100
Anchorage, AK 99501
)
Re: Distribution of Survey Data for Well L-112 MWD
Dear Dear Sir/Madam:
Enclosed are two survey hard copies and 1 disk
Tie-on Survey:
Window / Kickoff Survey
Projected Survey:
'MD
'MD
(if applicable)
9,640.00' MD
Please call me at 273-3545 if you have any questions or concerns.
Regards,
William T. Allen
Survey Manager
Attachment(s)
é;kd~d¿Jc¡
30-Jan-03
Sperry-Sun Drilling Services
North Slope Alaska
BPXA
PBU WOA L Pad
L-112 MWD
Job No. AKMW22209, Surveyed: 8 January, 2003
Survey Report
27 January, 2003
Your Ref: API 500292312900
Surface Coordinates: 5978244.24 N, 583040.40 E (70021' 01.9315" N, 149019'32.8636" W)
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4
_/
Surface Coordinates relative to Project H Reference: 978244.24 N, 83040.40 E (Grid)
Surface Coordinates relative to Structure: 94.94 N, 129.36 E (True)
Kelly Bushing: 82.04ft above Mean Sea Level
Elevation relative to Project V Reference: 82.04ft
Elevation relative to Structure: 82.04ft
spe....y-sul'l
DRILLING SERVICES
A Halliburton Company
Survey Ref: svy11437
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112 MWD
Your Ref: AP/500292312900
Job No. AKMW22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
722.00 2.750 232.000 639.42 721.46 18.52 S 6.86W 5978225.65 N 583033.74 E 1.27 MWD Magnetic
766.48 3.240 266.970 683.85 765.89 19.24 S 8.96W 5978224.90 N 583031.65 E 4.179 3.07
860.45 3.840 283.930 777.64 859.68 18.63 S 14.67 W 5978225.45 N 583025.94 E 1.277 8.71
956.52 4.290 288.180 873.4 7 955.51 16.73 S 21.20 W 5978227.28 N 583019.38 E 0.563 15.52
1051.96 6.550 292.910 968.4 7 1050.51 13.50 S 29.61 W 5978230.42 N 583010.94 E 2.412 24.50
1147.63 12.620 299.850 1062.77 1144.81 6.16 S 43.71 W 5978237.59 N 582996.76 E 6.447 40.11 ~/
1243.77 16.860 301.430 1155.72 1237.76 6.34 N 64.73 W 5978249.86 N 582975.60 E 4.430 63.83
1340.21 16.250 298.720 1248.17 1330.21 20.12 N 88.50 W 5978263.37 N 582951.69 E 1.020 90.55
1436.01 17.830 289.180 1339.78 1421.82 31.38 N 114.11 W 5978274.35 N 582925.95 E 3.347 118.32
1531.05 19.850 284.910 1429.72 1511.76 40.31 N 143.45 W 5978282.96 N 582896.51 E 2.572 148.99
1626.73 23.030 285.640 1518.77 1600.81 49.54 N 177.18 W 5978291.81 N 582862.68 E 3.335 183.94
1722.44 22.980 286.020 1606.87 1688.91 59.74 N 213.17W 5978301.62 N 582826.59 E 0.164 221.34
1817.93 24.540 285.450 1694.26 1776.30 70.17 N 250.20 W 5978311.63 N 582789.44 E 1.651 259.81
1914.86 26.690 284.740 1781.66 1863.70 81.07 N 290.66 W 5978322.09 N 582748.86 E 2.241 301 .70
2010.40 31.580 284.240 1865.09 1947.13 92.69 N 335.68 W 5978333.21 N 582703.71 E 5.125 348.16
2106.18 37.430 284.950 1943.99 2026.03 106.38 N 388.16 W 5978346.32 N 582651.09 E 6.122 402.36
2202.16 40.770 287.530 2018.46 2100.50 123.35 N 446.24 W 5978362.64 N 582592.82 E 3.870 462.87
2297.95 43.500 286.020 2089.49 2171.53 141.88 N 507.77 W 5978380.48 N 582531.09 E 3.040 527.13
2393.93 45.630 289.290 2157.88 2239.92 162.33 N 571.91 W 5978400.22 N 582466.72 E 3.261 594.45
2489.91 47.560 288.570 2223.83 2305.87 184.94 N 637.87 W 5978422.10 N 582400.52 E 2.083 664.12
2585.75 50.950 288.240 2286.38 2368.42 207.86 N 706.76 W 5978444.26 N 582331.38 E 3.547 736.68
2681.58 53.850 287.790 2344.84 2426.88 231.33 N 778.96 W 5978466.93 N 582258.93 E 3.049 812.58
2776.25 55.810 289.220 2399.37 2481.41 255.90 N 852.33 W 5978490.68 N 582185.28 E 2.411 889.92
2871.70 56.150 288.670 2452.77 2534.81 281.59 N 927.16 W 5978515.54 N 582110.18 E 0.596 968.97 '.~
2968.41 54.290 289.050 2507.94 2589.98 307.26 N 1002.33 W 5978540.38 N 582034.73 E 1.950 1048.34
3058.29 55.870 287.070 2559.39 2641 .43 330.09 N 1072.39 W 5978562.43 N 581964.42 E 2.520 1122.01
3189.93 57.060 285.100 2632.12 2714.16 360.48 N 1177.81 W 5978591.65 N 581858.66 E 1.540 1231.72
3287.46 56.680 284.950 2685.42 2767.46 381.65 N 1256.70 W 5978611.94 N 581779.55 E 0.410 1313.36
3383.41 56.160 285.350 2738.49 2820.53 402.54 N 1333.85 W 5978631.98 N 581702.17 E 0.644 1393.27
3477.27 55.650 286.940 2791.11 2873.15 424.15 N 1408.51 W 5978652.76 N 581627.27 E 1.504 1470.99
3572.91 57.480 287.580 2843.80 2925.84 447.84 N 1484.73 W 5978675.60 N 581550.80 E 1.993 1550.79
3668.14 58.500 287.750 2894.28 2976.32 472.34 N 1561.67 W 5978699.25 N 581473.59 E 1.082 1631.53
3764.95 56.380 287.070 2946.38 3028.42 496.76 N 1639.52 W 5978722.80 N 581395.48 E 2.268 1713.11
3861.90 56.360 287.830 3000.07 3082.11 520.97 N 1716.52 W 5978746.15 N 581318.21 E 0.653 1793.83
3957.25 56.170 287.790 3053.03 3135.07 545.22 N 1792.02 W 5978769.57 N 581242.45 E 0.202 1873.10
27 January, 2003 - 16:58 Page 20f5 DrillQLJest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112 MWD
Your Ref: API 500292312900
Job No. AKMW22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft)
4052.80 55.870 288.350 3106.43 3188.47 569.80 N 1867.34 W 5978793.31 N 581166.86 E 0.579 1952.31
4148.37 55.240 288.220 3160.48 3242.52 594.52 N 1942.18 W 5978817.20 N 581091.75 E 0.669 2031.09
4244.72 55.260 288.320 3215.40 3297.44 619.34 N 2017.35 W 5978841.19 N 581016.31 E 0.088 2110.23
4339.50 54.920 288.420 3269.65 3351.69 643.84 N 2091.12 W 5978864.86 N 580942.28 E 0.369 2187.92
4435.91 56.770 286.970 3323.77 3405.81 668.07 N 2167.12 W 5978888.26 N 580866.01 E 2.287 2267.68
4532.24 56.840 287.220 3376.51 3458.55 691.77 N 2244.17 W 5978911.10 N 580788.70 E 0.229 2348.29 ---'
4628.43 56.380 287.420 3429.45 3511.49 715.68 N 2320.84 W 5978934.16 N 580711.77 E 0.509 2428.60
4723.18 56.190 287.030 3482.04 3564.08 739.02 N 2396.12 W 5978956.66 N 580636.24 E 0.397 2507.4 1
4818.96 55.930 288.190 3535.52 3617.56 763.05 N 2471.85 W 5978979.86 N 580560.24 E 1.041 2586.85
4913.89 56.860 288.150 3588.06 3670.10 787.71 N 2546.98 W 5979003.68 N 580484.85 E 0.980 2665.89
5011.79 57.040 287.860 3641 .45 3723.49 813.07 N 2625.02 W 5979028.17 N 580406.54 E 0.309 2747.93
5108.09 58.270 288.120 3692.97 3775.01 838.20 N 2702.39 W 5979052.44 N 580328.88 E 1.297 2829.26
5203.76 58.440 288.830 3743.17 3825.21 864.01 N 2779.64 W 5979077.40 N 580251.35 E 0.656 2910.67
5300.50 58.380 289.830 3793.84 3875.88 891.29 N 2857.40 W 5979103.81 N 580173.30 E 0.883 2992.98
5396.60 58.680 290.790 3844.01 3926.05 919.74 N 2934.27 W 5979131.41 N 580096.12 E 0.907 3074.78
5493.25 57.680 290.290 3894.97 3977.01 948.55 N 3011.17 W 5979159.37 N 580018.91 E 1.124 3156.71
5589.73 58.020 288.210 3946.32 4028.36 975.48 N 3088.28 W 5979185.44 N 579941.50 E 1.859 3238.31
5684.94 58.450 286.710 3996.44 4078.48 999.76 N 3165.50 W 5979208.86 N 579864.02 E 1.414 3319.24
5779.67 56.960 286.940 4047.05 4129.09 1022.94 N 3242.14 W 5979231.19 N 579787.12 E 1.586 3399.32
5875.39 57.320 287.310 4098.99 4181.03 1046.62 N 3318.98 W 5979254.01 N 579710.02 E 0.497 3479.72
5970.83 56.460 287.190 4151.12 4233.16 1070.32 N 3395.33 W 5979276.87 N 579633.42 E 0.907 3559.66
6066.59 56.240 284.970 4204.19 4286.23 1092.40 N 3471.92 W 5979298.10 N 579556.59 E 1.943 3639.36
6159.91 55.830 285.130 4256.32 4338.36 1112.50 N 3546.66 W 5979317.37 N 579481.63 E 0.462 3716.72
6253.08 55.860 284.970 4308.63 4390.67 1132.52 N 3621.11 W 5979336.56 N 579406.96 E 0.146 3793.79 .--
6349.00 55.210 285.320 4362.91 4444.95 1153.18 N 3697.45 W 5979356.37 N 579330.40 E 0.741 3872.85
6448.54 55.010 285.210 4419.85 4501.89 1174.68 N 3776.22 W 5979377.00 N 579251.40 E 0.220 3954.47
6544.93 54.450 284.620 4475.51 4557.55 1194.93 N 3852.26 W 5979396.41 N 579175.13 E 0.766 4033.13
6640.62 53.500 286.130 4531.79 4613.83 1215.44 N 3926.88 W 5979416.09 N 579100.29 E 1.617 4110.50
6736.95 52.740 285.860 4589.60 4671.64 1236.68 N 4000.95 W 5979436.50 N 579025.99 E 0.820 4187.55
6831.51 52.470 286.520 4647.03 4729.07 1257.62 N 4073.09 W 5979456.65 N 578953.62 E 0.624 4262.67
6927.36 52.050 287.540 4705.70 4787.74 1279.82 N 4145.57 W 5979478.04 N 578880.90 E 0.949 4338.46
7023.00 52.120 286.600 4764.47 4846.51 1301.97 N 4217.69 W 5979499.39 N 578808.54 E 0.779 4413.91
7119.46 51 .780 288.400 4823.92 4905.96 1324.80 N 4290.13 W 5979521.42 N 578735.85 E 1.511 4489.86
7215.36 50.720 289.430 4883.95 4965.99 1349.04 N 4360.89 W 5979544.87 N 578664.83 E 1.387 4564.59
7311.73 48.880 288.000 4946.15 5028.19 1372.67 N 4430.59 W 5979567.73 N 578594.87 E 2.220 4638.14
27 January, 2003 - 16:58 Page 3 0'5 DrillQuest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112 MWD
Your Ref: AP/500292312900
Job No. AKMW22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical
Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment
(ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft)
7405.73 47.580 286.780 5008.77 5090.81 1393.63 N 4497.49 W 5979587.94 N 578527.74 E 1.688 4708.24
7502.48 46.240 286.460 5074.86 5156.90 1413.84 N 4565.19 W 5979607.40 N 578459.82 E 1 .406 4778.89
7597.82 44.710 286.620 5141 .72 5223.76 1433.19 N 4630.35 W 5979626.03 N 578394.46 E 1.609 4846.86
7693.43 43.600 286.400 5210.31 5292.35 1452.12 N 4694.20 W 5979644.25 N 578330.40 E 1.172 4913.46
7788.89 42.050 286.020 5280.32 5362.36 1470.23 N 4756.51 W 5979661.67 N 578267.89 E 1.646 4978.35
7884.99 41.210 285.260 5352.15 5434.19 1487.45 N 4817.98 W 5979678.21 N 578206.23 E 1.020 5042.18
7981.36 40.780 286.670 5424.89 5506.93 1504.83 N 4878.76 W 5979694.91 N 578145.26 E 1.058 5105.39
8077.64 39.870 286.350 5498.29 5580.33 1522.54 N 4938.49 W 5979711.96 N 578085.34 E 0.969 5167.69
8173.25 38.560 287.810 5572.37 5654.41 1540.28 N 4996.27 W 5979729.06 N 578027.36 E 1.676 5228.13
8269.34 36.920 288.860 5648.35 5730.39 1558.77 N 5052.10 W 5979746.93 N 577971 .33 E 1.833 5286.92
8364.45 35.300 290.130 5725.19 5807.23 1577.47 N 5104.94 W 5979765.04 N 577918.29 E 1.876 5342.90
8460.73 33.980 291.630 5804.40 5886.44 1596.96 N 5156.07 W 5979783.96 N 577866.95 E 1.632 5397.47
8555.50 32.310 289.11 0 5883.75 5965.79 1615.01 N 5204.63 W 5979801.48 N 577818.19 E 2.284 5449.17
8652.05 30.610 285.330 5966.12 6048.16 1629.96 N 5252.73 W 5979815.89 N 577769.93 E 2.697 5499.53
8747.56 28.780 286.490 6049.08 6131.12 1642.92 N 5298.23 W 5979828.34 N 577724.29 E 2.008 5546.83
8841 .83 26.320 286.680 6132.66 6214.70 1655.36 N 5340.01 W 5979840.32 N 577682.37 E 2.611 5590.43
8938.51 24.140 286.710 6220.11 6302.15 1667.20 N 5379.48 W 5979851.72 N 577642.77 E 2.255 5631.64
9035.30 22.630 287.070 6308.94 6390.98 1678.36 N 5416.24 W 5979862.47 N 577605.89 E 1.567 5670.06
9132.61 21 .200 287.150 6399.22 6481.26 1689.04 N 5450.95 W 5979872.77 N 577571.06 E 1.470 5706.37
9226.91 19.880 287.200 6487.52 6569.56 1698.81 N 5482.56 W 5979882.19 N 577539.35 E 1.400 5739.46
9325.11 19.370 288.670 6580.02 6662.06 1708.96 N 5513.94 W 5979891.99 N 577507.86 E 0.723 5772.43
9421.32 19.990 288.900 6670.61 6752.65 1719.39 N 5544.62 W 5979902.08 N 577477.07 E 0.649 5804.81
9516.71 20.320 288.560 6760.16 6842.20 1729.95 N 5575.74 W 5979912.29 N 577445.83 E 0.367 5837.65
9565.06 20.270 289.610 6805.51 6887.55 1735.43 N 5591.59 W 5979917.60 N 577429.92 E 0.760 5854.41
9640.00 20.270 289.610 6875.81 6957.85 1744.14 N 5616.05 W 5979926.04 N 577405.37 E 0.000 5880.34 Projected Survey
All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4.
The Dogleg Severity is in Degrees per 100 feet (US).
Vertical Section is from Well and calculated along an Azimuth of 286.660° (True).
'-'
~
Magnetic Declination at Surface is 25.681 0(31-Dec-02)
Based upon Minimum Curvature type calculations, at a Measured Depth of 9640.00ft.,
The Bottom Hole Displacement is 5880.65ft., in the Direction of 287.253° (True).
27 January, 2003 - 16:58
Page 4 0'5
DrillQuest 3.03.02.004
Sperry-Sun Drilling Services
Survey Report for PBU_WOA L Pad - L-112 MWD
Your Ref: AP/S00292312900
Job No. AKMW22209, Surveyed: 8 January, 2003
BPXA
North Slope Alaska
Comments
Measured
Depth
(ft)
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
Comment
9640.00
6957.85
1744.14 N
5616.05 W
Projected Survey
-.--"
Survey tool program for L-112 MWD
Fro m
Measured Vertical
Depth Depth
(ft) (ft)
To
Measured Vertical
Depth Depth Survey Tool Description
(ft) (ft)
0.00
722.00
0.00
721.46
722.00
9640.00
721.46 Tolerable Gyro(L-112 Gyro)
6957.85 MWD Magnetic(L-112 MWD)
-
27 January, 2003 - 16:58
Page 50f5
DrillQuest 3.03.02.004
Schlumbergel'
Alaska Data and Consulting Services
3940 Arctic Blvd, Suile 300
Anchorage, AK 99503-5111
ATTN: Beth
Well
Job#
Log Descñption
L-112 ~(jç¿ :~~:¡
S-115l).()~ -(9. ~O
SBHP SURVEY
SBHP SURVEY
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
K 0 \}', fV'~' (¡.C'I.'::"..("/V\
Dale Delivered:
R;- br~t:. "vi=r)
, K"",,,,, \.,þ' ~_ is n-.- lb.
R 1 ¡~. ')'00,;-1.
þ~P'í L- v
_. I·
.,., ," '-. ("J""<:- ¡ :rwpml~,~n
tJ~if\.l,..? ì í;', SI. \.;;I. 5.~ \......)111;'. ..... .....òoI; ,.I,.,;'¡-i'¡Ji
r'\I~\JI\Go! VII"....
t\r1çtmT~~
04103103
NO. 2735
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
Sepia
CD
Color
BL
02/19103
03112/03
---'
Schlumberger DCS
. 3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
ATTN: Beth
Received by:
-~
Schlum~erger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TTN: Beth
Well
L-112An;3-d~q
L-112
L-112
L-112
L-112
L-112
L-112 '" /
S-115...JO~_ ~50
S-115
S-115
S-115
S-115
S-115
S-115
S-115 ~
S-115
S-115
Job#
Log Description
23029 OH EDIT PEX,AIT,BHC (PDC)
23029 PEX-AIT
23029 PEX-BHC
23029 PEX-NEUTRON/DENSITY
23029 PEX-TRIPLE COMBO MD
23029 PEX-TRIPLE COMBO TVD
23029 CALIPER LOG
23028 OH EDIT LWD GR & ROPS
23028 MD IMPULSE GR
23028 TVD IMPULSE GR
23035 OH EDIT PEX,AIT,BHC (PDC)
23035 PEX-RESISTlVITY
23035 PEX-NEUTRONIDENSITY
23035 PEX-SONIC
23035 PEX-TRIPLE COMBO MD
23035 PEX-TRIPLE COMBO TVD
23035 CAUPER LOG
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrolectnical Oala Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Dale Delivered:
Rk.: ~ ~ ¡ \ l~ 't~;j
;, '. ~ \...J r_ ~ :.1 ;,.,..lr....J
r.¡;q
,; ....~
c~ -i~
~- -. -
:~..:. -'::~_~ 7?-_r- .~._
AJ~~~ C~:! (.~;~~. ~~~~:~-.:.-. :_'_~~¿4.'~·~~:·:-~
01109/03
01109/03
01/09/03
01/09/03
01/09/03
01/09/03
01/09/03
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
01/28/03
NO. 2829
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
Color
Sepia
BL
CD
_.
Schlumberger DeS
3940 Arctic Blvd Suile 300
Anchorage AK 99503-5789
ATTN: :: '- ~ .
R.œ¡0~(Jbp~
.~
)
\lJ6A- z../t,/IJ'5
)
~ t-p" '1../ ,1 Ð 3
d) rr.5 2./7/0 :3
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request:
FRAC ¡
Abandon_ Suspend_
Alter casing _ Repair well _
Change approved program _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
2754'FNL,3875'FEL,Sec.34,T12N, R11E,UM
At top of productive interval
1100' FNL, 4132' FEL, SEC 33, T12N, R11E, UM
At effective depth
1081' FNL,4188'FEL, Sec. 33,T12N, R11E,UM
At total depth
1069' FNL, 4223' FEL, Sec 33 T12N, R11 E, UM
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length Size
Conductor 112' 20"
Surface 2987' 9-5/8"
Production 9580' 7"
Perforation depth:
Operational shutdown _ Re-enter suspended well _
Plugging _ Time extension Stimulate - X
Pull tubing _ Variance Perforate Other
5. Type of Well: /' 6. Datum elevation (OF or KB feet)
Development _ X RKB 82.5 feet
Exploratory _ 7. Unit or Property name
Stratigraphic _
SeNice_ Prudhoe Bay Unit
8. Well number
(asp's 583040, 5978245) L-112
9. Permit number / approval number
(asp's 577482,5979840) 202-229 /'
10. API number
(asp's 577390, 5979870) 50-029-23129-00
11. Field / Pool /
(asp's 577426,5979858) Prudhoe Bay Field I Borealis Pool
9640 feet
6958 feet
9529 feet
6854 feet
Cemented
Plugs (measured)
Junk (measUred)
Measured Depth
144'
3019'
True vertical Depth
144'
3072'
260 sx Arctic Set (Aprox)
481 sx ArcticSet Lite III,
342 sx Class 'G'
143 bbls lead cmt, 154
sx Class 'G'.
9612'
6932'
RECEIVED
measured Open Perfs 9358' - 9382'
Ff"l-3 0 5 2003
true vertical Open Perfs 6693' - 6716' Alaska Oil & Gas Conc' ',',.~..¡;"¡... .
'. ù, l.lL\h !ilISSIOIl
,L'Ulcho rd(ìe
Tubing (size, grade, and measured depth 4-1/2",12.6#, L-80 TBG @ 73'. 4-1/2" x 3-1/2" XO @ 73'. 3-1/2" 9.2# L-80 TBG @ 9176'.
Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker PREM Packer @ 9118'.
3-1/2" HES X Nipple @ 2211' MD.
13. Attachments Description summary of proposal _X Detailed operations program _
14. Estimated date for commencing operation 15. Status of well classification as:
February, 2003
16. If proposal was verbally approved Oil _X Gas
BOP sketch
Suspended _
Signed
Bruce Smith
1..V
Name of approver Date approved Service
17. I hereby certify that the foregoing is true and co ect to the best of my knowledge.
~
Questions? Call Bruce Smith, (907) 564-5093.
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity _ ~OP Test _ Location clearance _ _ I I
Mechanical Integrity Test ~ Subsequent form required 1 0- ~ 0 ï
ORIGINAL SIGNED BY
M l. Bi1J
Approved by order of the Commission
Form 10-403 Rev 06/15/88 ·
Title: Borealis Development Petroleum Engineer
Date February 04, 2003
Prepared by DeWayne R. Schnorr 564·5174
Approval no.
c:303-D~
Commissioner
Date
SUBMIT IN TRIPLICATE
¡, I;
bp
February 04, 2003
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BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P. O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561·5111
Winton Aubert
Alaska Oil & Gas Conservation Commission
333 West ih Avenue Suite 100
Anchorage, AK 99501
Dear Winton:
Re: Sundry Notice for L-112 Fracture Stimulation Program
BP Exploration Alaska, Inc. proposes to fracture stimulate well L-112.
Attached is the Fracturing procedure, which consists of 1500 bbls of water for
diagnostics and fracturing with 100 Mlbs of 16/20 Carbo Lite proppant. See
pump schedule for details. The pump schedule is subject to change; fluid and
proppant volumes should be adequate to address any contingencies. The
procedure includes the following major steps:
//'
The procedure includes the following major steps:
Category NaB STEP Description
S 1500 1 Pull and dummy GLV.
o 1500 2 MIT IA //
o 1500 3 Perform Data Frac & Frac. Shut-in.
C 1500 4 FCO. Freeze protect. Shut-in.
S 1500 5 InstallGLV's.
T 1500 6 Frac, Flowback, HOT tubing, Simultaneously POP.
T 1500 7 Mobile Test Separator Test schedule.
Last Test:
Max Deviation:
Perf Deviation:
Min. 10:
Last TO tag:
Latest H2S value:
Reference Log:
BHT & BHP:
New Completion, never tested
58° @ 3843' MD
20° @ 9346' MD
2.813" X Nipple
9529' MD New Well
o ppm 12/02
Schlumberger PEX
estimated 1580 F & 3150 psia @ 6600' TVDSS
)
)
1. Slickline /
a) Perforate and run static survey from prior programs before moving to this program. /
b) Report well conditions. WHP, WHT, lA, OA. Production rate. Freeze Protect
wellbore and flowline.
c) Pull and dummy gas lift valves.
d) Service Tree
2. Fracture Treatment
a) Load Frac tanks with - 100 of seawater; - 1500 bbls are required (excluding tank
bottoms).
b) RU the tree-saver/isolation tool for 3% "- 9.3 #/ft. tubing (see attached tubing
detail). PT backside to 4000 psi and maintain 3500 psi throughout treatment (set
inner annulus pop-off at 4000 psi). Note this well has a 10' floating seal assembly
and maintenance of 2500 psi on IA is required to stay in the PBR. Pressure test
treating lines to 8500 psi. Set Nitrogen pop-off valve at 7500 psig. Set pump trips
afterwards to 7500 psi. This well is expected to treat at ± 7000 psi. It is
recommended that 4 pumps be on location (1 backup).
c) Breaker tests will be performed on fluids prior to frac. The breaker schedule will be
designed to ensure fluid stability at end of pump time with complete break with-in
one hour of shut down. A minimum of 100 cp @ 100 sec^-1 is required at shut
down.
d) Begin pumping Data Frac, initial rate will be 5 bpm while displacing wellbore fluid,
after spotting Data Frac fluid a few feet above top perf increase rate to 25 bpm and
displace data frac. Shut down for ISIP, monitor for closure time, calculate efficiency
and re-design frac schedule as necessary (Pad size, fluid loss additive, etc.)
,/
e) Additional diagnostic tests may be performed after data frac analysis. Consult with
engineer before proceeding with frac.
f) Re-establish injection, when add rates are lined out start counting PAD. Pump the
proppant schedule as detailed in the attached pump schedule. Flush with linear
fluid. Switch to diesel flush if at all possible for freeze protect. (34 bbls), switch
back to linear fluid.
g) Bleed off excess annulus pressure. Rig down Service Company.
3. Post Fracture
a) Perform CTU fill clean out to original PBTD (-8443' corr)
1 Perform an overbalanced pressure fill clean-out, circulating gel and sand to a
tank. A connection to a flowline will not be available.
2 Use filtered seawater to clean-out. If gel sweeps are required to clean-out, have
lab verify that breaker loading is adequate to break polymer & mix water at 1500
F.
3 Freeze protect to 3000' with neat MEOH.
b) Slickline to install gas lift design to lift from bottom.
c) Shut-in pending frac flowback.
)
)
4. Frac Flowback
a) As soon as possible flowback through portable flow-back separator:
1 For analog Kuparuk frac flowback, see L-11 0 & L-107 well files.
2 Kuparuk wells tend to hydrate-off, HOT oil IA with 100 bbls of hot diesel followed
by 20 bbls of neat MEOH. Kick off well simultaneouslv with POP well.
3 Expect FWHTs of 50 - 60°F and watercuts of 100% to begin with. Treat gas lift
with methanol to prevent freezing. Attempt to quantify returned proppant flushed
to tank. //
4 Unload the well with 0.5 MMSCFGPD.
5 Conduct 4 hour well tests. If after 12 hours, solids are <0.10/0, then increase GL T
to 1 MMSCFGPD.
6 Conduct 4 hour well tests. If after 12 hours, solids are <0.1 %, then increase GL T
to 1.8 MMSCFGPD.
7 Do not surge well to flowback proppant. Surging could cause formation
failure and sand production.
8 Continue producing to the flowback separator until the gel load has been
recovered or watercut <10% and the solids production <0.1 %.
9 Schedule wellbore for Pad Separator test.
b) Place well on production at gas lift rate of 1.8 MMSCFPD, Place well on normal 15
day AOGCC required testing schedule.
c) Service tree.
If you have any questions concerning this Sundry Application, please don't
hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at
SmithBW@BP.com
Sincerely,
(l~
v/~
Bruce W. Smith
GPB Borealis Development Engineer
')
)
TREE = 4-1/16"QW
WB..LI-EAD = Frvc
ACTUATOR = !\VA
KB. ELEV = 82.5'
·S'F:"EC8J"·;,;;···"oo.....,," .00''''''31':'65;'
KOP = 3ÓO'
Max"Angie ';. .. "S9"'@"5'397'
ÖatU rTj' MiS:;; ······..··..9325'·
ï5atüm·f\T5··;;;·····m···..····..66(rö·ìs~r
14-1/2"TBG, 12.6#, L-80, .01522 bpf, ID= 3.958" H
L-112
=) )
I
SAÆTY NOTES: 7" CSG 13CR-80
FROM 9053'-9529'
I
=---i
73'
993'
1--1 4-1/2"x 3-1/2" XO, ID=3.000" I
1-1 9-5/8" TAM PORT COLLAR 1
73'
I
.
2211'
H 3-1/2" HES X NIP, ID = 2.813" I
1 9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 31 09' ~
..
L
GA S LIFT MA. NDRB..S
ST MD TVD DBI TYÆ VLV LATCH FQR[ DATE
4 4599 3495 56 MMG DMY RK 0 01/13/03
3 6462 4509 55 MMG DMY RK 0 01/13/03
2 7710 5304 42 MMG DMY RK 0 01/13/03
1 9037 6390 22 MMG RP RK 01/13/03
Minimum ID = 2.813" @ 2211'
3-1/2 HES X NIPPLE
I I
9094' 1-1 3-1/2" BKR CMO SLIDING SLV, ID = 2.813" 1
:8:
~
9118' H 7"X3-1/2"BKRFR8v1IERPKR,ID=2.992" I
3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID= 2.992" H 9175'
PERFORATION SUMMARY
RB= LOG: TFC ÆRF ON xx/xx/xx
ANGLEAT TOP PERF: ___ @ ____'
Note: Refer to Production DB for historcal perf data
SIZE SPF INTERV AL Opn/Sqz DA TE
~
9143'
9164 '
\
9176'
H 3-1/2" HES X NIP, ID = 2.813"
H 3-1/2" HES X NIP, ID = 2.813"
H 3-1/2" WLEG, ID = 2.992" I
H ELMO TT NOT LOGGED I
. 9033'-9053'H MA.RKERJOINT I
I 7' CSG. 26#. 13CR-80. 10 = 6.276" H 9053"952!iJ I
9208'
~ RA TAG I
c:
9450'
H RA TAG I
1 FBTD H
9529'
~
1 7" CSG. 26#. L-80. ID = 6.276" H
9612'
DA TE RBI BY COMMENTS
01/14,u3 JLM/lLH ORlGINA.L COMPLETlON
01/26,u3 JKP/lP V LV /LA T~ CORRECTIONS
01/25,u3 JOv1/lP LATCH CORREC1l0N
DATE REV BY
COMMENTS
GPB BOREALIS
WELL: L-112
PERMT No: 2020229
API No: 50-029-23129
SEe 34. T12N. R11 E. 27555' NSL & 3874' WEL
BP Exploration (Alaska)
.....,,"'.\,~.,.'.'..'~" ..., Joo......~.'" r','...'" ".' .
""" '~"'... ¡.......'.'...H..............'~..,',...,',._,.;.."..._._~,,,~..M....'.~," ',",.,." /,". ." ,.1>
From:
Sent:
To:
Cc:
Subject:
Dawson, Bob S (PRA)
Monday, January 20, 2003 5:09 PM
Tirpack, Robert B; Magee, D Neil
Cerveny, Phillip F; Greet, David N
L-112 Surface hole interpretation
óJDcR -:J gc¿
Rob and Neil:
I have reviewed the log data and Pason gas data for the surface hole interval at L-112. There were three intervals, all
deeper than the base of permafrost, which had gas increases:
1) the first interval is at approximately 1885-19101 MD, where the background gas increased to approximatly 150 units, and
then went to zero. On the logs this appears to be a hydrate interval, given the elevated resistivity and the lack of
neutron/density crossover. It is within the SV4 interval.
2) the second interval is at approximately 2050-20621 MD, in the lower part of the SV4. The gas increased to approximately
150 units, and then returned to zero. On the logs this appears to be a shaly sandstone with water and some gas saturation
in the water. David Greet will be looking at this zone further. It does not appear to be a significant hydrate or free gas zone,
given the relatively low resistivity that it shows, the modest amount of neutron/density crossover: the same sandstone
appeared to have gas at V-107, where it had a much more definitive (for gas) log response.
3) The third interval is in the top of the SV2 sandstone, at 2450-24761 MD. The gas increased initially to 150 units, and then
climbed to a'.background of approximately 1200 units. The log shows very definitive gas hydrate response: high resistivity,
wide invasion or melting response on resistivity curves, slow Rap, and high neutron and density porosity (no crossover).
Below this third zone no free gas or hydrate zones were detected. I reviewed the log results with Kip Cerveny, and Log
Analyst David Greet is still working on the data. Kip and I are available to meet with AOGCC personel to discuss the
results.
Bob Dawson
PBU Satellites Operations Geologist
907 -564-5264 ( office)
907-345-3359 (home)
907-242-2391 (cell)
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Doyon Drilling, Inc.
50-029-23129
Dec 31, 2002 05:05 MST
Jan 01 2003 06:05 MST
Jan 03, 2003 06:05 MST
CONTRACTOR:
UNIQUE WELL ID:
SPUD DATE:
RELEASE DATE:
FROM DATE:
TO DATE:
Mon Jan 06. 2003 11 :52:00 MST
Well Dossier 1041365590
tdriskill (209.165.189.18)
I
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OPERATOR: BP-Amoco Production Co.
WELL: L-112
FIELD:
LOCATION:
COUNTRY: U.S.A.
RIG: Doyon 14
DataHub EDR Log
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AI~A~1iA. OIL AND GAS
CONSERVATION COMMISSION
Lowell Crane
Senior Drilling Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
J\nchorage,AJ( 99519
TONY KNOWLES, GOVERNOR
333 W. PH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Prudhoe Bay Unit L-112
BP Exploration (Alaska), Inc.
Permit No: 202-229
Surface Location: 2525' NSL, 3874' WEL, Sec. 34, T12N, RIlE, UM
Bottomhole Location: 4232' NSL, 4306' WEL, Sec. 33, T12N, RIlE, UM
Dear Mr. Crane:
Enclosed is the approved application for permit to drill the above referenced development well.
This pennit to drill does not exempt you from obtaining additional pennits or approvals required
by law from other governmental agencies, and does not authorize conducting drilling operations
until all other required pennits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may
result in the revocation or suspension of the pennit. Please provide at least twenty-four (24)
hours notice for a representative of the Commission to witness any required test. Contact the
Commission's North Slope petroleum field inspector at 659-3607 (pager).
Sincerely,
~~~
Michael L. Bill
Commissioner
BY ORDER OF THE COMMISSION
DATED this 9!!-day of December, 2002
cc: Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
lJ.J r.:~A- LI III (')1_
,I ) STATEOF ALASKA \
ALASKA ulL AND GAS CONSERVATION COMfvl.. .SION
PERMIT TO DRILL
20 AAC 25.005 vJ(¡Js;
1 a. Type of work II Drill 0 Redrill 1 b. Type of well 0 Exploratory 0 Stratigraphic Test ai Development Oil
ORe-Entry 0 Deepen 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Planned KBE = 82.2' Prudhoe Bay Field I Prudhoc
3. Address 6. Property Designation [Jay I""col A lA.-prct" 0;) ftt7ì
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028239 flP¿
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
2525' NSL, 3874' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit
At top of productive interval 8. Well Number ,
4174' NSL, 4114' WEL, SEC. 33, T12N, R11E, UM L..112 / Number 2S100302630-277
At total depth 9. Approximate spud datE(
4232' NSL, 4306' WEL, SEC. 33, T12N, R11 E, UM 12/18/02 7' Amount $200,000.00
12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TV~,
ADL 047449,974' MD No Close Approach 2560 9584' MD / 6870' TVD
16. To be completed for deviated wells 17. Anticipated pressure {sZ': 20 AAC 25.035 (e) (2)}
Kick Off Depth 400' MD Maximum Hole Angle 570 Maximum surface 2721 psig, At total depth (TVD) 6560' I 3377 psig
18. Casinø Program Specifications Setting Depth
Size Too Bottom Quantitv of Cement
Hole Casing Weiaht Grade Couolina Lenath MD TVD MD TVD (include staae data)
42" 20" Insulated 91.5# H-40 WLD 80' Surface Surface 110' 110' 260 sx Arctic Set (Approx.) i
12-1/4" 9-518" 40# L-80 BTC 2947' Surface Surface 2977' 2586' 439 sx Arctic Set Lite, 348 sx IG' ~
8-3/4" 7.&: 26# L-80 BTC-m 9554' Surface Surface 9584' 68701 333 sx Dowell LiteCrete, 148 sx 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing
Length
Size
Cemented
MD
TVD
Structural
Conductor
Surface
Intermediate
Production
Liner
RECEIVED
DEC 0 2 2002
true vertical
Alasl<a Oil & Gas Cons. Commission
Anchorage
Perforation depth: measured
20. Attachments
II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program
II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 MC 25.050 Requirements
Contact Engineer Name/Number: James Franks, 564-4468 Prepared By Name/Number: Sandra Stewman, 564-4750
21. I hereby certify that the for oing is true ,~sorrect to the best of my knowledge
Signed Lowell Crane .. I~ Title Senior Drilling Engineer Date / ¿ - z - ~rl-
COmß)~.ionUSe:iQnly¡' .
Permit Number API Number
.2 0 .z _ - z... Z 7 50- 0 2.. 9 - 2- 3 I;¿ '7
Conditions of Approval: Samples Required 0 Yes ~ No
See cover letter
for other requirements
ICI Yes 0 No s~~ RJ....
IQ "....ty
Hydrogen Sulfide Measures 0 Yes ~ No Directional Survey Required gJ Yes 0 No
Required ~orking Pressu~e for BOPE ,O,2K q 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for C~U
D'Vl..t<"...· iN~f;.¡;...!fIIJ~~· det'\..'\.(.d. /'-k~ i J,,'"¡A ~V'I""/.I t
Other: ·r~œISlftt.f!L ~~ I. M 1:. i, ~!- q ¡,WLl /..£\ CI~I Cu.\..o rrul.,)~l.-. r' "'.".c~( y..?~\w ~<1
M L 811 U by or er'ð .µ; v 'N)¿c "V'... '-;.ltv"¿'~..f .
. I Commissioner the commission Öate J, C) () 7-
Subr'lit n Triplicate
APrA\~,r~
Mud Log Reqùired
Approved By
Form 10-401 Rev. 12-01-85
) )
IWell Name: I L-112
Drill and Complete Plan Summary
r Type of Well (service I producer I injector): ~~r (contingency injector) ./'
Surface Location: X = 583,040.40' Y = 5,978,244.24'
As-Built 2524' FSL (2755' FNL), 3874~ FEL (1406' FWL), Sec. 34, T12N, R11 E
Target Location: X = 577,500' Y = 5,979,835'
Top Kuparuk 4174' FSL (1105' FNL), 4114' FEL (1166' FWL), Sec. 33, T12N, R11E
Bottom Hole Location: X = 577,307.40' Y = 5,979,890.76'
4232' FSL (1047' FNL), 4306' FEL (9741 FWL), Sec. 33, T12N, R11 E
I AFE Number: I BRD5Mxxxx I I Ri~: I Doyon 14 /
I Estimated Start Date: 112/18/2002 1
I OperatinQ days to complete: 114.8
I MD: 19584'
I TVD: 16870'
I RT/GL: 134.5' I
I KBE: 182.2'
I Well Design (conventional, slim hole, etc.): I Ultra Slimhole (Iongstring) /
Objective: Single zone producer into the Kuparuk formation. This well is to be left in a
condition for injection as a contingency.
Mud Program:
12 'IA" Surface Hole (O-2977'):
Densitv
(ppg)
8.5 - 9.2
9.0 - 9.5
9.5 max ../
Initial
Base PF to top SV
SV toTO
Viscosity
(seconds)
250-300
200-250
150-200
Fresh Water Surface Hole Mud
Yield Point API FL PH
(lb/1 OOft~) (mls/30min)
50 - 70 15 - 20
30 - 45 < 10
20 - 40 < 10
8.5-9.5
8.5-9.5
8.5-9.5
8 314" Production Hole (2977' - 9584'): LSND
Interval Density Tau 0 YP PV pH API 10' Gel
(ppg) Filtrate
Upper 9.7 4-7 25-30 1 0-15 8.5-9.5 6-10 10
Interval 10.2 /
Top of HRZ 3-7 20-25 1 0-15 8.5-9.5 4-6 10
toTO
L-112 Drilling Permit
Page 1
) ')
Hydraulics:
Surface Hole: 12-1/4"
Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA
GPM Pipe (fpm) ppg-emw ("/32) (in2)
0-1809' 550 5" 19.5# 90 1800 10.0 N/A 18,18,18,16 .942
1809' -2977' 650 5" 19.5# 110 2400 10.2 N/A 18,18,18,16 .942
Production Hole: 8 %"
Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA
GPM (fpm) ppg-emw ("/32) (in2)
2977' ··~9584' 600 5"19.5# 240 3400 11;2 N/A 3x14,3x15 .969
Hole Cleaning Criteria:
Interval Interval ROP Drill Pump Mud Hole Cleaning Condition
Pipe GPM Weight
Rotation
110' -2977' Surface Superior hole cleaning practices at
to SV-1 connections will greatly enhance
cuttings transport in the sliding mode
180 60 500 9.5 Acceptable
220 60 600 9.5 Acceptable
260 60 700 9.5 Acceptable
195 80 500 9.5 Acceptable
230 80 600 9.5 Acceptable
270 80 700 9.5 Acceptable
200 100 500 9.5 Acceptable
240 100 600 9.5 Acceptable
290 100 700 9.5 Acceptable
2977'·9584' 9-5/8" to Sweeps and fully reamed connections
TD to maintain minimum hole cleaning
requirements
240 80 500 9.7 Acceptable
265 80 600 9.7 Acceptable
300 100 500 9.7 Acceptable
340 100 550 10.2 Acceptable
400 120 550 10.2 Acceptable
L-112 Drilling Permit
Page 2
Directional:
Ver. Sperry-Sun WP04
KOP: 400'
Maximum Hole Angle:
Close Approach Wells:
None
Logging Program:
Su rface
Intermediate/Production Hole
)
)
57 deg at 2453' MD
All wells pass major risk criteria. The nearest wells are:
Plan L-02 -15.53 ctr-ctr@ 450' - drilled the well prior to L-112. Need to
verify following the drilling of the L-02 well.
IFR-MS corrected surveys will be used tor survey validation.
Camera Based Gyro will be needed for surface issues to 1000' MD.
Drilling:
Open Hole:
Cased Hole:
Drilling:
Open Hole:
Cased Hole:
Formation Tops
SV6
SV5
SV4
Base Permafrost
SV3
SV2
SV1
UG4A
UG3
UG1
Ma
WS2 Na
WS1 Oa
Obf Base
CM2 (Colville)
CM1 (Colville)
THRZ
BHRZ (Kalubik)
K-1
TKUP
Kuparuk C
LCU (Kuparuk B)
TD Criteria
Formation Markers:
TVDss
895
1545
1675
1690
1925
2065
2410
2745
3060
3515
3805
4060
4215
4570
4845
5550
6160
6375
6420
6530
6560
6715
L-112 Drilling Permit
-------J
~:~ I GR I RES I DENSI NEUT(._.~~~~dñ
None
MWD/GR/PWD
Pex/BHC Sonic /"
USIT cement evaluation
Estimated pore pressure, PPG
Non-Hydrocarbon Bearing, 8.6 ppg EMW
Non-Hydrocarbon Bearing, 8.6 ppg EMW
Non-Hydrocarbon Bearing, 8.6 ppg EMW
Non-Hydrocarbon Bearing, 8.6 ppg EMW
Hydrocarbon Bearing, 9.9 ppg EMW
lO.'<-
100' MD below LCU
Page 3
)
)
CasinglTubing Program:
Hole Csgl WtlFt Grade
Size TbQ O.D. /'
42" Insulated 20" 91.5# H-40
12 %" 9 5/8" 40# L-80
8 3A" 7" 26# L -80
Tubing 3 Y2" 9.2# L-80
Co¡
WLD
BTC
BTC-m
TCII
Length
80'
2947'
9554'
9057'
Top
MDITVD
GL
GL
GL
GL
8tm
MDITVD bkb
110'/110'
2977'/2586'
9584'/6870'
9087'/6410'
Integrity Testing:
Test Point Depth
Surface Casing Shoe 20' min (50' max) from
surface shoe
Test Type EMW
LOT 12.4 ppg EMW Target
Cement Calculations:
The following surface cement calculations are based upon a single stage job using a port collar as a
contingency if cement is not circulated to surface.
Casinq Size 19-5/8" Surface I
Basis: Lead: Based on conductor set at 110', 1809' of annulus in the permafrost @ 2250/0
excess and 268' of open hole from top of tail slurry to base permafrost @ 30% excèss.
Lead TOC: To surface.;"
Tail: Based on 800' MD(>500'TVD) open hole volume + 300/0 excess + 80' shoe track
volume. Tail TOC: At -2077' MD L:J
Total Cement Volume: Lead 348 bbl I 1950 fe I ~.sks of Dowell ARCTICSETLite at
10.7 ppg and 4..~sk.
Tail 71 bbl I 400 fe I~sks of Dowell 'G' at 15.8 ppg and
1 .15 cf/sk.
Casinq Size 17" Production Longstring I
Basis: Stage 1: Based on Tail TOC 500' above top of Kuparuk formation + 300/0 ex~e.... 80'
shoe. Cement Placement: Tail from shoe to 8787" MD, lead from 8787' to 2 - 500'
above Ma sand LJ'
Total Cement Volume: Lead 138 bbls I 775 fe I ~~sks of Dowell LiteCRETE at 12.0
ppg and 2.33 cf/~
Tail 31 bbl I 173 ft::! I ~ sks of Dowell 'G" at 15.8 ppg and
1.17 cf/sk.
L-112 Drilling Permit
Page 4
),
)
Well Control:
Surface hole will be drilled with diverter (diverterwåiv~rreqU~sted). The production hole well
control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and
annular preventer will be installed and is capable of handling maximum potential surface
pressures. Based upon the planned casing testJør future fracture stimulation treatment,
the BOP equipment will be tested to 4500 psi.
Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC.
Production Interval-
· Maximum anticipated BHP:
· Maximum surface pressure:
3377 psi @ 6560' TVgss - Kuparuk A Sands
2721 psi @ surface
(based on BHP and a full column of gas from TD @ 0.10 psi/ft)
4500 psi (The casing and tubing will be tested to 4500 psi as /
· Planned BOP test pressure:
required for fracture stimulation.)
· Planned completion fluid:
8.6 ppg filtered seawater / 6.8 ppg diesel
Disposal:
· No annular disposal in this well.
· Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind
and inject at OS-04.
· Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-
04 for disposal. Haul all Class I wastes to Pad 3 for disposal.
L-112 Drilling Permit
Page 5
)
')
DRILL AND COMPLETE PROCEDURE SUMMARY
Pre-Rig Work:
The 20" insulated conductor was installed in Aug. 2002.
1. Weld an FMC landing ring for the FMC Ultra slim hole wellhead on the conductor.
2. If necessary, level the pad and prepare location for rig move.
Rig Operations: /
1. MIRU Doyon 14. .... ... . ..... iJ·
2. Nipple up diverter and spool (divßrter waiver requested). PU 5"ÓP as required and stand back in
derrick. / '
3. MU 12 %" drilling assembly with MWD/LWD (page 4) and directionally drill surface hole to
approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a will be
performed prior to exiting the Permafrost. /
4. Run and cement the 9-5/8",40# surface casing back to surface. /'
5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4500 psi.
6. MU 8-3/4" drilling assembly with MWD/LWD(page 4) and RIH to float collar. Test the 9-5/8" casing to /'
3500 psi for 30 minutes. &
7. Drill out shoe joints and displace well t .7 pg drilling fluid. Drill new formation to 20' below 9-5/8"
shoe and perform Leak Off Test.
8. Drill ahead conducting wiper trips as necessary.
9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.2 ppg and perform short trip if needed.
Hold a Pre-Reservoir meeting highlighting kicVOlerance and detection prior to entering HRZ.
10. Drill ahead to TD at -100' MD below LCU.
11. Condition hole for logging/running 7" 26# long-string casing.
12. Run Pex/BHC Sonic on wireline. If wireline logs do not go down, DPC will be required. /'
13. Run and cement the 7" production casing in a single stage. (To be reviewed based on log/operational
results.) Displace the cement with 8.5 ppg filtered seawater if single stage. ~.
14. Verify zonal Isolation by running a USIT log over the Kuparuk formation for injection contingency.
15. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on the
Morning Report. /'
16. Test casing to ~O psi for 30 minutes.
17. Run the 3-1/2", 9.2#, L-80 TCII completion assembly. Set packer and test the tubing to 4500 psi and
annulus to 4500 psi for 30 minutes. Shear DCK shear valve and install TWC. Test below to 1000 psi.
18. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC.
19. RU hot oil truck and freeze py.tect well by pumping diesel to lowermost GLM. Allow to equalize.
20. Rig down and move off.
L -112 Drilling Permit
Page 6
)
)
L-112 Drilling Program
Job 1: MIRU
Hazards and Contingencies
~ L-Pad is not designated as an H2S site. None of the current producers on L-Pad have
indicated the presence of H2S. As a precaution however Standard Operating Procedures
for H2S precautions should be followed at all times.
~ The closest surface location is Planned L-02, 15' to the East.
þ> Check the landing ring height on L-112. The BOP nipple up may need review for space out.
Reference RPs
.:. Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure"
11I~~I:mlla>;.".,. I'I:III:m'UIII'II':l1llm:llllm:mlrl":m:n:mlm1111:.111111I:11. :':Imlmlml,,:rllmll. .:: 1;:1::-:- -I; - 111111111111:;I:m:lrml1:llllllm,mrllmmllllml
Job 2: DrillinQ Surface Hole
þ> There is one nearby well issue in the surface hole. Refer to page 4 for details.
þ> A Gyro survey will be required per the directional plan to 1000' MD or until the magnetic
interference at the surface has dissipated.
þ> Gas hydrates have been observed in wells drilled on L-pad. These were encountered near the
base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate
mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation
þ> L-112 will cross one fault in the Surface hole @ 2150'TVDss, +/- 100', with a throw of 70' to the
west. Faults in this area have not been problematic.
Reference RPs
.:. uPrudhoe Bay Directional Guidelines"
.:. uWell Control Operations Station Bill"
.:. Follow Halliburton logging practices and recommendations
'-'rll.J!IIIIII'IDIIIIII,IIIIIIIIIIIlaumlllllll:llnllnm:mllllllm.:I IIIlmmumlrUI:IIU'lm:U'-IJI- .1__'._III.I.lllIlml! :II! _ICllllllmllll,m1Im:mr11111111111._U- -111111111- '1-11-- .mIllIIIIIIlII11111111111:1II11111.1II1: I: IUII.I.a::-,::. .111:1. --IIII-11111111111,m:I':IIIII:IIIII:II:IIIUI:;:I_II:-'II---I-'-111:W""':UIIUHlllalllll.I!IIllImlllUlmllllll__I_III_ _II. :u I:L:III:llmmllUlllUmmlmllllll::II:lmUl
Job 3: Install Surface Casina
Hazards and Contingencies
~ It is critical that cement is circulated to surface for well integrity. 225% excess cement through the
permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be
positioned at ±1 OOO'MD to allow remedial cementing.
).> "Annular Pumping Away" criteria for future permitting approval for annular injection.
1. Pipe reciprocation during cement displacement
2. Cement - Top of tail >500' TVD above shoe using 30% excess.
3. Casing Shoe Set approximately 100'TVD below SV-1 sand.
Reference RPs
.:. UCasing and Liner Running Procedure"
.:. uSurface Casing and Cementing Guidelines"
.:. uSurface Casing Port Collar Procedure"
L-112 Drilling Permit
Page 7
)
)
Job 7: DrillinQ Production Hole
Hazards and Contingencies
~ L-112 will cross one fault - in the Schrader Bluff - 4275'TVDss (+/- 150') with the estimated throw
of the fault being 130'. The well will be - 57 degrees when crossing the fault. Lost circulation is
considered a medium risk.
~ For losses above the Kuparuk, consult the Lost Circulation Decision Tree regarding LCM
treatments and procedures. For losses in the Kuparuk, utilize Baracarb as the preferred choice in
LCM material. Should Baracarb be ineffective, notify the Production Engineer/Drilling Engineer
prior to the addition of a more damaging LCM. See the modified LCM Decision Tree in the Baroid
mud program.
~ KICK TOLERANCE: In the scenario of 9.9 ppg pore pressure at the Kuparuk target depth, gauge
hole, a fracture gradient of 12.4 ppg at the surface casing shoe, 10.2 ppg mud in the hole the kick
tolerance is 25.1 bbls. An accurate LOT will be required as well as heightened awareness
for kick detection. Contact Drilling Manager if LOT is less than 12.4 ppg. L-pad development
wells have "kick tolerances" in the 25-50 bbl range. A heightened awareness of kick
detection, pre-job planning and trip tank calibration will be essential while drilling/tripping
the intermediate/production intervals
~ Hole angle of 56 degrees will require optimized flow rates, pipe rotation and mud rheology to
achieve hole cleaning. Follow hole cleaning guidelines outlined in operational specifics.
Reference RPs
.:. Standard Operating Procedure for Leak-off and Formation Integrity Tests
.:. Prudhoe Bay Directional Guidelines
.:. Lubricants for Torque and Drag Management.
.:. IIShale Drilling- Kingak & HrZ"
1- ·-;T_I¡--:I1III. TV""
mIl"'· -'-"'~I:-Ir _'- _L ._1
1".1'. _I.T . -WIIIII- T _I ,. ....... I'( -II'''IT. flllO"mmm,'
Job 8: Loa Production Hole
Hazards and Contingencies
~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program.
Review the use of lubricant pill across logging interval.
~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the
longstring casing.
~ If Wireline logs are not successful, we will be logging the well DPC.
Reference RPs
.:. Follow Schlumberger logging practices and recommendations.
.:. "Drillpipe Conveyed Logging"
Job 9: Case & Cement Production Hole
Hazards and Contingencies
~ The interval is planned to be cemented in a single stage with a 12.0 ppg lead (500'MD above the
Schrader Ma) and a 15.8 ppg tail (500' above the Kuparuk). If a single stage cement job is
deemed too risky based on observations while drilling, then a 2 stage cement job may need to be
performed. As such, this will require the picking up of 3-1/2" drillpipe to drill out the ES cementer.
~ Since this well may be an injection well in the future, we need to get a USIT log across the
cemented interval.
L-112 Drilling Permit
Page 8
)
')
~ Ensure the lower production cement has reached a compressive strength of 500 psi prior to
freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 63 bbls of dead
crude (2300' MD, 2221 'TVD), the hydrostatic pressure will be 7.7 ppg vs 8.5 ppg EMW of the
formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the
annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may
be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could
be 110 psi underbalance to the open hole. (A second LOT will be required prior to displacing
freeze protect. This to satisfy AOGCC for future annular pumping permits.)
~ Ensure a minimum hydrostatic equivalent of 10.2 ppg on the Kuparuk formation during pumping of
cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a
reduction in hydrostatic pressure while pumping spacers and flushes.
~ Considerable losses during running and cementing the 7" longstring has been experienced on
offset wells. A casing running program will be jointly issued by the ODE and Drilling Supervisor
detailing circulating points and running speed. In addition a LCM pill composed of "Steel Seal" will
be placed across the Schrader and Ugnu to help arrest mud dehydration.
Reference RPs
.:. Ulntermediate Casing and Cementing Guidelines"
.:. uFreeze Protecting an Outer Annulus"
11:::m:I:-II- - ;:11:1111:-'1111::11-111--1-"-11:-111-.-11-'- -.-'111-11::-111111-1111'111111:;';- -11111-:llllm':lII:mlmn:,J/- . 'I~'II'
Ilml,__IIII"I-,---rll'-IIIIIIII;lIlmrl
Job 12: Run Completion
Hazards and Contingencies
~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this
completion. The well will be underbalanced if there is a casing integrity problem.
;;.. Shear valves have been failing at lower than the 2500 psi differential pressure. When testing
annulus maintain no more than a 1500 psi differential: 2500 psi tubing pressure, 4000 psi annulus
pressure. Avoid cycling pressure (pumping up and bleeding off) prior to activating shear valve as
this is thought to cause shearing at lower pressures.
Reference RPs
.:. Completion Design and Running
.:. Freeze Protection of Inner Annulus
·"'~'L llw-;:nlllllllTlU-IIIIIII;IWI":IITIlTH;,1I"1I" lillI- TITIIIII.IITITITlllrll" .I.T .,
"'--'1. .11. .n. _I. _mIU__ILIIII_I_m_il:-,-,-:u-'-··-r- -TIT:I:-.-ITI
ITITmTllIlI:TIW- ·W· _IIIIT_ Ii. .11I1.1. .1. -':ml'-'-'-B'- ,,:I.II:-,I:n-- -T- _"II:-III----lIlr--.w
Job 13: ND/NU/Release RiQ
Hazards and Contingencies
~ No hazards specific to this well have been identified for this phase of the well construction.
Reference RPs
.:. Freeze Protection of Inner Annulus
L-112 Drilling Permit
Page 9
Plan: L-112 wp04 (plan L-I I2IPlan L-112
Created By: Ken Allen Dale:
Cheeked: Date:
Date:
SURVEY PROGRAM
Deplli Fm Depth To Sur\'eylPlan Toot
2850 900.00 P1anoed: L-112 "J>!» V4 CB-GYRO-SS
900.00 987335 Planned: L-112 wp04 V4 MWD+IFR+M
REÆRENCE INFORMATION
C~ínate (NŒ) Reference: Well Centre: Plan L-112, Trœ Nor1\¡
Verti<al (IVD) ReIereoce: L-1l676.20
S<ction (VS) Ref."",",,: SIoI- (O.OON,O.OOE)
Measured Depth Reference: L-1l6 76.20
Cak'UJatioo Method: MinUDlIIl Curvature
0>.... ~ b. '..~... p
..:
- - t ~
WELL DETAILS
No<thing EasIing Latitude Longitude
5978244.2· 583040.40 70"2I'OL932N 149°19"32.864W
Slot
NlA
+EI-W
43.70
+NI-S
ILOJ
Name
Plan L-I
TARGET DETAILS
Nonhiog
5979834."
Target
-
L-112TI
L-112TI
VSec
0.00
0.00
-4.88
-8.55
106.63
228.97
275.21
784.27
4284.96
5764.78
5914.01
5965.31
-'
r~
~~ ~
/~~
It!
,I
I
¡P
I
I
-I
I
,
#,.,
##
, #'
7"
CASING DETAILS
No. TVD MD Name Size
2586.20 2976.63 95/8" 9.625
7157.14 9873.34 7" 7.000
FORMATION TOP DETAILS
No. TVDPath MDPath Formation
I 336.20 336.20 Gl
2 971.20 971.97 SV6
3 1621.20 1650.34 SV5
4 1751.20 1792.92 SV4
5 1766.20 1809.45 BPRF
6 2001.20 2076.35 SV3
7 2141.20 2251.27 SV2
8 2486.20 2795.56 SVI
9 2821.20 3402. 14 UG4A
10 3 I 36.20 3972.51 UG3
II 3591.20 4796.38 UGI
12 3881.20 5321.48 Ma
13 4136.20 5783.20 Na
14 4291.20 6063.86 Oa
15 4646.20 6706.66 Obfbase
16 4921.20 7183.70 CM2
17 5626.20 8169.14 CMI
18 6236.20 8884.85 THRZ
19 6451.20 9120.72 BHRZ
20 6496.20 9169.30 K-I
21 6606.20 9287.04 TKUP
22 6636.20 9318.96 KUPC
23 6791.20 9483.91 LCU
24 6941.20 9643.54 KUPA
25 7016.20 9723.35 TMLV
("akublion MctJ...-.I: Minin1\.1'11 CW\õ1Iun:
~ ~?~~~~~ ~~vV:~~rn."f ~)rtJl
Error Surface.:: EIliplj(al . Casin@
Warnjn~ M<U."J: Ruh... ß3SI.-.J
TFace
0.00
0.00
165.00
180.00
0.00
0.00
0.00
0.00
0.00
80.00
0.00
0.00
&sting Shape
577499.99 Point
DLeg
0.00
0.00
1.50
2.00
3.00
IrSO
~.OO
4.00
0.00
1.50
0.00
0.00
~EI-W
·5522.95
SECTION DETAILS
+N/-S +EI-W
0.00
0.00
2.41
4.21
-106.05
-223. I 7
-267.44
-754.79
-4106.22
-5522.95
-5665.82
-5714.93
0.00
0.00
-8.99
-15.73
17.55
52.89
66.25
213.32
1224.67
1652.18
1695.29
1710.11
+NI-S
1652.
1VD
6606.
TVD
28.50
300.00
566.45
766.29
1419.50
1716.20
1816.20
2409.16
4728.27
6606.20
70 I 6.20
7157.15
Name
L-1l2 TI
Azi
0.00
0.00
165.00
0.00
286.79
286.79
286.79
286.79
286.79
286.79
286.79
286.79
MD
Inc
0.00
0.00
4.00
0.00
20.00
24.82
24.82
56.48
56.48
20.00
20.00
20.00
28.50
300.00
566.67
766.67
1433.33
1754.36
1864.53
2656.07
6855.25
9287.04
9723.35
9873.35
Sec
I
2
3
4
5
6
7
8
9
10
II
12
300' MD, 3oo'TVD
Stan Dir 2/100': 566.67' MD, 566.45'TVD
,/'" Stan Dif 3/100': 766.67' MD, 766.29'TVD
/
.5/100'
StanDi
-A
Start Die 1.5/100': 1433.33' MD,
SV: 1.60° ESt~~~i~JJ¡~1l6;~¿\~?:1J: T~~.2'TVD
S\'4
BIRF
2000 (>
SV3 ", , ~ End Die : 2656.07' MD,
SV2' ,~
SVI ~~ 95/8"
3OO0~,
UG4A ....-'..
1419.5'TVD
300
2409.16' TVD
2600
c
;¡:
~
..c
ê5..
Ö
..
'Ë 3900
>-
.,
:::>
¡::
5200
9287.04' MD, 6606.2' TVD
6500
RKBE.
All TVD depths are
ssTVD plus 76.2'for
TVD
I
7800
7157.15'
9873.35' MD,
I
6500
I
5200
Vertical Section at 286.66° [I300ft/in]
I
300
I
o
Plan: L-112 wp04 (plan L-II2IPlan L-112
Created By: Ken Allen Date:
Checked: Date:
Reviewed: Date:
Toot
CB-GYRO-SS
MWD+IFR+MS
SURVEY PROGRAM
Sm'''Y!Plan
Planned:L-112wp(l4V4
Planned: L-1I2 wp(14 V4
Depth To
900.00
981335
Depth Fm
2850
900.00
REFERENCE INFORMATION
Co-ordinal< (NiE) Re!ere"",: Well Centre: Plan L-112. True North
V<rtic31 (IVD) Refen.>n<e: L-1167610
Section (VS) Reference: SIoI- (O.OON,O.OOE)
Me.asunxl Depth Ref""",,,: L·1I6 7610
C.k:uIatioo Method: MinimIm CurvabBe
('akulalk"() ML'tJk'd: Minirmm (Ùf\'3tm:
~: ~~~'~I \~~";~~'f North
Enur Sur(ãç4.:: EllipC.k4Il ... Casing
W.mill ! Mctho.1: Rules B.s.:.!
O,b...P
"
SIoI
WA
Longitude
149°19'32.864W
WELL DETA!l.S
Northing Easting La~tude
597824414 583040.40 70"21'O\.932N
TARGET DETAILS
+W.s +EI-W Næ1hing
1652.18 -5522.' 5979834.'
+EI-W
43.70
~W-S
1\.03
Name
.-.....-f
Target
L-112 TI
L-112 TI
FORMATION TOP DETAILS
Fonnation
...../
I
1600
All TVD depths are
ssTVD plus 76.2',for RKBE.
VSee
0.00
0.00
-4.88
-8.55
106.63
228.97
275.21
784.27
4284.96
5764.78
5914.01
5965.31
Easting Shape
577499.99 Point
TFaee
0.00
0.00
165.00
180.00
0.00
0.00
0.00
0.00
0.00
80.00
0.00
0.00
DLeg
0.00
0.00
1.50
2.00
3.00
1.50
0.00
4.00
0.00
1.50
0.00
0.00
SECTION DETAILS
+N/-S +FJ-W
0.00
0.00
2.41
4.21
-106.05
-223.17
-267.44
-754.79
-4106.22
-5522.95
-5665.82
-5714.93
0.00
0.00
-8.99
15.73
17.55
52.89
66.25
213.32
1224.67
1652.18
1695.29
1710.11
1VD
660610
TVD
28.50
300.00
566.45
766.29
1419.50
1716.20
1816.20
2409.16
4728.27
6606.20
7016.20
7157.15
Narœ
L-1I2 Tt
Azi
0.00
0.00
165.00
0.00
286.79
286.79
286.79
286.79
286.79
286.79
286.79
286.79
Ine
0.00
0.00
4.00
0.00
20.00
24.82
24.82
56.48
56.48
20.00
20.00
20.00
MD
28.50
300.00
566.67
766.67
1433.33
1754.36
1864.53
2656.07
6855.25
9287.04
9723.35
9873.35
See
I
2
3
4
5
6
7
8
9
10
II
12
2656.07' MD, 2409.16' TVD
Dir 4/100': 1864.53' MD, 1816.2'TVD
i Dir : 1754.36' MD, 1716.2' TVD
Start Dir 1.5/100': 1433.33' MO, 1419.5'TVD
tart Dir 3/100': 766.67' MD, 766.29'TVD
Start Dir 2/100': 566.67' MD, 566.45'TVD
Start Dir 1.5/100' : 300' MD, 300'TVD
GI
SV6
SV5
SV4
BPRF
SV3
SV2
SVI
UG4A
UG3
UGI
Ma
Na
Oa
Obfbase
CM2
CMI
THRZ
BHRZ
K-I
TKUP
KUPC
LCU
KUPA
TMLV
MDPath
336.20
971.97
1650.34
1792.92
1809.45
2076.35
2251.27
2795.56
3402.14
3972.51
4796.38
5321.48
5783.20
6063.86
6706.66
7183.70
8169.14
8884.85
9120.72
9169.30
9287.04
9318.96
9483.91
9643.54
9723.35
I
800
TVDPath
336.20
97 1.20
1621.20
1751.20
1766.20
2001.20
2141.20
2486.20
2821.20
3136.20
3591.20
3881.20
4136.20
4291.20
4646.20
4921.20
5626.20
6236.20
6451.20
6496.20
6606.20
6636.20
6791.20
6941.20
7016.20
No.
I
2
3
4
5
6
7
8
9
10
I I
12
13
14
15
16
17
18
19
20
21
22
23
24
25
Size
9.625
7.000
CASING DETAILS
Name
95/8'
7"
MD
2976.63
9873.34
TVD
2586.20
7157.14
No.
I
2
¡riP
I
,I
¡P
I
I
-I
I
,;
#~,
, #' #
;.;;.
o
EndDi
-800
600
-2400
West(-)Æast(+) [800ft/in]
6855.25' MD, 4728.2TTVD
-3200
-4000
9873.35' MD, 7157.15' TVD
: 9287.04' MD, 6606.2' TVD
"".....................
10
-4800
Total Depth
1- End Di
12 WP04: J
; L-
7" 1 ~- -i.
700(, 6500'
L-
-5600
600
800
c
;:::
o
~
~
t:
!
:;
o
CI)
)
Company:
Field:
Site:
Well:
Wellpath:
BP Amoco
Prudhoe Bay
PB L Pad
Plan L;.112
Plan L..112
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
Site: PB L Pad
UNITED STATES: North Slope
Site Position: Northing:
From: Map Easting:
Position Uncertainty: 0.00 ft
Ground Level: 0.00 ft
Well:
Plan L-112
BP
KW A Planning Report MAP
')
Date:. 11/11/2002 Time: 13:55:54 Page:
Co-ordinate(NE) 'Reference: Well: Plan L-112, True' North
Vertical (TVD) Rêference: L-11676.2·· .
Section (VS) Reference: Well (0.00N,0.00E,286.66Azi)
Survey Calculation Method: Minimum CurVature Db: . Oracle
Map Zone:
Coordinate System:
Geomagnetic Model:
5978232.73 ft
582996.83 ft
Latitude:
Longitude:
North Reference:
Grid Convergence:
Slot Name:
Well Position: +N/-S
+E/-W
Position Uncertainty:
11.03 ft Northing: 5978244.24 ft
43.70 ft Easting: 583040.40 ft
0.00 ft
Latitude:
Longitude:
Wellpath: Plan L-112
50029
Current Datum: L-116
Magnetic Data: 10/17/2002
Field Strength: 57506 nT
Vertical Section: Depth From (TVD)
ft
0.00
Plan: L-112 wp04
Principal: Yes
Casing Points
MD TVD Diameter Hole Size
ft ft in in
2976.63 2586.20 9.625 12.250
9873.34 7157.14 7.000 8.750
Formations
336.20 336.20 G1
971.97 971.20 SV6
1650.34 1621.20 SV5
1792.92 1751.20 SV4
1809.45 1766.20 BPRF
2076.35 2001.20 SV3
2251.27 2141.20 SV2
2795.56 2486.20 SV1
3402.14 2821.20 UG4A
3972.51 3136.20 UG3
4796.38 3591.20 UG1
5321.48 3881.20 Ma
5783.20 4136.20 Na
6063.86 4291.20 Oa
6706.66 4646.20 Obf base
7183.70 4921.20 CM2
8169.14 5626.20 CM1
8884.85 6236.20 THRZ
9120.72 6451.20 BHRZ
9169.30 6496.20 K-1
9287.04 6606.20 TKUP
9318.96 6636.20 KUPC
Height 76.20 ft
Drilled From:
Tie-on Depth:
Above System Datum:
Declination:
Mag Dip Angle:
+E/-W
ft
0.00
Alaska, Zone 4
Well Centre
BGGM2002
70 21 1.823 N
149 19 34.141 W
True
0.63 deg
70 21 1.932 N
149 19 32.864 W
Well Ref. Point
0.00 ft
Mean Sea Level
25.76 deg
80.78 deg
Direction
deg
286.66
11/11/2002
4
From Well Ref. Point
+N/-S
ft
0.00
Date Composed:
Version:
Tied-to:
Name
95/8"
7"
J)ipAngle
deg
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
Dipþkection
deg
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
0.00
)
BP
KW A Planning Report MAP
Company: BP Amoco
Field: Prudhoe Bay
Site: PB L Pad
Well: Plan b112
Wellpath: Plan L-112
Date: 11/11/2002 Time: 13:55:54 . Page: 2
Co-ordinate(NE) Reference: Well: Plan L-112, True North
Vertical (TVD) Reference: L.;116 76.2
Section (VS) Refereöce: Well (0.00N,0~00E,286.66Azi)
Survey Calculation Method: . Minimum Curvature Db: Oracle
Formations
MD
ft
9483.91
9643.54
9723.35
Targets
TVD
ft
6791.20
6941.20
7016.20
LCU
KUPA
TMLV
Formätions
Name Description
Dip. Dir.
L-112 T1
-Plan hit target
Plan Section Information
MD
ft
28.50
300.00
566.67
766.67
1433.33
1754.36
1864.53
2656.07
6855.25
9287.04
9723.35
9873.35
Survey
MD
ft
28.50
100.00
200.00
300.00
336.20
400.00
500.00
566.67
600.00
700.00
766.67
800.00
900.00
971.97
1000.00
1100.00
1200.00
1300.00
1400.00
1433.33
1500.00
1600.00
1650.34
1700.00
1754.36
1792.92
Incl
deg
0.00
0.00
4.00
0.00
20.00
24.82
24.82
56.48
56.48
20.00
20.00
20.00
Inel
deg
0.00
0.00
0.00
0.00
0.54
Azim
deg
0.00
0.00
165.00
0.00
286.79
286.79
286.79
286.79
286.79
286.79
286.79
286.79
Azim
deg
0.00
0.00
0.00
0.00
165.00
1.50 165.00
3.00 165.00
4.00 165.00
3.33 165.00
1.33 165.00
0.00 0.00
1.00 286.79
4.00 286.79
6.16 286.79
7.00 286.79
10.00 286.79
13.00 286.79
16.00 286.79
19.00 286.79
20.00 286.79
21.00 286.79
22.50 286.79
23.26 286.79
24.00 286.79
24.82 286.79
24.82 286.79
TVD
ft
28.50
300.00
566.45
766.29
1419.50
1716.20
1816.20
2409.16
4728.27
6606.20
7016.20
7157.15
TVD
ft
28.50
100.00
200.00
300.00
336.20
399.99
499.91
566.45
599.72
699.63
766.29
799.62
899.51
971.20
999.04
1097.93
1195.91
1292.72
1388.08
1419.50
1481.94
1574.82
1621.20
1666.70
1716.20
1751.20
TVD
ft
6606.20
. +N/;,S
ft
0.00
0.00
-8.99
-15.73
17.55
52.89
66.25
213.32
1224.67
1652.18
1695.29
1710.11
Sys TVD
ft
-47.70
23.80
123.80
223.80
260.00
323.79
423.71
490.25
523.52
623.43
690.09
723.42
823.31
895.00
922.84
1021.73
1119.71
1216.52
1311.88
1343.30
1405.74
1498.62
1545.00
1590.50
1640.00
1675.00
+N/-S +E/-W
ft ft
1652.18 -5522.95
+E/-W
ft
0.00
0.00
2.41
4.21
-106.05
-223.17
-267.44
-754.79
-4106.22
-5522.95
-5665.82
-5714.93
MapN
ft
5978244.24
5978244.24
5978244.24
5978244.24
5978244.07
5978242.98
5978239.20
5978235.28
5978233.23
5978229.31
5978228.56
5978228.64
5978229.86
5978231.63
5978232.52
5978236.63
5978242.18
5978249.15
5978257.51
5978260.61
5978267.10
5978277.42
5978282.86
5978288.40
5978294.65
5978299.15
Lithology
Map Map
Northing Easting
ft ft
5979834.97 577499.99
')
Dip Angle
deg
0.00
0.00
0.00
Dip Direction
deg
0.00
0.00
0.00
<~~- . Latitude --> <~-:- . Longitude · --->
Deg Min··· Sec Deg Min ·Sec
70 21 18.161 N 149 22 14.307 W
DLS Build Turn
deg/toOft deg/100ft deg/100ft
0.00 0.00 0.00
0.00 0.00 0.00
1.50 1.50 0.00
2.00 -2.00 -82.50
3.00 3.00 0.00
1.50 1.50 0.00
0.00 0.00 0.00
4.00 4.00 0.00
0.00 0.00 0.00
1.50 -1.50 0.00
0.00 0.00 0.00
0.00 0.00 0.00
MapE
ft
583040.40
583040.40
583040.40
583040.40
583040.45
583040.75
583041.81
583042.91
583043.48
583044.58
583044.79
583044.51
583040.32
583034.20
583031.12
583016.92
582997.78
582973.73
582944.86
582934.17
582911.75
582876.16
582857.36
582838.25
582816.67
582801.13
VS
ft
0.00
0.00
0.00
0.00
-0.09
20.47 3.00
40.40 3.00
65.44 3.00
95.51 3.00
106.63 3.00
129.98 1.50
167.03 1.50
186.60 1.50
206.51 1.50
228.97 1.50
245.15 0.00
TFO
deg
0.00
0.00
165.00
180.00
0.00
0.00
0.00
0.00
0.00
-180.00
0.00
0.00
DLS TFO
deg/10Off deg
0.00 0.00
0.00 0.00
0.00 0.00
0.00 0.00
1.50 0.00
-0.69 1.50
-2.75 1.50
-4.88 1.50
-6.00 2.00
-8.14 2.00
-8.55 2.00
-8.26 3.00
-3.89 3.00
2.48 3.00
5.69 3.00
Target
L-112 T1
L-112 T1
Tool/Comment
CB-GYRO-SS
CB-GYRO-SS
CB-GYRO-SS
CB-GYRO-SS
G1
0.00 CB-GYRO-SS
0.00 CB-GYRO-SS
0.00 CB-GYRO-SS
180.00 CB-GYRO-SS
180.00 CB-GYRO-SS
180.00 CB-GYRO-SS
0.00 CB-GYRO-SS
0.00 MWD+IFR+MS
0.00 SV6
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 L-112T1
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 SV5
0.00 MWD+IFR+MS
0.00 MWD+IFR+MS
0.00 SV4
) , )
BP
KW A Planning Report MAP
Company: BP Amoco Date: 11/11/2002 Time: . . 13:55:54 Page: 3
Field: Prudhoe Bay Co';'ordinate(NE) Reference: Well: Plan L-112, True North
Site: PBL Pad Vertical (TVD)R~fe¡'ence: L-116 76.2
Well: Plan L-112 Section(VS) Reference: Well (0.OON,0.00E,286.66Azi)
Well path: Plan L-112 Survey Calculation Method: Minimum Curvature Db: Oracle
Survey
MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Toòl/Comment
ft deg deg ft ft ft ft ft d eg/1 000 deg
1800.00 24.82 286.79 1757.62 1681.42 5978299.98 582798.28 248.12 0.00 0.00 MWD+IFR+MS
1809.45 24.82 286.79 1766.20 1690.00 5978301.08 582794.47 252.09 0.00 0.00 BPRF
1864.53 24.82 286.79 1816.20 1740.00 5978307.51 582772.26 275.21 0.00 0.00 MWD+IFR+MS
1900.00 26.23 286.79 1848.20 1772.00 5978311.77 582757.59 290.49 4.00 0.00 MWD+IFR+MS
2000.00 30.23 286.79 1936.29 1860.09 5978324.93 582712.16 337.79 4.00 0.00 MWD+IFR+MS
2076.35 33.29 286.79 2001.20 1925.00 5978336.11 582673.57 377.97 4.00 0.00 SV3
2100.00 34.23 286.79 2020.86 1944.66 5978339.77 582660.95 391.12 4.00 0.00 MWD+IFR+MS
2200.00 38.23 286.79 2101.50 2025.30 5978356.21 582604.19 450.21 4.00 0.00 MWD+IFR+MS
2251.27 40.28 286.79 2141.20 2065.00 5978365.24 582573.03 482.66 4.00 0.00 SV2
2300.00 42.23 286.79 2177.83 2101.63 5978374.18 582542.17 514.79 4.00 0.00 MWD+IFR+MS
2400.00 46.23 286.79 2249.46 2173.26 5978393.58 582475.18 584.53 4.00 0.00 MWD+IFR+MS
2500.00 50.23 286.79 2316.06 2239.86 5978414.33 582403.56 659.11 4.00 0.00 MWD+IFR+MS
2600.00 54.23 286.79 2377 .29 2301.09 5978436.32 582327.66 738.14 4.00 0.00 MWD+IFR+MS
2656.07 56.48 286.79 2409.16 2332.96 5978449.16 582283.36 784.27 4.00 0.00 MWD+IFR+MS
2700.00 56.48 286.79 2433.42 2357.22 5978459.35 582248.18 820.89 0.00 0.00 MWD+IFR+MS
2795.56 56.48 286.79 2486.20 2410.00 5978481.52 582171.67 900.55 0.00 0.00 SV1
2800.00 56.48 286.79 2488.65 2412.45 5978482.55 582168.12 904.26 0.00 0.00 MWD+IFR+MS
2900.00 56.48 286.79 2543.88 2467.68 5978505.74 582088.05 987.62 0.00 0.00 MWD+IFR+MS
3000.00 56.48 286.79 2599.11 2522.91 5978528.94 582007.99 1070.99 0.00 0.00 MWD+IFR+MS
3100.00 56.48 286.79 2654.33 2578.13 5978552.14 581927.92 1154.35 0.00 0.00 MWD+IFR+MS
3200.00 56.48 286.79 2709.56 2633.36 5978575.33 581847.85 1237.72 0.00 0.00 MWD+IFR+MS
3300.00 56.48 286.79 2764.79 2688.59 5978598.53 581767.79 1321.09 0.00 0.00 MWD+IFR+MS
3400.00 56.48 286.79 2820.02 2743.82 5978621.73 581687.72 1404.45 0.00 0.00 MWD+IFR+MS
3402.14 56.48 286.79 2821.20 2745.00 5978622.22 581686.01 1406.24 0.00 0.00 UG4A
3500.00 56.48 286.79 2875.24 2799.04 5978644.92 581607.66 1487.82 0.00 0.00 MWD+IFR+MS
3600.00 56.48 286.79 2930.47 2854.27 5978668.12 581527.59 1571.18 0.00 0.00 MWD+IFR+MS
3700.00 56.48 286.79 2985.70 2909.50 5978691.31 581447.52 1654.55 0.00 0.00 MWD+IFR+MS
3800.00 56.48 286.79 3040.93 2964.73 5978714.51 581367.46 1737.92 0.00 0.00 MWD+IFR+MS
3900.00 56.48 286.79 3096.15 3019.95 5978737.71 581287.39 1821.28 0.00 0.00 MWD+IFR+MS
3972.51 56.48 286.79 3136.20 3060.00 5978754.53 581229.34 1881.73 0.00 0.00 UG3
4000.00 56.48 286.79 3151.38 3075.18 5978760.90 581207.33 1904.65 0.00 0.00 MWD+IFR+MS
4100.00 56.48 286.79 3206.61 3130.41 5978784.10 581127.26 1988.01 0.00 0.00 MWD+IFR+MS
4200.00 56.48 286.79 3261.84 3185.64 5978807.30 581047.19 2071.38 0.00 0.00 MWD+IFR+MS
4300.00 56.48 286.79 3317.06 3240.86 5978830.49 580967.13 2154.75 0.00 0.00 MWD+IFR+MS
4400.00 56.48 286.79 3372.29 3296.09 5978853.69 580887.06 2238.11 0.00 0.00 MWD+IFR+MS
4500.00 56.48 286.79 3427.52 3351.32 5978876.89 580807.00 2321.48 0.00 0.00 MWD+IFR+MS
4600.00 56.48 286.79 3482.75 3406.55 5978900.08 580726.93 2404.84 0.00 0.00 MWD+IFR+MS
4700.00 56.48 286.79 3537.97 3461.77 5978923.28 580646.86 2488.21 0.00 0.00 MWD+IFR+MS
4796.38 56.48 286.79 3591.20 3515.00 5978945.64 580569.70 2568.55 0.00 0.00 UG1
4800.00 56.48 286.79 3593.20 3517.00 5978946.48 580566.80 2571.58 0.00 0.00 MWD+IFR+MS
4900.00 56.48 286.79 3648.43 3572.23 5978969.67 580486.73 2654.94 0.00 0.00 MWD+IFR+MS
5000.00 56.48 286.79 3703.66 3627.46 5978992.87 580406.67 2738.31 0.00 0.00 MWD+IFR+MS
5100.00 56.48 286.79 3758.88 3682.68 5979016.07 580326.60 2821.67 0.00 0.00 MWD+IFR+MS
5200.00 56.48 286.79 3814.11 3737.91 5979039.26 580246.53 2905.04 0.00 0.00 MWD+IFR+MS
5300.00 56.48 286.79 3869.34 3793.14 5979062.46 580166.47 2988.40 0.00 0.00 MWD+IFR+MS
5321.48, 56.48 286.79 3881.20 3805.00 5979067.44 580149.27 3006.31 0.00 0.00 Ma
5400.00 56.48 286.79 3924.57 3848.37 5979085.66 580086.40 3071.77 0.00 0.00 MWD+IFR+MS
5500.00 56.48 286.79 3979.79 3903.59 5979108.85 580006.34 3155.14 0.00 0.00 MWD+IFR+MS
5600.00 56.48 286.79 4035.02 3958.82 5979132.05 579926.27 3238.50 0.00 0.00 MWD+IFR+MS
5700.00 56.48 286.79 4090.25 4014.05 5979155.25 579846.20 3321.87 0.00 0.00 MWD+IFR+MS
5783.20 56.48 286.79 4136.20 4060.00 5979174.55 579779.59 3391.23 0.00 0.00 Na
5800.00 56.48 286.79 4145.48 4069.28 5979178.44 579766.14 3405.23 0.00 0.00 MWD+IFR+MS
5900.00 56.48 286.79 4200.70 4124.50 5979201.64 579686.07 3488.60 0.00 0.00 MWD+IFR+MS
) ~ )
BP
KW A Planning Report MAP
Company: BP Amoco Date: 11/11/2002 Time: 13:55:54 Page: 4
Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan L-112, True North
Site: PB L Pad Vertical (TVD) Reference: L-11676.2
Well: Plan L-112 Section (V5) Reference: Well (0.00N,0.00E,286.66Azi)
\Vellpath: Plan L-112 Survey Calculation Method: Minimum Curvature Db: Oracle
Survey
MD lnel Azim TVD SysTVD l\'lapN MapE VS DL5 TFO Tool/Comment
ft deg deg ft ft ft ft ft deg/10OO deg
6000.00 56.48 286.79 4255.93 4179.73 5979224.83 579606.01 3571.97 0.00 0.00 MWD+IFR+MS
6063.86 56.48 286.79 4291.20 4215.00 5979239.65 579554.88 3625.20 0.00 0.00 Oa
6100.00 56.48 286.79 4311.16 4234.96 5979248.03 579525.94 3655.33 0.00 0.00 MWD+IFR+MS
6200.00 56.48 286.79 4366.39 4290.19 5979271.23 579445.87 3738.70 0.00 0.00 MWD+IFR+MS
6300.00 56.48 286.79 4421.61 4345.41 5979294.42 579365.81 3822.06 0.00 0.00 MWD+IFR+MS
6400.00 56.48 286.79 4476.84 4400.64 5979317.62 579285.74 3905.43 0.00 0.00 MWD+IFR+MS
6500.00 56.48 286.79 4532.07 4455.87 5979340.82 579205.68 3988.80 0.00 0.00 MWD+IFR+MS
6600.00 56.48 286.79 4587.30 4511.10 5979364.01 579125.61 4072.16 0.00 0.00 MWD+IFR+MS
6700.00 56.48 286.79 4642.52 4566.32 5979387.21 579045.54 4155.53 0.00 0.00 MWD+IFR+MS
6706.66 56.48 286.79 4646.20 4570.00 5979388.75 579040.22 4161.08 0.00 0.00 Obf base
6800.00 56.48 286.79 4697.75 4621.55 5979410.41 578965.48 4238.89 0.00 0.00 MWD+IFR+MS
6855.25 56.48 286.79 4728.27 4652.07 5979423.22 578921.24 4284.96 0.00 0.00 MWD+IFR+MS
6900.00 55.81 286.79 4753.20 4677.00 5979433.56 578885.55 4322.11 1.50 180.00 MWD+IFR+MS
7000.00 54.31 286.79 4810.47 4734.27 5979456.37 578806.83 4404.08 1.50 180.00 MWD+IFR+MS
7100.00 52.81 286.79 4869.88 4793.68 5979478.75 578729.57 4484.52 1.50 180.00 MWD+IFR+MS
7183.70 51.55 286.79 4921.20 4845.00 5979497.15 578666.08 4550.64 1.50 180.00 CM2
7200.00 51.31 286.79 4931.36 4855.16 5979500.70 578653.84 4563.38 1.50 180.00 MWD+IFR+MS
7300.00 49.81 286.79 4994.90 4918.70 5979522.18 578579.67 4640.60 1.50 180.00 MWD+IFR+MS
7400.00 48.31 286.79 5060.43 4984.23 5979543.20 578507.13 4716.14 1.50 180.00 MWD+IFR+MS
7500.00 46.81 286.79 5127.91 5051.71 5979563.73 578436.26 4789.93 1.50 180.00 MWD+IFR+MS
7600.00 45.31 286.79 5197.31 5121.11 5979583.76 578367.11 4861.93 1.50 180.00 MWD+IFR+MS
7700.00 43.81 286.79 5268.56 5192.36 5979603.28 578299.73 4932.08 1.50 180.00 MWD+IFR+MS
7800.00 42.31 286.79 5341.63 5265.43 5979622.28 578234.16 5000.35 1.50 180.00 MWD+IFR+MS
7900.00 40.81 286.79 5416.46 5340.26 5979640.74 578170.45 5066.69 1.50 180.00 MWD+IFR+MS
8000.00 39.31 286.79 5493.00 5416.80 5979658.64 578108.65 5131.04 1.50 180.00 MWD+IFR+MS
8100.00 37.81 286.79 5571.20 5495.00 5979675.98 578048.79 5193.36 1.50 180.00 MWD+IFR+MS
8169.14 36.77 286.79 5626.20 5550.00 5979687.64 578008.57 5235.24 1.50 180.00 CM1
8200.00 36.31 286.79 5651.00 5574.80 5979692.75 577990.92 5253.62 1.50 180.00 MWD+IFR+MS
8300.00 34.81 286.79 5732.35 5656.15 5979708.93 577935.07 5311.77 1.50 180.00 MWD+IFR+MS
8400.00 33.31 286.79 5815.20 5739.00 5979724.51 577881.29 5367.76 1.50 180.00 MWD+IFR+MS
8500.00 31.81 286.79 5899.48 5823.28 5979739.48 577829.61 5421.57 1.50 180.00 MWD+IFR+MS
8600.00 30.31 286.79 5985.15 5908.95 5979753.83 577780.07 5473.16 1.50 180.00 MWD+IFR+MS
8700.00 28.81 286.79 6072.13 5995.93 5979767.56 577732.70 5522.48 1.50 180.00 MWD+IFR+MS
8800.00 27.31 286.79 6160.38 6084.18 5979780.64 577687.53 5569.52 1.50 180.00 MWD+IFR+MS
8884.85 26.03 286.79 6236.20 6160.00 5979791.24 577650.95 5607.60 1.50 180.00 THRZ
8900.00 25.81 286.79 6249.83 6173.63 5979793.08 577644.59 5614.22 1.50 180.00 MWD+IFR+MS
9000.00 24.31 286.79 6340.41 6264.21 5979804.86 577603.92 5656.57 1.50 180.00 MWD+IFR+MS
9100.00 22.81 286.79 6432.08 6355.88 5979815.98 577565.54 5696.53 1.50 180.00 MWD+IFR+MS
9120.72 22.49 286.79 6451.20 6375.00 5979818.20 577557.87 5704.51 1.50 180.00 BHRZ
9169.30 21.77 286.79 6496.20 6420.00 5979823.29 577540.30 5722.81 1.50 180.00 K-1
9200.00 21.31 286.79 6524.76 6448.56 5979826.43 577529.47 5734.08 1.50 180.00 MWD+IFR+MS
9287.04 20.00 286.79 6606.20 6530.00 5979834.97 577499.99 5764.78 1.50 180.00 L-112 T1
9300.00 20.00 286.79 6618.38 6542.18 5979836.20 577495.73 5769.21 0.00 0.00 MWD+IFR+MS
9318.96 20.00 286.79 6636.20 6560.00 5979838.01 577489.50 5775.70 0.00 0.00 KUPC
9400.00 20.00 286.79 6712.35 6636.15 5979845.72 577462.88 5803.41 0.00 0.00 MWD+IFR+MS
9483.91 20.00 286.79 6791.20 6715.00 5979853.70 577435.32 5832.11 0.00 0.00 LCU
9500.00 20.00 286.79 6806.32 6730.12 5979855.23 577430.04 5837.62 0.00 0.00 MWD+IFR+MS
9600.00 20.00 286.79 6900.29 6824.09 5979864.75 577397.19 5871.82 0.00 0.00 MWD+IFR+MS
9643.54 20.00 286.79 6941.20 6865.00 5979868.89 577382.89 5886.71 0.00 0.00 KUPA
9700.00 20.00 286.79 6994.26 6918.06 5979874.26 577364.34 5906.02 0.00 0.00 MWD+IFR+MS
9723.35 20.00 286.79 7016.20 6940.00 5979876.48 577356.67 5914.01 0.00 0.00 TMLV
9800.00 20.00 286.79 7088.23 7012.03 5979883.78 577331.49 5940.22 0.00 0.00 MWD+IFR+MS
Company: BP AmOco
Field: Prudhoe Bay
Site: .. PB L Pad
Well: Plant-112
Wêllpath: Plan L-112
Survey
MD.."",,·\
f?1
/".. .1
(:;?fs
Incl Azim
deg deg
20.00 286.79
TVD
ft
7157.15
)
BP
KW A Planning Report MAP
Sys TVD
ft
7080.95
MapN
ft
5979890.76
')
Date: . ...11/11/2002 Time: 13:55:54 Page: 5
Co-ordinate(NE) Reference: Well: PlanL~112,True North .
Vertical (TVD) Reference: . L~n6 76;2
Section (VS) Reference: . Well (0.00N;0.OOE;286.66Azi)
Survey Calculation Method: Minimum Curvature Db: Oracle
MapE
ft
577307.40
VS
ft
5965.31
DLS TFO Tool/Comment
deg/10OO deg
0.00 0.00 MWD+IFR+MS
TREE = 4-1/16" crw
~ELLHEJ\D = FMC
A'ëTDÃ~fõR,;;,,-,,",^w"^""W,w"'ÑÃ
w._"",',·,'.w,",',y,",·,'.',','."",,.,.,., """,'"','"".,,",'."".',',,,,".
KB. ELEV = 82.2'
'BF:'ECBï';"^W~,,^w'-'~'-"'^"^ÑÃ
KOP = 300'
'~~~~-~~!~""~~~~~~~~~~~~~
Datum MD =
'6ãiu'ñ1'iVÖ';'" ·"··'··8aÒQìSs
)
9-5/8" CSG, 40#, L-80, ID = 8.835" 1-1 2977' ~
Minimum ID = 2.813" @ xxxx'
3-1/2" HES X NIPPLE (3 total)
(top joint)4-1/2" TBG, 12.6#, L-80, TCII, .0087 bpf, ID = 2.992"
3-1/2" TBG, 9.2#, L-80, TCII, .0087 bpf, ID = 2.992"
13-1/2" TBG, 9.2#, L-80, TCII, .0087 bpf, ID = 2.992"11 9167'
ÆRFORA TION SUMMARY
REF LOG: TCP ÆRF
ANGLEATTOPÆRF: xx @ xxxx'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
I PBTD 1-1
I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 1-1
9504'
9584'
L-112
-
-
I I
:8:
~t
I'
)
=---1 1011' 1-1 9-5/8" TAM PORT COLLAR I
I 2200' 1-1 3-1/2" HES X NIP, ID = 2.813" 1
~ GAS LIFT MANDRELS
ST MD lVD DEV TYPE VLV LATCH PORT I DATE
1 tbd KBG DCK-3 BTM 3.5x 1.0
2 5300 KBG Dummy BTM 3.5x 1.0
3 4500 KBG Dummy BTM 3.5x1.0
4 3500 KBG Dummy BTM 3.5x1.0
L
I I
I
/
~
~
~
DA TE REV BY COMMENTS
11/15/02 jdf PROPOSED COMA...ETION
DA TE REV BY
COMMENTS
9067'
1-13-1/2" BKR CMD SLIDING SL V, ID = 2.813"
9087'
~I 7" X 3-1/2" BKR PREMIER PKR, ID =
I 2.992"
9107' 1-1 3-1/2" HES X NIP, ID = 2.813" I
9137' 1-1 3-1/2" HES X NIP, ID = 2.813"
9167' 1-1 3-1/2" WLEG, ID = 2.875" 1
9207'
I~ Radioactive Pip Tag 2jt
I above TKUP
11
9444'
Radioactive Pip Tag @
TKUPC1
GPB BOREALIS
WELL: L-112
PERMrr No:
API No:
SEC 34, T12N, R11E 2755' NSL & 3874' We..
BP Exploration (Alaska)
')
')
L-112 Well
Summary of Drilling Hazards
POST THIS NOTICE IN THE DOGHOUSE
Surface Hole Section:
· Gas hydrates have been observed in offset wells. These are expected to be encountered near
the base of the Permafrost and near the TD hole section as well. In addition, there is some
recent data from the V-1 07 well that indicates surface hole free gas in the SV3 sands. The
only surface hole log done on L-pad, however, showed no signs of surface hole free gas. The
closest offset L-114 did show a gas reading of 723 units while drilling the hydrate zone.
· Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is
being circulated out. Ensure adequate mud viscosity and yield point is maintained to avoid
stuck pipe situations.
Production Hole Section:
· The production section will be drilled with a recommended mud weight of 10.2 ppg to ensure
adequate overbalance in the Kuparuk formation and shale stability in the HRZ shale.
· Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this
pad. The short trips in the production hole has proved problematic if hole cleaning practices
are not in place. Back reaming at connections and monitoring excessive annular ECD via the
PWD will contribute to favorable hole conditions.
· FAULTS: The well trajectory is expected to intersect 2 faults - one in the surface hole, and
one in the Schrader Bluff. Losses are unexpected, but if losses are encountered, consult the
Lost Circulation Decision Tree for recommended LCM treatments.
· KICK TOLERANCE: With 9.9 ppg pore pressure at the Kuparuk target depth, gauge hole, a
fracture gradient of 12.4 ppg at the surface casing shoe, and 10.2 ppg mud in the hole, the
kick tolerance is 25 bbls.
· L-Pad development wells have "kick tolerances" in the 25-50 bbl range. At least 100' prior to
entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to
ensure that a heightened awareness of kick detection will be in place while drilling/tripping
through the intermediate/production intervals.
HYDROGEN SULFIDE - H2S /'
. This drill-site not designated as an H2S drill site. As a precaution Standard Operating
Procedures for H2S precautions should be followed at all times.
CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION
Version 1.0
Rigsite Hazards and Contingencies
Page 1 of 1
'>
,\tA_I. bp
""""...~"'I'''~.....-
~~- --:.....--
....~ F.....
·'I'·"I\~
".
)
To:
Winton Aubert, AOGCC
Date: November,6 2002
From: J ames Pranks
Subject: Dispensation for 20 AAC 25.035 (c) on L-112
BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter
system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling
and Completion: Blowout Prevention Equipment and Diverter Requirements".
Experience and data gathered, summarized herein, support the rationale for the request.
To date, none of the Borealis/Kuparuk wells at L-pad, nor the two NWE wells 1-01 and
1-02 drilled in 1998 experienced pressure control or shallow gas problems above the
surface casing depth, apart from minor and inconsequential hydrate shows. All of the
Borealis L-pad Development wells were drilled to the shale underlying the SV 1 sands.
The shale underlying the SVl is the deepest planned surface casing setting depth for
future pad development wells. This casing point is ±200' TVD above the U gnu horizon.
RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg
EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-112 is planned to
reach a 9.5 ppg mud weight before TD at ....2,600' TVDss.
This request is being made based on L-Pad data submitted regarding mud weight, surface
open hole logging in the Borealis development (PEX/Dipole sonic), and a meeting
between Jack Hartz, Robert Crandall, Steve Davies, Bob Dawson (BP), Ray Eastwood
(BP) and Kip Cerveny (BP).
Your consideration of the waiver is appreciated.
RECE\VED
GEC G 2. 2002
~ 01\ & Gas Cons. comm\ss\O\"l
~'as a I.\.11c\1oraCæ
H 207133
DATE
INVOICE I CREDIT MEMO
9/20/02 INV# CK091602A
L-I12_
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE.
BP EXPLORATION, (ALASKA) INC.
P.O. BOX 196612
ANCHORAGE, ALASKA 99519-6612
PAY
TO THE
ORDER
OF
DESCRIPTION
VENDOR
DISCOUNT
GROSS
PERMIT TO DRILL FEE
TOTAL ~
RECE -V ED
DEC 0 2 2002
Alaska Oil & Gas Cons. Commission
Ancllo'ags
FIRST NATIONAL BANK OF ASHLAND
AN AFFIUATE OF
NATIONAL CITY BANK
CLEVELAND. OHIO
56-389
412
B P r;" ~ ..,... ,11ilt ~JJfItI . ''''I .... II
"," f· ,. ,I t ) t,t ':,..1' I; .:
. .~.. ~ .:J..l.. '11I' 'HI" 'U"H ~III" ",..
DATE
SEPT. 20, 2002
ALASKA OIL & GAS CONSERVATION
333 W. 7th AVE. STE 100
ANCHORAGE, AK99501
DATE
9/20/02
CHECK NO.
H207133
NET
No. H 207133
CONSOLIDATED COMMERCIAL ACCOUNT
AMOUNT
****$100.00****
~~~~~.~.:::~r:$.~}~~:~~.}~~:~~;·\:.:.~~~~~)
...... ·'.::A~~ ,....".... -..... ...... ...... ·····1
+>~i'"~~~:~;:.:.:':::~·d
r:::?::·";:··:::·::~.· .:::::.:~~::~~::.~ ::" :':::~'-"::::": ..::~ ::··::<:~~L.)
II- 2 0 7 ~ j j II- I: 0 L. ~ 2 0 j 8 r:¡ 5 I: 0 0 8 ~ L. ~ r:¡ II-
H
-'
-.
I .
)
)
TRANSMIT AL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME
PTD#
CHECK WHAT
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
(If API number
last two (2) digits
are between 60-69)
PILOT
(PH)
"CLUE"
The permit is for a new wellbore segment of
existing well
Permit No, API No.
Production should continue to be· reported as
a function of the original, API number stated
above.
HOLE In accordance with 20 AAC 25.005(f), all
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
EXCEPTION
DRY DITCH
SAMPLE
Rev: 07/10/02
C\jody\templates
The permit is approved subject to full
compliance with 20 AAC 25.055. Approval to
perforate and produce is contingent upon
issuance of a conservation order approving a
spacing exception.
(Companv Name) assumes the liability of any
protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the
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.
WELL PERMIT CHECKLIST COMPANY ßfJ X WELL NAME I',&q t. -11::2-. PROGRAM: Exp _ Dev)( Redrll _ Re-Enter _ Serv _ Wellbore seg _
FIELD & POOL r.;; <';r' ó / ~~ INIT CLASS tJ e,¿/ /... o~ ¡ GEOL AREA Ç' 7'", UNIT# /) h ~ rl ON/OFF SHORE ~
ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ry, N
2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N
3. Unique well name and number. . . . . . . . . . . . . . . . . Y N
4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . Y N
5. Well located proper distance from drilling unit boundary. Y N
6. Well located proper distance from other wells.. . . . . . . . . Y N"1 ¡. II r L J / ¡. ?
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N K 117~ /~P..41 d š-rJt~~:r 0 ~ 4~~-r rp.--$ c; ¿/
ß?/ ~-..l. ) 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y A 11 · / I (' tJ JJ
~ /~".2.. 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y ~ ~""...v fl!i.- þ'~' """",, "//"""C- rt:f r;-$ I~ lit, s;.- ~
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y ~ r.J/ ,J J / ) I/'/1 J) ~ /. /
11. Permit can be issued without conservation order. . . . . . . . Y N c:. ......,1' 1;-- ßrp~..J.J~{'I¡Þ':r ¡....9? .~ / - /'. r ~"'/I /~..Co~
12. Permit can be issued without administrative approval.. . . . . 't) /I /J ~/I / / í' / / I / A I / / / A J //1 A
(Service Wel1 Only) 13. Well located w/in area & strata authorized by injection order#~~ ~'-fl(?- v ("'"r-;..~'-- h-V-<., /41 d<1'~' ,,5'ftd"'~ ,,~"' _M'JIJ~Y..P"/
(Service Wel1 Only) 14. All wel1s wlin ~ mile area of review identified. . . . . . . . .. . N .¡ ð i V /I /1 ~) /
ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . fæN~ ~ /' -f/ /y./~~ ~/Jth(L~~';UÎ <7"'(."'7 ~~~~ J
16. Surface casing protects al1 known USDWs. . . . . . . N / 'l /, I / / ð, // j¡ I ~ 1
17. CMTvol adequate to circulate on conductor & surfcsg. . ~ ~/..Jpd~d I".ld;¡Lf-J:r ~ ~(Jr ~~'f?tJ'o'^)_ d/,ø~-//Z.J .4P~J:-1'"
18. CMT vol adequate to tie-in long string to surf csg. . I/J.I / ¿/ J "
19. CMT will cover al1 known productive horizons. . . . . . . . N·<"..t~ 7~ ~4-''¿ / _~ -/~ 7"rj ð-1Jv .......-t"-!Jt<t/ ..Jë:-S- "..~¿'r~~ e s:
20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N r . J 0 J r .// ~ - ß/1)C
21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . - N1<'1r ~Sf¡~7¿"/ ~f4.<'- ~.i p.7'¿.. j.6c"'-'t~ 7~/"1 ~ 1\ f~ _
22. If a re-drill, has a 10-403 for abandonment been approved. . . -Y N V
23. Adequate wellbore separation proposed.. . . . . . . . . . . . N J
24 If d· rt . d d ·t t I t· N Wttl\i"...-- V Me_a,
. Ive er reqUire , oes I mee regu a Ions. . . . . . . . . . 111/1 I
25, Drilling fluid program schematic & equip list adequate. . . . . NN IJ1IXA/ rr {~ , tJ ,'~L P Pq .
26. BOPEs, do they meet regulation. . . . . . ~ f . . . . . . . .
APPR DATE 27. BOPE press rating appropriate; test to Lf So 0 P sig. N (U c) f) "Z (l..l P , l .
l.A I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N
\J~ Ill-/- 0 z.- 29. Work will occur without Operation shutdown. . . . . . . . . . . N
30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . -&.
31. Mechanical condition of wells within AOR verified. . . . . . . . --¥--N-Ai/ It-
@f\(
M JLJ, 11,
APPR
DATE
(Service Well Only)
GEOLOGY
APPR DATE
/,p/ /.d~ <..
~ (Exploratory Only)
Rev: 10/15/02
(
32.
33.
34.
35.
36.
(
Permit can be issued wlo hydrogen sulfide measures. . . . .
Data presented on potential overpressure zones. . . . . . . .
Seismic analysis of shallow gas zones. . . . . . . . . . . . .
Seabed condition survey (if off-shore). .. . . .. ......
Contact namelphone for weekly progress reports. ......
GEOLOGY:
RP&
RESERVOIR ENGINEERING
JDH
COMMISSIONER:
COT J :.pIt¡ /ð .;)..
DTS 1(/6/°,<-
MLB f~/c./o ¿"
Comments/Instructions:
UIC ENGINEER
JBR
PETROLEUM ENGINEERING:
TEM
SFD_
/..
MJW
WGA
G:\geology\perm its\checklist.doc
)
)
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Pennitting Process
but is part of the history file. .
To inlprove the readability of the Well History file and to
simplify finding information. information of this
nature is accumulatèd at the end of the file under APPENDIX.
No special'effort has been made to chronologically
organize this category of information.
)
')
1-112. txt.
$Revision: 3 $
Li8L1b $Revision: 4 $
Wed Jun 02 12:29:10 2004
f /)f¡3
Sperry-Sun Drilling Services
LIS Scan Utility
Reel Header
Service name.... ...... ...LISTPE
Date......... ............04/06/02
Origin. . .. . . . . . . . . . . . . . . . STS
Reel Name................ UNKNOWN
Continuation Number... ...01
Previous Reel Nam.e....... UNKNOWN
Commen·ts. . . . . . . . . . . . . . . . . STS LIS Wr.i.t:i..ng Li.brary.
213). -).1-<1
Scientifi.c Technical Services
Tape Header
Service name.............LISTPE
Date.....................04/06/02
Origin. . . .. .. .. . . . . .. . . . . 81'S
Tape Name............... . UNKNOWN
Continuation NuI!ibe.r...... 01
P.cevious Tape Name....... UNKNOWN
Comments.................STS LIS Writing Library. Scientific Technical Services
Physical Eor
Comment Record
TAPE HEADER
GoreaU.s
MWD/MAD LOGS
if
WELL NAME:
¡\PI NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
#
cJOB DATA
L-112
500292312900
BF Exploration, Alaska
Sperry Sun
02-JUN-04
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 1
MW2220900000
C.A. DEMOSKI
A. MADSEN
MWD RUN 2
MW2220900000
C.A. DEMOSKI
A. MADSEN
MWD RUN 3
MW2220900000
C.A. DEMOSKI
A.. MADSEN
if
SURFACE LOCATION
SECTION:
TOWNSHI P:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
34
12N
11E
2525
1406
.00
82.50
34.34
if
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
OPEN HOLE
BIT SIZE (IN)
12.250
8.750
8.750
CASING
SIZE (IN)
16.000
9.625
9.625
DRILLERS
DEPTH (FT)
110.0
3109.0
3109.0
FŒMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
'-'
ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD).
Page 1.
)
)
1-112. t.xt
3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR),
ELECTRO-
MAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4),
COMPENSATED NEUTRON
POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD).
4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DGR, EWR4,
COMPENSATED
THERMAL NEUTRON POROSITY (CTN), SLD, AND BIMODAL
ACOUSTIC TOOL
(BAT) .
5. THERMAL NEUTRON DATA FROM MWD RUNS 2 AND 3 HAS BEEN
REPROCESSED
WITH REVISED ALGORI'rHM.8 '"['HAT YIELDS RESULTS THAT
VARY FROM FIELD
DATA.
6. MWD DIGITAL AND LOG DA'I'A ARE DEPTH SHIFTED TO THE
PDC WIRELINE GR
LOG OF 1/20/03 (BHCS). LOG HEAD.ER DJ.\TA AND REMARKS
RETAIN THE
ORIGINAL DRILLER'S DEPTH REFERENCE.
7. MWD RUNS 1-3 REPRESENT WELL 1,-112 WITH API#:
50-029-23129-00.
THIS WELL REACHED A TOTAL DEPTH (TO) OF 9461'MD,
6958'TVD.
SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING
SGRC SMOOTHED GAMMA EAY 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 FOEMATION EXPOSURE TIME (RESISTIVITY)
TNPS SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY -
SANDSTONE LITHOLOGY
CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE
(NEUTRON)
CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE
(NEUTRON)
SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW
COUNT-RATE BIN)
SC02 = SMOOTHED STANDOFF CORRECTION (LOW COUNT-RATE
BIN)
SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC
ABSORPTION FACTOR
(LOW COUNT-RATE BIN)
CALA = SMOOTHED SLD RAPID SAMPLE CALIPER
PARAMETERS USED IN POROSITY LOG CALCULATIONS:
HOLE SIZE: ACAL - VARIABLE 8.75 NOMINAL
MUD WEIGHT: 9.8 I?PG
MUD SALINITY: 450 PPM CHLORIDES
fORMATION WATER SALINITY: 10000-27000 PPM CHLORIDES
fLUID DENSITY: 1.0 G/GG
MATRIX DENSITY: 2.65 G/CC
LITHOLOGY: SANDSTONE
$
File Header
Service name.............STSLIB.OOl
Ser.vice Sub Level Name...
Version Number. ..... ... ..1.0.0
Page 2
)
Date of Generation.......04/06/02
Maximum Physical Record..65535
File Type................LO
Previous File Name.......STSLIB.OOO
Comment Record
FI LE HEADEE
FILE NUMBER:
EDITED MERGED MWD
Depth shi fted
DEPTH INCREMENT:
#
FILE SUMMAEY
PBU TOOL CODE
ROP
NPHI
rCNT
NCNT
RHOB
DRHO
PEF
RPX
RPS
RPM
RPD
FET
GR
CALA
DTC
$
)
1-112.txt
and clipped curves; all bit runs merged.
.5000
START DEPTH
103.5
673.5
673.5
673.5
687.5
687.5
687.5
719.5
719.5
719.5
719.5
719.5
728.0
2980.0
2995.5
STOP DEPTH
9643.0
9543.5
9544.0
9544.0
9559.5
9559.5
9559.5
9592.5
9592.5
9592.5
9592.5
9592.5
9600.0
9546.0
9517.5
#
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
--------- EQUIVALENT UNSHIFTED DEPTH ---------
B.ASELINE DEP'l'H
3079.0
3089.0
3102.5
3139.0
3167.0
3188.0
3190.5
3205.0
3253.0
3303.5
3320.0
3327 . 0
3331.0
3334.5
3347.5
3391.5
3400.5
3433.0
3446.0
3453.0
3456.0
3491. 0
3496.0
3514.5
3531.0
3535.0
3600.5
3673.5
3684.0
3693.5
3779.0
3818.0
3893.0
3922.5
3936.0
3944.5
3964.5
3962..5
GR
3083.5
3093.5
3105.0
3143.0
3171.0
3192.0
3194.5
3209.0
3257.5
3308.0
3323.0
3330.5
3334.5
3338.0
3351.0
3394.5
3404.0
3436.5
3449.5
3454.5
3458.5
3493.5
3497.5
3516.0
3532.5
3537.5
3603.0
3675.5
3686.0
3695.5
3781.0
3820.0
3895.5
3926.0
3940.0
3947.5
3967 . 5
3971. 5
P':¡'Je 3
)
)
1-112.tx.t
397.5.5 3978.5
3979.5 3982.0
3983.5 3986.0
3998.5 4001.5
4005.0 4008.0
4011. 0 4014.5
4065.0 4067.5
4077 . 5 4080.0
4080.5 4082.5
4090.5 4093.0
4133.5 4136.5
4274.0 4277.5
4293.5 4297 . 0
4326.5 4330.5
4380.0 4383.5
4400.5 4404.0
4444.0 444"7.5
4455.5 44.59.0
4460.5 4464.0
4487.5 4490.5
4494.0 4497 . 0
4542.5 4545.5
4557.0 4560.0
4582.0 4586.0
4686.0 4689.5
4721. 5 4724.5
4735.0 4738.0
4782.0 4784.5
4787.5 4790.0
4803.5 4805.0
4869.5 4871. 0
4873.0 4874.5
4879.0 4880.5
4914 . 0 4917.0
4924. .5 4927.5
4931. 5 4934.5
4939.5 4942.0
4943.0 4947.5
4953.0 4956.5
4958.5 4961. 5
4975.0 4978 . 0
4980.0 4983.5
4984.0 4987.5
5010.5 5014 . 0
5032.5 5036.0
5066.0 5069.5
5079.5 5083.0
5106.0 5109.5
5114.5 5116.5
5160.0 5162.5
5IT! . 5 5180.5
5239.5 5241.0
5288.0 5289.5
5334.5 5336.0
5392.0 5393.5
5409.0 5410.5
5422.5 5424.0
5431. 0 5434.0
5445.5 5449.0
5476.0 5478.5
5567.0 5569.5
5576.5 5579.5
5602.0 5605.0
5605.0 5608.0
5618.0 5621.0
5638.0 5641. 5
5683.5 5687.0
5718.0 5720.0
5725. .5 5727.5
5739.5 5741.5
5747.0 5749.0
5761. 5 5763.5
5766.5 5768.5
Paoe
5817.0
5833.0
5872.5
5880. ~)
5890.5
5896.5
5899.5
.5902.5
5921. 5
5932.5
5963.0
5984.5
5997.0
6003.0
6007.0
6025.5
6052.0
6085.5
6090.0
6100.5
6105.0
6107.5
6115.5
6124.5
6154.5
6159.5
6164.0
6165.5
6214.0
6253.0
6310.0
6348.5
6377.5
6397.0
6440.5
6462.5
6475.0
6493.5
6504.5
6584.5
6722.0
6750.0
6776.5
6793.0
7044.0
7128.0
7156.5
7169.0
7615.5
7637.0
7661..5
7702.0
7705.0
7712.0
7719.5
7750.0
7759.0
77 66.0
7812.5
7894.5
7915.0
7928.0
8001.0
8053.0
8105.5
8135.0
8145.5
8176.0
8190.0
8204.0
8212.0
8215.0
8221.0
5819.0
5834.0
5873.5
5883.0
5892.0
5898.0
5901. 0
5904.0
5923.5
5933.5
5962.5
.5984.5
5997.5
6002.5
6008.0
6026.5
6053.5
6087.0
6091. 5
6102.0
6105.5
6109.0
6117.0
6126.0
6156.5
6159.5
6166.0
6167.5
6215.5
6254.5
6311 . 0
6349.5
6379.0
6398.0
6442.0
6464.0
6476.5
6495.0
6506.0
6587.0
672 4.0
6751. 0
6777.5
6793.5
7044.5
7128.5
7157.5
7169.5
7615.5
7636.5
7661.:)
7702.0
7705.0
7712.0
7719.5
7750.0
7759.0
7766.0
7812.5
7894.0
7913.5
7928.5
8001.5
8053.0
8106.0
8135.5
8145.5
8176.0
8190.5
8205.0
8211.5
8215.0
8221.0
)
)
1-112. txt
Paqr2 ~)
)
)
1-112. txt
8223.5 8224.0
8237.0 8237.5
8251. 5 8252.0
8266.0 8266.~)
8318.5 8318.5
8323.0 8324.0
8336.5 8337.0
8344.5 8345.0
8351.5 8352.0
8377.0 8377.5
8390.5 8391. 0
8406.0 8406.5
8409.5 8410.0
8419.0 8419.0
8427.0 8427.0
8438.5 8438.5
8449.5 8449.5
8455.5 8455.5
8497 . 0 8497.0
8559.5 8559.0
B605.5 8605.0
8677.0 8676.5
8710.0 8707.5
8760.5 8758.0
8766.5 8764.0
8790.0 8788.5
8799.5 8797.5
8819.5 8817.5
8836.5 8834.5
8846.5 8844.0
8882.0 8880.0
8886.0 8883.5
8891. 0 8888.5
8897 . 0 8894.5
8902.5 8900.0
8911. 0 8908.5
8919.5 8917.0
8924.0 8920.5
8929.0 8926.5
8945.5 8943.0
8948.5 8946.0
89.58.5 8956.0
8963.5 8961. 0
8992.5 8990.0
8997.0 8994.5
9026.5 9024.0
9034.0 9031. 5
9048.5 9046.0
9068.5 9068.0
9071. 0 9072.0
9083.5 9083.5
9090.0 9089.5
9094.5 9094.5
9096.0 9095.5
9098.5 9097.5
9104.0 9103.5
9107 . 0 9106.5
9154.5 9154.0
9158.0 9158.0
9183.5 9183.0
9189.0 9188.5
9192.0 9192.0
9215.0 9215.0
9222.5 9222.5
9237.0 9237.0
9241.5 9240.5
9246.5 9245.5
9254.5 9253.~)
9:276.0 9275.5
9282.5 9281.0
9317.0 9315.5
9327.5 9325.5
9330.0 9328.0
Pag'2 6
)
)
1-112.txt
9331.5
9333.5
9337.5
9343.0
9347.5
9356.0
9376.0
9382.5
9385.0
9393.0
9407.0
9415.0
9445.0
9449.5
9455.5
9459.5
9463.0
9465.5
9472.5
9476.0
9480.0
9485.5
9490.0
9499.0
9511. 5
9518.0
9520.5
9527.5
9536. .5
9543.0
9551. 5
9575.0
9579.0
9589.5
9643.0
$
9329.5
9331.5
9335.5
9342.0
9345.5
9354.0
9375.0
9381.5
9384.0
9392.0
9406.0
9414.0
9444.0
9448.5
9454.5
9457.5
9461. 0
9463.5
9470.0
9474.0
9477.5
9483.0
9487.5
9496.0
9508.5
9515.0
9517.5
9526.0
9.535.0
9540.5
9549.0
9572.5
9575.5
9587.0
9641.0
#
MERGED DAT.A SOURCE
PBU TOOL CODE
MWD
MWD
MWD
$
BIT RUN NO
1
2
3
MERGE TOP
107.5
3125.0
3775.0
MERGE BASE
3125.0
3775.0
9641.0
#
REMARKS:
MERGED MAIN PASS.
$
#
Data Format Specification Record
Data Record Type.................. 0
Data Specification Block Type.....O
Logging Direction.................Down
Optical log depth units...........Feet
Data Reference Point..............Undefined
Frame Spacing.....................60 .1IN
Max frames per record.. ...........Undefined
Absent value.. .......... .... ......-999.25
Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block sub-type...O
Name Service Order Units Size Nsarn Rep Code Offset Channel
DEPT FT 4 1 68 0 1.
Rap MWD F'I'/I-! 4 1 68 4 2
GR MWD API 4 1 68 8 3
RPX MWD OHMM 4 1 68 12 4
RPS MWD OHMM 4 1 68 16 :)
RPM MWD OHMI'-1 4 1 68 20 6
RPD MWD OHMM 4 1 68 24 7
FET MWD HOUR 4 1 68 28 8
NPHI Mí.-JD PU-S 4 1 68 32 9
tCNT MWD CN'I'S 4 1 68 36 10
NCNT MWD CNTS 4 1. 68 40 11
RHOB MWD G/CM 4 1. 68 44 12
DR.EO ¡vlWD G/CM 4 1. 6B 48 13
!?aqe -ì
)
)
1-112. txt
PEF MWD B/E 4 1 68 52 14
DTC MWD USPF 4 1. 68 56 15
CALA MWD IN 4 1 68 60 16
First Last
Name Service Unit Min Max Mean Nsam Read:i.ng Readi.ng
DEPT FT 103.5 9643 4873.25 19080 103.5 9643
ROP MWD FT/H 0 11937.8 271. 678 19056 103.5 9643
GR MWD API 3.46 441.51 90.4174 17745 728 9600
RPX MWD OHMM 0.21 2000 11.3623 17700 719.5 9592.5
RPS MWD OHMM 0.26 2000 14.0579 17'700 719.5 9592.5
RPM MWD OHMM 0.11 2000 20.7213 17700 719.5 9592.5
RPD MWD OHMM 0.35 2000 22.8761 17700 719.5 9592.5
FET MWD HOUR 0.05 55.22 0.856589 17700 719.5 9592.5
NPHI MWD PU-S 9.52 96.46 36.5126 17613 673.5 9543.5
rCNT MWD CNTS 475 2639 894.882 17'742 673.5 9544
NCNT MWD CNTS 2040 187133 105536 17742 673.5 9544
RHOS MWD G/CM 1. 065 3.149 2.22002 17618 687.5 9559.5
DRHO MWD G/CM -0.231 0.452 0.050253 17618 687.5 9559.5
PEF MWD B/E 0.16 11. 42 2.42427 17635 687.5 9559.5
DTC MWD USPF 50 171 115.923 13045 2995.5 9517.5
CALA MWD IN 8.25 20.84 9.23078 12817 2980 9546
First Reading For Entire File..........103.5
Last Reading For Entire File...........9643
File Trailer
Service name.............STSLIB.OOl
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation.......04/06/02
Maximum Physical Record..65535
File Type............... .10
Next File Name.. ... ......STS1IB.002
Physical Eor
File Header
Service name.............STSLIS.002
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generation.......04/06/02
Maximum Physical Record..65535
F'i le Type................ LO
Previous File Name.......STSLIB.OOl
Comment Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
.II
FILE SUMMARY
VENDOR TOOL CODE
ROP
NPHI
F'CNT
NCNT
PEF
RHOS
DR!-IO
RPM
RPS
RPD
1:'£1'
2
header data for each bit run in separate files.
1
.5000
START DEPTH
107.5
683.5
683.5
683.5
693.0
693.0
693.0
724.0
724.0
724.0
724.0
STOP DEPTH
3125.0
3033.5
3033.5
3033.5
3043.5
3043.5
3043.5
3075.5
3075.5
3075.5
3075.5
Paqe 8
)
RPX
GR
$
724.0
732.5
3075.5
3083.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME) :
'I'D DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG IN'I'ERVA.L (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
if
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
SLD
CTN
$
BOTTOM)
TOOL TYPE
DUAL GAMMJ.\ Rl\Y
ELECTROMA.G. RESIS. 4
STABILIZED LITHO DEN
COMP THERMAL NEUTRON
if
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
11
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT 'TEMPERl\TURE (DEGF)
MUD AT MEASURED TEMPERATURE (M'I'):
MUD A'rMAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
#
NEUTFì.ON TOOL
MATFì.IX:
MATRIX DENSITY:
HOLE CORFì.ECTION (IN):
H
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
#
Data Format Specification Record
Data Record Type..... .............0
Data Specification Block Type.....O
Logging Direction.................Down
Optical log depth units...........Feet
Data Reference Point..............Undefined
Frame Spacing... ... ...... ........ .60 .lIN
Max frames per record.. ...........Undefined
Absent value..................... .-999.25
Depth Units.......................
Datum Specification Block sub-type...O
1-112. txt
02-JAN-03
Insite
6.02
Memory
3125.0
110.0
3125.0
.0
55.9
TOOL NUMBER
136692
103792
133314
181190
12.250
1l0.0
SPUD
9.70
120.0
9.5
450
8.0
63.000
1. 360
4. 000
3.200
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1.
ROP Mí~D01 0 FT/H 4 1 68 4
GR !'1WD010 API 4 1 62, 8 3
RPX Mt"JDOlO OHMM 4 1 68 12 4
EPS MWDOlO OHMM 4 1 68 16 5
RP¡V¡ ¡V¡í~D010 OHMM 4 1 68 20 6
Page 9
)
1.6
80.6
63.0
63.0
)
)
1-112. txt
RPD MWD010 OHMM. 4 1 6£3 24 7
FET MWD010 HOUR 4 1. 68 28 8
NPHI MWDOIO PU-S 4 1 68 32 9
FCNT MWD01.0 CNTS 4 1. 68 36 10
NCNT MWD010 CNTS 4 1 68 40 11
RHOB MWD010 G/CM 4 1 68 44 12
DRHO MWD010 G/CM 4 1 68 48 13
PEF MWD010 B/E 4 1 68 52 14
First Last
Name Service Unit Min Max Mean Nsam Read.ing Reading
DEPT FT 107.5 3125 1616.25 6036 107.5 3125
ROP MWD010 FT/H 8.14 1274.84 211. 451 6036 107.5 3125
GR MWD010 API 20.2 124.09 72.0649 4702 732.5 3083
RPX .MWD010 OHMM 0.21 206.27 24.9277 4704 724 3075.5
RPS MWD010 OHMM 0.26 1668.41 35.068 4704 724 3075.5
r\PM MWD010 OHMM 0.25 2000 54.0419 4704 724 3075.5
RPD MWD010 OHMM 0.5 2000 57.3774 4704 724 3075.5
FErr MWDOIO 1:-IOUR 0.09 6.79 0.563225 4704 724 3075.5
NPHI MWD010 PU-S 12.83 72. 9 9 44.0'78 4701 683.5 3033.5
FCNT MWD010 CNTS 475 751 612.739 4701. 683.5 3033.5
NCNT MWD010 CNTS 2040 2920 2386.62 4701 683.5 3033.5
RHOB MWD010 G/CM 1.065 2.395 2.04426 4702 693 3043.5
DRHO MWD010 G/CM -0.231 0.452 0.03651304 4702 693 3043.5
PEF MWD010 B/E 0.16 3.62 2.09796 4702 693 3043.5
First Reading For Entire Fi1e..........107.5
Last Reading For Entire File.... .......3125
FJ1e Tr·a.tler
Service name.............STSLIB.002
Service Sub Level Name...
Version Number.... . . . . . . .1. 0.0
Date of Generation..... ..04/06/02
Maximum Physical Record..65535
File Type............... .LO
Next File Name.... .......STSLIB.003
Physical EOF
FHe Header
Service name. .... .... ... .STSLIB.003
Service Sub Level Name...
Version Number... ....... .1.0.0
Date of Generation.. .....04/06/02
Maximum Physical Record..65535
Fi 1 e Type................ LO
Previous File Name..... ..STSLIB.002
Comment Record
FILE HEADE.R
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DePTH INCREMeNT:
#
FILe SUMMARY
VENDOR TOOL CODE
DTC
RPX
RPS
RPM
RPD
E'ET
GR
!:~CNT
3
header data for each bit run in separate files.
2
.5000
START DE PTH
3000.0
3020.0
3020.0
3020.0
3020.0
3020.0
3027.0
3034.0
STOP DEPTH
3651.0
3726.0
3ï2 6.0
3726.0
3726.0
3726.0
3732.5
3676.5
Page 10
')
NCNT
PE E'
NPHI
CALl~
DRHO
RHOB
ROP
$
3034.0
3099.0
3099.0
3104.0
3107.5
3107.5
3125.5
3676.5
3690.0
3676.5
3678.5
3690.0
3690.0
3775.0
#
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DA'1'A TYPE (MEMORY OR REAL-TIME):
'I'D DRILLER (FT):
TOP LOG INTERVAL (FT):
130T'rOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
#
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
CTN
SLD
BAT
$
BOTTOM)
TOOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
COMP THERMA.L NEU~[,RON
STABILIZED LITHO DEN
Bi-modal Accostic
#
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (E~):
#
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (1B/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (I?PM):
FLUID LOSS (C3):
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERA.TURE (M'I'):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MU 0 CAKE 1\''1' MT:
#
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
#
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
#
REMARKS:
$
/I
Data Format Specification Record
Data Record Type..................O
Data Specification Block Type.....O
Logging Direction................ . Down
Optical log depth units.... .... ...Feet
Data Reference Point..............Undef ned
Frame Spacing... ..................60 .1 N
Max frames per record.............Undef ned
l\bsent value.................... _ .-999. 5
Depth Units.......................
Datum Specification Block sub-type...O
1-112. txt
05-JAN-03
Insite
6.02
Memory
3775.0
3125.0
3T15.0
55.7
57.5
TOOL NUMBER
101523
101523
101523
101523
101523
8.750
3109.0
I,SND
9.70
45.0
9.1
450
9.0
69.000
2.080
2.700
2.200
Name Service Order Units Size Nsam Rep Code Offset Chan~e~
PaGe 11
)
2.8
95.0
69.0
69.0
)
)
l-llL~.txt.
DEPT FT' 4 1 68 0 1.
ROP MWD020 FT/I'! 4 1 68 4 2
GR MWD020 API 4 1. 68 8 3
RPX MWD020 OHMM 4 1. 68 12 4
RPS MWD020 OHMM 4 1. 68 16 5
RPM MWD020 OHMM 4 1 68 20 6
RPD MWD020 OHMM 4 1. 68 24 7
FE'r MWD020 HOUR 4 1. 68 28 8
NPHI MWD020 PU-S 4 1 68 32 9
FCNT MWD020 CNTS 4 1. 68 36 10
NCNT MWD020 CNTS 4 1. 68 40 11
RHOB MWD020 G/CM 4 1. 68 44 12
DI~HO MWD020 G/CM 4 1. 68 48 13
PEF MWD020 B/E 4 1 68 52 14
mc MWD020 USPF 4 1 68 56 15
CALA MWD020 IN 4 1 68 60 16
Fi n,t Last.
Name Service Uni.t. Min Max Meêln N.sam Reading Reading
DEPT FT 3000 3775 3387.5 1551 3000 3775
ROP MWD020 FT/H 0 11902.8 368.158 1300 3125.5 3775
GR MWD020 1\P1 6.97 116.79 63.6758 1301 3027 3732.5
RPX MWD020 OHMM 3.49 15::J.9b 14.833 1256 3020 3726
RPS MWD020 OHMM 3. ::)9 412.97 15.2568 1256 3020 3726
RPM MWD020 OHMM O.:U 2000 40.6682 1256 3020 3726
RPD MWD020 OHMM 4.49 2000 43.1073 1256 3020 3726
FE'T' MWD020 HOUR 0.08 55.22 2.8181 1256 3020 3726
NPHI MWD020 PU-8 11. 97 96.46 42.1007 1156 3099 3676.5
FCNT MWD020 CNTS 483 1051 805.079 1286 3034 3676.5
NCNT MWD020 CNTS 114167 .1.52197 134183 1286 3034 3676.5
RHOS MWD020 G/CM 1.232 2.487 2.13992 1166 3107.5 3690
DR I-I 0 MWD020 G/CM -0.107 0.302 0.0550472 1166 3107.5 3690
PEF MWD020 B/E 0.71 11.42 3.37172 1183 3099 3690
DTC MWD020 USPF 50 171 129.431 1303 3000 3651
CALA MWD020 IN 8.2b 20.84 9.4067'7 1150 3104 3678.5
First Reading For Entire File..........3000
Last Reading For Entire File...........3775
File Trailer
Service name...... .......STSLIB.003
Service Sub Level Name...
Version Number.......... .1.0.0
Date of Generat.ion. ... ...04/06/02
Maximum Physical Record..65535
t~ile 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.......04/06/02
Maximum Physical Record..65535
File Type............... .100
Previous File Name.......STSLI8.003
Corrunent Record
FILE HEADER
FILE NUMBER:
RAW MWD
Curves and log
BIT RUN NUMBER:
DEPTH INCREMENT:
#
header data for each bit run in separate files.
3
.5000
Page 1'::
FILE SUMMAEY
VENDOE TOOL CODE
DTC
NCNT
FCNT
NPHI
CALA
RHOB
DRHO
PEF
RPX
RPS
RPM
RPD
FET
GR
ROP
$
START DEPTH
3651.0
3678.5
3679.0
3679.5
3680.5
3691. 5
3691.5
3691.5
3726.5
3726.5
3726.5
3726.5
3726.5
3734.5
3777.0
#
LOG HEADER DATA
DATE LOGCiE:D:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWA.RE VERSION:
DATA TYPE (MEMORY OR REAL-'I'1ME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG IN'I'ERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
')
STOP DEPTH
9515.0
9540.5
9540.5
9540.0
9543.5
9554.0
9554.0
9554.0
9590.0
9590.0
9590.0
9590.0
9590.0
9597.5
9641.0
TOOL STRING (TOP TO
VENDOR TOOL CODE
DGR
EWR4
CTN
SLD
BAT
$
BOTTOM)
'1'OOL TYPE
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
COMP THERM1\L NEUTRON
STABILIZED LITHO DEN
Bi-modal Accostic
j¡
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 MA.,'{ CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
j~
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
RSM_1\RKS:
$
Data Format Specification Record
Data Record Type.................. 0
Data Specification Block Type.....O
)
1-112.txt
08-JAN-03
Insite
6.02
Memory
9641. 0
3775.0
9641. 0
19.4
58.7
TOOL NUMBER
143790
143790
143790
143790
143790
8.750
3109.0
LSND
9.80
43.0
9.3
450
4.5
100.000
.670
1. 800
1. 000
1.0
152.6
68.0
68.0
['age 13
)
)
1-11.2.txt
Logging Direction......... ........DOWTI
Optical log depth units...........Feet
Data Reference Point..............Undefined
Frame Spacing.....................60 .lIN
Max frames per record.............Undefined
Absent value...................... -999.25
Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . .
Datum Specification Block I:mb-type... 0
Name Service Order Units Size Nsam Rep Code Offset Channel
DE P'I' FT 4 1 68 0 1
ROP MWD030 F'T/H 4 1 68 4 2
GR MWD030 API 4 1 68 8 3
RPX MWD030 OHMM 4 1 68 12 4
RPS MWD030 OHMM 4 1 68 16 5
RPM MWD030 OHMM 4 1 68 20 6
RPD MWD030 Ol-IMM 4 J 68 24 7
FET MWD030 HOUR 4 :1 68 28 8
NPHI MWD030 PU-S 4 1 68 32 9
FCNT MWD030 CNTS 4 1 68 36 10
NCNT MWD030 CNTS 4 1 68 40 11
RHOB MWD030 G/CM 4 1. 68 44 12
DRHO MWD030 G/CM 4 1 68 48 13
PEF MWD030 B/E 4 1 68 52 14
DTC MWD030 USPF 4 1 68 56 15
CALA MWD030 IN 4 1. 68 60 16
First Last.
Name Service Unit Min Max Mean Nsam Reading Reading
DEFT FT 3651 9641 6646 11981 3651 9641
ROP MWD030 FT/H 0 11937.8 292.069 11 7 05 3777 9641
GR MWD030 A.PI 3.46 441. 51 100.738 11727 3734.5 9597.5
RPX MWD030 OHMM 0.39 2000 5.41354 11728 3726.5 9.590
RFS MWD030 OHMM 0.3l:¡ 2000 5.36372 11728 3726.5 9590
RPM MWD030 OHMM 0.32 88.17 4.91339 11728 3726.5 9590
RPD M.WD030 OHMM 0.35 2000 6.4330.1 11728 3726.5 9590
FET MWD030 HOUR 0.05 13.52 0.756919 11728 3726.5 9590
NPHI MWD030 pu-s 9.52 87.42 32.888 11722 3679.5 9540
FCNT MWD030 CN'l' S 494 2639 1017.91 11724 3679 9540.5
NCNT MWD030 CNTS 114486 187133 143675 11725 3678.5 9540.5
RHOB MIfI1D030 G/CM 1.245 3.149 2.29862 11.726 3691.5 9554
DRHO MWD030 G/CM -0.148 0.444 0.0551556 11726 3691. 5 9554
PEF MWD030 B/E 0.85 8.53 2.46058 11726 3691. 5 9554
DTC MWD030 USPF 57 162 114.423 11729 3651 9515
CALA MWD030 IN fL66 11.59 9.213TI 11654 3680.5 9.543.5
First Reading For Entire File..........3651
Last Reading For Entire File...........9641
File Trailer
Service name.............STSLIB.004
Service Sub Level Name...
Version Number........... 1. 0.0
Date of Generation.......04/06/02
Maximum Physical Record..65535
File Type................ LO
Next File Name.......... .STSLIB.005
Physical EOF
Tape Trailer
Service name.............LISTPE
Da t '2. . . . . . . . . . . . . . . . . . . . . iJ 4/06/0:::
Origin.. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. STS
Tape Name. .... ...........UNKNOWN
Continuation Number......Ol
Next Tape Name...........UNKNOWN
Page 14
')
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l-112.t.xt:
Comments................ .S'1'S LIS Wri.U.ng Library. Scientific Technical Services
Reel Trailer
Service namB..... ........LISTPE
Date.....................04/06/02
Origin. . . . . . . . . . . . . . . . . . . S'1'S
Reel Name.. ..............UNKNOWN
Continuation Number......Ol
Next Reel Name... ... .....UNKNOWN
Comments......... ........S'1'S LIS Writing Library. Scientific Technical Services
Physical Eor
PhYi.,ical Eot~
End Of LIS File
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