Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
Loading...
HomeMy WebLinkAbout193-112MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg I`; ��1" DATE: 5/16/20
P. I. Supervisor
FROM: Bob Noble SUBJECT: Surface Abandonment
Inspector PBU P-23
BPXA
PTD 1931120; Sundry 319-202
5/16/2020: 1 traveled to BPXA's PBU P -pad and met with BPXA rep John Perl. We
talked about what they had done to get cement to surface in P-23. He told me cement
was 3.5 ft down in the tubing and 7 inches down in the IA. They had topped it off early
on 5/15/2020.
I inspected the cut off which is cut off at 3 ft 8 inches below tundra grade. The marker
plate was found to have the proper API and PTD numbers, well name and oil company
name. The plate was placed over the cut off well and is the proper size. The thickness
of the plate is 3/8 inch. I told them it was ok to weld it on and fill in the excavation. I also
told John to leave a mound over the well.
Attachments: Photos (2)
2020-0516—Surface—Abandon PBU—P-23 bn.docx
Page 1 of 2
' �4S 3'G•
y
3 •„ 'Y
Af4`
v/
R
1a. Well Status:
GINJ
Oil 1b. Well Class:
Exploratory
Service 5
BP Exploration (Alaska), Inc
14. Permit to Drill Number/Sundry
193-112
8/23/1993
9/16/1993
GL PRUDHOE BAY, PRUDHOE OIL
4a.
Surface:
Top of Productive Interval:
Total Depth:
2598' FNL, 2077' FWL, Sec. 31, T11N, R13E, UM
962' FNL, 4391' FWL, Sec. 32, T11N, R13E, UM
957' FNL, 4524' FWL, Sec. 32, T11N, R13E, UM
Surface: x- y- Zone -631358 5947411 ASP 4
11.
Gas SPLUG 5Abandoned
20AAC 25.105
Suspended
20AAC 25.110
WINJ WAG WDSPL No. of Completions:
5/17/2020
15.
50-029-22393-00-00
16.
PBU P-23
Well Name and Number:
Surface / Surface
53.90
17.
TPI:y- Zone -638640 ASP 4x-5949177
Total Depth: x-y-Zone -638773 ASP 45949185
12275' / 9230'
None
DNR Approval Number:19.
88-016
5. Directional or Inclination Survey:
Yes No
Submit electronic and printed information per 20 AAC 25.050 (ft MSL)
20.Thickness of Permafrost MD/TVD:
DIT / BHCS / GR / MWD
CASING WT. PER
FT.GRADE SETTING DEPTH MD
TOP BOTTOM
HOLE SIZE CEMENTING RECORD AMOUNT
PULLED
Location of Well (Governmental Section):
Field/Pool(s):
Date Comp., Susp., or Aband.:6.
Total Depth (MD/TVD):
CASING, LINER AND CEMENTING RECORD
TOP BOTTOM
22.
SETTING DEPTH TVD
7-5/8"
5-1/2"
91.5#
45.5#
29.7#
17#
NT-80
NT-95
L-80
Surface
Surface
11705'
11863'
12275'
Surface
Surface
8736'9230'
8868'
6-3/4"
9-7/8"
280 cf Arctic Set (Approx.)
1825 cu ft Class 'G'
140 cu ft Class 'G'
25.
GRADE PACKER SET (MD/TVD)
26.
4-1/2" 12.6# L-80 11710'
DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED
PRODUCTION TEST27.
Date First Production: Not on Injection N/A
Date of Test:
Flow Tubing
Press
Oil-Bbl:
Oil-Bbl:
Gas-MCF:Water-Bbl:
Oil Gravity - API (corr):
Method of Operation (Flowing, gas lift, etc.):
Gas-Oil Ratio:Choke Size:
Water-Bbl:
See Attached
Open to production or injection?Yes No 524.
If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
H-40 115'30"20"
10-3/4"Surface 3322'13-1/2"2016 cu ft CS III, 408 cu ft Class 'G'Surface 2860
11649' / 8691'
Gas-MCF:
Production for
Test Period
Calculated
24 Hour Rate
Hours Tested:
Casing Press:
115'
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
TUBING RECORD
DEPTH SET (MD)
Yes No 5Was hydraulic fracturing used during completion?
Per 20 AAC 25.283 (i)(2) attach electronic and printed
information
ADL 028288
319-202
Other
12. SSSV Depth (MD/TVD):
Ref Elevations
BF Surface
(attached)
KB
Form 10-407 Revised 3/2020
Sr Pet Eng Sr Pet Geo Sr Res Eng
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Development
Stratigraphic Test
2.Operator Name:
3.Address:
P.O. Box 196612 Anchorage, AK 99519-6612
7. Date Spudded:
8. Date TD Reached:
9.
10. Plug Back Depth(MD/TVD):
4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27):
87.10
Water Depth, if Offshore:13.
N/A
Zero
API Number:
Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,
suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper,
resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record.
Acronyms may be used. Attach a separate page if necessary
23.
18.Property Designation:
21.Re-drill/Lateral Top Window
MD/TVD:
N/A
1900' (Approx.)
5
Submit within 30 days of Completion, Suspension, or Abandonment
By Samantha Carlisle at 9:39 am, Jun 10, 2020
Abandonment Date
5/17/2020
HEW
RBDMS HEW 6/11/2020 xG
MGR29JUN20 SFD 6/11/2020 DSR-6/11/2020
If yes, list intervals and formations tested, briefly summarizing test results. Attach
separate sheets to this form, if needed, and submit detailed test information per 20
AAC 25.071.
Permafrost - Base
Formation at total depth:
Contact Name:Worthington, Aras J
Contact Email:Aras.Worthington@bp.com
Authorized Name:Lastufka, Joseph N
Authorized Title:SIM Specialist
Authorized Signature with Date:Contact Phone:+1 907 564 4102
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit
a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.
All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted.
Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is
a completion.
Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other.
Item 4b. TPI (Top of Producing Interval).
Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29.
Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of
completion, suspension, or abandonment, whichever occurs first.
Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool.
Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the
producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,
showing the data pertinent to such interval).
Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain).
Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and
analytical laboratory information required by 20 AAC 25.071.
Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical
laboratory information required by 20 AAC 25.071.
Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests
as required including, but not limited to: core analysis, paleontological report, production or well test results.
11866'
11891'
11988'
12202'
12259'
8870'
8892'
8976'
9165'
9216'
Sag River
Shublik
Sadlerochit - Zone 4
CGL - Zone 3
Base of CGL - Zone 2
Zone 2
28.CORE DATA
Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5
If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water
(submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071.
Well Tested? Yes
12259'9216'
Top of Productive Interval 11988'8976'
Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment
30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered):
NAME MD TVD
Permafrost - Top No 5
31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList of Attachments:
Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis,
paleontological report, production or well test results, per 20 AAC 25.070.
Joseph N Lastufka Digitally signed by Joseph N Lastufka
Date: 2020.06.10 09:30:08 -08'00'
WWEL L NAME:P-23
226.Ac i d , Fr ac t u r e, Cem en t Sq u eeze, Et c .
Depth Interval (MD) Amount & Kind of Material Used
10632' 23.5 Bbls Class 'G'
9404' - 9409' Tubing Punch
5232' 322 Bbls Class 'G'
3200' - 3210' Tubing / Casing Punch
Surface 195 Bbls Class 'G'
Surface ~5 Gal AS I Cement
ACTIVITYDATE SUMMARY
8/10/2019
T/I/O = SSV/760/180. Temp = SI. Purge C & B lines. Balance line @ 2200 psi.
Control line @ 280 psi. Bled balance line from 2200 psi to 0 psi in ~1 min, (gas).
Monitored for 20 min. Pressure increased to 380 psi. Pressured balance line to 4387
psi with ~ 0.5 gal of hydraulic fluid and started 15 min pressure test. Balance line lost
25 psi in 15 min. RU to control line. Pressured control line to 4500 psi. SD pump
and pressure would fall off to ~100 psi. Repeated 10 times with the same results.
Pumped 1.5 gal of hydraulic fluid. Final WHPs = SSV/760/180.
SV, WV, SSV, MV = C. IA, OA = OTG. 15:00
8/24/2019
T/I/O = SSV/760/180. Temp = SI. Cement C & B lines (Pre P & A). No AL or
flowline. Balance line passed a pressure test to 2800 psi (no injectivity). Established
injectivity down the control line @ 800 psi (~.25 gallons pumped, hydraulic oil).
Pumped 2 gallons of squeezecrete (D-163) down the control line (max injection
pressure reached). Purged control line needle valve with hydraulic oil before
departure. Tag hung. FWPs = SSV/760/180.
SV, WV, SSV, MV = C. IA, OA = OTG. 17:00
8/28/2019
T/I/O = 230/770/200. Temp = SI. PT control line PASSED to 2688 psi (P & A). No
flowline or AL. CLP = 270 psi. Pressured CLP with hydraulic fluid to ~2780 psi 2
times. CLP decreased 42 psi in 15 min on 2nd test. Bled CLP back to 200 psi.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00.
9/7/2019
***WELL S/I UPON ARRIVAL*** (plug and abandonment)
RAN 3.70" CENT W/ 3-1/2" DOGLESS GS TO SPEAR @ 9,350' MD (gs sheared)
RAN 4-1/2" GR TO SPEAR (unable to latch)
RAN 3.70" CENT W/ 2-5/8" BULL NOSE STEM TO SPEAR (jar down 45 minutes)
PULLED SPEAR FROM PATCH @ 9,350' MD
DRIFT W/ 2.00" CENT, 1-3/4" SAMPLE BAILER TO TD @ 12,101' MD (30' rathole)
***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS***
1/4/2020
T/I/O = 170/820/200. Temp = SI. IA FL (FB Request). No flowline or AL. IA FL @
540' (14 bbls).
SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 08:30
1/13/2020
T/I/O=125/825/160 Injectiity test (Plug And Abondanment) Load IA w/ 20 bbls Diesel.
Pump down Tbg. w/ 48 bbls Fresh Water with Surfactant, Displace w/ 280 bbls 2%
KCL. Rate= 5 BPM @ 800 PSI Freeze protect w/ 40 bbsl 60/40 FWHP=0/800/0
SV,WV,SSV shut. MV,IA,OA Open
1/13/2020
T/I/O = SSV/630/Vac. Temp = SI. C & B line injectivity test (P & A). No AL or
flowline. Control line has been cemented and pressure tested. Balance line pressure
= 680 psi. Bled BLP to 280 psi in <1 min (FTS). Rig to balance line and pressured
up to 4980 psi with hydraulic fluid (0.1 gal). BLP decreased 50 psi in 15 min. Bled
BLP to 20 psi (gas/fluid 1 gal).
SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:00.
2/9/2020
T/I/O = Vac/600/Vac TEMP = S/I Assist SLB With Cement Job ( PLUG AND
ABANDONMENT) Pre heat Worley DSL tanker to 75*, ***WSR Continued on 02-10-
20***
Daily Report of Well Operations
PBU P-23
Daily Report of Well Operations
PBU P-23
2/10/2020
SLB Cementers - Reservoir Cement Plug (PLUG AND ABANDONMENT)
T/I/O = 0/600/0. ***LRS in control of well upon arrival***
The following fluids were bullheaded down TBG into formation: LRS pumped 5 bbls
60/40 spear, SLB pumped 10 bbls freshwater spacer, 23.5 bbls Class G Cement, 2
bbls freshwater flush, foam wiper ball, 3 bbls freshwater spacer, LRS pumped 171
bbls diesel. IA pressure bled down during displacement before lead cement reached
Tx IA holes with ~10 bbls of diesel returns. ***LRS in control of well upon departure***
FWHPS = 1530/1950/0. ***Job Complete***
est. TBG TOC @ 11630' MD
2/10/2020
***WSR Continued from 02-09-20*** T/I/O= Vac/600/Vac Assist SLB with Cement
Job (PLUG AND ABANDONMENT) Pumped 5 bbls 60/40 spear followed with 171
bbls diesel down TBG, Pumped 4 bbls 60/40 through choke skid & hard line to OTT
to flush, Valve position at departure- SV, SSV= Closed, MV= Open IA & OA= OTG,
FWHP= 1530/1950/Vac
2/10/2020
T/I/O = 1780/2200/0. Temp = SI. Bleed IAP (Ops call in/ high IAP). No AL or
flowline. Choke skid and hardline rigged up to the TC. IA FL @ surface. Bled the
IAP from 2200 psi to 2140 psi in ~3 minutes (60 psi, Production, #1). During the IA
bleed the TBG decreased 60 psi to 1720 psi. Called Fullbore. Bled the IAP from
2140 psi to 1900 psi in ~5 minutes (240 psi, Production, #1). During the second IA
bleed the TP decreased 240 psi to 1480 psi. Per town, bled the IAP again from 1900
psi to 1500 psi in 7 minutes (400 psi, production, #1. During the third IA bleed the TP
decreased 400 psi to 1080 psi. During the 30 minute monitor the TBG & IAP
increased 20 psi. FWPs = 1100/1520/0.
SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. FWPs = 1100/1520/0. 13:00
2/12/2020
T/I/O = SSV/1570/VAC. Temp = SI. WHPs (Post Bleed). No AL or flowline. IAP
increased 50 psi since 02/10/2020.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:00
3/7/2020
***WELL S/I ON ARRIVAL***(p&a)
R/U SWCP SLICKLINE UNIT 4517
***CONTINUED ON 03/08/20 WSR***
3/8/2020
***CONTINUED FROM 03/07/20 WSR***(p&a)
TAG TOC W/ 1-3/4" BAILER, 2.00" CENT @ 10,614' SLM
RAN 1.90" CENT W/ T.E.L., LOCATED BOTTOM OF PATCH @ 9,367' SLM
RAN HES PRESSURE/TEMP LOG W/ 2.14" CENT TO 9,389' SLM
***CONTINUED ON 03/09/20 WSR***
Daily Report of Well Operations
PBU P-23
3/8/2020
T/I/O = 465/1248/0 Temp - SI. LRS Unit 46 assist SLB with MIT-TxIA (PLUG AND
ABANDONMENT) Pre AOGCC CMIT TxIA **Inconclusive** Pumped 14 bbls dsl
down TxIA to reach test pressure. 15 min TxIA lost 80/92. 30 min TxIA lost 66/64.
Total loss in 30 mins = 146/156. Bleed TxIA back to 511/544 down P-01 flowline.
AOGCC Witnessed by **Guy Cook** MIT TxIA **PASSED** to 2649/2667. Max
applied = 2750 psi/Target = 2500 psi. Pumped 21.45 bbls dsl down TxIA to reach
test pressure. Test #1 15 min TxIA lost 65/61. 30 min TxIA lost 29/29. Total loss in
30 mins = 94/90. Bleed TxIA back. Bled .4 bbl to unit/started getting gas/Swap to
bleed tank. Bleed tank level = 18.5"= 8.8 bbls at start. SI bleed at 27" = 14.59 bbls.
Bled back 5.79 bbls 2nd bleed trailer on location.Tank Level at start = 1.25" = 0.15
bbl. SI bleed/Tank level at 15" bled back 5.78. Total bbls bled back = 12 bbls.
Pumped 10 bbls dsl down IA to check tbg tracking reaction time. Bled TxIA back to
552/537. Bled back 7.4 bbls. Slickline still on well at LRS departure.
FWHP=550/535/0
**Fluid packed tags hung on IAV/WV**
**AFE sign in place on arrival**
3/9/2020
***CONTINUED FROM 03/08/20 WSR***(p&a)
PUNCHED TBG W/ HES MAX FIRE & 5' TBG PUNCH, BTM PUNCH @ 9,409' MD
***WELL S/I ON DEPARTURE***
4/10/2020
T/I/O= 700/700/0 Circ Out Well (Plug And Abandonment) Pump down Tbg taking
returns up IA to Open top w/ 5 bbls 60/40, 50 bbls Fresh water w/ Surfactant, 507
bbls 9.8# Brine. Freeze protect w/ 8 bbls 60/40, U-Tube FP into Tbg.
**WSR Continued on 04-11-2020***
4/11/2020
**WSR Continued from 04-10-2020***
Completed U-Tube TBG and IA. Pumped 5 bbls 60/40 to FP suface lines and
reverse out skid to open top tanks.
Valve Positions=SV,WV,SSV closed MVopen CV's OTG Caution tag hung from WV
and IA. AFE sign on MV ***FLUID PACKED WELL***
FWHP=0/0/10
4/14/2020
SLB Cementers - TxIA Balance Plug / IA surface Cement (PLUG AND
ABANDONMENT)
MIRU LRS and SLB. Pump the following fluids down TBG w/ IA Returns to OTTs:
LRS pumped 5 bbls 60/40, SLB pumped 10 bbls freshwater spacer, 322 bbls 15.8
ppg Class G cement, 2 bbls freshwater flush, drop 7" foam ball, 3 bbls freshwater,
LRS pumped 72 bbls 9.8 ppg NaCl displacement, 5 bbl 60/40 freeze protect. Verified
clean cement returns.***Refer to LRS AWGRS on 4/14/20 for LRS job details***
TBG TOC est @ 5400' MD / IA TOC @ surface
Tx IA BOC @ 9409' MD
Daily Report of Well Operations
PBU P-23
4/14/2020
T/I/O= 12/05/vac Temp= S/I (LRS Unit 70 Assist Cement Crew with P & A)
Pumped 5 bbls neat meth spear down TBG taking returns up IA to open top tank.
Cement crew pumped cement program and dropped foam ball.
Pumped 72 bbls 80*F 9.8 ppg Brine down TBG, displacing cement, and taking
returns up IA to open top tank.
Pumped 5 bbls neat meth to freeze protect surface lines. Pumped 10 bbls neat meth
for clean up/freeze protect for choke skid and hardline.
Hung "IA cementend to surface tag" All tree valves closed. IA & OA casing valves
open to gauges. FWHP's 1165/vac/7
4/19/2020
T/I/O= 0/0/0. LRS unit 72. MIT-T PASSED at 2547 psi, Max Applied Pressure= 2750
psi, Target Pressure= 2500 psi (PLUG AND ABANDONMENT)
Pumped .7 bbls 60/40 down TBG to reach test pressure, TBG lost 20 psi in 1st 15
min and 19 psi in 2nd 15 min for a total loss of 39 psi in 30 min test, Bled back .6
bbls, Tags hung on well, Valve position at departure- WV, SV, SSV= Closed, MV=
Open, IA & OA= OTG, FWHP= 0/0/0
4/25/2020
***WELL S/I ON ARRIVAL*** (ELINE DRIFT/TAG & PERFORATE)
D&T W/ 3-3/8" X 10' DUMMY GUN & 1-1/2" SAMPLE BAILER. TAG TOC ~ 5232'
MD (good sample).
PUNCH 3200' - 3210' W/ 3-3/8" x 10' POWERFLOW HMX, 12 SPF, 135 DEG
PHASE GUN (good TxOA pressure response).
ALL LOGS TIED INTO 4-1/2" TBG TALLY 08-SEP-1993.
***JOB COMPLETE ON 25-APR-2020***
4/28/2020
T/I/O=13/vac/330 LRS 72. CIRC TBG x OA (P & A)
Pump 5 bbls 60/40, 74 bbls surfactant pill & 225 bbls 9.8 ppg brine down TBG taking
returns up OA to tank. Pump 12 bbls 60/40 down tbg up OA to tank. Shut in & U-tube
TBG & OA for ~ 200' of freeze protect, Pumped 1 bbl 60/40 through choke trailer to
tank for FP of surface line, FWHP= 0/0/0
***Job Complete***
4/29/2020
SLB Fullbore Pumping Crew. Job Scope: (CEMENT TBG & OA TO SURFACE -
P&A).
Cemented TBG and OA to surface by circulating in 5bbl 60/40, 5bbl fresh water,
195bbl 15.8ppg Class G cement, pumping down the TBG taking returns from the OA.
Cement to surface in OA after 176bbl away. Full returns based on final return tank
volume.
***Job Complete***
TBG and OA BOC = 3210' MD
TBG and OA TOC = surface
5/2/2020
T/I/O = 0/0/0. Dryhole conversion. Removed 4" FMC120 upper tree and installed
Tree cap Assembly. Torque to API specs. RDMO ***Job Complete*** SEE LOG
FOR DETAILS Final T/I/O 0/0/0. MV = C, IA/OA = OTG.
5/4/2020
T/I/O=0/0/0. RD 2" FMC working side and companion side I/A valves. RU 2" 5000
blind flanges on working side and companion side. Torqued to API spec. RD 2" FMC
O/A valve. RU 2" 5000 blind flange. Torqued to API spec. Job Complete. See log.
Final WHP,s 0/0/0.
Daily Report of Well Operations
PBU P-23
5/17/2020
***P-23 P&A*** Excavate from pad grade down 11.6', Install shoring system. Cut
wellhead 8.2' below pad grade. Found 3.7' void in tubing, 0.7' void in IA. Top off both
tubing and IA with AS-1 cement. Top of cement and marker plate installation
witnessed by AOGCC Bob Noble. All final depths are: Pad grade = 54.0', Tundra
grade = 49.5' Wellhead cut = 45.8', Wellhead is cut and abandoned 3.7' below tundra
grade. Pull shoring box and backfilled excavation with gravel*** Job Complete***
MEMORANDUM
Founded on
State of Alaska
De th To
MW Above
Alaska Oil and Gas Conservation Commission
TO:
Jim Regg I\a 3I Z6 &,,17
fl
DATE: March 8, 2020
10632' MD"
P.I. Supervisor
Wireline tag
0
0
SUBJECT: Well Bore Plug & Abandonment
PBU P-23 -
FROM:
Guy Cook
BPXA
Petroleum Inspector
PTD 1931120; Sundry 319-202
Section:
31 Township:
11N
Range: 13E Meridian: Umiat-
Drilling Rig:
n/a Rig Elevation:
n/a
Total Depth: 12275 ft MD Lease No.: ADL0028288
Operator Rep:
Chuck Nardini
Suspend: P&A: X '
Casing/Tubing
Data (depths are MD):
Casing Removal:
Conductor:
20" - O.D. Shoe@
115
Feet Csg Cut@ Feet
Surface:
10 3/4" - O.D. Shoe@
3322
Feet Csg Cut@ Feet
Intermediate:
7 5/8" O.D. Shoe@
11863
Feet Csg Cut@ Feet
Production:
O.D. Shoe@
Feet Csg Cut@ Feet
Liner:
5 1/2" O.D. Shoe@
12275
- Feet Csg Cut@ Feet
Tubing:
4 1/2" - O.D. Tail@
11710
Feet Tbg Cut@ Feet
Plugging Data:
Test Data:
T e Plu
Founded on
De th Btm
De th To
MW Above
Verified
Open Hole
Bottom
12275' MD'
10632' MD"
15.8 ppg
Wireline tag
0
0
Initial 15 min 30 min 45 min Result
Tubing
2743
2678
2649
IA
2957
2696 -
2667 -
P
OA
0
0
0
Remarks:
The first tag of cement was at 10614 ft wirelimne measurement (WLM) and the drive -down bailer was driven to 10618 ft' WLM.
They retrieved a sample of good cured cement. The second tag of cement after the CMITAA was at 10614 ft WLM and the
bailer was driven down to 10618 ftWLM. There is an 18 -foot correction for WLM to MD. 21.5 bbls were pumped and they got
back 12 bbls. The well was not fluid packed at the beginning of the job. After talking with Chuck Nardini (BP) about the cement
job I understand the fluid pumped before the cement plug was mostly lost down -hole into the formation. And the tubing -IA
communication at the packer is relatively small so the fluid did not fully displace the gas that was in the IA. They could have
improved the communication between the tubing and the IA before pumping to resolve this issue, but they didn't. Even with the
barrels-in/barrels-out difference I believe this is a passing CMITxIA. They will be punching holes in the tubing for the next plug
so they should have no problem with circulation from here on.
Attachments: none
rev. 11-28-18 2020-0308_Plug Verification_PBU_P-23_gc
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Aras Worthington
Interventions and Integrity Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU P-23
Permit to Drill Number: 193-112
Sundry Number: 319-202
Dear Mr. Worthington:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.olaska.gov
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
Daniel T. Seamount, Jr.
Commissioner
DATED this �SdayofApril, 2019.
1R8DW1SL4j APR 16 HIS
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
•— rr 9.2W`V
APR 18 2019
1. Type of Request Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑
Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program
Plug for Rednll ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other ❑
2. Operator Name: BP Exploration (Alaska), Inc
4. Current Well Class:
Exploratory ❑ Development ❑
5. Permit to Drill Number: 193-112
3, Address: P.O. Box 196612 Anchorage, AK
99519-6612
Stretigrephic ❑ Service
6. API Number: 50-029-22393-00-00 '
7, If perforating:
8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes ❑ No ❑
PBU P-23
9. Property Designation (Lease Number):
10. FielNPools:
ADL 028288 '
PRUDHOE BAY. PRUDHOE OIL
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (8): Total Depth TVDnQ: Effective Depth MD' Effective Depth TVD: MPSP (psi):
Plugs (MD): Junk (MD):
12275 ' 9230 12194 9158
None None
Casing Length Size MD TVD
Burst Collapse
Structural
Conductor 80 20" 35-115 35-115
1490 470
Surface 3287 10-3W' 35-3322 35-2860
5210 2480
Intermediate 11830 7-5/8" 33-11863 33-8868
6890 4790
Production
Liner 570 5-1/2" 11705-12275 8736-9230
1 7740 1 6280
Perforation Depth MD It) :
Perforation Depth TVD (fl):
Tubing Size:
Tubing Grade:
Tubing MD (fp:
11988- 12070
1 - 9048
4-1/2" 12.6#
1 30-11710
Packers and SSSV Type: 4-1/2" TIW HBBP Packer
Packers and SSSV MD (ft) and TVD (fl): 11649 / 8691
No SSSV Installed
No SSSV Installed
12. Attachments: Proposal Summary 0 Wellbore Schematic m
13. Well Class after proposed work.
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stratigraphic ❑ Development ❑ Service m -
14. Estimated Date for Commencing Operations: June 1, 2019
15. Well Status after proposed work:
Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16. Verbal Approval: Date:
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Award. Mike (Udelhoven)
be deviated from without prior written approval.
Contact Email: mike.aivanoCQbp.com
Authorized Name: Worthington, Aras J Contact Phone: +1 9075645475
Authorized Title: Interventions 8lntegnty Eng' eer
l
Authorized Signature: // // Date:
a /Jim
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Suntlry Number: ,r I ,r ��
Plug Integrity LQ� BOP Test ❑ Mechanical Integrity Test lam Location Clearance :fJ• L/
Other. 6<Lcj'�(G�aH-Ur.r+.t�
1
Post Initial Injection MIT Req'd? Yes 1:1 No ❑/. RBDMSl�✓APR 2 6 2019
Spacing Exception Required? Yes ❑ No Q Subsequent Form Required. )c -LloO l
APPROVED BYTHE
Approved by: COMMISSIONER COMMISSION Date: Z I
S�
�/o q�216H
ORIGINAL
Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval.
.�i
mi; PU Mrt 16't> >fzzi9
Submit Form and
Attachments in Duplicate
by
P-23 P&A
Intervention Engineer
Mike Aivano (907) 564-5475
Aras Worthington (907) 564-4102
Production Engineer
Jordan Haffener (907) 564-5383
Expected Start Date:
June 1. 2019
History:
P-23 was originally completed in September of 1993 as a Zone 4 producer for about 2 years.
The well was then converted to an injector in 1996 and functioned as a water and MI injection
well till about 2002. By 2002, the well started to demonstrate TAA communication and was shut
in due to holes in the tubing.
Over the years, several tubing holes have been found and patched with tubing patches, the first
one was run on 07/15/02 at a depth of 9436'md to 9466'md and the second was run on
05/25/05 at a depth of 9350'md to 9385'md. After the second patch, the well still failed an MIT -
IA and a leak detect log found additional tubing leaks at 9385'md (bottom of the top patch) and
at 9848'md. The well then failed a CMIT-TAA in 2005 with a liquid leak rate of 2.5 bpm@
2100psi. A second CMIT-TxIA failed approximately two years later but at 0.3 bpm liquid leak
rate at 2400 psi. This was followed by a leak detect log which found a leak point at the packer.
Multiple attempts have been made to pull the patches but have been unsuccessful. Currently
the well is shut in with a releasable 4-1/2" spear stung into the top tubing patch. OA Integrity
test passed to 1200 psi — LLR of 2.9 qpm at 1200 nsi on 3/27/19.
Objective: V
Perform a full P&A on the well. Pull the 4-1/2" releasable spear and place cement plugs at and
above the reservoir, across the 10-3/4" casing shoe, inside the 7-5/8" x 10-3/4" annulus, and at
surface. Once the well is cemented to surface, excavate and cut off the wellhead >3 ft below
tundra level and weld a marker / cover plate over top the well.
DPZ 1 from 2164'md — 7382'md
DPZ 3 from 11865'md—12275'md
Procedural Steps:
Slickline
1. D&T to top of releasable spear at 9350' md.
2. Pull spear
3. D&T to the top of fill inside 5-1/2" liner
P-23 P&A Sundry v2
4. Confirm no control lines on this well, it was a producer originally but last documented
SSSV was an MCX. If control lines will need to add in cementing of control lines.
Fullbore
1. Load / fluid pack IA with diesel.
2. Bullhead the following down the tubing to confirm injectivity
• 5 bbl McOH
• 50 bbls hot fresh water + surfactant (2gal/mgal F103 and 2 gal/mgal UO67)
• 190 bbis 2% KCL
• 35 bbis of Freeze Protect if required ✓
3. Bullhead cement down the tubing
• 5 bbis McOH
• 5 bbis fresh water
25 bbis Class G Cement as per design (-15 bbis sqz behind pipe) ✓
• 5 bbis freshwater
• Foam ball
• 171 bbis of diesel ✓
• Estimated TOC at 11630' and in the 4-1/2" tubing
Cement Type/weight:
Class G 15.8 ppg mixed on the fly. Field blend to be =lab
ppg +/- 0.1 ppg
Slurry Temperature:
between 800 and 110°F
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive
Strength:
2000 psi in 48 hrs.
Thickening Time:
Minimum 6 hours
Fullbore / Slickline
1. CMIT TxIA 2500 psi - AOGCC Witness
2. Drift and Tag top of cement - AOGCC Witness l
3. Punch tubing between the two tubing patches at-9390'md.
Fullbore
1. Circulate Surfactant Pili and brine down the tubing and up the IA.
• 5 bbis McOH
• 50 bbls hot fresh water + surfactant (2gal/mgal F103 and 2 gal/mgal UO67)
• 400 bbis of 9.8 ppg brine
2. Circulate cement down the tubing and up the IA.
• 5 bbis McOH
• 5 bbis fresh water
• 322 bbis Class G Cement as per design (- 15 bbls over calc volume)
• 5 bbis freshwater
• Foam ball
• 72 bbis of 9.8ppg Brine
P-23 P&A Sundry v2
• 5 bbls McOH Freeze Protect
• Estimated TOC in 4-1/2" tubing at 5400'md and TOC in IA at surface.'
Cement Type/weight:
Class G 15.8 ppg mixed on the fly. Field blend to be =lab
ppg +/- 0.1 ppg
Slurry Temperature:
between 80° and 110°F
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive
Strength:
2000 psi in 48 hrs.
Thickening Time:
Minimum 6 hours
Slickline / Fullbore
1. D&T TOC inside 4-1/2" tubing.
2. MIT -T to 2500 psi.
3. Perforate tubing and IA @—3200'md (use Eline if Slickline unable)
Fullbore
1. Circulate Surfactant Pill and brine down the tubing and up the OA. Should be no Arctic
Pack in the OA.
a. 5 bbls McOH
b. 50 bbls hot fresh water + surfactant (2gal/mgal F103 and 2 gal/mgal UO67)
c. 200 bbls of 9.8 ppg brine
d. Freeze Protect as required
2. Circulate cement down the tubing and up the OA.
a. 5 bbls McOH
b. 5 bbls fresh water
c. 191 bbls Class G Cement as per design (— 15 bbls over calc volume)
d. Top of cement for both the tubing and the OA will be at surface
Cement Type/weight:
Class G 15.8 ppg mixed on the fly. Field blend to be =lab
ppg +/- 0.1 ppg
Slurry Temperature:
between 800 and 110°F
Fluid Loss:
40-200cc (20-100cc/30 min)
Compressive
Strength:
2000 psi in 48 hrs.
Thickening Time:
Minimum 4 hours
P-23 P&A Sundry v2
DHD
1. Assist Fullbore with cement job and pump N2 across the wellhead to remove excess
cement from the valves. This will allow valves to be opened prior to the wellhead
removal to check for pressure.
2. Bleed all wellhead pressures to 0 psi.
3. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi.
Special Projects
1. Excavate around wellhead.
2. Cut Wellhead a minimum of 3' below tundra level. pko�®�ire O
3. Top off all annuli / voids with cement to surface. -AOGCC Witness
4. Weld on cap over conductor casing with the following info bead welded on top of plate. —
AOGCC Witness
5. Back fill and grade level with the rest of the pad.
BP Exploration Alaska, Inc.
P-23
PTD # 193-112
API # 50-029-22393
Cement Plug Calculations
5-1/2"
0.0232 bpf
4-1/2"
0.0152 bpf
7-5/8" x 4-1/2"
0.0262 bpf
10-3/4" x 7-5/8"
0.0398 bpf
_ower Cement Plug
Btm Too Footaae Volume
12059 11710349
399060.6
8.1
11710 11630
80
1.2
Total Volume
9.3
Total Vol w/ 15 bbls extra
24.3
Middle Cement Plug
Btm Top Footaqe Volume
4-1/2" 9390 5400
399060.6
48.6
7-5/8" x 4-1/2" 9390 0
9390
246.0
Total Volume
306.7
Total Vol w/ 15 bbls extra
321.7
Upper Cement Plug
Btm Top Footage Volume
4-1/2" 3200 0
3200
48.6
10-3/4" x 7-5/8" 3200 0
3200
127.4
Total Volume
176.0
Total Vol w/ 15 bbls extra
191.0
P-23 P&A Sundry v2 4
10-3/4" CMT to Surf w/ Top lob P-23
MITOA Fail to 2000psi
LLR 5bpm @ 1700psi
Est TOC of 7-5/8" Csg @ 5438'
Minimum ID = 224' @ 8436'
ECLIPSE PACKOFF PATCH ASSY
Prod Leak -0.3 bpm @ 2400 psi
Patches Leak
Tbg Leaks ID'd at 9370', 9460, 9848'
5-1/2" Liner fully CMT'd
SAFETY MOTES:I T MWS"EMOE 126 ppm
WHEN! ON NI. WELL REOURES A SSS VWHEN OR
YL
18'
GAS LFT M17 ELS
STI
FEWORATONSLIA%RY
ND
RJi LOG ShS OHM. 0905153
VLV LAT H
ANGLEAT TOPFEW: 29' O 11986'
Nola: Wer b Pm&cbn ® ter lrbrbal pert dab
SIZE
SPF
HIBWAL OpN DATE
Z
6
11908-121M O 12A6196
3.3fir8
1
Z144. 2050 O 12A6M
3-3W
6
1205612070 O 12)0696
5-1/2" Liner fully CMT'd
SAFETY MOTES:I T MWS"EMOE 126 ppm
WHEN! ON NI. WELL REOURES A SSS VWHEN OR
YL
18'
GAS LFT M17 ELS
STI
fm
ND
IMTYPE
VLV LAT H
10RT
DALE
3
3192
21
13 076
OVI BK
0
OW1093
1
6201
1781
18 OILS
DAW BK
0
0811055
3
8537
6390
17 1076
01N BK
0
0811055
2
10364
7663
/a Oi6
O1M W(
0
08110,%
t i
ll5;aas"
5, iossiuifl
a.
i o
i�;�;:Ai
P-23 P&A Sundry Q
= 2164'- 7382'
=11865'- 12275'
PRDIOEBAY WT
WELL'. R23
FBOAT No: 1931120
ARFb� 50-0297239300
See. 31. TI IK 573E 259E FSL & 207r
DATE FWV BY CMANTS DATE REV BY 001/.8115
OWaB113 LIMB{ 011X3 "CMR.E710M WWI! 7WJC VAX AN3LEOOFVWWC ON
07113'01 RTKAK COWB:TENS 07710/11 1B1JA0 A00®SSSV SAFETY NOTE
0711102 (AO1KK FKCKOMPATCHASSB,BLY 1111211 MO PJC 511/RBtTSR'#R 11AYi1)
032503 .PAAW B'1PSE PATCH Otn6n2 lA9IJAO AOMH25 SAFELY NOTE
OBNa107 RID' PJC SET 8W OPO 11676
0&09116
GOAD UOVEDGLV TYFE&DAIE
BPEapbrrtbn(Abeka)
1111907 CWJC RiL&MBP(11R)07
P-23 P&A Sundry Q
= 2164'- 7382'
=11865'- 12275'
10-314'Ce>Ie rSun
PeATtg&l40
-3210
E5TCCtr70'Q5536—
Tu[ %Xh@-9390
Ea TCCoICm P4
5lquyc
P-23 P&A Sundry v2
P-23 Proposed
!TD4Pym-«P6tM4ITD0Ps Original Estimated Cement from Drilling
NN Cement added for P&A
21194-IrPSMNq rvv
33221DN'ShM
TOC b14.112-TbyP4
so
50-93&5 SIR' P8A
Tay Leafs IC d 0 9370, 9460, 9&4&
36-94663 W'PaT6 -2 Abp@
11631 SHS No
116494-I17Prdhr
%LeAIDC IM7-0.3bpmQ140Gp&
11681 SM No
705 51R'TDL
710 4 IR'HlEG
963 T 5M, swe
t 1199&-12036.12044.12050,12056-12070
)d:i *-12759 tM SL Ta06ep2000
A PBTD
75 -Arsine
L
BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT P-23 (193-112)
PRUDHOE BAY, PRUDHOE OIL
Monthly Production Rates
1,000,000
c Produced Gas (MCFM) Produced Oil (SOPM) Produced Water (BOPM) _ -_
100,000 _
S
C
O
10,000
L
CL
ti
1,000
V
100
10
Jan -1990
1,000,000
100,000
L
Y
C
cO 10,000
C
L
d
G
1,000
u
100
Cum. Prod Oil (bbls): 603,827
Jan -1995 Jan -2000
Cum. Prod Gas (mcf): 534,374
Jan -2005
Monthly Injection Rates
Cum. Prod Water (bbls): 292,103
Jan -2010 Jan -2015
1,000,000
100,000 07
N
10,000 vm—i
13
rD
1,000 3
O
7
.e
100 S
—1 10
Jan -2020
10 +—
Jan -1990
Jan -1995 Jan -2000
Jan -2005
Jan -2010 Jan -2015
- 1,000,000
W
v
- 100,000 N
O
M
10,000
d
M
1,000
M
100
0
s
—F 10
Jan -2020
SPREADSHEET_1931120_PBU_P-23_Prod-Inject_Cumes_W ell_Oil_V120_20190422.xlsx
4/22/2019
• i
bp
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB -20
Post Office Box 196612
Anchorage, Alaska 99519 -6612
August 22, 2011 ,,;,;, 7) ')F . r
Mr. Tom Maunder IVEly
Alaska Oil and Gas Conservation Commission Mi1; 3 i mi
333 West 7 Avenue
Anchorage, Alaska 99501 Ak ka f3tf & Gas C oot.
r 1,aC�, (�j M1183
Subject: Corrosion Inhibitor Treatments of GPB P -Pad 9
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P-
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, Gerald
Murphy, at 659 -5102.
Sincerely,
Mehreen Vazir
BPXA, Well Integrity Coordinator
III •
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10 -404)
P -Pad
Date: 07/21/11
Corrosion
Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date
ft bbls ft na gal
P -01 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010
P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010
P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010
P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010
P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010
P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010
P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010
P -08A 2000850 500292237701 0.10 NA 0.10 NA 0.85 4/24/2010
P -09 1930580 500292236200 0.10 NA 0.10 NA 0.85 4/24/2010
P -10 1910520 500292215800 3.00 NA 3.00 NA 28.05 4/24/2010
P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010
P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010
P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010
P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011
P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010
P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010
P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010
P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010
P -21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010
P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010
P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010
P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010
P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011
P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010
P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010
P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010
• •
If ~-~L'~
~s-
ProActive Diagnostic Services, Inc.
To: AOGCC
Christine Mahnken
333 W. 7th Ave
Suite 100
Anchorage, Alaska 99501
(907j 793-1225
~~~6~N~ MAY ~ ~ 200
RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following
BP Exploration (Alaska), Inc.
Petrestechnical Data Center
Attn: Joe Lastuflca
LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
and
vsG tq.3 - ~ t a ~ ~~~9
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road
Suite C
Anchorage, AK 99518
Fax: (907) 245-8952
1) Leak Detection - WLD 1 &Oct-07 P-23
2)
_ 1
Sig~ted
Print Name: (',~(,~~~. ~~
1 Color Log / EDE 50-029-22393-00
,::
Date
PROACTIVE DIAGNOSTIC SERVICES, INC., 1so w. INTERNATIONAL AIRPORT Ra SUITE C, ANCHORAGE, AK 99518
PHONE: {907)245-8951 FAX: (90712458952
E-MAIL: ~d~ala~a~s~r~c~Ct~lrsea*or^~4®C.:c~s~I WEBSITE:~~,v~fl~n~.~e~~r+.a€3~~~..~ra~
C:\Documen6 and Settingsl0wner~Desidop\Txansaut_BP.doc
)
93·-·/(7-
't.
~:'C'ífl~' ~~
"" ti /JJ1\ I[ "
) lJI 'll,
;/
/1 I FRANK H. MURKOWSKI, GOVERNOR
333 W. pH AVENUE, SUITE 100
I ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
AlASKA OIL AlQ) GAS
CONSERVATION COMMISSION
J ennifer Julian
Wells Engineer
BP Exploration (Alaska), Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
5CANNE[.} JUL 1. 2 2.00~j
Re: Prudhoe Bay P-23
Sundry Number: 305-160
Dear Ms. Julian:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in
the enclosed form.
Please provide at least twenty-four (24) hours notice for a representative
of the Commission to witness any required test. Contact the
Commission's petroleum field inspector at (907) 659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an
application for rehearing. A request for rehearing is considered timely if
it is received by 4:30 PM on the 23rd day following the date of this letter,
or the next working day if the 23rd day falls on a ,liday or weekend. A
person may not appeal a Commission decisio 0 ¡ perior Court unless
rehearing has been requested0 S. c r
. -. -u.
Chai
DATED this-'L day of July, 2005
Encl.
T1
'(¡
iì
)
,
"
~
~
June 29, 2005
Winton Aubert
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, AK 99501
Dear Winton:
RE: Sundry Notice for P-23 OA Downsqueeze
BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain an
injection waiver for well P-23.
Step Type Proced u re
1 0 OA FL depress
2 F OA cement down squeeze /'
3 F MIT OA after WOC /
Well P-23 is an injector which requires a waiver for TxlA communication.
Attempts to fix the tubing with patches have not been successful due to the
numerous small holes, making this well a RWO candidate. However, BP would /'
like to get the well back on PWI while waiting on RWO. In order to waiver the
well for injection, an OA downsqueeze must be performed. This procedure will
pump a column of cement from the OA shoe to approximately 500 ft above the /'
shoe for waiver compliance.
Please contact Jennifer Julian at 564-5663 (H) 274-0929, (Cell) 240-8037 with
any questions.
Sincerely,
C~~~~
J;tnnifer Julian
Wells Engineer
RECEJ\/ED
JUN 3 0 2005
J\laska Oil & Gas Cons. Corn;-¡',:ss;:::n
t\~d¡¡Jí;JW:;
ORIGINAL
\H6A- 7 f */ ~()Ç
) STATE OF ALASKA )
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
20 AAC 25.280
StratigraphicD Service ŒJ
9. Well Name and Number:
P-23 .,/
10. Field/Pool(s):
Prudhoe Bay Field I Prudhoe Oil Pool
PRESENT WELL CONDITION SUMMARY
Effective Depth MD (ft): Effective Depth TVD (ft):
12194 9158.1
Size MD TVD
, Jo
1. Type of Request:
Ii
Operation Shutdown D
Plug Perforations D
Perforate New Pool D
4. Current Well Class:
Abandon D Suspend D
Alter Casing D Repair Well I!I
Change Approved Program D Pull Tubing D
2. Operator
Name:
3. Address:
BP Exploration (Alaska), Inc.
Development D
P.O. Box 196612
Anchorage, Ak 99519-6612
7_ KB Elevation (ft):
87.10 KB
8. Property Designation:
ADL-028288
11. Presen1
Total Depth MD (ft):
12275
Casing
Total Depth TVD (ft):
9230.2
Length
Perforate D Waiver D Other D
StimulateD Time Extension D
Re-enter Suspended Well D
5. Permit to Drill Number:
193-1120 /'
Exploratory D
/'"
6. API Number /"
50-029-22393-00-00
Plugs (md):
None
Burst
Junk (md):
None
Collapse
CONDUCTOR
SURFACE
PRODUCTION
LINER
top bottom top bottom
80 20" 91.5# H-40 32 112 32.0 112.0
3289 10-3/4" 45.5# L-80 33 3322 33.0 2860.2
11832 7-5/8" 29.7# NT-95HS 31 11863 31.0 8867.9
570 5-1/2" 17# L-80 11705 12275 8736.3 9230.2
470
2480
5120
6280
Perforation Depth MD (ft):
11988 - 12036
12044 - 12050
12056 - 12070
Perforation Depth TVD (ft):
8976 - 9017.9
9025 - 9030.3
9036 - 9047.9
Tubing Size:
4-1/2 "
Packers and SSSV Type:
4-1/2" TIW HBBP-R Packer
5-1/2" TIW Top Packer
4-1/2" Otis SSV Nipple
1490
5210
8180
7740
Tubing Grade: Tubing MD (ft):
12.6 # L-80 30
11710
Packers and SSSV MD (ft):
12. Attachments:
11649
11705
2119
13. Well Class after proposed work:
Description Summary of Proposal ŒI
Detailed Operations Program D BOP Sketch D
14. Estimated Date for
Commencing Operation:
//
Service[&]
July 13, 2005
Exploratory D DevelopmentD
15. Well Status after proposed work:
Oil D GasD PluggedD
Abandoned D
Mechanciallntegrity Test ~
f~EiCE~\JE:,[)
JUN 3 0 2005 ¥'l
., 9 r,'"~,',"\",, !"',', ("m,~,',"-, c.m1h-:-,¡~,si:'~~~~~~~~~ION Date: '0tr
n\ash.~~ Du èL '-'_.~
RBDMS BFl',JUL 11 20'05:':hi~YC\\2': 0 R 1 GIN ^
" I, '1LS'fV1IT IN DUPLICATE
16. Verbal Approval: Date: WAG 0
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Printed Name
Signature
n Jenn-ferfiÃ.
\J~'rv(7" --
rJ ; ,j
Commission Use Only
Conditions of approval: Notify Commission so that a representative may witness
BOP TestD
Other:
-'t 0 4 .
Subseq
\-,/
Form 10-403 Revised 11/2004
GINJD WINJ[&] WDSPLD
Prepared by DeWayne R. Schnorr 564-5174.
Contact Jennifer Julian
Title
Phone
Wells Engineer
564-5663
6/29/05
Sundry Number:
.~(Y5 -(00
Location Clearance D
TREE = 4-1/16" 5M CIW
WELLHIiAD = 11" 5M FMC
, AciiJAfÖR'';' ,. BAKER
"...... ,.....w, ..
KB. ELE\! = 87.8'
'B'F.·ELEV·~ . ........ . 's:fg"
Kòp~ 600
MâxÄngle~ 821'
Datum MD = 11885'
. Dai'ÜrTiwÖ; . . 8SÖÖ;SS
')
110-3/4" CSG, 45.5#, L-80, ID = 9.953" 1-1
~
3322'
Minimum ID = 2.24" @ 9436'
ECLIPSE PACKOFF PATCH ASSY
1 TOP OF 5-1/2" LNR 1-1 11705' 1
14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1---1 11710'
17-5/8" CSG, 29.7#, NT-95HS, ID = 6.875" 1---1 11863' 1
ÆRFORA TION SUMMARY
REF LOG: SWS BHCS, 09/05/93
A NGLE AT TOP ÆRF: 29 @ 11988'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERV AL Opn/Sqz DA TE
3-3/8" 6 11988-12036 0 12/06/96
3-3/8" 6 12044-12050 0 12/06/96
3-3/8" 6 12056-12070 0 12/06/96
I PBTD 1-1 12194' 1
15-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 1---1 12275'
DATE
09/08/93
03/04/01
03/08/01
07/15/01
07/14/02
REV BY COMMENTS
LINDER ORIGINAL COMPLETION
SIS-SL T CONVERTED TO CANVAS
SIS-LG FINAL
RNlKA K CORRECTIONS
CAO/KK PACKOFF PA TCH ASSEMBLY
~
P-23
e
L
~ S5T
4
3
2
1
SAf
) NOTES
2119' 1---14-1/2" OTIS SSSV NIP, ID = 3.813" 1
MD TVD
3492 2894
6204 4783
8557 6399
10364 7663
11574 8544
GAS LIFT MANDRELS
DE\! TYÆ VLV LATCH PORT DATE
43 OTIS BK
48 OTIS BK
47 OTIS BK
44 OTIS BK
37 OTIS BK
!
59350' .9385'1---14-1/2" ECLIPSE PATCH (SET 5/25/05), ID = 2.25" 1
19436'-9466'1---1 ECLIPSE PACKOFF PATCH ASSEMBLY, ID = 2.24" 1
11631' 1---14-1/2" PKRSWS NIP, ID = 3.813" 1
¿S-1 11649' 1---17-5/S"X4-1/2"TIWÆRMPKR 1
¿s
~ 11681' 1---14-1/2" PKR SWS NIP, ID = 3.813" I
11698' 1---14-1/2" PKR SWN NIP, ID = 3.725" I
~ 11705' 1---15-1/2" TIW LNR TOP PKR 1
~I 11710' 1---14-1/2" WLEG, ID = 3.958" 1
I 11698' 1---1 ELMD TT LOGGED 11/11/95
~
~
~
J!lIIIIJ..
DA TE REV BY COMMENTS
OS/25/05 JRA/PJC ECLIPSE PATCH
PRUDHOE BA Y UNIT
WELL: P-23
ÆRMIT No: '1931120
API No: 50-029-22393-00
Sec.31,T11N,R13E
BP Exploration (Alaska)
ORIGINAL
i(
(
BP Exploration (Alaska) Inc.
Post Office Box 196612
PRB-20
Anchorage Alaska 99519-6612
December 14, 2003
Mr. Winton Aubert, P.E.
Alaska Oil & Gas Conservation Commission
333 W. 7th Ave.
Anchorage, Alaska 99501
Subject: P-23i (PTD 1931120) Application to cancel Sundry #301-246
Dear Mr. Aubert:
Attached is Application to Cancel Sundry form 10-404 for Sundry #301-246. This
request is to cancel the current sundry for rapid T x IA communication at well P-23i. The
well is a L TSI due to the lack of water in the area.
If you require any additional information or clarification, please contact either John
Cubbon or Joe Anders at (907) 659-5102.
Sincerel
R
J hn Cubbon
Well Integrity Engineer
Attachment:
1) Application for Sundry Cancellation form 10-404
RECEIVED
DEC 1 7 2003
Alaska Oil & Gas Cons. Gomrm:;sion
Anchorage
nD1~1t\1^'
1£'::: '" I, 1",~I",I lÇ;;:b" 1'1~-' ((j¡ c:.~ 1 2nD".!)
~~~tr'~tI~c~¡¡'¡;;;¡¡J LJ ¡r~ \L~ clJ J ,'IJ j,
f STATE OF ALASKA (
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed:
Abandon 0
Alter CasingD
Change Approved Program 0
2. Operator I
Name: BP Exploration (Alaska), Inc.
3. Address: I P.O. Box 196612
Anchorage, Ak 99519-6612
7. KB Elevation (ft):
87.10
8. Property Designation:
ADL-o028288
11. Present Well Condition Summary:
Total Depth
measured 12275
true vertical
Suspend 0
AepairWellD
Pull TubingD
Perforate 0 VarianceŒj Annular DisposalD
Stimulate 0 Time ExtensionD OtherD
Ae-enter Suspended WellD
5. Permit to Drill Number:
193-1120
Operation Shutdown 0
Plug PerforationsO
Perforate New PaolO
4. Current Well Class:
Development 0
Exploratory 0
Service I!J
6. API Number
50-029-22393-00-00
Stratigraphic 0
9. Well Name and Number:
P-23
10. FieldlPool(s):
Prudhoe Bay Field I Prudhoe 011 Pool
feet
9230.2 feet
None
Plugs (measured)
Junk (measured)
None
true vertical
measured 12194 feet
9158.1 feet
Effective Depth
Casing
Conductor
Liner
Production
Surface
Length
80
570
11832
3289
Size
20" 91.5# H-40
5-1/2" 17# L-80
7-5/81'29.7# NT-95HS
10-31411 45.5# L-80
MD TVD Burst Collapse
32 112 32.0 - 112.0 1490 470
11705 - 12275 8736.3 - 9230.2 7740 6820
31 - 11863 31.0 - 8867.9 8180 5120
33 3322 33.0 - 2860.2 5210 2480
Perforation deDth:
Measured depth: 11988 -12036,12044 -12050,12056 -12070
True vertical depth: 8975.79 - 9017.93,9024.98 - 9030.27,9035.56 - 9047.93
4-1/2" 12.6# L-80
@
RECEIVED
11649 DEC I 7 2003
117"'aska Oil & Gas Cons. Commission
An
Tubing ( size, grade, and measured depth):
30 -
11710
Packers & SSSV (type & measured depth):
4-1/2" TIW HBBP-R Packer
5-1/2" TIW Liner Top Packer
@
@
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure:
Aecresentative Dailv Averaae Production or Injection Data
Daily Aeport of Well Operations -
17. I hereby certify that the foregoin i true and correct to the best of my knowledge.
Contact J hn C
Printed Name
Signature
13
Prior to well operation:
Subsequent to operation:
14. Attachments:
Copies of Logs and Surveys run -
Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure
15. Well Class after proposed work:
Exploratory 0
Development 0
Servical!)
16. Well Status after proposed work: Operational Shutdown 0
OilO GasD WAG 0 GINJD WINJ[!) WDSPLD
Prepared by Garry Catron (907) 564-4657.
Sundry Number or NIA if C.O. Exempt:
301-246
Title Welllnte~lneer
Phone 659-5102
~tiL
Date
12/14/03
R8DMS BFl
DEC 1 ., æDJ
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _
SET TUBING PATCH Pull tubing _ Alter casing _ Repair well _X Other _
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet)
BP Exploration (Alaska), Inc. Development__ RKB 87 feet
3. Address Explorato~__. 7. Unit or Property name
P. O. Box 196612 Stratigraphic__
Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit
4. Location of well at surface 8. Well number
2597' FNL, 2077' FWL, Sec. 31, T11 N, R13E, UM (asp's 631357, 5947411) P-23
At top of productive interval 9. Permit number / approval number
1042' FNL, 883' FEL, Sec. 32, T11 N, R13E, UM (asp's n/a) 193-112
At effective depth 10. APl number
961' FNL, 854' FEL, Sec. 32, T11 N, R13E, UM (asp's 638674, 5949179) 50-029-22393-00
At total depth 11. Field / Pool
956' FNL, 755' FEL, Sec. 32, T11 N, R13E, UM (asp's 638773, 5949185) Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured 12275 feet Plugs (measured) TD Tag @ 12059' (09/14/2000)
true vertical 9230 feet
Effective depth: measured 12059 feet Junk (measured)
true vertical 9038 feet
Casing Length Size Cemented Measured Depth True Vertical Depth
Conductor 112' 20" 280 c.f. Arcticset (Approx.) 146' 146'
Surface 3288' 10-3/4" 2016 c.f. 111/408 c.f. 'G' 3322' 2693'
Production 11829' 7-5/8" 1825 c.f. Class 'G' 11863' 8707'
Liner 570' 5-1/2" 140 c.f. Class 'G' 11705' - 12275' 8512' - 9161'
Perforation depth: measured Open Perfs 11988' - 12036', 12044' - 12050', 12056' - 12070'
true vertical Open Perfs 8976' - 9018', 9025' - 9030', 9036' - 9048'
~!~Ska 0ii & t~as CONS.
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 11649' MD. Tubing Tail @ 11698'. Anchorage
Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" TIW PERM, Latch Packer @ 11649' MD, 5-1/2" Liner Top Packer @ 11705'.
4-1/2" Otis SSSVLN @ 2119' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14. Representative Daily Averaqe Production or Injection Data
Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 06/20/2002 1651 637
Subsequent to operation 07/18/2002 Shut-In
15. Attachments 16. Status of well classification as:
Copies of Logs and Surveys run __
Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service WATER INJECTOR
17. I hereby certify that the foregoing i_s tru~and correct to the best of my knowledge.
DeWayne R. Schnorr
Prepared b~/DeWa)/ne R. Schnorr 564-5174
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
P-23
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
07/08/20O2
07/11/2002
07/12/2002
07/12/2002
07/13/2002
07/14/2002
PATCH TUBING / LINER:
PATCH TUBING / LINER:
PATCH TUBING / LINER:
PATCH TUBING / LINER:
PATCH TUBING / LINER:
PATCH TUBING / LINER:
DRIFT/TAG
PATCH TUBING / CASING
PATCH TUBING / CASING
FISH / LOAD WELL TO SECURE; PATCH TUBING / CASING
FISH
PATCH TUBING / CASING
EVENT SUMMARY
07/08/O2
07/11/02
DRIFT W/DUMMY PATCH, DRIFT TO 11658' SLM, WELL SHUT IN UPON ARRIVAL, DSO
NOTIFIED. <<< WELL LEFT SHUT-IN >>>
SET LOWER ECLIPSE 4.5" TUBING PATCH AT 9466', RBIH WITH UPPER PATCH,
UNABLE TO STAB INTO LOWER ASSEMBLY, POOH. SECURE WELL, LAY DOWN
LUBRICATOR, ORDER FLUIDS AND PUMP TO COMPLETE SECOND RUN IN MORNING.
07/12/02
MU SWS TOOLS WITH ECLIPSE UPPER PACKER AND PATCH ASSEMBLY. PUMPED 147
BBLS HOT SW WITH 3 BBLS 50/50 METHANOL. DISCOVERED THAT WEAK POINT
FAILED LEAVING ENTIRE RUNNING ASSEMBLY DOWNHOLE. TOP OF FISH @ 9420' IF
STUNG INTO LOWER PACKER. FISH OAL = 46'. FREEZE PROTECT TUBING WITH 40
BBLS 50/50 METHANOL. RDMO SWS. LRS. <<< WELL SHUT-IN >>>
07/12/02
SLICKLINE GETTING RIGGED UP AND PT TO FISH E-LINE TOOLS 46' LONG. <<<
FOUND TOP OF FISH AT 123', STAND-BY FOR SCHLUMBERGER TO ARRIVE ON
LOCATION >>>
07/13/O2
PULLED E-LINE FISH 46' OVER ALL 15' E-LINE TOOLS AND 31' UPPER ECLIPSE PATCH --
-- D & T W/3.80" CENT, SB TOP OF LOWER PATCH @ 9444' SLM. <<< LEAVE WELL
SHUT IN >>>
07/14/02
SET ECLIPSE SERIES 3 STRADDLE PACKOFF ASSY AT 9435.5'-9466', MIN ID=2.24 STING
INTO LOWER PACKER ASSEMBLY PREVIOUSLY SET. PATCHING OVER THE INTERVAL
9435.4' - 9466'. LEAK ON SWS LDL DATED 5-0CT-2000 SHOWN AT9460', CALIPER LOG
SHOWED THE 23RD JOINT BELOW GLM #3 WAS LEAKING. SET DEPTH CHOSEN SO
THAT NEITHER PACKER WAS SET IN A COLLAR AND TO ADEQUATELY COVER
LEAKING JOINT. FP WITH 50/50 METH, NOTIFY PAD OP OF WELL STATUS. <<< LEFT
WELL SHUT-IN >>>
Fluids Pumped
BBLS
7 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 5
TESTS)
53 METHANOL
60 50/50 METHANOL WATER
150 FILTERED SW
147 WATER
417 TOTAL
Page 1
SCANNED JUL 2 1 2002
TREE = 4-1/16" 5M CIW
,WFILFEAD= 11"5MFMC I SAFETYNQTES
P-23
KB. ELEV = 87.8'I
BF. ELEV = 53.9'i
KOP = 600
' H
Max Angle= 821';~.~ I 2119' 4-1/2"OTIS SSSV I~P, D =3.813"
Datum MD = 11885'
DatumTVD = 8800' SS
GAS LFT MANDRELS
~'10-3/4" CSG, 45.5#, L-80, ID= 9.953" r-~ll 3322' , ~-~k ST MD TV D BEV TYPE VLV LATCH PORT DATE
5 3492 2894 43 OTIS BK
4 6204 4783 48 OTIS BK
3 8557 6399 47 OTIS BK
L 2 10364 7663 44 OTIS BK
I 11574 8544 37 OTIS BK
J II ' 9436'-9466' HECLIPSEPACKOFFPATCHASSEIVI3LY, D=2.24" I
" I
~ Minimum ID = 2.24" @ 9436' I ' ' 11631' H4-1/2"PKRSWSNIP, ID= 3.813"
I ,
ECLIPSE PACKOFF PATCH ASSY
I
X X I 11649' H7-~8"X4-1/Z'~WPER~KRI
I ' ~ 11681' H4-1/2"PKRSWSNIP, ID=3.813" I
a I
! I
I = I 11698' H4-1/2''PKRSWNNIP, ID: 3.725"
ITOPOF5-1'2"LNRH11705'I ~ ~ I11705' H5-1/2"T~NLNRTOPPKRI
14-1'Z'TBG, 12'6#,L-80,'0152bpf, D:3'958" H~o' I · ~ I ~o'H4-1'2"WLEG,'D:3.958"I
I 11698' HELMDTT LOGGED11/11/95 I
17-5/8'' CSG, 29.7#, NT-95HS, ID= 6.87~' H 11863' I '~ ·
, []
PERFORATION SUMMA RY
REF LOG: SWS BHCS, 09/05/93
ANGLEATTOPPERF: 29 @ 11988'
Note: Refer tD Production DB for historical perf data
SIZE SPF INTERVAL I Opn/Sqz ~ DATE
3-3/8" 6 11988-12036I O 12/06/96
3-3/8" 6 12044-12050 O 12/06/96
3-3/8" 6 12056-12070 O 12/06/96
, ' I
I ~TD H ~'~' I
15-1/2"LNR, 17#,L-80,.0232bpf, D=4.892" H 12275' j'
DATE REV BY COMIVENTS DATE REV BY corv'I'vlENTS PRUDHOEBAY LI,,IIT
09/08/93 LINDER ORIGINAL COIVI%~ION J WELL: P-23
03/04/01 I SIS~SLT CONVERTED TO CANVAS ! PERIVIT No: 1931120
03/08/01 SI~LG RNAL APl No: 50q:)2~22393~00
07/15/01 RN/KAK CORRECTIONS Sec. 31, T11N, R13E
07/14/02 CAO/KK PACKOFF PATCHASSEIVBLY J ~ Exploration (Alaska)
SCANNED JUl_
SIZE SPF INTERVAL Opn/Sqz DATE
3-3/8" 6 11988~ 12036 O 12/06/96
~3/8" 6 12044-12050 O 12/06/96
3-3/8" 6 12056-12070 O 12/06/96
DATE REV BY COMIVENTS DATE REV BY COIVIVIENTS
09/08/93 LINDER ORIGINAL COIVPLErlON
03/04/01 SIS~SLT CONVERTED TO CANVAS
03/08/01 SI~LG RNAL
07/15/01 RN/KAK CORRECTIONS
07/14/02 CAO/KK PACKOFF PATCH ASSEIVBLY
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request:
Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _
Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _
Change approved program _ Pull tubing _ Variance _X Perforate _
Other_
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
2597' FNL, 2077' FWL, Sec. 31, T11 N, R13E, UM
At top of productive interval
1042' FNL, 883' FEL, Sec. 32, T11N, R13E, UM
At effective depth
961' FNL, 854' FEL, Sec. 32, T11N, R13E, UM
At total depth
956' FNL, 755' FEL, Sec 32 T11 N, R13E, UM
5. Type of Well:
Development __
Exploratory __
Stratig raphic __
Service__._X
(asp's 631357, 5947411)
(asp's n/a)
(asp's 638674, 5949179)
(asp's 638773, 5949185)
6. Datum elevation (DF or KB feet)
RKB 87.1 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
P-23
9. Permit number / approval number
193-112
10. APl number
50-029-22393
11. Field / Pool
Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measu red
true vertical
Effective depth: measured
true vertical
Casing Length
Conductor 112'
Surface 3288'
Intermediate 1 1829'
Liner 570'
12275 feet Plugs (measured)
9230 feet
12059 feet Junk (measured) TD Tag @ 12059'. (09/14/2000)
9038 feet
Size Cemented Measured Depth
20" 280 c.f. Arcticset(Approx) 146'
10-3/4" 2016 c.f. 111/408 c.f. 'G' 3322'
7-5/8" 1825 c.f. Class 'G' 11863'
5-1/2" 140 c.f. Class 'G' 11705' - 12275'
Perforation depth:
measured Open Perfs 11988' - 12036', 12044' - 12050', 12056' - 12070'
true vertical Open Perfs 8976' - 9018', 9025' - 9030', 9036' - 9048'
Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 TBG @ 11649' MD. Tubing Tail @ 11698'.
True vertical Depth
146'
2693'
8707'
8512' - 9161'
RECEIVED
1 6 ZOO
Alaska Oil & Gas Cons. Commission
Anchorage
Packers & SSSV (type & measured depth) 7-5/8" x 4-1/2" TIW PERM, Latch Packer @ 11649' MD. 5-1/2" Liner Top Packer (TIW) @ 11705'
4-1/2" Otis SSSVLN @ 2119' MD.
13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __
15. Status of well classification as:
14. Estimated date for commencing operation
August 13, 2001
16. If proposal was verbally approved
Name of approver
Date approved
Oil __ Gas __
Service __Water Injection Well X
Suspended __
17.1 hereby cert. ify that the foregoing is true and correct to the best of my knowledge.
Signed 1f'~~ Title: Well Integrity Engineer
Joe Anders, P.E.
FOR COMMISSION USE ONLY
Questions? Call Joe Anders or Kevin Yeager, (907) 659-5102.
Date: August 13, 2001
Prepared by DeWayne R. Schnorr 564-5174
Conditions of approval: Notify Commission so representative may witness
Plug integrity__ BOP Test__ Location clearance__
Mechanical Integrity Test_~ ,.,, · Subsequent form required 10-
Approved by order of the Commission Original Signed By Commissioner Date
Cammy Oechsli
Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE
P-23
Sundry Application Action Plan
08/13/01
Well History and Status
Well P-23 (PTD 175-026) is an injector that failed an MIT-IA on 09/11/00. The well was
SI until 8/01 when injection was restarted post-passing CMIT TxlA. Recent events:
> 09/11/00:
> 10/02/00:
> 10/03/00:
> 10/05/00:
> 10/08/00:
> 11/18/00:
> 02/19/01:
> 06/23/01:
> 07/10/01:
> 07/14/01:
min.
MIT-IA Failed, .6 BPM @ 2500 psi.
SL set TTP.
MIT-T Failed, 1 BPM @ 2000 psi.
LDL located leak 9460'.
SL pulled TTP.
MITIA failed, LLR 2.5 BPM @ 2000 psi.
SL set plug @ 11676', ran Kinley caliper.
CMIT TxlA Failed, LLR 1 bpm @ 2000 psi.
WL pulled the re-set TTP @ 11631' (MD).
CMIT T x IA Passed to 2400 psi. IA lost 25 psi 1st 15 min, 10 psi 2nd 15
> 07/19/01: SL pulled TTP.
This sundry request is to allow for continued injection of water into Well P-23. The
following supports the request:
- A CMIT-TxlA Passed on 07/14/01 to 2400 psi against a tubing plug,
demonstrating competent production casing.
- Pressures and injection rates will be monitored and recorded daily and checked
for indications of a production casing leak.
- A CMIT TxlA against a TTP will be conducted every 2 years to confirm
production casing integrity.
Proposed Action Plan
1. Allow well to continue water-only injection.
2. Perform combination MIT Tubing x IA against a plug every 2 years.
3. Record wellhead pressures and injection rates daily.
4. Submit a monthly report of daily pressures and injection rate.
5. Stop injection and notify the AOGCC if there is any indication of loss of production
casing integrity.
TREE = 4-1/16" 5M ClW
'
P 23 SAFE-Pr'NOTES
ACTUATOR = BAKER
KB. ELEV = 87.8'
ELEV = 53 9',
iKOP = ~ ,
Max Angle= ~ ' 1fl4-1/2" SSSV NIP, = !
11~'~'A;'I ~ I I 2119' o-ns D 3.813"
DatumMD=
Datum -I-VD = 88~3~ SSl
i
GAS LFT MANDRELS
110-3/4" CSG, 45.5#, L-80, ID = 9.953" I--~ 3322' ~--~ ~k SZ5 3492M~~~2894TV'--~"~43 ~OTIS ~~~V---~LATCHPBK OR'----f DA~"'~'
4 6204 4783 48 OTIS BK
'~ 3 8557 6399 47 OTIS BK
2 10364 7663 44 OTIS BK
I 11574 8544 37 OTIS BK
Minimum ID: 3.725" @ 11698'
4-1/2" PARKER SWN NIPPLE I I J 11631' Jd4-1/2"PKRSWSNIP, ID= 3.813" J
~ ~~ ~4~' I-I~¢,~"xa-~,~"~R~ I
I I t11601' H4-1/2""KRSWSN'",'D=3.813"I
I I t 11698' H4-1/2"PKRSWNN'P, ID: 3.725" I
~~t 11705' HS-1/2"TIWLNRTOPPKRI
I~o~ ~-~,~"..~ H. ~o~' I~~1
I"gl/2"TBe, 12.e#,l-80,.0152bpf, D=3.958"I-I ~'~o'I -~ ,
~- ~ I 11710' I--~4-1/2"WLEG,,D= 3.958"I
I 11698' HELMD'FI-LOOG[D 11/11/95 I
.ERFORA'I'IO N SUM MA RY [
RI~: LOG: SWS BHCS, 09/05/93
ANGLEAT IO..I~F: 29 @ 11988'
Noto: Rofor to R'oduction DB for historical porf data
i SIZE SPF INTERVAL Opn/Sqz DATE I
i 3-3/8" 6 11988-12036 O 12/06/96
I
3-3/8" 6 12044-12050 O 12/06/96
3-3/8" 6 12056-12070 O 12/06/96
I
I*~T~ Iq ~2~4' I,
5-112"INR, 17#,L-80, .0232 bpf, D =4.892" I'~ 1227S'
DATE REV BY ! COMIVENTS DATE REV BY COIVlVlB'4TS PRUDHOEBAY UNIT
09/08/93 LINDER iORIGINAL COIVPLETION WELL: P-23
03/04/01 SIS-SLT CONVERTED TO CANVAS PERIVIT No: 93-1120
03/08/01 SIS-LG FINAL APl No: 50-029-22393-00
07/15/01 RN/KAK CORRECTIONS Sec. 31, T11N, R13E
BP Exploration (Alaska)
SIZE SPF INTERVAL Opn/Sqz DATE
3- 3/8" 6 11988-12036 O 12/06/96
3-3/8" 6 12044-12050 O 12/06/96
3-3/8" 6 12056-12070 O 12/06/96
DATE REV BY COMIVENTS DATE REV BY COIVlVlB'4TS
09/08/93 LINDER ORIGINAL COIVPLETION
03/04/01 SIS-SLT CONVERTED TO CANVAS
03/08/01 SIS-LG FINAL
07/15/01 RN/KAK CORRECTIONS
II
(
BP Exploration Alaska Inc.
Post Office Box 196612
PRB-24
Anchorage, Alaska 99519-6612
August 13, 2001
Mr. Tom Maunder, P.E.
Alaska Oil & Gas Conservation Commission
333 W. 7th Ave.
Anchorage, Alaska 99501
Subject: 12-21 (PTO 184-048) Application for Sundry Approval
A-17 (PTO 180-122) Application for Sundry Approval
P-23 (PTO 193-112) Application for Sundry Approval
Dear Mr. Maunder:
Attached is Application for Sundry Approval form 10-403 for wells 12-21, A-17 and P-
23. These requests are for approval to continue produced water injection with known
tubing x inner annulus communication. A proposed Action Plan and wellbore schematic
is included for each well.
If you require any additional information or clarification, please contact either Kevin
Yeager or me at (907) 659-5102.
Sincerely,
l~nCf:::
Well Integrity Engineer
Attachments
RECEIVED
AUG 1 ß ?nn1
Atasks Oil & Gas Cons. Commission
ÀP.,chorage
.... RECEIVED
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 8 Z001
REPORT OF SUNDRY WELL OPERATION i s aoil co s. Commission
1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ PerlorateArlc_,horage
Ann-Com & Caliper Pull tubing_ Alter casing _ Repair well _ Other_X
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
2597' FNL, 2077' FWL, Sec. 31, T11 N, R13E, UM
At top of productive interval
1042' FNL, 883' FEL, Sec. 32, T11 N, R13E, UM
At effective depth
961' FNL, 854' FEL, Sec. 32, T11N, R13E, UM
At total depth
956' FNL, 755' FEL, Sec. 32, T11 N, R13E, UM
5. Type of Well:
Development __
Exploratow~
Stratigraph lc__
Service__X
(asp's 631357, 5947411)
(asp's n/a)
(asp's 638674, 5949179)
(asp's 638773, 5949185)
6. Datum elevation (DF or KB feet)
RKB 87 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
P-23
9. Permit number / approval number
193-112
10. APl number
50-029-22393
11. Field / Pool
Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Conductor 112'
Surface 3288'
Production 11829'
Uner 570'
12275 feet Plugs (measured)
9230 feet
12059 feet Junk (measured)
9038 feet
,..
td Tag @ 12059'. (09/14/2000)
Size Cemented Measured Depth True Vertical Depth
20" 280 c.f. Arcticset (Approx.) 146' 146'
10-3/4" 2016 c.f. 111/408 c.f. 'G' 3322' 2693'
7-5/8" 1825 c.f. Class 'G' 11863' 8707'
5-1/2" 140 c.f. Class 'G' 11705' - 12275' 8512' - 9161'
Perforation depth:
measured Open Perfs 11988'- 12036', 12044' - 12050', 12056'- 12070'
true vertical Open Perfs 8976' - 9018', 9025' - 9030', 9036' - 9048'
Tubing (size, grade, and measured depth)
Packers & SSSV (type & measured depth)
4-1/2", 12.6#, L-80 TBG @ 11649' MD. Tubing Tail-@ 11698'.
7-5/8" x 4-1/2" TIW PERM, Latch Packer @ 11649' MD, 5-1/2" Liner Top Packer @ 11705'.
4-1/2" Otis SSSVLN @ 2119' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached-)-
Treatment description including volumes used and final pressure
14.
Prior to well operation
Subsequent to operation
Oil-ELl
Representative Daily Avera.qe Production or Injection Data
Gas-Md Water-ELl
Casing Pressure Tubing Pressure
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
16. Status of well classification as:
Oil __ Gas __ Suspended __
Service __X (Water Injection Well).
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
DeW'a, ne''%''~~ ~_____.~)~ Title; Technical Assistant
y R. Schnorr
Date June 26, 2001
Prepared by DeWayne R. Schnorr 564-5174
ORI61NAL
Form 10-404 Rev 06/15/88 ·
SUBMIT IN DUPLICATE
P-23
Description of Work Completed
NRWO OPERATIONS
01/02/2001
01/19/2001
02/18/2001
02/19/2001
02/25/2001
06/23/2001
CALIPER: DRIFT W/3.70" CENT TO 11,700' SLM (PRE-
CALIPER)
CALIPER: CALIPER SURVEY
CALIPER: DRIFT, CALIPER SURVEY, SET PLUG (ANN COM)
ANN-COMM: SET TTP (ANN COM) (CONTINUED)
ANN-COMM: CMIT TXIA
ANN-COMM: CMIT- TBG X IA
SUMMARY
01/02/01 DRIFT W/3.7" CENT TO 11,700' SLM (PRE-CALIPER).
01/19/01 RUN 3.63" CENT W/KINLEY CALIPER TO 7803' SLM. UNABLE TO GO
DEEPER. HAVE TO SPANG OUT. RDMO. ****TALK W/PAD OPERATOR. WELL LEFT
·
:.
SHUT IN.**** ~.
02/18/01 DRIFT 3.80 SWAGE & 3.50 D-GUN TO XN @ 11680' SLM. 2) KINLEY
CALIPER SURVEY TBG FROM 11690' SLM. LEAVE WELL SHUT IN.
02/19/01 SET XXN PLUG @ 11676' SLM (NOTE---> 400# SITP, FLUID LEVEL @ 170'
AT TIME OF SET). 2) RUN CHECK SET TO PLUG AND VERIFY GOOD SET. WELL
LEFT SHUT IN.
02/25/01 CMIT TXIA FAILED, 10.5 GPM @ 180 PSI. T/FO: 280/VAC/VAC CMIT
TXIA FAILED TBG FL @ 200' IA FL @ 60' PUMPED 24 BBLS METHANOL DOWN IA
AND COULD NOT GET IT TO PRESSURE UP. PUMPED ENTIRE VOLUME @ 180
PSI. ESTABLISHED LLR OF 10.5 GPM @ 180 PSI. SHUT DOWN WHP'S 300/100/VAC
MONITORED FOR 45 MIN. TBG AND IA FL @ SURFACE. FINAL WHP'S 200/10/VAC
06/23/01 REPEAT CMIT TBG X IA FAILED, LLR 1.1 BPM @ 2000 PSI ** WILL
REQUEST PULL AND RE-RUN TTP ** T/I/O - 400/220/0. CMIT- T X IA FAILED. TBG
& IA FL'S @ SURFACE. ATTEMPTED TO PRESSURE TBG & IA TO 2000 PSI AT 1
BPM. PRESSURES REACHED 1000 PSI. PUMPED 11 BBLS AT I BPM @ 1000 PSI.
INCREASED RATE TO 1.5 BPM. PRESSURES INCREASED TO 2000 PSI. SD AND
MONITORED PRESSURES FOR 5 MIN. PRESSURES DROPPED FROM 2000 PSI TO
1150 PSI. REPRESSURED TBG & IA TO 2000 PSI. ESTABLISHED INJECTIVITY
RATE OF 1.1 BPM AT 2000 PSI. WITH 10 BBLS OF DIESEL. SD AND MONITORED
PRESSURES FOR 15 MIN. PRESSURES DROPPED FROM 2000 PSI TO 800 PSI.
BLED REMAINING PRESSURE BACK. FINAL WHP'S = 600/300/0.
Fluids Pumped
BBLS. Description
4 PRESSURE TEST LUBRICATOR TO 2500 PSWI W/DIESEL (4 TRIPS TO WELL).
24 METHANOL
60 DIESEL
88 TOTAL
193-112-P23mitfait100800.txt
Subject: Re: P-23i (193-112) Leak Detection Logging
Date: Sun, 08 Oct 2000 12:24:58 -0800
From: Tom Maunder <tom maunder@admin.state.ak.us>
To: "PBU, Well Integ T L" <pbuwetlintegtl@bp.com>
Kevin,
Sounds like a good plan. I'll look forward to receiving the sundry. I
don't
suspect there will be anything controversial regarding it.
Tom
"PBU, Well Integ T L" wrote:
> Tom,
>
> A follow up on this well after it failed the MIT test, leak detection
> logging was performed this weekend and the tubing was discovered to ha
vea
> small hole at 9460'. A sundry notice will be forthcoming latter this w
eek
> and remedial action will be discussed with our town engineers to defin
e a
> remedial way forward. Would like to keep the well on water injection o
nly
> for the time being if you approve. Please advise if further informatio
n is
> required.
>
> Thanks.
>
> Kevin.
>
> Joe Anders, PE / Kevin Yeager
> Well Integrity Engineer
> BP Exploration, Alaska Inc.
> (907) 659-5102 - Work
> (907) 659-5100, x1154 - Pager
>
> Joe Anders / Kevin Yeager
> 659-5102, work
> 659-5100, x1154, pager
>
> <<...>>
Page 1
Re: P-23 (193-112) Failed MITIA 'r'-* .~ '-- '
Subject: Re: P-23 (193-112) Failed MTIA
Date: Mon, 02 Oct 2000 11:09:30 -0800
From: Tom Maunder <tom_maunder@admin.state.ak. us>
To: "PBU, Well Integ T L" <pbuwellintegtl@bp.com>
Joe/Kevin,
Thanks for the information. Did the failure get lost in the shuffle up
there? I don't remember seeing anything on a failure in September. Also,
please include the permit to drill number in the message title. It helps with
our filing and tracking.
Tom
"PBU, Well Integ T L" wrote:
Heflo Tom. Injection Weft P-23 (PTD 193¢ 120) failed a recent MIT-IA. On
9/11/00, an MIT-IA failed and a liquid leak rate of.6 BPM @ 2500 psi down
the IA was established.
Our plan is to set a tubing tail plug, run a leak detect log then pressure
test the production casing.
Please call if you have any questions.
Joe Anders, PE / Kevin Yeager
Well Integrity Engineer
BP Exploration, Alaska Inc.
(907) 659-5102 - Work
(907) 659-5100, xl 154 - Pager
ITom Maunder <tom maunderC, admin.state.ak, us>
P--~roleTm ~eer
Alaska Oil and Gas Conservation Commission
1 nf 1 10/2/00 11:09 AM
': ..... · STATE OF ALASKA
A. KA OIL AND GAS CONSERVATION COMMIS,.,:.DN
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown
Stimulate__ Plugging__ Perforate__
Pull tubing Alter casing Repair well I
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
2598' NSL, 2077' EWL, SEC. 31, T11N, R13E
At top of productive interval
1042' SNL, 883'WEL, SEC. 32, T11N, R 13E
At effective depth
958' SNL, 792' WEL, SEC. 32, T11N, R 13E
At total depth
1036' SNL, 750' WEL, SEC. 32, T11N, R13E
12. Present well condition summary
Total depth: measured
true vertical
5. Type of Well:
Developmec¢~
Exploratory
Stratigraphic .~_
Servi~c~__ [.~/~-.[
Effective depth: measured
true vertical
ORIGINAL
Other X cQnverted well to in.ie,
Il,.
6. Datum elevation (DF or KB)
KBE=87.1 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
P-23(41-32-11-13)
9. Permit number/approval number
93-112 / 95-140
10. APl number
50- 029-22393
11. Field/Pool
Prudhoe Oil Pool
12275 feet Plugs (measured)
9230 feet
12194 feet Junk (measured)
9158 feet
Casing Length Size Cemented Measured depth True vertical depth
Structural -- BKB
Conductor 112' 20" 280 c f Arcticset(Approx) 112 112
Surface 3288' 10 3/4" 2016 c.f. 111/408 c.f. "G" 3322 2860
Intermediate 11829' 7 5/8" 1825 c.f. Class "G" 11863 8867
Production --
Liner 570' 5 1/2" 140 c.f. Class "G" 11705-12275 8736-9230
:tot
Perforation depth: measured 11988' - 12036', 12044'- 12050', 12056'- 12070'
true vertical subsea 8976'- 9018'
Tubing (size, grade, and measured depth) 4 1/2", 12.6# L-80 @ 11710
Packers and SSSV (type and measured depth) Packer @ 11649 & SSSV@2119
13. Stimulation or cement squeeze summary Converted weft from producer to injector on August 29, 1995
Intervals treated (measured) ,!AN 0 5 1996
Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission
Anchorage
14.
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure
Tubing Pressure
Prior to well operation 1200 346 291 1920 279
Subsequent to operation
1054 1184 384 3070 286
15. Attachments ~ 16. Status of well classification as: .~-~_
Copies of Logs and Surveys run I _~ ~//~ ~.~ J I'~/ . ¥
Daily Report of Well Operations I~ Gas Suspended Service~
17. I hereby/~¢Tertify that t,b~foregoing is true and correct ~ the best of my knowledge.
Signed -- Title Supervisor Waterflood/Miscible Flood
Form 10-404 Rev 06/15/88.~ SUBMIT IN DUPLICATE
LARRY GRANT
Attn. ALASKA OIL + GAS CONSERVATION
3001 PORCUPINE DRIVE
~NCHORAGE
AK, 99501.
Date: 20 November 1995
Transmittal of Data
Sent by: HAND CARRY
..
:
Dear Sir/Madam,
Enclosed, please find the data as described below:
DESCRIPTION
1 PLS FINAL BL+RF
Run # 1
R-04 ,(22-05-11-13) 1 PFC/PERF FINAL BL+RF Run ~ 1
M-30 q ~_/~O 1 PLS FINAL BL+RF Run
P-23 (41-32-11-13) _ ~ ,1~ PLS FINAL BL+RF Run # 1
A-08 {23-3~-1!-13') P~C/~ ~I~ B~+R~ Run
~ COL ~I~ BB+R~ Run
F-43 q (/0~- ~ b 1 PLS FIN~ BL+~ Run ~ 1
ECC No.
2187.07 ''
5627.10
5671.02
5957.05
6043.04
6163.03
6236.05
Please sign and return to: Attn. Rodney D. Paulson
· Atlas Wireline Services
5600 B Street
Suite 201
Anchorage, AK 99518 ~~/
Or F~ to (907) 56~
Received by: ~~ Date
STATE OF ALASKA
AL,~,.,r(A OIL AND GAS CONSERVATION COMMIS,.,.,.)N
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __
Alter casing __ Repair well __ Plugging __ Time extension Stimulate __
Change approved program __ Pull tubing __ Variance __ Perforate __ Other X
2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB)
BP Exploration (Alaska)/nc. Development x KBE=87.1
Exploratory __
3. Address Stratigraphic__ 7. Unit or Property name
P. O. Box 196612, Anchorage, Alaska 99519-6612 service__ Prudhoe Bay Unit
4. Location of well at surface 8. Well number
2598' NSL, 2077' EWL, SEC. 31, T11N, R13E
At top of productive interval
1042' SNL, 883'WEL, SEC. 32, T11N, R13E
At effective depth
958' SNL, 792' WEL, SEC. 32, T11N, R13E
At total depth
1036' SNL, 750' WEL, SEC. 32, T11N, R13E
P-23(41-32-11-13)
9. Permit number
93-112
10. APl number
50- 029-22393
11. Field/Pool
Prudhoe Oil Pool
feet
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
12275 feet Plugs (measured)
9230 feet
12194 feet Junk (measured)
9158 feet
Casing Length
Structural --
Conductor 112'
Surface 3288'
I nte r mediate 11829'
Production --
Liner 570'
Perforation depth:
Size Cemented
20" 280 c f Arcticset(Approx)
10 3/4" 2016 c.f. 111/408 c.f. "G"
75/8" 1825 c.f. Class "G"
5 1/2" 140 c.f. Class "G"
measured 11988'-12036', 12044'-12050', 12056'-12070'
true vertical subsea 8976'- 9018'
Tubing (size, grade, and measured depth) 4 1/2", 12.6#L-80 @ 11710
Packers and SSSV (type and measured depth) Packer @ 11649 & SSSV@2119
Measured depth True verticaldepth
BKB
112 112
3322 286O
11863 8867
11705-12275 8736-9230
,.i ;v' ED
AUG l 0 1995
Nask,3 0il & Gas Cons. Commission
13. Attachments - Description summary of proposal__
Convert we//from producer to injector
Detailed operations program__
BOP sketch
14. Estimated date for commencing operation 15. Status of well classification as:
August 10, 1995
16. If proposal was verbally approved Oil X Gas __ Suspended __
Name of approver B. Wondze// 8/7/95 Date approved Service
17. I hereby ff~/j~(/that the f~iegoing is true and correct to the best of my knowledge.
FOR COMMISSION USE ONLY
Conditions of approval: '~
Notify Commission so representative may witness
Plug integrity_ BOP Test__ Location clearance
Mechanical Integrity Test ~ Subsequent form required 10- ]~(~¢¢'
Original Signed By
Approved by order of the Commission 13mild W ,inhnston
Form 10-403 Rev 06/15/88
I Approw,
Approved Copy
Returned,/,~ ~-'"
SUBMIT IN T~PLICATE
STATE OF ALASKA ........
OIL AND GAS CONSERVATION COMMI:
REPORT SUNDRY WELL OPEHATIONS
1. Operations performed: Operation shutdown Stimulate Plugging
Pull tubing__ Alter casing __ Repair well_
Perforate
Other__
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. 0. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
2598' NSL, 2077' EWL, SEC. 31, T11N, R13E
At top of productive interval
1042'SNL, 883'WEL, SEC. 32, T11N, R13E
At effective depth
958' SNL, 792' WEL, SEC. 32, T11N, R13E
At total depth
1036'SNL, 750' WEL, SEC. 32, T11N, R13E
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
6. Datum elevation (DF or KB)
KBE=87.1 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
P-23(41-32-11-13)
9. Permit numbe#approvalnumber
93-112 /
10. APInumber
50- 029-22393
11. Field/Pool
Prudhoe Oil Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length Size
Structural --
Conductor 112' 20"
Surface 3288' '0 3/4"
Intermediate 11829' 7 5/8 '
Production --
Liner 570' 5 1/2"
Perforation depth: measured 11988'- 12036'
12275 feet
9230 feet
12194 feet
9158 feet
Plugs (measured)
Junk (measured)
Cemented
280 c f Arcticset(Approx)
2016 c.f. 111/408 c.f. "G'
1825 c.f. Class 'G'
140 c.f. Class 'G'
true vertical subsea 8976'- 9018'
Tubing (size, grade, and measured depth) 4 1/2", 12.6#L-80 @ 11710
Packers and SSSV (type and measured depth) Packer @ 11649 & SSSV@2119
13. Stimulation or cement squeeze summary See Attachment
Intervals treated (measured)
Treatment description including volumes used and final pressure
Measured depth
112
3322
11863
11705-12275
True vertical depth
BKB
112
286O
8867
8736-9230
RECEIVED
JUN -7 !995
u~ 6 ~as uons. Commission
~ch0r: -,
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure
1200 346 291 1920
1054 1184 384 3070
Tubing Pressure
279
286
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil X Gas Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Signed~.~~ /,~ ~.~ Title SeniorTechnicalAssistantll
Form 10-404 Rev 06/15/88 7'-
/
Date
SUBMIT IN DOPL'~CATE
6/11/94
WELL P-23(41-32-11-13)
Addperf
The following additional interval were perforated using 3 3/8"
guns, 6 SPF, random orientation and 60°phasing.
12044- 12050 MD
12056- 12070 MD
RECEIVED
, ~chor~_.'-'"
F' [: R H I T
8 3 .... 1 i '~
83 ..... i i2
93" ! I 2
83 .... i i 2
8~ ..... i '!2
83'-'-"'i I2
9~ .... I 'i2
D ~'l/'
I i'l V e i'l ti ~";, r" y
5 8 '~- 9
DAIL. Y W-ULLL .
::; !J R V E Y
B H C S/G R
G R / C :' L/, I W L )~::~ 'i ..,
PFC/Gl~/r'oi...(. , .... P:cRF) ~F: 1 .~
~ 114.88 12'i75
1833-" 12100
F' FC/,S R/'C L.
PI!../S F L/G R
/'q R /"-' P i..
SBL/., , .......
I'.' ,Fi ':i ,:: l
I),:::,1 e" {)/, "2()/95
I~ !.1 i',! 12' A 'i' ['..: ..... i:?. E C V b
..................
1 ~1}/' ;it i / 'i .9 9 ?
~)9/2 /,/ 'i 983
ii 9/'27/ i 89 ,ii
(/!.) 'o7 ' i9q ?'
· // ,; ,/ . ,.. 0
"'i 9 q 3
{) l;t/' I E; / .~,
1 0//OA / 'i 9 9 '2
iO/r'}a.,/'in°
.. .:? ...., 3
i 0 6/' 2 .~.~/' 'i 9 9 ;'4
0 9/ i 6/ '1 9 St 3
"i 9 q ~''
i I)/0 .q/, ......
0 l~/" 2' 8 / 'i 9 94
~d 'i' t. c h s a m p 1 e s r'e q u 'i r' e d ({:' y e s :_: r" e e el":: 'y' e: ::~
we'l'i cor'ed? yes ~~,nalys'is & ct~p !: "i o r/ r"ece'ive,:':!'?
r" e v./e I 'i t e s t s r' e q u '¥ i-" e d '.' V e s ~ R e c e 'i v e d ? ~ e s r,.,..:,
W,.'..::ii '¥s i'n compJ'¥ance ._. '_~
,.
i n ~ !: '¥a 1
'3 ("H H :' '
· ~:::: N S
y (: :!; i"l O
RECEIVED
Ji. JN £ ,1 1994
Alaska Oil & Gas Cons. Commission
Anchorage
. .
·
·
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Dear Sir/Madam,
Date: 15 June 1994
RE:
Transmittal of Data
Sent by: ANCHORAGE EXPRS
Enclosed, please find the data as described below:
WELL # DESCRIPTION
ECC No.
R-10
F-34 (44-35-12-13)
/1 PLS PRESURE FINAL BL
1 PLS.PRESURE RF SEPIA
'/_ PLS/ PRESURE FINAL BL
1 PLS PRESURE RF SEPIA
Run # 1 5823.01
Run # 1
Run # 1
Run # 1
61~1.02
H-13
/1 PFC/GR/PERF FINAL EL
1 PFC/GR/PERF RF SEPIA
Run # 1 6090.01
Run # 1
C-30
~ PFC/PERF FINAL BL
1 PFC/PERF RF SEPIA
Run # 1 3983.01
Run # 1
H-25
/1PFC/GR/PERF FINAL BL
1 PFC/GR/PERF RF SEPIA
Run # 1 5666.02
Run # 1
H-19 (22-15-11-13)
~ PFC/PERF FINAL BL
1 PFC/PERF RF SEPIA
Run # 1
Run ~ 1
3448.01
R-27
.
P-23 (41-32-11-13)
//1 PFC/PERF FINAL BL
1 PFC/PERF RF SEPIA
/1 PFC/PERF FINAL BL
i PFC/PSRF RF SSPIA
Run # 1 5670.03
Run # 1
Run # 1 6043.03
Run # 1
H-32 (42-20-11-13)
/1 PFC/PERF FINAL BL
1 PFC/PERF RF SEPIA
Run # 1 6170.04
Run # 1
H-31
/1 PFC/PERF FINAL BL
1 PFC/PERF RF SEPIA
Run # 1 6158.04
Run # 1
N-21
/! DTEMP/GR FINAL BL
1 DTEMP/GR RF SEPIA
Run # 1 5630.01
Run # 1
C-ll
/1 DTEMP FINAL BL
1 DTEMP FINAL RF SEPIA
Run # 1 5942.01
Run # 1
Cont/
STATE OF ALASKA
, -....~
ALAS 3IL AND GAS CONSERVATION COMMISSIC
REPORT OF SUNDRY WELL OPEhATIONS
1. Operations performed: Operation shutdown Stimulate Plugging
Pull tubing Alter casing Repair well
Perforate
Other ×
2. Name of Operator
BP Exploration (Alaska) inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
2598' NSL, 2077' EWL, SEC. 31, T11N, R13E
At top of productive interval
1042' SNL, 883'WEL, SEC. 32, T11N, R13E
At effective depth
958' SNL, 792' WEL, SEC. 32, T11N, R13E
At total depth
1036'SNL, 750' WEL, SEC. 32, T11N, R13E
5. Type of Well:
Development X
Exploratory
Stratigraphic
Service
6. Datum elevation (DF or KB)
KBE=87.1 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
P-23(41-32-11-13)
9. Permit number/approval number
93-112 /
10. APl number
50- 029-22393
11. Field/Pool
Prudhoe Oil Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
12275 feet
9230 feet
12194 feet
9158 feet
Casing Length Size
Structural --
Conductor 112' 20"
Surface 3288' '0 3/4"
Intermediate 11829' 7 5/8"
Production --
Liner 570' 5 1/2"
Perforation depth: measured 11988'- 12036'
Plugs (measured)
Junk (measured)
Cemented
280 c f Arcticset(Approx)
2016 c.f. 111/408 c.f. "G"
1825 c.f. Class "G"
140 c.f. C/ass "G"
Measured depth
112
3322
11863
11705-12275
True vertical depth
BKB
112
286O
8867
8736-9230
true vertical subsea 8976'- 9018'
Tubing (size, grade, and measured depth) 4 1/2", 12.6,fL-80 @ 11710
Packers and SSSV (type and measured depth) Packer @ 11649 & SSSV@2119
RECEIVED
13. Stimulation or cement squeeze summary See Attachment
Intervals treated (measured)
Treatment description including volumes used and final pressure
Gas Cons. Cornmissior~
Anchorage
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
420 -2 0 793
1930 2294 846 1354
Tubing Pressure
225
301
15. Attachments
Copies of Logs and Surveys run
Daily Report of Well Operations
16. Status of well classification as:
Oil X Gas Suspended
Service
17. I hereby ce. rtify that thee forego~., is true and correct to the best of my knowledge.
Signed ~.-"~w~ Title Senior Technical Assistant I
Form 10-404 Rev 06/15/88 /
SUBMIT IN DUeLlO/ATE
WELL P-23(41-32-11-13)
FRAC
10/28/93
fjh
6/13/94
Performed a Hydraulic Fracture using the following fluids:
OPERATIONAL PROBLEMS
Battery went dead on one pump on DF#2, causing pump to quit.
We sd anyway, because of concern that fluid was not x-linked.
Turned out to be a sample port was sampling a different fluid.
Got back on it and satisfactorily finished dfg2.
Comments
TSO looked like it came a bit early, but had very nice looking
pressure rise. Should be well packed, and a good frac though.
Note that original design called for 143 bbls of 8# for 2200 psi
pressure rise. At the last minute, this was jacked up to 2800 psi
pressure rise and 184 bbls 8#. I think we probably got
something reasonable (if you re-run the TSO with 8.5' time to end
of job, one obtains 1600 psi pressure rise and 103 bbls 8#
pumped). By slowing the rate to 15 bpm prior to pad on perfs, we
allowed some of the linear gel to leak off so we probably had an
area closer to what we really wanted. Note sand:pad ratio of 20:1 !
Total sand placement was somewhat less, because due to
constraints in ramping we took longer to get to 8#. Since this is
further back in the frac, it shouldn't have much impact.
FLUIDS PUMPED DOWNHOLE
INJ TEST: 51
5 Bbls
317 Bbls
DATA FRAC#1
65 Bbls
176 Bbls
DATA FRAC#2:
69 Bbls
176 Bbls
FRAC: 30 Bbls
25 Bbls
15 Didy
1
2
4
6
9
12
187
104
Bbls 35% xylene/65% diesel
diesel
20# Gel
20 Bbls 40~ Gel Prepad To Establish Rate
40# X-Link Gel Pad W/*.*% Esl (*** Gal)
20# Gel Data Frac Flush
20 Bbls 40~ Gel Prepad To Establish Rate
40# X-Link Gel Pad
20# Gel Data Frac Flush
40# Gel Prepad To Establish Rate
40# X-Link Gel Pad
1 Ppg
2 Ppg
3 Ppg
4 Ppg
5 Ppg
6 Ppg
7 Ppg
8 Ppg
20# Linear Gel Flush
RECEIVED
'Ui~, 1 5 'i994
Gas Cons. Cornmissior,
Anchorage
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Date: 19 April 1994
Transmittal of Data
Sent by: ANCH. EXPRESS
Dear Sir/Madam,
Enclosed, please find the data as described below:
WELL # DESCRIPTION
$1-5 c-19
1 PLS PROFILE FINAL BL
1 PLS PROFILE RF SEPIA
~-~ ' B-29 (32-3'1-11-14)
PLS STATIC FINAL BL
PLS STATIC RF SEPIA
D-22 (42-23-11-13)
./1 PLS STATIC FINAL BL
1 PLS STATIC RF SEPIA
G-16 (44-11-11-13)
/1 PLS STATIC FINAL BL
1 PLS STATIC RF SEPIA
G-17 (12-18-11-14)
j 1 PLS STATIC FINAL BL
1 PLS STATIC RF SEPIA
/PLS STATIC FINAL BL
I PLS STATIC RF SEPIA
P-23 (41-32-11-13)
H-31
1 PLS STATIC FINAL BL
1 ~STATIC RF SEPIA
/1 PLS STATIC FINAL BL
1 PLS STATIC RF SEPIA
c-2c
/1 PL STATIC FINAL BL
t PL STATIC RF SEPIA
Cont/
Run # 1
Run ~ 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1
Run # 1. · :
Run # 1 -
Run # 1
Run # 1
Run # 1
ECC No.
5746.02
5818.02
6091.03
1130.03
1113.04
5785.01
6043.02
6158.01
3267.01
No. BP0005
SCHLUMBERGER GEOQUEST
INTERPRETATION AND COMPUTING SERVICES
500 W. INTERNATIONAL AIRPORT ROAD
ANCHORAGE, ALASKA 99518-1199
COMPANY '
LOCATION :
ATTENTION ·
STATE OF ALASKA
ALASKA OIL & GAS CONSERVATION ~..
3001 PORCUPINE DRIVE
LARRY GRANT
OCTOBER 21, 1993
WELL NAME '
SERVICES '
Y-17A
I OH LIS TAPE
WELL NAME '
SERVICES ·
NO. OF BOXES: 1 NO. OF BOXES:
JOB NO. · 93435 JOB NO. '
1 OH LIS' TAPE
INCLUDED IN ABOVE BOX
93412
WELL NAME '
P-23 (41-32-11-13)
SERVICES ' I OH LIS TAPE
WELL NAME '
SERVICES '
NO. OF BOXES: TNQI_Ill')Fn _TN ABOVE BOX NO. OF BOXES:
JOB NO. ' 93418 ~' JOB NO. ·
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP EXPLORATION (ALASKA)INC.
PETROTECHNICAL DATA CENTER, MB3-3
900 EAST BENSON BLVD.
ANCHORAGE, ALASKA 99519-6612
SCHLUMBERGER COURIER:
DATE DELIVERED:
SCHLUMBERGER GEOQUEST
500 WEST INTERNATIONAl,AIRPORT ROAD
ANCHORAGE, ALASKA 99~ ~~,,
v ~,-.- - ~%~a Oil, 2 7 199,~
RECEIVED BY: ~ ~g~ ~ ~
INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT
PERMIT DATA DETAIL
10/08/1993
PAGE · I
93-I12 BHCS/GR
93-112 GR/CCL(JWL)
93-112 PFC/GR/CCL(PERF)
93-112 PIL/SFL/GR
93-112 SBL/GR/CCL
93-112 407
93-112 DAILY WELL OP
93-112 SURVEY
R1,2&5",l1854-12228
R1,5",11488-12175
R1,5",11833-12100
R1,2&5",10750-12259
R1,5",11488-12175
COMP DATE:09/16/93
08/23/93-09/09/93
MAGNETIC MULTI-SHOT
Are well tests required?
Was well cored? Yes
SUMMARY
Yes No
No
If yes, was the core analysis & description received?
Are dry ditch samples required? Yes No
Yes No
WELL IS IN COMPLIANCE.
INITIAL
COMMENTS:
BP EXPLORATION
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
RO. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
DATE: 09/22/93
T# 85045
BPX/PBU~LOGS
Enclosed is your copy of the materials listed below. If you have any
questions, please contact BP Well Records at (907) 564-4004.
BRIDGE PLUG 09/15/93
A-24 ZA-70 CNL / G~/cC~ 09/18/93
A-4095-1~ PRODUCTION LOG~ 09/17/93
C-03 Q~ PRODUCTION LOG ~' 09/15/93
D-09'~-~5 ~PERF)~F&/dC~ 09/16/93
D-27 ~-~ ~PERF3 9fi~. eCU 09/16/93
G-~077~¥~ PRODUCTION LOGv/ 09/14/93
09/13/93
09/16/93
09/16/93
09/16/93
09/18/93
09/17/93
09/13/93
09/13/93
09/14/93
09/15/93
09/18/93
_
Information Control
Well Records
#1 9250.00- 9700.00 ATLAS 5 "
#1 10600.00-11052.00 ATLAS 5 "
#1 9800.00-10196.00 ATLAS 5 "
~1 9800.00-10188.00 ATLAS 5 "
#1 10230.00-10494.00 ATLAS 5 "
#1 9100.00- 9634.00 ATLAS 5 "
#1 11000.00-11356.00 ATLAS 5 "
#1 12480.00-12736.00 ATLAS 5 "
#1 11488.00-12175.00 ATLAS 5 "
#1 11833.00-12100.00 ATLAS 5 "
~1 11488.00-12175.00 ATLAS 5 "
#1 8740.00- 9130.00 ATLAS 5 "
#1 9340.00- 9552.00 ATLAS 5 "
#1 10100.00-11013.00 ATLAS 5 "
#1 10100.00-11013.00 ATLAS 5 "
#1 10200.00-10850.00 ATLAS 5 "
#1 9630.00- 9914.00 ATLAS 5 "
#1 11150.00-11719.00 ATLAS 5 "
OCT 0 4 199,~
Alaska 0il ~ ~as Cons.
Anchorage C°rnrng,ion
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COw, MISSION
WELL COMPLETION OR RECOMP LETION REPORT AND LOG
1. Status of Well Classification ol Service Well
OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
BP Exploration 93-112
3. Address 8. APl Number
P. 0. Box 196612, Anchora~Te, Alaska 99519-6612 50- 029-22393
4. Location of well at surface 9. Unit or Lease Name
2598' NSL, 2077' EWL, SEC. 31, T11N, R13E ~ C0,,"~-PL~-!'ii~-~ Prudhoe Bay Unit
[OC..~'l(~- 10. Well Number
At
Top
Producing
Interval
1042'SNL, 883'WEL, SEC. 32, T11N, R13E ............. ¢ V'~i'II?IE.0__ .......... -~!'~i 11. FieldprudhoeandBayPOOIFie/d/Prudhoe Bay Po~ol
1036' SNL, 750' WEL, SEC. 32, T11N, R 13E ~ [
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No.
KBE = 87.1' J ADL 28288
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions
8/23/93 9/4/93 9/16/93I N/A feet MSL I One
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost
12275' MD/9230' TVD 12194' MD/9158' TVD YES [] NO []I 2119'feet MD 1900'(Approx.)
22. Type Electric or Other Logs Run
DIT/BHCS/GR/MWD
23. CASING, LINER AND CEMENTING RECORD
SE-r'rING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
20" 91.5¢/ H-40 32' 112' 30" 280 c f Arcticset (Approx.)
10-3/4" 45.5# NT-80 33' 3322' 13-1/2" 2016 cu It cs 111/4o8 cu It "G"
7-5/8" 29. 7# NT-95HS 31' 11863' 9-7/8" 1825 cuft Class "G
5-1/2" 17# L-80 11705' 122 75' 6-3/4" 140 cu ft Class "G"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI
GunDiameter 3-3/8" 6spT 4-1/2", 12.6# 11710' 11649'
MD TVD
11988'-12036' 8976'-9018' L-80
26. ACID, FRACTURE, CEMENT SQUEEZe, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
27. PRODUCTION TEST
Date First Production IMethod of Operalion (Flowing, gas lift, etc.)
9/19/93 I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL ,.GAS-MCF WATER-BBL !CHOKESlZE IGAS-OIL RATIO
TEST PERIOD ]~
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE I~'
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips.
RECEIVED
SE P 2 7 t995
Alaska 0ii & 6as Cons. Gurm'r~issi0~
Anchorage
Form 10-407 Submit in duplicate
Rev. 7-1-80 CONTINUED ON REVERSE SIDE
29. 30.
GEOLOGIC MARKERS t-,.,,-{MATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Subsea
Sag River 11866' 8783'
Shublik 11891' 8805'
Top Sadlerochit 11988' 8888'
31. LIST OF ATTACHMENTS
32. I hereby certify that the foregoing is true and correct to the besl of my knowledge
Signed ,.~~:~~/"~~ Title DrillinclEnoineerSuoorvi$or Date ¢/'~ 7/i~'
/
INSTRUCTIONS
General: This form is designed for submitting a complete and correct well completion report and log on
all types of lands and leases in Alaska.
Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt
water disposal, water supply for injection, observation, injection for in-situ combustion.
Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements
given in other spaces on this form and in any attachments.
Item 16 and 24: If this well is completed for separate production from more than one interval (multiple
completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported
in item 27. Submit a separate form for each additional interval to be separately produced, showing the
data pertinent to such interval.
Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
Item 23: Attached supplemental records for this well should show the details of any multiple stage cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none". R E t~ E IV E D
Form 10-407
S EP 2 7 199,
Alaska 0il & 6as 0OHS.
Anchorage
BP/AAI SHARED SERVICE
DAILY OPERATIONS
PAGE: 1
WELL: P-23
BOROUGH: NORTH SLOPE
UNIT: PRUDHOE BAY
FIELD: PRUDHOE BAY
LEASE:
APl: 50-
PERMIT:
APPROVAL:
ACCEPT: 08/23/93 02:00
SPUD: 08/23/93 07:30
RELEASE:
OPERATION:
DRLG RIG: NABORS 28E
WO/C RIG: NABORS 28E
08/23/93 (1) RIG MOVE MW: 0.0
TD: 0 SPLIT COMPLEXES, SPOT SUB AND MOTOR COMPLEXES OVER P-23.
PB: 0 MOVE PITS TO END OF PAD. CHANGE OUT MUD PUMP. REMOVE BOP
STACK FROM SUB STRUCTURE AND PUT IN REBUILT RAM UNITS.
ASSEMBLE STACK. CONT INSTALLATION OF NEW MUD PUMP.
08/24/93 (2) DRLG. MW: 8.7 VIS:300
TD: 785'(0) MOVE RIG. RIG ACCEPTED @ 14:00 HRS, 8/23/93. N/U
DIVERTER. TEST SAME. P/U BHA. SPUD WELL @ 19:30 HRS,
8/23/93. DRLG TO 785'.
08/25/93 (3) DRLG. MW: 9.3 VIS:300
TD: 3150'(2365) DRLG F/785'-2551'. SHORT TRIP 7 STDS. DRLG F/
2550'-3150'.
08/26/93 (4) MW: 9.6 VIS: 56
TD: 3340'(190) DRILL FROM 3150-3340'. CIRC BOTTOMS UP. SHORT TRIP TO
HWDP. CIRC SWEEP. DROP SURVEY & TRIP OUT OF HOLE TO RU 10
3/4" CASING. RIG UP & RUN 10 3/4" CSG. MAKE UP LANDING
JOINT & CEMENT HEAD. CIRC & & RECIPROCATE CASING. TEST
CEMENT LINES. CHECK FLOATS. LAY DOWN CEMENT HEAD AND
LANDING JOINT. ND DIVERTER SYSTEM. PICI UP TOP JOB PIPE &
PERFORM TOP JOB. MAKE UP SPLIT HEAD. SET BOPE ON HEAD.
REMOVE BOPE & TUBING SPOOL.
08/27/93 (5) DRILLING MW: 9.1 VIS: 40
TD: 4060'(720) WELD CASING HEAD. NU TUBING SPOOL & BOPE. INSTALL RAMS.
TEST CASING HEAD. TEST BOPE. PULL TEST PLUG & INSTALL
BOWL PROTECTOR. MAKE UP & ORIENT BHA. RUN HWDP & FLOW
TEST. TRIP IN HOLE & TAG FLOAT COLLAR @3242'. CIRC BOTTOM
UP. PRESSURE TEST 10 3/4" CASING. DRILL FLOAT EQUIPMENT,
CEMENT & 10' NEW HOLE TO 3350'. PERFORM LEAK OFF TEST.
DRILL FROM 3350-4060'.
08/28/93 (6) RIH. MW: 9.6 VIS: 42
TD: 6552'(2492) DRLG F/4060'-4360'. SHORT TRIP TO SHOE. DRLG F/
4360'-5409'. SHORT TRIP 11 STDS. DRLG F/5409'-6552'.
CIRC. POOH. CHANGE BIT. RIH.
08/29/93 (7) DRLG. MW: 9.7 ViS: 42
TD: 8220'(1668) DRLG F/6552'-7498'. SHORT TRIP 11 STDS. DRLG F/
7498'-8220'.
RECEIVED
$ E P 2 7 1993
Alaska 0)1 & Gas Cons. Commission
Anchorage
WELL :P-23
OPERATION:
RIG : NABORS 28E
PAGE: 2
08/30/93 ( 8) DRLG. MW: 9.8 VIS: 45
TD: 9175'( 955) DRLG F/8220'-8476'. CIRC. POOH. CHANGE BIT. RIH. DRLG
F/8476'-9175'.
08/31/93 (9) DRILLING MW: 9.9 VIS: 45
TD:10350'(1175) DRILL F/9175-9544'. 11 STD. SHORT TRIP, NO HOLE PROBLEMS.
DRILL F/9544-10350'.
09/01/93 ( 1
TD:I 1275'(
0) POOH. MW:10.0 VIS: 46
925) DRLG F/10350'-1051~. SHORT TRIP 11 STDS. DRLG F/
10517'-10705'. POOH FOR WASHOUT. FOUND 24 STDS OUT.
CHANGE OUT. TEST. OK. RIH. DRLG F/10705'-11275'.
CIRC. POOH.
O9/02/93 ( 1
TD:I 1723'(
1 ) DRILLING MW:I 0.4 VIS: 46
448) TRIP OUT OF HOLE AND CHANGE BHA. TEST BOPE. TEST PLUG,
PARTED WHEN REMOVING FROM BOWL. TRIP IN HOLE WITH BIT #5.
REAM 11180-11275'. HOLE PACKED OFF @11190', WORKED FREE.
DRILL FROM 11275-11723'.
09/03/93 (12) RUN 7 5/8" CSG. MW:I 0.4 VIS: 41
TD:11875'( 152) DRILLF/11723-11875'. CIRC PRIOR TO SHORT TRIP. 21 STD.
SHORT TRIP, PULLED TIGHT 10793-10133' SLICK ON TRIP IN.
CIRC LOW-HIGH SWEEP AND CONDITION MUD FOR CSG. TRIP OUT OF
HOLE L/D PIPE, HOLE SLICK. CHANGE TOP RAMS TO 7 5/8", TEST
DOOR SEALS AND PULL WEAR RING. RIG UP AND RUN 7 5/8"
CASING.
O9/O4/93 ( 1
TD:I 1875'(
3) DRILL CEMENT MW: 9.9 VIS: 44
0) RUN 7 5/8" CASING. CIRC, UNABLE TO RECIPROCATE CASING.
TEST CEMENT LINES. DROP PLUG AND PUMP. CHECK FLOATS AND
LAY DOWN CMT HEAD. INSTALL AND TEST PACKOFF. CHANGE TOP
RAMS. CHANGE OUT KELLY AND MASTER BUSHINGS. TEST BOPE AND
SET WEAR RING. PICK UP 6 3/4" BHA AND TRIP IN HOLE. SLIP
AND CUT DRILLING LINE. TRIP IN HOLE, TAG FLAT COLLAR AT
11742'. CBU. TEST CASING. DRILL CEMENT TO 11825'.
09/05/93 (14) LOGGING MW: 9.8 VIS: 41
TD:12275'(4O0) DRILL CEMENT AND FLOAT SHOE. DRILL F/11875-12275'. SHORT
TRIP TO 7 5/8" SHOE. CIRC SWEEP AROUND AND CONDITION FOR
LOGS. DROP SPERRY SUN ELECTRONIC MULTI-SHOT. TRIP OUT OF
HOLE, SLM. RIG UP AND RUN SCHLUMBERGER DITE-BHC-GR.
RECEIVE'D
Alaska 0d & L~aS Cons.
Anchorage
WELL : P-23
OPERATION:
RIG : NABORS 28E
PAGE: 3
09/06/93 (15)
TD:12275'(O)
CIRCULATE MW: 9.7 VIS: 41
RUN SCHLUMBERGER LOGS. MAKE UP BHA AND TRIP IN HOLE. CIRC
SWEEP AND CONDITION MUD FOR LINER. DROP 1 7/8" RABBIT AND
TRIP OUTOF HOLE FOR LINER. PICK UP 5 1/2" LINER, CIRC
LINER VOLUMNE. TRIP IN HOLE WITH LINER ON 3 1/2" DRILL
PIPE. BREAK CIRC AT SHOE. TRIP IN HOLE W/LINER, TAG
BOTTOM @12275'. ClRC FOR CEMENT. TEST LINES. RELEASE
FROM LINER AND PULL 10 STDS. CIRC THROUGH CHOKE W/200#,
PRESSURE ON WELL, NO FLUID LOSS OBSERVED.
O9/O7/93 ( 1
TD:12275'(
6) CIRCULATE MW: 9.7 ViS: 0
0) CIRC THROUGH CHOKE HOLDING 200# ON WELL. TRIP OUT OF HOLE,
L/D LINER RUNNING TOOL. PICK UP 7 5/8" CSG SCRAPER AND
TRIP IN HOLE. DRILL HARD CEMENT FROM 11416 TO LINER TOP
@11705'. CIRC HOLE CLEAN. TRIP OUT OF HOLE AND LAY DOWN
BHA. PICK UP 4 3/4" MILL-BHA-AND TRIP IN HOLE. SLIP AND
CUT 104' DRILLING LINE. TRIP IN HOLE TO TOP OF LINER
@11705'. TEST 75/8" CSG & LINER LAP. TRIP IN HOLE TO
LANDING COLLAR @12194', NO CEMENT ON PLUG. TEST CASING.
CHANGE WELL OVER TO FILTERED SEA WATER.
09/08/93 (17) LAND TUBING MW: 0.0
TD:12275 DISPLACE WELL TO SEAWATER. TEST CASING/LINER. TRIP OUT OF
PB:12194 HOLE & LAY DOWN DP & BHA. BREAK KELLY. PULL BOWL
PROTECTOR. RUN 4 1/2" COMPLETION. MAKE UP SSSV & CONTROL
LINES. PRESSURE TEST LINES. TAG UP WLEG IN LINER TIE
BACK. SPACE OUT TUBING. MAKE UP TUBING HANGER & CONTROL
LINES. TEST LINES.
09/09/93 (18) RELEASED RIG MW: 0.0
TD:12275 TEST CONTROL LINES. LAND TUBING & RILDS. LAY DOWN LANDING
PB:12194 JOINT & CLEAR FLOOR OF CASING TOOLS. ND DLOW LINE & BOPE.
MAKE UP & TEST CONTROL LINES. PULL 2-WAY CHECK W/
LUBRICATOR & RIG UP TO SET PACKER. U-TUBE DIESEL FOR
FREEZE PROTECTION. SET BACK PRESSURE VALVE. RELEASED RIG
09/08/93 @ 18:00 HRS.
SIGNATURE: DATE:
(drilling superintendent)
RECEIVED
o E P 2 7' 1993
Alaska 0ii & 6as Cons. bu~lflnisslo,
Anchorage
"RY-SUN DRTLLTNG SERVTCES
ANCHORAGE ALASKA
PAGE
PRUDHOE BAY DRZLLZNG
PBU/P-23
500292239300
NORTH SLOPE
CONPUTATZON DATE: 9/ 8/93
MAGNETTC MULTT-SHOT SURVEY
JOB NUMBER' AK-ET--30063
ELLY BUSHTNG ELEV. = 86,00
OPERATOR: BP EXPLORATTON
FT.
TRUE SUB-SEA COURS COURSE DLS
HEASD VERTZCAL VERTZCAL ZNCLN DZRECTZON RECTANG
DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/
TOTAL
ULAR COORDZNATES
SOUTH EAST/NEST
VERT.
SECT.
11803 8817.44 8731.44 33 17 N 86.00 E .00 1633
11981 8969,75 8883,75 28 59 N 88,02 E 2.49 1638
12074 9051,54 8965,54 27 48 N 86.97 E 1,38 1640
12167 9134.14 9048.14 26 54 N 87.19 E .97 1642
12200 9163,53 9077.53 '27 8 N 87.81 E 1,07 1642
.29N 7216,26E 7398,72
.19N 7308.17E 7489.51
.12N 7352.36E 7533,07
.29N 7395,05E 7575,22
.95N 7410.03E 7589.98
THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF
THREE-DZHENSZON HZNZHU~ CURVATURE ~ETHOD,
HORZZONTAL DZSPLACENENT = 7589.98 FEET
AT NORTH 77 DEG. 29 HZN. EAST AT ND = 12200
VERTZCAL SECTZON RELATZVE TO NELL HEAD
VERTZCAL SECTZON COHPUTED ALONG 77.50 DEG.
iR E C E!V E
~:; ~ P 2 / t99,'5
Anchorage
SF-RRY-SUN DRZLLZNG SERVZCES
ANCHORAGE ALASKA
PAGE
PRUDHOE BAY DRZLLZNG
PBU/P-23
500292239300
NORTH SLOPE
CONPUTATZON DATE: 9/ 8/93
DATE OF SURVEY: 090593
JOB NUMBER: AK-EZ-30063
KELLY BUSHZNG ELEV. = 86.00
OPERATOR: BP EXPLORATZON
ZNTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
NEASD VERTZCAL VERTZCAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDZNATES
NORTH/SOUTH EAST/WEST
ND-TVD VERTZCAL
DZFFERENCE CORRECTZON
11803 8817,44 8731.44 1633.29 N 7216.26 E 2985.56
12200 9163.53 9077,53 1642,95 N 7410.03 E 3036,47 50,91
THE CALCULATZON PROCEDURES ARE BASED ON THE USE OF
THREE-DZMENSZON MZNZMUN CURVATURE METHOD.
FT.
RECEIVED
S EP 2 7 t993
Alaska Oil & Gas Cons. (;ommissto¢
Anchorage
SF RY-SUN DRZLL]:NG SERVZCES
ANCHORAGE ALASKA
PAGE
PRUDHOE BAY DRZLLZNG
PBU/P-23
500292239300
NORTH SLOPE
CONPUTATZON DATE: 9/ 8
/93
DATE OF SURVEY' 090593
JOB NUHBER' AK-EZ-30063
KELLY BUSHZNG ELEV, = 86,00
OPERATOR' BP EXPLORATZON
ZNTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA TOTAL
MEASD VERTZCAL VERTZCAL RECTANGULAR COORDZNATES
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST
MD-TVD VERTZCAL
DZFFERENCE CORRECTZON
11803 8817,44 8731,44 1633,29 N 7216,26 E 2985,56
11884 8886,00 8800,00 1636,00 N 7259,54 E 2998,13
11999 8986,00 8900,00 1638,50 N 7317,17 E 3013,58
12112 9086,00 9000,00 1641,07 N 7370,49 E 3026,95
12200 9163,53 9077,53 1642,94 N 7410,03 E 3036,47
!
THE CALCULATZON PROCEDURES USE A LZNEAR ZNTERPOLATZON BETWEEN
1~2..~7 THE NEAREST 20 FOOT MD (FROM NZNZNUM CURVATURE) POZNTS
/
12,57
15,46
13,36
9.52
FT.
RECEIVED
S EP l 199
Alaska Oil & Gas Cons. Commission
Anchorage
SCHLUMBERGER WELL SERVICE ......
A DI. ,ON OF SCHLUMBERGER TECHNOLOGY C ~ORATION
HOUSTON, TEXAS 77251-2175
S EP 1 $ 1993 sc~Lu~.,.o~ w,,~ s~,wc.s
Pouch 340069
Prudhoe Bay, AK 99734-0069
Attn: Bernie/Shelley
BP Exploration
900 E. Benson Blvd.
Anchorage, AK 99519-6612
Attention' Petrotechnical Data Center, MB 3-3
Gentlemen'
Enclosed are2 BL prints of the DIT-E, BHC, Run 1, 9/05/93 on:
Company BP Exploration ~[~.-~{~b-(~ ~" /~7~-IZZ~ ' t2A.,
Well P-23 ~ft¢-.~-~,,_l~_ ~" I~ --I~ ~t
Field Prudhoe Bay .. County North Slope State Alaska
Additional prints ore being sent to:
3 BL prints, 1 RRolled Sepia
ARCO Alaska, Inc. AT0-1529
P. O. Box 100360
Anchorage, AK 99510-0360
Attn: Prudhoe Records Clerk
BzJ~L~iints, 1RFolded Sepia~
Alaska Oil & Gas Conservation/
Commission .
~3001P_orcupine Drive
At~ Grant
1BL .prints
Mobil 0il Company
12450 Greenspoint Drive
Houston, TX 77060
Attn: Barbara Sullivan, Suite 550B
1BL prints
Chevron U.S.A., Inc.
Technical Information Services
P. 0. Box 1635
Houston, TX 77251
At. tn: Okay-Cha Sea
1BL prints
Exxon Company U.S.A.
800 Bell Street, Suite 3083
~ouston, TX 77252
Attn: Susan Nisbett
I BL prints
Texaco, Inc.
P, O. Box 46555
J~enver, C0 80201~6555__
.JI0.- Attn: R. W. Hill
1BL prints
Phillips Petroleum Company
P~ O. Box 1967
Houston, TX 77251-1967
Attn~ Mmnica Warnken+ Room B-2
The film is returned to BP.
We appreciate the privilege of serving you.
prints
Very truly yours,
SCHLUMBERGER WELL SERVICES
SW~-- I 327-F
OH (t tBL/tRF/tRR)
Raymond N. Dickes
DISTRICT MANAGER
MEMORANDUM
State Alaska
Alaska Oil and Gas Conservation Commission
TO:
David Johnston,
Chairman~
DATE: September 1, 1993
THRU: Blair Wondzell, ~..~ FILE NO:
P. !. Supervisor 9/7
AIRIIAAC.doc
,,
FROM: Bobby Foster, SUBJECT:
Petroleum Inspector
BOP Test - Nabors 28 E
BPX-PBU-P-23
PTD#93- 112
PB Field
September 1, 1993: I traveled to Nabors rig 28 E this date and witnessed the
weekley BOP test. As the attached BOPE Test Report form shows there were
no failures.
Summary: ! witnessed the BOP test on 28 E - test time 2 hours - no failures.
·
Attachment' AIRIIAAC.XLS
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg: X Workover:
Drlg Contractor: NABORS Rig No.
Operator: BPX
Well Name: P - 23
Casing Size: 10 3/4 Set ~ 3,322
Test: i~i{:iai_____ Weekly .X Other
DATE: g/'I/g3
28E PTD# g3-112 RigPh.# 65g-4863
Rep.: BILL BIXBY
Rig Rep.: MIKE DOWNEY
Location: Sec. 31 T. 11 N R. 13E Meridian U
MISC. INSPECTIONS:
Location Gen.: OK
Housekeeping: OK (Gert)
Resen/e Pit N ~',,~
,, .
Well Sign OK
Dfl. Rig OK'
_
BOP STACK:
Annular Preventer
Pipe Rams
Pipe Rams
Blind Rams
Choke Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Quan.
,, !
1
2"
Test
Pressure
300 ! 3000
300 ~ 5000
30015000
300 ! 5000
300 ~ 5000
30015000
MUD SYSTEM: Visual
Trip Tank YES
Pit Level Indicators ' YES
Flow Indicator ' ~YEs
Gas Detectors YES
, ~
. .
Test
FLOOR SAFETY VALVES: Ouan. Pressure
Upper Kelly / IBOP 1 ~ 30015000
Lower Kelly / IBOP I~0 150~
Ball Type . I J l 5
Inside BOP , I il 5
P/F
P
P/F
P
P
P
P
P
., .
P
Alarm
YES
Y'E~
'YEs
YES
~ ,
CHOKE MANIFOLD:
No. Valves 18
No. Flanges 42.
Manual Chokes 2
,,
Hydraulic Chokes 1
Test
Pressure
300 ~ 5000
300 ~ 5000
Functioned
Functioned
P/F
P
_
P
P
, L
ACCUMULATOR SYSTEM:
System Pressure 3,000 I P.
Pressure After Closure 1,500 I P
200 psi Attained After Closure 0 minutes '22
System Pressure Attained '- ~" minutes' 3~
Blind Switch Covers: Master:. YES Remote:
Nitgn. Btl's: 8 ~ 2000
Psig.
sec,
sec.
YES
Number of Failures: 0 ,Test T~rne: 2.0 Hours. Number of valves tested 28 Repair or Replacement of Failed
Equipment will be made within! ' 0 da~s. Notify the Inspector and follow with Writ{en or Faxed verification to
the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433
I IIII II I. I I I I II .r I I I I J Ill I I [ I I I I III
REMARKS: GOOD TEST
Distribution:
orig-Well File
c - Oper./Rig
c - Database
c - Trip RFt F~le
C -Inspector
STATi~ WitNEss REQOIRED? '
YES NO X
~ . ,
24 HOUR NOTICE GIVEN
YES X NO
Waived By:
~tnessed By:
FlqY21L (Rev, 7/93) AIRliAAC.XLS
ALASKA OIL AND GAS
CONSERVATION COMMISSION
August 13~, 1993
'WALTER J. HICKEL, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOPY: (907) 276~7542
R. C. Maskell
Drilling Engineer Supervisor
BP Exploration (Alaska), Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re:
Prudhoe Bay Unit P-23
BP Exploration
Permit No. 93-112
Sur. Loc 2598'SNL, 2027'WEL, Sec. 31, TllN, R13E, UM
Btmhole Loc. 846'SNL, 788'WEL, Sec. 32, TllN, R13E, UM
Dear Mr. Maskell:
Enclosed is the approved application for permit to drill the above
referenced well.
The permit to drill does not exempt you from obtaining additional
permits required by law from other governmental agencies, and does not
authorize conducting drilling operations until all other required
permitting determinations are made.
The blowout prevention equipment (BOPE) must be tested in accordance
with 20 AAC 25.035; and the mechanical integrity (MI) of the injection
wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3).
Sufficient notice (approximately 24 hours) of the MI test before
operation, and of the BOPE test performed before drilling below the
surface casing shoe, must be given so that a representative of the
Commission may witness the tests. Notice may be given by contacting the
Commission petroleum field inspector on the North Slope pager at
659-3607.
Chairman~
BY ORDER OF THE COMMISSION
dlf/Enclosure
cc:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work Drill [] Redrill l-lllb. Type of well. Exploratory I-1 Stratigraphic Test [] Development Oil []
Re-Entry [] Deepen~1 Service [] Development Gas [] Single Zone [] Multiple Zone []
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration KBE = 86' feet Prudhoe Bay Field/Prudhoe
3. Address 6. Property Designation Bay Pool
P. O. Box 196612. AnchoracTe. Alaska 99519-6612 ADL 28288
4. Location of well at surface 7. Unit or property Name 11. Type Bond(me 2o ,,.AC 25.025)
2598' SNL, 2927' WEL, SEC. 31, T11N, R13E Prudhoe Bay Unit
At top of productive interval 8. Well number Number
869' SNL, 881' WEL, SEC. 32, T11N, R 13E P-23 (41-32-11-13) 2S 100302630-277
At total depth 9. Approximate spud date Amount
846' SNL, 788' WEL, SEC. 32, T11N, R13E 9/15/93 $200,000.00
12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(uDandTVD)
property line
ADL 28305-788' feet P-01-34' @ 250' TVD feet 2560 12301' MD/9222' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (see 2o Mc 25.o35 (e)(2))
Kickoff depth 487' feet Maximum hole angle 47 o Max~rnum surface 3330 pslg At total depth ('rVD) 8800'/4390 pslg
18. Casing program Setting Depth
s~ze Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
30" 20" 91.5# H-40 Weld 80' 32' 32' 110' 110' 280 cuft Arcticset
13-1/2" 10-3/4" 45.5# NT-80 Butt 3199' 31' 31' 3230' 2850' lO5O sx CS 111/355 sx "G"/250 sx CS II
9-7/8" 7-5/8" 29.7# NTO5HS NSCC 11867' 30' 30' 11897' 8858' 715 sx Class "G"
6-3/4" 5-1/2" 17# L-80 NSCC 554' 11747' 8722' 12301' 9222' 120 sx Class "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 Measured depth True Vertical depth
Structural
Conductor ~ ~'C F i V ~* ,~*',
Surface ' ' [~ ~'*)
Intermediate
Production /~,U(::; '~ ~'~ ~o~,_~
Liner Alaska 0il & Gas Co~m. (;ormnissio~
Perforation depth: measured
true vertical Anchorage,
20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[]
Drilling fluid program,,J~ Time vs deptJ;! pict [] Refraction analysis FI Seabed report[] 20 AAC 25.050 requirements[]
21.1 hereby certif~~/t the foregoi~,g is tru,e a~d correct to the best of my knowledge Date'~'/~C~/¢.~
Signed ,~,~,,._..~~ ~,X~.~J_.~ ~ Title Dri//ing Engineer Supervisor
Commission Use Only r"
Permit Number IAPI number IAppro~al d~}~ ISeo cover letter
~.¢-~//.2.~ 15o- c~_?_ .~z ,7 73 ~[ ~ for other requiremeats
Conditions of a~roval Samples required [] Yes ~ ~ Mud log required []Yes ~ ~
Hydrogen sulfide measures [] Yes 1~ No Directional survey requ~roo ~1 Yes [] No
Required working pressure for BOPE 1-12M; 1-13M; J;[~LSM; I-I10M; 1-115M;
Other: :O~i~"ra~ $i~cJ"F'~ ~'Y by order of
Approved by D a',;id W. JohnS:l~c~, Commissioner ~ne commission Date ~-"~_~- ;~
Form 10-401 Rev. 12-1-85 Submit in triplicate
I WellName: IP-23 PBU
Well Plan Summary
I Type of Well (producer or injector): ! Injector
I Bottom Hole Location:
Surface Location:
Target Location:
2598' FNL 2927' FEL Sec 31TllN R13E
0869' FNL 0881' FEL Sec 32 TllN R13E
0846' FNL 0788' FEL Sec 32 T11N R13E
I AFE Number: 1 4P0471 ]
I Estimated Start Date: ] Sept 15 1993 I
IMD: I 12301' I ITVD:
[ Well Design (conventional, slimhole, etc.):
I Rig: ] Nabors 28-E
I Operating days to complete: ] 23
19222. I IKBE: 186'
I S limhole (pre-produced injector)
Formation Markers:
Formation Tops MD TVD (BKB)
Ugnu Zone 4A 5042' 4086'
W. Sak Sands 6310' 4951'
Top Seabee 7579' 5816'
Kuparuk~ut River Absent
IKRU/LCU 10130' 7556'
Top Sag River 11897' 8858'
Eileen Absent
Top Sadlerochit 12016' 8964'
Target 12072' 9015'
Total Depth 12301' 9222'
Casing/Tubin Program:
Wt/Ft
Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm
Tbg O.D. MD/TVD MD/TVD
30" 20" 91.5# H-40 Weld 80' 32'/32' 110'
13 !/2" 10 3/4" 45.5# NT80HLE Butt 3199' 31V31' 3230'/2850'
9 7/8" 7 5/8" 29.7# NT95HS NSCC 11867' 30'/30' 11897'/8858'
6 3/4" 5 1/2" 17# L-80 NSCC 554' 11747'/8722' 12301'/9222'
4 1/2" 12.6g L-80 NSCT 11668 29'/29' 11697'/8677'
Well Plan Summary
Page 1
Logging Prog
Open Hole Logs:
13 1/2" Hole
9 7/8" Hole
6 3/4" Hole
I Cased Hole Logs:
7 5/8" Casing
5 1/2" Liner
ram:
None
None
GR/DIL/BHCS
SBT to TOC since well is an injector
SBT. LDT (optional). Gyro after rig release.
Mud Program:
I Special design considerations
Surface Mud Properties:
Density Marsh Yield 10 sec 10 rain pH Fluid
(PPG) Viscosity Point gel gel Loss
8.5 100 20 15 20 9 15
tO tO tO tO tO tO tO
9.5 300 60 60 80 10 25
Intermediate Mud Properties: I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
9.0 35 10 5 10 9.5 5
tO tO tO tO tO tO tO
10.2 50 15 10 20 10 10
Production Mud Properties: [
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
9.6 30 8 3 7 8 6
tO tO tO tO tO tO tO
10.0 45 13 10 15 9 8
Well Control:
Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer
will be installed and is capable of handling maximum potential surface pressures.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
Directional'.
[KOP: 1487'
IMaximum Hole Angle:
Close Approach Well:
47 degrees
P-01 - 34' away at 250' TVD.
The above listed wells will be secured during the close approac, h, ~
Well Plan Summary
Page 2
CASING SIZE: 10-3/4"
10-3/4" SURFACE CASING
CEMENT PROGRAM - BJ SERVICES
CIRC. TEMP 38°F
SPACER: 75 bbls fresh water ahead of lead slurry.
LEAD CEMENT TYPE: ColdSet III
ADDITIVES: retarder
WEIGHT: 12.2 ppg
APPROX #SACKS: 1050
YIELD:1.92 ft3/sx MIX WATER: 10.5 gps
THICKENING TIME: Greater than 4 hrs @ 50°F
TAIL CEMENT TYPE' Class G
ADDITIVES: 2% A-7 +1 ghs FP-6L.
WEIGHT: 15.8 ppg YIELD:1.15 ft3/sx
APPROX #SACKS: 355
MIX WATER: 4.95 gps
THICKENING TIME: Greater than 3 1/2 hrs @ 50°F
TOP JOB CEMENT TYPE: Coldset II
ADDITIVES: retarder
WEIGHT: 14.5 ppg
APPROX #SACKS: 250
CENTRALIZER PLACEMENT:
1. Run one(l) bow type centralizer per joint for the first 20 joints.
2. Place the centralizers in the middle of each joint with a stop collar.
CEMENT VOLUME:
1. Lead slurry to surface w/100% excess.
2. Tail slurry volume 355 sx (500' MD above shoe with 100% excess)
3. Top job volume 250 sx.
YIELD:0.96 ft3/sx MIX WATER: 3.89 gps
THICKENING TIME: Greater than 2 hrs @ 50°F
7-5/8" INTERMEDIATE CASING
CEMENT PROGRAM- BJ SERVICES
CIRC. TEMP: 140° F
SPACER: 50 bbls BJ MCS-4, weighted to current mud weight.
LEAD CEMENT TYPE: CLASS G
ADDITIVES: 0.4% FL-52+0.5% CD-32+3% A-2+lghs FP-6L
WEIGHT: 11.0ppg YIELD: 3.31 ft3/sx MIX WATER: 20.9 gps
APPROX #SACKS: 450 THICKENING TIME: Greater than 5 hrs at 140°F
FLUID LOSS: 100-150 cc @ 140°F FREE WATER: 0 cc
TAIL CEMENT TYPE: CLASS G
ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + lghs FP-6L
WEIGHT: 15.8ppg YIELD: 1.14 cu ft/sk MIX WATER: 4.85 gps
APPROX # SX: 265 THICKENING TIME: 3 1/2-4 1/2 hrs @ 140°F
FLUID LOSS: 100-150 cc @ 140°F FREE WATER: 0 cc
CENTRALIZER PLACEMENT: I Turbulator centralizer per joint on the bottom 500' of 7-
5/8" casing ( 12 required ). One solid body 7-3/4" x 9-1/4" centralizer or turbolator on first 2
joints inside 10-3/4" surface casing shoe.
OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and
ensure compatibility prior to pumping job. Ensure thickening times are adequate relative
to pumping job requirement. Displace at 12 bpm. DO not batch mix tail cement.
CEMENT VOLUME:
1 .Lead slurry up to 5810' MD (500' above West Sak) with 30% excess to isolate Cretaceous
interval.
2. Tail slurry to 1000' MD above casing shoe with 30% excess.
3.80' MD 7-5/8", 29.7# capacity for float joints.
5-1/2" PRODUCTION LINER
CEMENT PROGRAM - BJ SERVICES
CIRC. TEMP 1400 F
PREFLUSH: 20 bbls fresh water
BHST
226 deg F at 8800' TVDSS.
SPACER: 60 bbls BJ MCS-4 weighted 1.0 ppg above mud weight.
CEMENT TYPE: CLASS G
ADDITIVES: 150 ghs BA-86L+0.6% CD-32+0.2% FL-33+0.2% A-2+0.5% gel
WEIGHT: 15.7 ppg
APPROX #SACKS: 120
FLUID LOSS: < 50 cc @ 140°F
YIELD:1.17 ft3/sx MIX WATER' 3.58 gps
THICKENING TIME: 45 min @ surface + 3-4 hrs @ 140°F
FREE WATER: 0 cc at 45° angle.
Note: Ensure that a thickening time test is performed that simulates the shut down time incurred
while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when
consistometer is re-started after shutdown period - additional retarder may be required -
consult w/cementer.
CENTRALIZER PLACEMENT: Run 2 right hand turbolators per joint in open hole, 1 per joint
in lap, and none opposite intermediate casing shoe..
OTHER CONSIDERATIONS' Batch mix the cement slurry. Perform fluid loss test on the
batch mixed slurry. Report actual fluid loss on morning report. Displace @ 6-8 bpm.
LINER CEMENT VOLUME'
o
.
Open hole (6-3/4" X 5-1/2") + 30% excess (adjust if a caliper log is run and it indicates
severe washouts).
5-1/2", 17# casing capacity below landing collar.
150' liner lap (6 3/4"x 5-1/2")
200' of cement on top of the liner in the 7-5/8" casing.
HALLIBURTI-]N
DI~.ILL IN~ SYS]EMS
07/~?11993 0:48 om
~700 I
9O°
240°
,,/ellpo ih
}019ct
~-04
J]9mwd
>-11
>-13
)-16
)17cj4:t
)-].8
)-19
)-L::13
_--3D
z-3c'
?tty-O1
k301113
k331112
31012
311331112
382311113
5~301113
~43311113
;eeilee; n - 1
seeileen-;~
-tba-3~
wen omw 01
wenorqwPd
x,x
180°
CLF1SES~ PB]Nl'S
Slot l~s±once I)inec±ion ReF MD Ref ]VD Sep. Foc±o¢
P-O1 34.40
P-~ 69.~ 819.48 5~.~ ~.~ 47.~
P-03 ]04.71 8]3.83 0.~ 0.~ 104.70
P-04 140.~ ~13.17 4~.~ 4~.~
P-~ ~.81 813.~ 2~.~ ~.~ 237.~
P-~ 314.~ ~13.~ 0.~ 0.~ 314.~
P-~ 314.~ ~13.~ 0.~ 0.~ 314.~
P-J0 ~ ~1 ~.9~ 0.~ 0.~ ~.~
P-]~ 179.76 ]64.~ 1104.78 ll~.~ ~.~
P-13 ~3.04 i~.~ 1~.78 1~.~ ~,80
P- ] 4 2~.~ l ~.93 0.~ 0.~ ~.~
P- ] 5 ~. ] 5 l ~.97 6~.~ 6~.~ 63.10
P- ] 6 ~77.~ l 17~.31 0.~ 0.~ ~77.~
P-~7 ~3.84 ~76.67 5~.~ ~.~
P-J9 363.73 183.~ 0.~ 0.~ 363.70
P-~ ~4.~ l ~.74 5~.~ ~.~ 1%.~
P-~ 1 4~. 19 i 87.~ 0.~ 0.~ 4~.80
~-~ N/A ~A N/A N/A N/A
~-3B N/A N/A N/A N/A N/A
~-~ N/A N/A N/A N/A N/A
~-3D N/A N/A N/A N/A
~TY-0I N/A N/A N/A N/A N/A
~S~-01 N/A N/A N/A N/A N/A
~S~-0] R N/A N/A N/A N/A N/A
k2211 i 2 N/A N/A N/A N/A N/A
K241 l 12 N/A N/A N/A N/A N/A
K~I ] ~ 3 N/A N/A N/A ~A N/A
K331112 N/A N/A N/A N/A N/A
K~ST-OI N/A N/A N/A N/A N/A
~31012 N/A N/A N/A N/A N/A
~11331112 ~A N/A N/A N/A N/A
~8831 I 113 N/A N/A N/A ~A N/A
~ ] ] 3 N/A N/A N/A N/A N/A
~433~ ] I ~3 N/A N/A N/A N/A N/A
~-0 ] N/A N/A N/A N/A N/A
~331113 N/A N/A N/A N/A N/A
~STO] ~A N/A N/A ~A N/A
SEE]LEE~ l N/A N/A N/A N/A N/A
SEEILEEN-~ N/A N/A N/A N/A N/A
T~-31 ~A N/A N/A N/A N/A
WE~ ~ N/A N/A N/A N/A N/A
~D N/A N/A N/A N/A N/A
Prudhoe Bay Drilling
Prudhoe Bay, Alaska
Well' P-23 File' P-S3wp2
HORIZONTAL VIEW
SCALE 1000 ft. / DIVISION
SURVEY REF: WELLHEAD
~U~N ~ B UR T E1 Ix]'
HALL I
¥ E DR]LL ING SYSTEMS
s
07/87/1993 9: 08 am
2000
1000
8850 TVD
250 750 1750 8750 3750 4750 5750 6750 7750
VERTICAL VIEW
SCALE 1000 ft. / DIVISION
TVD REF: RKI3
VERTICAL SECTION REF: WELLHEAD
0--~ 0,00° ~ 0 MD TIE IN/~d ~'
487--~ 0.00° e 487 MD START DF BUILD e 8.00 DEG/IO0 FT
4.00* ~ 687 MD
8,00o ~ 887 MD
1°°°--I '~' ' 18.oo' ~ lO87 ~$
1
~ 16.00' ~ la87 HD
~ 80.00° @ 1487 HD
~ 84.00° @ 1687 ND
1886 '~ a8.O0o e 1887 HD
65 ~ a9'83° ~ 1949 MD BASE PERMAFRgST
8000-- ~o ~ 34.00° ~ ~187 ND
~X 38.00° e a387 HO
~, 44.00° ~ aSS7 HS
8588 ~ 47.00~ ~ 2837 MD END OF BUILD
3000-- 10.750~D, ~ 3~30 MD, ~850 TVD
-..,
",xx.
4000--
CASING POINTDATA
OD MD Inc AZI TVD North Eos~
10.750 in. 3~30 47.00 77.23 2850 265 1169
7,625 In. I1897 28,52 77.23 8858 1640 7241
CRITICAL POINT DATA
MD Inc ~ TVD North E~st
TIE IN 0 0.00 0 O 0 0
START OF BUIL~487 0.00 0.00 487 0 0
~ 2,00 DEG/IO0
FT
BASE 1949 29.23 77.23 1886 81 356
PERMAFROST
END OF BUILD 2837 47,00 77.23 2582 201 888
UGNU ZONE 4A 5048 47,00 77.23 4086 558 8461
(UG4A)
WESK SAK SANDS6310 47,00 77.~3 4951 763 3366
TOP SEABEE 7579 47,00 77.23 5816 968 4271
(CM3)
]KRU/LCU 10130 47,00 77.23 7556 1380 6090
START OF DROP 10972 47,00 77.23 8131 1516 6691
8 2.00 DEG/iO0
FT
TOP SAG RIVER ;189728.58 77,23 8858 1640 724]
TOP SHUBLIK 11923 27.99 77.23 9981 1643 7253
PRUDHOE ~AY 12016 26.13 77.~3 8964 1653 7294
MEHBER
(TSAD)/Z4B
IARGET 12072 25.00 77.~3 9015 1658 7318
TOTAL DEPTH 12301 85.00 77.23 9222 1679 7418
4086
4951
5000--
5816
6000--
7000 --
7556----
8000--
8131
SSSl~_~
8964 ~.~
9000~--
9015~-'- I
9 086'/ I
9222~ I
10000
_
2524
3451
4379
47 O0° ~ 504~ MD UGNU ZONE 4A (UG4A)
6245
47 00° @ 6310 MD WESK SAK SANDS
47,00° ~ 7579 MD TOP SEABEE (CM3)
47.00° ~ 10130 MD IKRU/LCU
BHL DATA
TVD'--9-~-21.95[
MD 12300.81[
VS ?600.03[
North 1679.28[
East 7412.191
~ 47.00° 8 10978 MD SFARI OF DROP
'- ---------- @ 2.00 DEG/IO0 FI
6861 "x,~/41.O0' @ 11272 MD
~_~-----35.00' @ 11572 MD
~, /31.00- e 11772 MD
7 685 OD, @ 11897 MD, 8858 TVD \~x~2@.52' 8 11897 MD lap SAG RIVER
~87,99° 8 ~1923 MD lOP SHUBLIK
748q'-/-4-37-7479~ %q-~--~86,13' e 18016 MD PRUDHOE BAY
~ ~ MEMBER (TSAD)/Z4B
7600 ~ -85.D0' 8 18078 MD IARGET
~25.00' ~ 1830] MD TOTAL DEPIH
I I I
O0 900 i900 8900
VERTICAL SECTION PLANE: 77.23'
3900 4900 5900 6900 7900
ITEM
(1) Fee
(2) Loc
(3) Admin. [~9~,~ru 1~
[10 & 13]
[14 thru 22t]
(4) Casg
(5) BOPE
Is
Is
Is
Is drilling fluid program schematic & list of equipment adequate .....
Are necessary diagrams & descriptions of diverter & BOPE attached ....
Does BOPE have sufficient pressure rating -- test to ~O¢6~ psig .....
Does choke manifold comply w/API RP-53 (May 84) ......................
Is presence of H2S gas probable ......................................
Lease & Wel 1 ~zzj2f~L
NO
** CHECK LIST FOR NEW WELL PERMITS ** Company
APPROVE DATE Y_/~
1. Is permit fee attached ............................................... ~
2. Is well to be located in a defined pool .............................. ~
3. Is well located proper distance from property line ...................
4. Is well located proper distance from other wells ..................... ~
. Is sufficient undedicated acreage available in this pool
Is well to be deviated & is wellbore plat included.
i Is operator the only affected party ................
. Can permit be approved before 15-day wait ..........
9. Does operator have a bond in force ................................... ~
10. Is a conservation order needed ....................................... -L
11. Is administrative approval needed ....................................
12. Is lease nLrnber appropriate .......................................... L
13. Does well have a unique name & nLrnber ................................
14. Is conductor string provided ......................................... ~
15. Will surface casing protect all zones reasonably expected
to serve as an underground source of drinking water ..................
16. Is enough cement used to circulate on conductor & surface ............
17. Will cement tie in surface & intermediate or production strings ...... ~
18. Will cement cover all known productive horizons ..................... ~
19. Will all casing give adequate safety in collapse, tension, and burst. ~
20. Is well to be kicked off from an existing wellbore ................. '..
21. old wellbore abandonment procedure included on 10-403 ........... '.. ~
¢/] 22. adequate wellbore separation proposed .............................
~ 23. a diverter system required ........................................
[23 thru 28 ' 24. -~F
25. ]~
26.
27. ~
28.
REMARKS
(6) Other
[29 thru 31] 30.
31.
32.
(7) Contact
(8) Addl
[32]
geology: engineerinq'
DWJ MTM -- ~RAD]~) ~-~ 7~
RP~ B EW~,fi~ D~~"
TAB~___k~_.
rev 6/93
jo/6.011
33.
FOR EXPLORATORY & STRATIGRAPHIC WELLS:
Are data presented on potential overpressure zones ...................
Are seismic analysis data presented on shallow gas zones .............
If offshore loc, are survey results of seabed conditions presented...
Name and phone n~nber of contact to supply weekly progress data ......
Additional
requirements .............................................
Additional
INITIAL GEOL UNIT ON/OFF
POOL CLASS STATUS AREA ~ SHORE
I-
remarks'
UM ~/
MERIDIAN' SM
WELL TYPE'
Red r il 1
Inj ~k,
Rev
0
--I
"'FZ
,'--'0
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simp!ify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
ALASKA COMPUTING CENTER
* SCHLUMBERGER *
COMPANY NAME : BP EXPLORATION
WELL NAME : P-23 (41-32-11-13)
FIELD NAME : PRUDHOE BAY
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 50-029-22393-00
REFERENCE NO : 93418
Date_
LIS Tape Verification LishSng
Schlumberger Alaska Computing Cenher
20-0CT-1993 10:36
**** REEL HEADER ****
SERVICE NAME · EDiT
DATE · 93 0/20
ORIGIN : FLIC
REEL NAME : 93418
CONTINUATION # :
PREVIOUS REEL :
COMMENT ' BP EXPLORATION, PRUDHOE BAY, P-23, 50-029-22393-00
**** TAPE HEADER ****
SERVICE NAME · EDIT
DATE ' 93/10/20
ORIGIN : FLIC~
TAPE NAME : 93418
CONTINUATION # : 1
PREVIOUS TAPE :
COMMENT : BP EXPLORATION, PRUDHOE BAY, P-23, 50-029-22393-00
TAPE HEADER
PRUDHOE BAY
OPEN HOLE WIRELINE LOGS
WELL NAME' P-23 (41-32-11-13)
API NUMBER' 500292239300
OPERATOR: BP EXPLORATION
LOGGING COMPANY: SCHLUMBERGER WELL SERVICES
TAPE CREATION DATE: 20-0CT-93
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
RUN 1
93418
WARNER
KALISH/BIXBY
RUN 2 RUN 3
31
11N
13E
2598
2077
87.80
86.30
53.90
OPEN HOLE CAS ING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6.750 7.625 11863.0
PAGE:
LIS Tape Verification Listing 20-0CT-1993 10'36
Schlumberger Alaska Computing Center
3RD STRING
PRODUCTION STRING
REMARKS: NO DEPTH-ADJUSTMENTS WERE MADE BECAUSE DITE WAS LOGGED
IN COMBINATION WITH THE BHC.
# $
LIS FORMAT DATA
LIS FORMAT DATA
**** FILE HEADER *W**
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION · 001C0}
DATE · 93~0 20
MAX REC SIZE · 10
FILE TYPE : LO
LAST FILE
PAGE'
FILE HEADER
FILE NUMBER: 1
EDITED CURVES
All tool strings; ~e th
DEPTH INCREMENT- v.~000
FILE SUMMARY
LDWG TOOL CODE START DEPTH
shifted and clipped curves; all runs merged; no cased hole data.
BCS 1 2230.0
DTE 1 2260.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
STOP DEPTH
$
MERGED DATA SOURCE
LDWG TOOL CODE
11854.0
11854.0
EQUIVALENT UNSHIFTED DEPTH
RUN NO. PASS NO.
MERGE TOP MERGE BASE
# $
REMARKS' NO DEPTH-ADJUSTMENTS WERE MADE BECAUSE DITE WAS LOGGED
IN COMBINATION WITH THE BHC.
#
LIS FORMAT DATA
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 52
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 19
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE, REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
DEPT FT 599371 00 000 00 0 1' 1 1 4 68
DT BCS US/F 599371 00 000 00 0 1 1 1 4 68
GR BCS GAPI 599371 00 000 00 0 1 1 1 4 68
TENS BCS LB 599371 00 000 00 0 1 1 1 4 68
TEND BCS LB 599371 00 000 00 0 1 1 1 4 68
IDPH DTE OHMM 599371 00 000 00 0 1 1 1 4 68
IMPH DTE OHMM 599371 00 000 00 0 1 1 1 4 68
ILD DTE OHMM 599371 00 000 00 0 1 1 1 4 68
ILM DTE OHMM 599371 00 000 00 0 1 1 1 4 68
SFL DTE 599371 00 000 00 0 1 1 1 4 68
SP DTE MV 599371 00 000 00 0 1 1 1 4 68
MTEM DTE DEGF 599371 00 000 00 0 1 1 1 4 68
MRES DTE OHMM 599371 00 000 00 0 1 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
** DATA **
DEPT. 12280.000 DT.BCS -999.250 GR.BCS -999.250
TEND.BCS 38.456 IDPH.DTE -999.250' IMPH.DTE -999.250
ILM.DTE -999.250 SFL.DTE -999.250 SP.DTE -999.250
MRES.DTE -999.250
TENS.BCS
ILD.DTE
MTEM.DTE
4245.000
-999.250
-999.250
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
PAGE:
DEPT. 12000.000 DT.BCS
TEND.BCS 1218.028 IDPH.DTE
ILM.DTE 7.345 SFL.DTE
MRES.DTE 0.80]
89.400 GR.BCS 48.013
7.289 IMPH.DTE 9.832
15.536 SP.DTE -56.813
DEPT. 11854.000 DT.BCS 118.800 GR.BCS 116.095
TEND.BCS 1112.658 IDPH.DTE 0.400 IMPH.DTE 0.552
ILM.DTE 0.669 SFL.DTE 2.527 SP.DTE -14.563
MRES.DTE 0.839
** END OF DATA **
TENS.BCS
ILD.DTE
MTEM.DTE
TENS.BCS
ILD.DTE
MTEM.DTE
6010.000
8.382
193.708
5735.000
0.419
188.387
**** FILE TRAILER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION · 001C0}
DATE · 93~I0 20
MAX REC SIZE · 10
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION · 001C01
DATE · 93/10/20
MAX REC SIZE · 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 2
EDITED CASED HOLE MAIN PASS
Depth shifted and clipped curves
PASS NUMBER: 3
DEPTH INCREMENT: 0.5000
FILE SUMMARY
LDWG TOOL CODE START DEPTH
for open hole logs run into casing.
STOP DEPTH
BCS 11 854.0 1 0750.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
EQUIVALENT UNSHIFTED DEPTH
LIS Tame' Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
BASELINE DEPTH BCS
$
REMARKS: THIS FILE CONTAINS THE GR AND TENSION CURVES FROM THE
O.H. DITE/BHC LOGGING SUITE FROM THE BOTTOM OF THE
7.625" CASING UP TO 10750'.
# $
LIS FORMAT DATA
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 64
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
SET TYPE - CHAN **
NAME ,SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
DEPT FT 599371 00 000 00 0 2 1 1 4 68
GRCH BCS GAPI 599371 00 000 00 0 2 1 1 4 68
TENS BCS LB 599371 00 000 00 0 2 1 1 4 68
TEND BCS LB 599371 00 000 00 0 2 1 1 4 68
0000000000
0000000000
0000000000
0000000000
** DATA **
LIS TaDe~ Verification Listing
Schlumberger Alaska Computing Center
DEPT. 11854.000 GRCH.BCS
DEPT. 11500.000 GRCH.BCS
DEPT. 11000.000 GRCH.BCS
DEPT. 10750.000 GRCH.BCS
END OF DATA
20-0CT-1993 10:36
72.310 TENS.BCS
51.549 TENS.BCS
63.686 TENS.BCS
66.523 TENS.BCS
5660.000
5590.000
5615.000
5165.000
TEND.BCS
TEND.BCS
TEND.BCS
TEND.BCS
PAGE:
1093.089
1095.452
1058.970
998.070
**** FILE TRAILER
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION · 00lC0
DATE ' 93 10 20
MAX REC SIZE ' 102
4
FILE TYPE : LO
LAST FILE
**** FILE HEADER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION ' 001C01
DATE ' 93/10/20
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 3
RAW OPEN HOLE MAIN PASS
Curves and log header data for each run and tool string in separate files; Tool String #1 fo
Sadlerochit run presented first (primary depth control string used to depth shift the Sadler
interval) followed by files for other main pass tool strings per run.
RUN NUMBER: 1
TOOL STRING NUMBER: 1
PASS NUMBER: 2
DEPTH INCREMENT: 0.5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
BHC
DTE
$
LOG HEADER DATA
DATE LOGGED:
12295.5 11775.5
12295.5 11775.5
05-SEP-93
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT)'
TD LOGGER(FT):
TOP LOG INTERVAL (FT/'
BOTTOM LOG INTERVAL%~T)'
LOGGING SPEED (FPHR):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
5C0-423
25 05-SEP-93
551 05-SEP-93
12275.0
12269.0
11854.0
12228.0
0.0
TOOL NUMBER
AMS
TCC
GR
BHC
SDT
DTE
DTE
$
AUXILIARY MEASUREMENTS
TELEMETRY CARTRIDGE
GAMMA RAY CARTRIDGE
BOREHOLE SONIC CART.
SONIC SONDE
PHASOR INDUCTION CART.
PHASOR INDUCTION SONDE
AMS-A 712
TCC-B 281
SGC-SA 50
SLC-UA 278
SLS-WA 2004
DIC-EB 427
DIS-HB 434
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (INI:
DRILLERS CASING DEPTH (FT)'
LOGGERS CASING DEPTH (FT)'
6.750
11863.0
11854.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (L~/Q)'
MUD VISCOSITY (S)'
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE'(DEGF
RESISTIVITY (OHMM) AT TEMPERATURE
MUD AT MEASURED TEMPERATURE (MT
MUD AT BOTTOM HOLE TEMPERATURE
MUD FILTRATE AT (MT):
MUD FILTRATE AT()BHT '
MUD CAKE AT (MT):
MUD CAKE AT()BHT '
DEGF ):
:
BHT ):
LSND
9.80
41 .00
10.10
196.0
2.490
2.650
2.060
72.0
68.0
68.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN): 0.8
REMARKS: THE TOOL STRING WAS CENTRALIZED WITH 0.8" RUBBER FIN
STANDOFF AND A 2' HOLE FINDER.
#
LIS FORMAT DATA
PAGE:
LIS Tape Verification Listing
Schlumoerger~Alaska Computing Center
20-0CT-1993 10:36
PAGE:
** DATA FORMAT SPECIFICATION RECORD **
SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 164
4 66 1
5 66
6 73
7 65
8 68 O.5
9 65 FT
11 66 6
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB' NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
DEPT FT 599371 00 000 00 0 3 1 1 4 68
DT BHC US/F 599371 00 000 '00 0 3 1 1 4 68
TT1 BHC US 599371 00 000 00 0 3 1 1 4 68
TT2 BHC US 599371 00 000 00 0 3 1 1 4 68
TT3 BHC US 599371 00 000 00 0 3 1 1 4 68
TT4 BHC US 599371 00 000 00 0 3 1 1 4 68
SP BHC MV 599371 00 000 00 0 3 1 1 4 68
GR BHC GAPI 599371 00 000 00 0 3 1 1 4 68
TENS BHC LB 599371 00 000 00 0 3 1 1' 4 68
MTEM BHC DEGF 599371 00 000 00 0 3 1 1 4 68
MRES BHC OHMM 599371 00 000 00 0 3 1 1 4 68
HTEN BHC LB 599371 00 000 00 0 3 1 1 4 68
CIDP DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IDPH DTE OHMM 599371 00 000 00 0 3 1 1 4 68
CIMP DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IMPH DTE OHMM 599371 00 000 00 0 3 1 1 4 68
CDER DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IDER DTE OHMM 599371 00 000 00 0 3 1 1 4 68
CMER DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IMER DTE OHMM 599371 00 000 00 0 3 1 1 4 68
CDVR DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IDVR DTE OHMM 599371 00 000 00 0 3 1 1 4 68
CMVR DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IMVR DTE OHMM 599371 00 000 00 0 3 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
PAGE:
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
CILD DTE MMHO 599371 00 000 00 0 3 1 1 4 68
ILD DTE OHMM 599371 00 000 0'0 0 3 1 1 4 68
CILM DTE MMHO 599371 00 000 00 0 3 1 1 4 68
ILM DTE OHMM 599371 00 000 00 0 3 1 1 4 68
IDQF DTE 599371 00 000 00 0 3 1 1 4 68
IMQF DTE 599371 00 000 00 0 3 1 1 4 68
IIRD DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IIXD DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IIRM DTE MMHO 599371 00 000 00 0 3 1 1 4 68
IIXM DTE MMHO 599371 00 000 00 0 3 1 1 4 68
SFLU DTE OHMM 599371 00 000 00 0 3 1 1 4 68
SP DTE MV 599371 00 000 00 0 3 1 1 4 68
GR DTE GAPI 599371 00 000 00 0 3 1 1 4 68
TENS DTE LB 599371 00 000 00 0 3 1 1 4 68
MTEM DTE DEGF 599371 00 000 00 0 3 1 1 4 68
MRES DTE OHMM 599371 00 000 00 0 3 1 1 4 68
HTEN DTE LB 599371 00 000 00 0 3 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
** DATA **
DEPT. 12295.500 DT.BHC 78.100 TT1.BHC 520.800
TT3.BHC 502.000 TT4.BHC 355.200 SP.BHC -70.000
TENS.BHC 2690.000 MTEM.BHC 196.873 MRES.BHC 0.778
CIDP.DTE 224.400 IDPH.DTE 4.456 CIMP.DTE 267.373
CDER.DTE 223.884 IDER.DTE 4.467 CMER.DTE 267.349
CDVR.DTE 224.306 IDVR.DTE 4.458 CMVR.DTE 267.419
CILD.DTE 226.951 ILD.DTE 4.406 CILM.DTE 269.286
IDQF.DTE 0.000 IMQF.DTE 0.000 IIRD.DTE 194.942
IIRM.DTE 252.062 IIXM DTE 12.032 SFLU.DTE 3.920
GR.DTE 16.250 TENS.DTE 2690.000 MTEM.DTE 196.873
HTEN.DTE 24.600
DEPT. 12000.000 DT.BHC 89.400 TT1.BHC 546.000
TT3.BHC 548.800 TT4.BHC 384.400 SP.BHC -56.813
TENS.BHC 6010.000 MTEM.BHC 193.708 MRES.BHC 0.801
CIDP.DTE 137.184 IDPH.DTE 7.289 CIMP.DTE 101.710
CDER.DTE 119.458 IDER.DTE 8.371 CMER.DTE 113.399
CDVR.DTE 159.526 IDVR.DTE 6.269 CMVR.DTE 161.400
CILD.DTE 119.303 ILD.DTE 8.382 CILM.DTE 136.151
IDQF.DTE 0.000 IMQF.DTE 0.000 IIRD.DTE 110.938
IIRM.DTE 128.588 IIXM.DTE 23.187 SFLU.DTE 15.536
GR.DTE 48.013 TENS.DTE 6010.000 MTEM.DTE 193.708
HTEN.DTE 1218.028
DEPT. 11775.500 DT.BHC' 63.900 TT1.BHC -999.-250
TT3.BHC -999.250 TT4.BHC -999.250 SP.BHC 27.375
TENS.BHC 5770.000 MTEM.BHC 184.409 MRES.BHC 0.854
CIDP.DTE 68.609 IDPH.DTE 14.575 CIMP.DTE -226.658
CDER.DTE 49.543 IDER.DTE 20.184 CMER.DTE -233.459
TT2.BHC
GR.BHC
HTEN.BHC
IMPH.DTE
IMER.DTE
IMVR.DTE
ILM.DTE
IIXD.DTE
SP.DTE
MRES.DTE
TT2.BHC
GR.BHC
HTEN.BHC
IMPH.DTE
IMER.DTE
IMVR.DTE
ILM.DTE
IIXD.DTE
SP.DTE
MRES.DTE
TT2.BHC
GR.BHC
HTEN.BHC
IMPH.DTE
IMER.DTE
355.200
16.250
24.600
3.740
3.740
3.739
3.714
19.582
-70.000
0.778
372.800
48.013
1218.028
9.832
8.818
6.196
7.345
19.526
-56.813
0.801
-999.250
83.807
1169.689
1950.000
1950.000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
CDVR.DTE 33.246 IDVR.DTE
CILD.DTE 75.022 ILD.DTE
M F.
IDQF.DTE 0.000 IIQMX DTE
IIRM DTE -112.792 I DTE
GR.DTE 83.807 TENS.DTE
HTEN.DTE 1169.689
20-0CT-1993 10:36
30.079 CMVR.DTE
13.329 CILM.DTE
0.000 IIRD.DTE
-293.596 SFLU.DTE
5770.000 MTEM.DTE
-249.737
-158.779
41.030
0.626
184.409
IMVR.DTE
ILM.DTE
IIXD.DTE
SP.DTE
MRES.DTE
PAGE:
1950.000
1950.000
-11.045
27.375
0.854
10
END OF DATA
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION · 001C~I
DATE '93~ 20
MAX REC SIZE ' 10
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION ' 001C0}
DATE · 93/10 20
MAX REC SIZE ' 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 4
RAW OPEN HOLE REPEAT PASSES
Curves and log header data for each pass,
RUN NUMBER: 1
TOOL STRING NUMBER: 1
PASS NUMBER: 1
DEPTH INCREMENT: 0.5000
FILE SUMMARY
LDWG TOOL CODE START DEPTH
tool
STOP DEPTH
BHR 1 2286.0
DTR 1 2286.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
11766.5
11766.5
string, and run in
05-SEP-93
5C0-423
25 05-SEP-93
551 05-SEP-93
separate files.
LIS TaDe Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10:36
TD DRILLER. (.FT) ·
TD LOGGER(FT):
TOP LOG INTERVAL (FTI '
BOTTOM LOG INTERVAL~T)-
LOGGING SPEED (FPHR):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
12275.0
12269.0
11854.0
12228.0
0.0
TOOL NUMBER
AMS
TCC
GR
BHC
SDT
DTE
iDTE
AUXILIARY MEASUREMENTS
TELEMETRY CARTRIDGE
GAMMA RAY CARTRIDGE
BOREHOLE SONIC CART.
SONIC SONDE
PHASOR INDUCTION CART.
PHASOR INDUCTION SONDE
AMS-A 712
TCC-B 281
SGC-SA 50
SLC-UA 278
SLS-WA 2004
DIC-EB 427
DIS-HB 434
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (INI:
DRILLERS CASING DEPTH.(F?)'
LOGGERS CASING DEPTH (FT)'
6.750
11863.0
11854.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENS'ITY (LB/ .'
MUD VISCOSITY (S~)
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF
RESISTIVITY (OHMM) AT TEMPERATURE
MUD AT MEASURED TEMPERATURE (MT
MUD AT BOTTOM HOLE TEMPERATURE
MUD FILTRATE AT (MT):
MUD FILTRATE AT()BHT '
MUD CAKE AT (MT):
MUD CAKE AT()BHT ·
DEGF ):
:
BHT ):
LSND
9.80
41 .00
10.10
196.0
2.490
2.650
2.060
72.0
68.0
68.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN): 0.8
REMARKS: THE TOOL STRING WAS CENTRALIZED WITH 0.8" RUBBER FIN
STANDOFF AND A 2' HOLE FINDER.
# $
LIS FORMAT DATA
PAGE:
11
LIS Tape Verification Listing
Schlumberger~ Alaska Computing Center
20-0CT-1993 10:36
DATA FORMAT SPECIFICATION RECORD
SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 164
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 6
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
PAGE:
12
SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
DEPT FT 599371 00 000 00 0 4 1 1 4 68
DT BHR US/F 599371 00 000 00 0 4 1 1 4 68
TT1 BHR US 599371 00 000 00 0 4 1 1 4 68
TT2 BHR US 599371 00 000 00 0 4 1 1 4 68
TT3 BHR US 599371 00 000 00 0 4 1 1 4 68
TT4 BHR US 599371 00 000 00 0 4 1 1 4 68
SP BHR MV 599371 00 000 00 0 4 1 1 4 68
GR BHR GAPI 599371 00 000 00 0 4 1 1 4 68
TENS BHR LB 599371 00 000 00 0 4 1 1 4 68
MTEM BHR DEGF 599371 00 000 00 0 4 1 1 4 68
MRES BHR OHMM 599371 00 000 00 0 4 1 1 4 68
HTEN BHR LB 599371 00 000 00 0 4 1 1 4 68
CIDP DTR MMHO 599371 00 000 00 0 4 1 1 4 68
IDPH DTR OHMM 599371 00 000 00 0 4 1 1 4 68
CIMP DTR MMHO 599371 00 000 00 0 4 1 1 4 68
IMPH DTR OHMM 599371 00 000 00 0 - 4 1 1 4 68
CDER DTR MMHO 599371 00 000 00 0 4 1 1 4 68
IDER DTR OHMM 599371 00 000 00 0 4 1 1 4 68
CMER DTR MMHO 599371 00 000 00 0 4 1 1 4 68
IMER DTR OHMM 599371 00 000 00 0 4 1 1 4 68
CDVR DTR MMHO 599371 00 000 00 0 4 1 1 4 68
IDVR DTR OHMM 599371 00 000 00 0 4 1 1 4 68
CMVR DTR MMHO 599371 00 000 00 0 4. 1 1 4 68
IMVR DTR 0HMM 599371 00 000 00 0 4 1 1 4 68
CILD DTR MMHO 599371 00 000 00 0 4 1 1 4 68
ILD DTR OHMM 599371 00 000 00 0 4 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Cent
er
20-0CT-1993 10:36
PAGE:
13
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
CILM DTR MMHO 599371 00
ILM DTR OHMM 599371 00
IDQF DTR 599371 00
IMQF DTR 599371 00
IIRD DTR MMHO 599371 00
IIXD DTR MMHO 599371 00
IIRM DTR MMHO 599371 00
IIXM DTR MMHO 599371 00
SFLU DTR OHMM 599371 00
SP DTR MV 599371 00
GR DTR GAPI 599371 00
TENS DTR LB 599371 00
MTEM DTR DEGF 599371 00
MRES DTR OHMM 599371 00
HTEN DTR LB 599371 00
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
000 00 0 4 1 1 4 68
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
DATA **
DEPT. 12286.000
TT3.BHR 502.800
TENS.BHR 2065.000
CIDP.DTR 221.945
CDER.DTR 221.389
CDVR.DTR 221.817
CILD.DTR 224.622
IDQF.DTR 0.000
IIRM.DTR 255.398
GR.DTR 21.667
HTEN.DTR 182.367
DEPT. 12000.000
TT3.BHR 549.600
TENS.BHR 6035.000
CIDP.DTR 128.396
CDER.DTR 121.855
CDVR.DTR 186.348
CILD.DTR 112.872
IDQF.DTR 0.000
IIRM.DTR 123.360
GR.DTR 44.006
HTEN.DTR 1216.138
DEPT. 11766.500
TT3.BHR -999.250
TENS.BHR 5900.000
CIDP.DTR 63.021
CDER.DTR 70.518
CDVR.DTR 69.307
CILD.DTR 44.826
DT.BHR 79.400 TT1.BHR 524.800
TT4.BHR 354.800 SP.BHR -15.000
MTEM.BHR 194.577 MRES.BHR 0.791
IDPH.DTR 4.506 CIMP.DTR 270.770
IDER.DTR 4.517 CMER.DTR 270.724
IDVR.DTR 4.508 CMVR.DTR 270.725
ILD.DTR 4.452 CILM.DTR 272.917
IMQF.DTR 0.000 IIRD.DTR 193.064
IIXM.DTR 9.656 SFLU.DTR 3.685
TENS.DTR 2065.000 MTEM.DTR 194.577
DT.BHR 89.100 TT1.BHR 545.600
TT4.BHR 384.000 SP.BHR -88.063
MTEM'.BHR 191.919 MRES.BHR 0.817
IDPH.DTR 7.788 CIMP.DTR 107.826
IDER.DTR 8.206 CMER.DTR 128.461
IDVR.DTR 5.366 CMVR.DTR 200.325
ILD.DTR 8.860 CILM.DTR 130.566
IMQF.DTR' 0.000 IIRD.DTR 105.803
IIXM DTR 21.787 SFLU.DTR 15.370
TENS.DTR 6035.000 MTEM.DTR 191.919
DT.BHR 56. 200 TT1.BHR -999.250
TT4. BHR -999 . 250 SP. BHR -2.31 3
MTEM. BHR 1 80 . 1 29 MRES .BHR 0. 874
IDPH. DTR 1 5 . 868 CIMP. DTR -1 60 . 428
IDER. DTR 1 4.1 81 CMER. DTR -1 60 . 236
IDVR.DTR 14.429 CMVR.DTR -161 .692
ILD. DTR 22 . 308 CILM.DTR -1 48. 894
TT2.BHR
GR.BHR
HTEN.BHR
IMPH.DTR
IMER.DTR
IMVR.DTR
ILM.DTR
IIXD.DTR
SP.DTR
MRES.DTR
TT2.BHR
GR.BHR
HTEN.BHR
IMPH.DTR
IMER.DTR
IMVR.DTR
ILM.DTR
IIXD.DTR
SP.DTR
MRES.DTR
TT2.BHR
GR.BHR
HTEN.BHR
IMPH.DTR
IMER.DTR
IMVR.DTR
ILM.DTR
355.200
21.667
182.367
3.693
3.694
3.694
3.664
17.840
-15.000
0.791
376.800
44.006
1216.138
9.274
7.784
4.992
7.659
17.533
-88.063
0.817
-999.250
87.257
1~74.287
1950.000
1950.000
1950.000
1950.000
LIS TaDe Verification Listing
Schlumberger Alaska Computing Center
IDQF.DTR 0 . 000 IMQF. DTR
IIRM DTR -245.679 IIXM DTR
GR.DTR 87.257 TENS.DTR
HTEN.DTR 1174.287
20-0CT-1993 10:36
0.000 IIRD.DTR
-492.573 SFLU.DTR
5900.000 MTEM.DTR
59.273
0.600
180.129
IIXD.DTR
SP.DTR
MRES.DTR
PAGE: 1 4
-76.267
-2.313
0.874
END OF DATA
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSiO · oo co
· 3t o/2o
DATE
MAX REC SIZE ' 10
FILE TYPE : LO
LAST FILE :
**** FILE HEADER
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION ' 001C01
DATE ' 93~0/20
MAX REC SIZE ' 10
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 5
RAW CASED HOLE MAIN PASS
Curves and log header data for open hole logs run
RUN NUMBER: 1
TOOL STRING NUMBER: 1
PASS NUMBER: 3
DEPTH INCREMENT: 0.5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
into casing.
CSG 11925.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLEg (~T)'
TD LOGGER[FT):
TOP LOG INTERVAL (FT):
11745.5
05-SEP-93
5C0-423
25 05-SEP-93
· 551 05-SEP-93
12275.0
12269.0
11854.0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10'36
· BOTTOM LOG INTERVAL (FT)'
LOGGING SPEED (FPHR)'
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
12228.0
0.0
TOOL NUMBER
AMS
TCC
GR
BHC
SDT
DTE
DTE
$
AUXILIARY MEASUREMENTS
TELEMETRY CARTRIDGE
GAMMA RAY CARTRIDGE
BOREHOLE SONIC CART.
SONIC SONDE
PHASOR INDUCTION CART.
PHASOR INDUCTION SONDE
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT)'
LOGGERS CASING DEPTH (FT)'
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/O)'
MUD VISCOSITY (S)'
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF
RESISTIVITY (OHMM) AT TEMPERATURE
MUD AT MEASURED TEMPERATURE (MT
MUD AT BOTTOM HOLE TEMPERATURE
MUD FILTRATE AT (MT):
MUD FILTRATE AT()BHT '
MUD CAKE AT (MT)
;
MUD CAKE AT(BHT)'
DEGF) ·
·
BHT) ·
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL)'
MATRIX'
MATRIX DENSITY'
HOLE CORRECTION (IN)'
TOOL STANDOFF (IN):
REMARKS:
# $
LIS FORMAT DATA
AMS-A 712
TCC-B 281
SGC-SA 50
SLC-UA 278
SLS-WA 2004
DIC-EB 427
DIS-HB 434
6.750
11863.0
11854.0
LSND
9.80
41 .00
10.10
196.0
2.490
2.650
2.060
0.8
72.0
68.0
68.0
PAGE'
15
lIS Tape Verification Listing
;chlumberger Alaska Computing Center
20-0CT-1993
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 64
12 68
13 66 0
1 4 65 FT
15 66 68
16 66
0 66 1
10:36
PAGE:
16
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE
PROCESS
( HEX )
DEPT FT 599371 00 000 00 0 5 1 1 4 68
GR CSG GAPI 599371 00 000 00 0 5 1 1 4 68
TENS CSG LB 599371 00 000 00 0 5 1 1 4 68
HTEN CSG LB 599371 00 000 00 0 5 1 1 4 68
0000000000
0000000000
0000000000
0000000000
** DATA **
DEPT. 11925.000 GR.CSG 54.168 TENS.CSG 2215.000
DEPT. 11500.000 GR.CSG 51.549 TENS.CSG 5590.000
DEPT. 11000.000 GR.CSG 63.686 TENS.CSG 5615.000
DEPT. ]0745.500 GR.CSG -999.250 TENS.CSG -999.250
HTEN.CSG
HTEN.CSG
HTEN.CSG
HTEN.CSG
630.213
1095.452
1058.970
-999.250
END OF DATA
LIS Tame Verification Listing
Schlumberger Alaska Computing Center
20-0CT-1993 10'36
PAGE'
17
**** FILE TRAILER ****
FILE NAME : EDIT .005
SERVICE : FLIC
·
VERSION · 001C~1
DATE ' 93/1 /20
MAX REC SIZE ' 10
24
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME ' ED%T
DATE · 93/10/20
ORIGIN : FLIC
TAPE NAME : 93418
CONTINUATION # : 1
PREVIOUS TAPE
COMMENT : BP EXPLORATION, PRUDHOE BAY, P-23, 50-029-22393-00
**** REEL TRAILER ****
SERVICE NAME ' EDIT
DATE ' 93/1 0/20
ORIGIN : FLIC
REEL NAME : 93418
CONTINUATION # :
PREVIOUS REEL :
COMMENT : BP EXPLORATION, PRUDHOE BAY, P-23, 50-029-22393-00
