Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout197-164STATE OF ALASKA � A. 16-9 #.
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG nrr s 3n,,
la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® ' Suspended ❑
lb. Well Class:
20AAC 25.105 20MC 25.110
11'0''
GINJ ❑ WINJ ❑ WAG WDSPL ❑ No. of Completions: Zero
D`�/ �i pl refory ❑
Service ❑ Stratigraphic Test ❑
2. Operator Name:
6. Date Comp., Susp., or Aband.:
14. Permit to Drill Number/Sundry
BP Exploration (Alaska), Inc
11/15/2019
197-164 r 318,365
3. Address:
7. Date Spudded:
15. API Number:
P.O. Box 196612 Anchorage, AK 99519-6612
9/16/1997
50-029-22803-00-00
4a. Location of Weil (Governmental Section):
S. Date TO Reached:
16. Well Name and Number:
10/3/1997
PBU W34 y
Surface: 3224' FSL, 1265' FEL, Sec. 21,T11N, R13E, UMRef
Elevations
9. KB 74.80
17. Field/Pool(s):
Top Of Productive Interval: 2990' FSL, 3174' FEL, Sec. 21, T11 N, R13E, UM
GL 45.40 BF Surface
PRUDHOE BAY, PRUDHOE OIL
Total Depth: 3620' FSL, 4174' FEL, Sec, 21, Tl 1N, R13E, UM
10. Plug Back Depth(MD/TVD):
i
18. Property Designation:
Surface/Surface
ADL 028284 /
4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27):
11, Total Depth (MD/rVD):
19. DNR Approval Number:
Surface. x- 643340 y- 5958733 Zone - ASP 4
10710' / 9111'
69-026
TPI: x- 641436 y- 5958463 Zone - ASP 4
12. SSSV Depth (MD/TVD):
20Thickness of Permafrost MD/ D.
Total Depth: x- 640423 y- 5959074 Zone - ASP 4
None
1900' (Approx.) ,
5. Directional or Inclination Survey: Yes ❑ (attached) No 0
13. Water Depth, if Offshore:
21. Re-drillLateral Top Window
Submit electronic and printed information per 20 AAC 25.050
N/A (ft MSL)
MDTVD:
N/A
22. 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
MWD, GR, RES, RLL, RFT, USIT
23.
CASING, LINER AND CEMENTING RECORD
CASING
Wr. PER
FT.
GRADE
SETTING DEPTH MO
SETTING DEPTH TVD
HOLE SIZE
CEMENTING RECORD
AMOUNT
PULLED
TOP
BOTTOM
TOP
BOTTOM
20"
94#
H-40
Surface
111'
Surface
111'
30"
260 sx Arctic Set(Approx.)
9-5/8"
40#
Lao
Surface
3643'
Surface
3639'
12-1/4"
1637 sx Coldset, 500 sx Class'G'
7"
26#
L-90
Surface
9167'
Surface
8670'
8-1/2"
250 sx Class'G'
4-1/2"
12.6#
L-80
8995'
10709'
8552'
9110'
6"
178 sx Class'G'
24. Open to production or injection? Yes ❑ No 9
25, TUBING RECORD
If Yes, listeach interval open (MD/TVD of Top and Bottom; Perforation
Size and Number; Date Perfd):
GRADE DEPTH SET (MD) PACKER SET (MD/TVD)
4-1/2" 12.6# L-80 9011' 8956'/ 8524
AVQnjBn
26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
Was hydraulic fracturing used during completion? Yes ❑ No m
Per 20 AAC 25.283 (i)(2) attach electronic and printed
=tT
information
_
VE I IE
DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED
See Attached
27. PRODUCTION TEST
Date First Production: Not on Production
Method of Operation (Flowing, gas lit, etc.): WA
Date of Test:
Hours Tested:
Production for
Test Period --►
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Choke Size
Gas -Oil Ratio:
Flow Tubing
Press
Casing Press:
Calculated
24 Hour Rate --►
Oil -Bbl:
Gas -MCF:
Water -Bbl:
Oil Gravity- API(com
Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only
Y u ron t q RBDMSA'JDEC 17 2019 V,CB liglac -�G
28. CORE DATA Conventional Cones) Yes ❑ No IZ Sidewall Cores Yes ❑ No 0
If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presenceof 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.
29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS
NAME
MD
TVD
Permafrost - Top
Well Tested? Yes ❑ No
Permafrost - Base
If yes, list intervals and formations tested, briefly summarizing lest results. Attach
Top of Productive Interval
9409'
8774' separate sheets to this form, if needed, and submit detailed test information per 20
AAC 25.071.
Sag River
9166'
8670' ,
ShublikA
9202'
8692' r
Shublik B
9273'
8729'
Shublik C
9325'
8750'
Sadlerochit-Zone 4
9409'
8774'
CGL - Zone 3
10539'
8972'
Base of CGL - Zone 2
10641'
9049'
Formation at total depth:
Zone 2
10641'
9049'
31. List of Attachments: Summary of Daily Work, Photo Documentation, Wellbore Schematic Diagram
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.
32. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Authorized Name: Lastufka, Joseph N Contact Name: Hibbert, Michael
Authorized Title: peciatt Contact Email: Michael. HlbbertQBP.com
Authorized Signature: Date: v -/W7 Contact Phone: +1 907 564 4351
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 10404 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: Flawing, 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 orwell test results.
Form 10407 Revised 512017 Submit ORIGINAL Only
TREE= 4-1/16'CAMERON
WELLHEAD=
FMC
ACTUATOR=
BAKER
KB.ELEV=
DATE
BF. ELEV=
SURFACE
ROP =
5400'
Ma%A =
91' 9708'
Dawn MD =
10341'
Datum TVD=
8800'SS
ABANDONED H-34
T X a X OASuI�4RS76�44"4R4
66 SP�
(08/06/19)
L80, D = 8.835'
SPF (07/04/1 W 36� 57' - 36f
OF TBG CMT(
,C N TBG 8 W
Minimum ID = 3.725" @ 8999'
4-1/2" HES XN NIPPLE
STOP OF BAKER TACK SLV, D=5.25' I
X5,
7' CSG, 26#, L-80, D=6.276'9167
PERFORATIONSUMMARY
REF LOG: SPERRY MWD ON 10/03197
ANGLE AT TOP PERF: 81'@ 9440'
Note: Refer to Prodrehan DB for historical perfdata
S Z
SPF
INTERVAL
OpnSaz
DATE
2-3/4'
4
9440-9470
C
10/08/97
2-7/8'
6
9470-9555
C
01/06/03
2-7/8'
4
9555-9580
C
05/06/02
2-7/8'
6
9580-9725
C
01/06/03
2-7/8'
4
9725-9750
C
05/06/02
27/4'
4
9810-9960
C
10/08/97
2-7/8'
6
9980-10080
C
01/06/03
2-7/8'
6
10120-10170
C
01/06/03
12.6#,
SAFETY NOTES: WELL > 70" @ 9330' AND> 900
9671'. "` WAIVER CANCELLED 1226/04 BY
JLW "`
2126' 4-1/2' EES HXO SSSVN, D= 3.813'
3025--3660 'EL TAGGED TX IA TOC @ 3025' ON
08/06/19 - EST BOC IN TX IA (0726/19)
WELLHEAD CUT OFF 41612
BELOW TUNDRA 11/15/19
rAC I eT MA Anara c
ST
MD
TVD
DEV'
TYPE
VLV
LATCHIPORTI
NXW/JMD EL TAGGED TX b TOC 08/06/19
DATE
4
3832
3753
2
KBG2LS
DMY
NTG
0
02/14/19
3
5827
5729
20
KBG2LS
EMPTY
-
-
11/07/18
2
7539
7244
29
KBG2LS
EMPTY
-
-
11/07/18
1
8795
8329
39
KBG2LS
5/O
NTG
20
01/31/03
HIM EZ -DRILL CMT RE
HFSX NP, D=3.813'
X 4-12' BKR S-3 PKR, D =
1/2' HES X NP, D = 3.313-
89W I-j4-12'HESXNNP.D=3.725'
TBG, 12.6#, L-80,
WLEG, D = 3.958'
9014' B MD TT LOGGED 0624/98
DATE
REV BY COMMENTS
DATE
REV BY COMMENTS
10/10197
ORIGINAL COMPLETION
10/01/19
NXW/JMD EL TAGGED TX b TOC 08/06/19
02/19/19
JMGtJMD SL TAGGED TBG TOC 02/13/19
10/01/19
MRD/JMD TX WXOACMT 0827/19
07/17/19
NXW/JMD TBG PUNCHES 07/03-04/19
12102/19
JA/JMD ABANDONED J11/15/19
0724/19
TS/JMD UPDATED TBG TOC TAG
07/31/19
MRD/JMD CMT PLUG NTXa 0726/19
0821/19
NXW/JMD TBG PUNCH & TAGGED CMT
IN&*03
PRUDHOE BAY UNIT
WELL: H-34
PERMIT No: r1971640
API No: 50-029-22803-00
BP Exploration (Alaska)
WELL NAME:
H-34
26.
Acid, Fracture, Cement Squeeze, Etc.
Depth Interval (MD)
Amount & Kind of Material Used
8645'- 8656'
Tubing Punch
8668'
Set Cement Retainer
4084'
150 Bbls Class'G'
4052'- 4057'
Tubing Punch
3928'-3933'
Tubing Punch
3657'- 3662'
Tubing Punch
3025'
17 Bbls Class'G'
3001'- 3006'
Perforate Casing
Surface
138 Bbls Class'G', 87 Bbls Class'G'
Surface
-2 Gal AS I
****WELL S/I UPON ARRIVAL**** (P&A)
PULLED 4-1/2" HXO DSSSV PLUG FROM SVLN @ 2,126' MD
11/4/2018
****CONT JOB ON 11/5/18****
****CONT. JOB FROM 11/4/18**** (P&A)
DRIFTED W/ 3.70" WRP DRIFT, S -BAILER, TAG FILL @ 8,667' SLM (Sample of scale)
SET 4-1/2" SLIP STOP CATCHER @ 7,582' SLM
PULLED STA #3 INT-LGLV FROM 5,816' SLM / 5,827' MD
PULLED STA #2 INT-LGLV FROM 7,535' SLM / 7,539' MD
PULLED STA #4 INT-LGLV FROM 3,819' SLM / 3,832' MD
SET STA #4 INT-DGLV
11/5/2018
****CONT JOB ON 11/6/18****
****CONT. JOB FROM 11/5/18**** (P&A)
SET STA #3 INT-DGLV
MADE 2 ATTEMPTS TO SET STA #2 DGLV (Unable to s/d in glm)
RAN KJ, 4-1/2" OK -6, 1" POCKET POKER TO STA #2 (All tt pins sheared)
MADE 1 ATTEMPT TO SET STA #2 DGLV (Unable to s/d in glm)
RAN 4-1/2" D&D HOLEFINDER (See log, Unable to catch pressure until set just below sta #4
@ 3,845' slm)
PULLED STA's #3 & #4 INT-DGLV's
RAN 4-1/2" GR, S/D @ 7,580' SLM (Unable to latch catcher)
RAN 10'x 2-1/2" P -BAILER TO TOP OF CATCHER @ 7,580' SLM (Recovered —1 gal scale)
****CONT JOB ON 11/7/18****
11/6/2018
NOTE: STA's #2, #3 & #4 GLM'S LEFT AS OPEN POCKETS PER SOR
T/1/0=525/413/348 Temp=Sl Assist S -line LDL Spear in to TBG with 10 bbls of 50* 60/40
possible hydrates Pumped 32 bbls of 60* crude to assist S -line with D&D hole finder. ***WSR
11/6/2018
continued on 11-07-18***
****CONT. JOB FROM 11/6/18**** (P&A)
PULLED 4-1/2" SLIP -STOP CATCHER FROM 7,581' SLM (Empty)
LRS PUMPED —100 BBLS HOT (180*F) DIESEL DOWN IA (See LRS log)
UNABLE TO ACHIEVE INJECTIVITY ON BALANCE OR CONTROL LINES
11/7/2018
****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE****
***WSR continued from 11-06-18*** Assist Slickline with Plug & Abandonment. Pumped 100
bbls, 180*F, diesel down IA to thaw control line. Slickline in control of well upon LRS
11/7/2018
departure. FWHP's 530/555/685
T/I/0= 460/500/340 Temp=S/I (LRS Unit 70- Assist E -line w/ injectivity test/Plug And
Abandonment) Pumped 2 bbls 60/40 and 25 bbls 10* diesel down TBG to establish baseline
11/25/2018
injectivity of: 5 bpm @ 565 psi. E -line RI to punch tubing. ***Continued on 11-26-18 WSR***
T/I\O = 490/50/340. Temp = SI. TBG & IA FL (Eline Request). ALP = 150 psi, SI @ CV.
TBG FL @ Near Surface. IA FL @ Surface.
11/25/2018
SV, WV = C. SSV, MV = O. IA, OA = OTG. 15:00
***JOB STARTED 25-NOV-2018*** (SLB ELINE TUBING PUNCH, SET CEMENT RET)
WELL SHUT IN ON ARRIVAL
INITIAL T/I/O = 450/500/400
RU. PT,
LRS PERFORM BASELINE INJECTIVITY TEST OF 5 BPM @ 565 PSI.
11/25/2018
***JOB CONTINUED ON 26-NOV-2018***
Daily Report of Well Operations
PBU H-34
***JOB CONTINUED FROM 25-NOV-2018*** (SLB ELINE TUBING PUNCH AND SET
CEMENT RET)
RUN 1: RIH W/ 11' TUBING PUNCH O DEG PHASED SMALL CHARGES.
TAG FILL @ 8678' ._ PUNCH TUBING 8645'- 8656'. (SOF SMALL CHARGES AND 5'
MEDIUM CHARGES). POOH.
LRS PERFORMED INJECTIVITY 5 BPM @ 560 PSI.
RDMO FOR INCOMING BLOW.
11/26/2018
***JOB INCOMPLETE WILL RETURN LATER AFTER WEATHER***
***Continued from 11-25-18 WSR*** (LRS Unit 70- Assist E -line w/ injectivity test/Plug and
Abandonment) E -line shot perfs- Pumped 10 bbls 10* diesel down TBG for injectivity of: 5
bpm @ 560 psi. E -line SD for wind. E -line in control of well upon departure. IA OA= OTG
11/26/2018
Final WHP's=470/530/330
T/1/0= 470/500/400 Temp= S/I (LRS Unit 70 - Injectivity Test 3 Post Cement Retainer Set)
Pumped 2 bbls 18* 60/40 followed by 15 bbls 10* diesel down TBG to establish an injectivity
rate of 5 bpm @ 600 psi.
WV,SV,SSV= closed; MV, CV's= open
11/28/2018
FWHP's 500/500/353
***JOB CONT FROM 11-26-18 WSR'**(SLB ELINE TUBING PUNCH AND SET CEMENT
RET)
PICK BACK UP AFTER WINDS DIED DOWN
RUN 2: SET HES 4 1/2" EZ -DRILL CEMENT RET. @ 8669' ME, CCL TO ME = 77, TOP OF
PLUG @ 8668'
11/28/2018
RDMO
1/20/2019
Heat diesel transports to 90*
1/22/2019
LRS Unit 70: Heat two diesel transports to 90*
CTU 9 1.75" coil 0.156WT HT 110 bluecoil
Objective: P&A
MIRU
1/23/2019
***In progress***
CTU 9 1.75" Blue Coil
Standby due to GC -2 Simops from 09:00 to 21:00.
1/23/2019
CTU 9 1.75" coil 0.156WT HT 110 bluecoil
Objective: P&A
Continue RU. Rate check MM's. Displace IA, well and coil to diesel. Pump surfactant wash
on top of cement retainer, Sting into retainer, unable to inject without tripping pump at
4200psi. Unsting and then re -sting to confirm. No injectivity still. Discuss with town.
Pressure up to 2500psi and perform 15min leakoff test. Pull out of retainer and pump/lay in a
total 150bbis of 15.8ppg class G cement. Cement pump lost prime several times during
laying in cement. Estimated TOC= —4150'. POOH pumping diesel pipe disp. Well/IA are
FP with diesel to 2500'.
1/24/2019
CTU 9 1.75" coil 0.156WT HT 110 bluecoil
Objective: P&A
Complete rig down
1/25/2019
***Job complete***
Daily Report of Well Operations
PBU H-34
T/1/0=347/200/338 Temp= S/I (LRS Unit 70 - CMIT-TxIA, OA Injectivity Test Post Coil
Cement Job)
CMIT Tx IA FAILED 2250 psi test (Target 2250 psi Max applied 2500 psi) Pumped 2 bbls of
10* diesel down IA to reach test psi
1st test 1st 15 min TP lost 130 IAP lost 130 2nd 15 min TxIA lost 128/124 for a total of
258/254 psi in 30 min
2nd test 1st 15 min TxIAP lost 152/128 2nd 15 min 113/120 for a total of 265/248 psi in 30
min
3rd test 1st 15 min TxIA lost 157/125 2nd 15 min 104/120 for a total of 261/245 psi in 30
min
OA Injectivity Test:
Pumped 1 bbl of -10* diesel down OA to reach 1497 psi monitor psi in 8 min lost 1017 psi
2nd attempt @ pumping down OA psi started falling @ 1111 psi shut down look for leaks no
leaks 3rd attempt @ pumping down OA pumped .8 bbl to reach 1500 psi & in 8 min lost 211
psi.
1/29/2019
IPumped 0.5 bbls diesel down OA to check for injectivity, came down on pump @ 1500 psi
***WSR continued from 01-29-19*** (LRS Unit 70 - CMIT-TxIA, OA Injectivity Test Post Coil
Cement Job)
4th CMIT-TxIA FAILED to 2086/2196 psi. Target Pressure= 2250 psi, Max Applied Pressure=
2500 psi. Reached starting test pressure 2456/2485 psi with 1.6 bbls -10* diesel (see
previous day AWGR's) TBG/IA lost 240/149 psi in 1 st 15 minutes and 130/140 psi in 2nd 15
minutes for a total loss of 370/289 psi during 30 minute test. Bled T/IA to 280/300 psi,
returned — 1 bbl.
1/30/2019
WV,SV,SSV= closed; MV,CV's= open
***WELL S/I ON ARRIVAL***(p&a)
DRIFT & TAG TOC W/ 3.00" CENT & 2.50" SAMPLE BAILER @ 4,062' SLM
PERFORMED STATE WITNESSED CEMENT TAG W/ 3.0" CENT, 2.50" SAMPLE BAILER
2j0.67' SLM
DRIFTED TUBING W/ 3.80" GAUGE RING AND STOPPED @ 4,000' SLM (no issues)
DROPPED 4 1/2" SS-CATCHER ON CEMENT @ 4,061' SLM
ATTEMPTED TO SET INT-DGLV IN STA #4 @ 3,832' MD (unable to sd)
PULLED SS-CATCHER FROM 4,061' SLM
2/13/2019
***CONT WSR ON 2/14/19***
***CONT WSR FROM 2/13/19*** (p&a)
RAN 4 1/2" BRUSH, 3.80" GAUGE RING DOWN TO 4,000' SLM (brushed glm #4)
RAN 1" POCKET BRUSH W/ TT PIN TO STA #4 @ 3,832' MD (ring on no-go)
4 1/2" SS-CATCHER SET ON CEMENT @ 4,061' SLM
SET INT-DGLV IN STA #4 @ 3,832' MD
PULLED EMPTY 4 1/2" SS-CATCHER FROM 4,061' SLM
2/14/2019
***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS***
T/1/0= 408/223/216 Temp= S/I CMIT TxIA ***FAIL*** at 2399/2208 psi Max Applied
Pressure = 2500 psi Target Pressure= 2250 psi, (PLUG AND ABANDONMENT) Pumped
1.58 bbls 60/ 40 to achieve test pressure. 1st 15 min lost 50/141 TxIA psi. 2nd 15 min lost
38/120 TxIA psi. Total loss of 88/261 TxIA psi.. 3 attempt in which Remote gauge lost
battery to send to MDAS recorder, so Visival readings where taken. Pumped 1.48 bbls 60/40
to achieve test pressure. 1st 15 min lost 161/302 TxIA psi. 2nd 15 min lost 60/154 TxIA psi.
Total loss of 221/456 TxIA psi. Fail per J.Lau. AFE sign and tags hung on tree, Valve
2/20/2019 1position
at departure- SV,WV,SSV=closed MV=open IA/OA=otg, FWHP= 303/308/285
T/I/O = 350/210/340. Temp = SI. WHPs (LTSI survey). ALP = 1440 psi.
2/27/2019
SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:50
Daily Report of Well Operations
PBU H-34
***WELL S/I ON ARRIVAL*** (tbg punch)
TAG TOC @ 4084' ELM.
PUNCH TUBING FROM 4,051.5'-4,056.5', CCL TO TOP SHOT = 3.4', CCL STOP AT
4048.1' (cannot circulate through punched tubing).
PUNCH TUBING FROM 3,928'-3,933', CCL TO TOP SHOT = 7.5', CCL STOP AT 3,920.5'
(cannot circulate through punched tubing).
LOGS CORRELATED TO TUBING DETAIL RECORD DATED 10 -OCT -97
7/3/2019
*** CONT. ON 07/04/19 WSR***
***CONT. FROM 07/03/19 WSR*** (tbg punch)
PUNCH TUBING FROM 3657'- 3662'. CCL TO TOP SHOT = 75, CCL STOP AT 3649.5'.
GOOD INDICATION OF T -IA COMMUNICATION.
LOGS CORRELATED TO TUBING DETAIL RECORD DATED 10 -OCT -97
7/4/2019
***JOB COMPLETE / DSO NOTIFIED***
(LRS Unit 70 Injectivity test, Freeze Protect IA) Staged up on edge of pad for hardline crew
7/5/2019
did not rig up. ***Job continued on 07/06/19*****
(LRS Unit 70 Injectivity test, Freeze Protect IA) Did not rig up due to hardline not being
7/6/2019
completed on their rig up.
7/6/2019
LRS unit 46 (Injectivity test) *** Job postponed ***
T/1/0=220/220/340 Temp=Sl Circ Out (PLUG AND ABANDONMENT) Pumped 20 bbls
50/50 meth down TBG w/ IA returns to OTT. Injectivity 5 bpm @ 430 psi. Pumped 20 bbls
down IA, w/ TBG returns to OTT. Pad Op notified of well status per LRS departure.
7/7/2019
FWHP's=170/-12/434 SV,WV,SSV,CT=C MV=O IA,OA=OTG
SLB Cement Crew: TAA Balance Cement Plug from 3160'-3660'.
LRS Pumped the following down the Tubing, up the IA, to Surface Return Tanks: 5 bbls
50/50 meth spear, 50 bbls Hot Surfactant, 70 bbls 9.8 ppg NaCl Brine, SLB Cementers
pumped 3 bbls Freshwater, -17 bbls 15.8 ppq Class G Cement. 3 bbls Freshwater. Shut
down. Launch 1x7" Foam Ball. LRS displace cement with 43 bbls 9.8 ppg NaCl brine, 5 bbls
50/50 meth. U -Tube to freeze protect TAA to 150'. Grease crew serviced tree valves and
choke trailer. Tags hung on MV and IA CV.
15.8 ppg Class G Cement
EST TOC = 3160' MD/3156' TVD
7/26/2019
EST BOC = 3660' MD/3656' TVD
T/I/0= 326/100/351. LRS Unit 46 to assist with cementing job (PLUG AND
ABANDONMENT)
Pumped down the TBG taking returns from the IA:
5 bbls 50/50 meth spear
47 bbls Hot Surfactant
70 bbls 9.8 ppg NaCl Brine
SLB pumped 3 bbls Freshwater, 17 bbls cement, 3 bbls Freshwater. Drops foam wiper
ball
43 bbls 9.8 ppg NaCl Brine (displacement)
5 bbls 50/50 for freeze protect.
7/26/2019 1
U-tube FP into TAA for 1 hour. Flush and FP lines to open top.
Daily Report of Well Operations
PBU H-34
***WELL S/I ON ARRIVAL***(P&A)
LRS PERFORMED PRE AOGCC CMIT TxIA TO 2,250 PSI (pass per state criteria, fail per
by criteria)
TAGGED CEMENT TOP AT 3,006' SLM W/ 10' x 2.5" DUMMY GUNS & 2.5" SAMPLE
BAILER (small hard cement sample, possible stringer)
LRS PERFORMED PASSING CMIT TxIA TO 2,250 PSI (pass by criteria)
LRS PERFORMED PASSING AOGCC WITNESSED (adam earl) CMIT TxIA TO 2,500 PSI
(pass state, fail by criteria)
AOGCC WITNESSED TAG TOC AT 3,058' SLM W/ 2.74" CENT, 2 1/2" SAMPLE BAILER
(aogcc rep adam earl, bailer full of cement)
LRS PERFORMED PASSING CMIT TxIA TO 2332psi (see log for details)
8/3/2019
***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS***
T/I/0= 0/0/337. LRS unit 72. Assist S/L (PLUG AND ABANDONMENT) Pre AOGCC CMIT-
TxIA to 2250 psi (2500 psi max applied pressure) *PASSED* (3rd attempt) TBG/IA lost 22/23
psi during the first 15 minutes. TBG/IA lost 19/19 psi during the second 15 minutes. This third
test was performed with TxIA jumper open per WSL. Pumped 1.7 bbls of 50/50 McOH to
achieve test pressure. Bled back 1.7 bbls to T/I/0= 8/13/289. Bled the OA from 528 psi to
280 psi prior to the third test.
AOGCC (witnessed by Adam Earl) CMIT-TxIA to 2500 psi (2650 psi max applied pressure
per WSL) *PASSED* AOGCC criteria. TBG lost 32 psi and IA lost 61 psi during the first 30
minutes. TBG lost 15 psi and IA lost 36 psi during the second 15 minutes. TBG lost 47 psi
and IA lost 97 psi during the 30 minute test. Pumped 1.6 bbls of 60* F 50/50 McOH to
achieve test pressure. Bled back 0.8 bbls to T/1/0= 122/130/288. S/L tagged cement and had
control of the well upon departure.
Pumped 1.8 bbls 50/50 meth down Tbg/IA for CMIT-TxIA. Took Tbg/IA to 2502/2495 psi. On
the 5th 15 mins Tbg/IA lost 19/20 psi and 17/17 psi in 6th 15 mins for a total loss of 163/163
psi in 90 min test. PASS per WSL Grey.
Bled Tbg/IA to 265/260 psi. Got back —1 bbl. SLine in control of well per LRS departure.
FW H P's=265/260/150 IA, OA=OTG
8/3/2019
**Tags hung on IA and MV
***WELL S/I ON ARRIVAL*** (Tubing Punch)
PERFORATE TBG & PROD CSG 3,001'-3,006- W/ 2" BIG HOLE CHARGES, 6 SPF, 60
DEG PHASE GUN.
TAGGED TOC @ 3025' ELMD.
CONFIRM COMMUNICATION WITH IA AND OA.
8/6/2019
***JOB COMPLETE 06 -AUG -2019***
T/1/0=160/250/250. I/A,O/A RD. Could not get I/A or O/A to bleed to Opsi. Turned over to
8/6/2019
DHD. Job Complete. See log. Final WHP,s 160/0/260.
T/l/O = 180/0+/240. Temp = SI. Bleed IAP & OAP to 0 psi (pre valve c/o). OA FL @
surface. Prior to arriving on location the valve crew bled IAP to 0 psi and attempted to bleed
the OAP to 0 psi without success returning 7 bbls of fluid. Bled OAP to BT from 240 psi to to
180 psi in 20 min (7 bbls). During bleed IAP went on VAC. Monitored for 30 min. IAP
unchanged, OAP increased 10 psi. Final WHPs = 180NAC/190.
8/6/2019
SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:00
Daily Report of Well Operations
PBU H-34
T/1/0=0/0/390 Temp=Sl (PLUG AND ABANDONMENT)
Verify circulation down Tbg, taking returns up OA w/ 10 bbls 50/50. OA had sufficient returns
to OTT while pumping.
Verify circulation down Tubing, taking returns up IA w/ 27 bbls 50/50. IA did not have any
returns until 17 bbls was pumped. Pumped an additional 10 bbls of 50/50 after returns were
established to confirm good communication.
TxIAxOA Integrity Test: Pressured T/IA/OA to 1190/110311097 psi with 0.42 bbls 50/50.
Integrity Test lost 48/44/44 psi in 5 minutes.
Bled TBG/IA/OA to 75/4/2 psi. Valve postions=SV/WV/SSV Closed, MV,IA,OA Open
8/21/2019
FWHP=75/0/0
SLB Fullbore Pumping Crew Objective: P & A TxIAx0A from 3001' to surface. Pumped
down the TBG taking returns from the OA: 30 bbls Surfactant, 10 bbls FW spacer and x138
bbls 15.8 ppg Class G cement. Clean cement returned from OA. Pumped 87 bbls 15.8 ppg
Class G cement down the TBG taking returns from the IA. Clean cement returned from the
IA. SI wellhead and wash up. JOB COMPLETE
15.8 ppg Class G Cement in TxIAxOA
TOC TxIAxOA = surface
8/27/2019
Est BOC TxIAxOA = 3001' MD/ 3001' TVD
T/l/O = Vac/Vac/Vac. Temp = SI. Bleed WHPs to 0 psi (P&A). No flowline or wellhouse. No
need to bleed. Temporary scaffold installed around wellhead.
8/31/2019
SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00
T/I/0= 0/0/0. Dry hole conversion for P&A. RD Upper Tree x MV. Install tree cap x MV. Torq
to API specs. Remove 2" FMC vlv's from IA, IA companion, and OA. installed 2" intergals.
11/9/2019
Torq to API specs. RDMO ***job complete*** **SEE LOG FOR DETAILS**
*** Permanent Plug and Abandon *** Excavate around wellhead to 12.6'. Pad Grade @
48.6'. Tundra grade @ 43.9'. Wellhead cut 4.5' below T.G. Found void to depth of 3.6' in
tubing and filled with AS -1 cement. AOGCC witness of TOC and marker plate install is Jeff
Jones. Pulled shoring box and backfilled excavation with gravel.
11/15/2019
*** Job Complete ***
AIF-..
r «
f"
MEMORANDUM
TO: Jim Regg(l * llq
P.I. Supervisor
FROM: Adam Earl
Petroleum Inspector
Section: 21 Township:
Drilling Rig: n/a Rig Elevation:
Operator Rep: Eric Dickerson
Casing/Tubing Data (depths are MD):
Conductor:
20"
O.D.
Shoe@
Surface:
9 5/8"
O.D.
Shoe@
Intermediate:
PTD 1971640; Sundry 318-3651
O.D.
Shoe@
Production:
7
O.D.
Shoe@
Liner:
41/2"
O.D.
Shoe@
Tubing:
41/2"
O.D.
Shoe@
Plugging Data:
Test Data:
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE:
August 3, 2019
SUBJECT:
Pluig Verification
Cut@
PBU H-34 -
Csg
BPXA
Feet
PTD 1971640; Sundry 318-3651
11N Range:
13E Meridian: Umiat '
n/a Total Depth:
10710 ft MD Lease No.: ADL028284
Suspend:
X P&A:
111 - Feet
3643 Feet
Feet
9167 Feet
10709 - Feet
9011 Feet
Type Plug
Casing
Removal:
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Tbg
Cut@
Feet
Type Plug
Founded on
Depth Btm
Depth To MW Above
Verified
Fullbore
Balanced
3660 ftMD
3058 ft MD '
Wireline tag
OA
444
397
378
Initial 15 min 30 min 45 min Result
Tubing
2657
2625
2610
IA
2648 -
2587
2551
P
OA
444
397
378
Remarks:
I traveled out to PBU H-34 to witness a cement plug tag and combo pressure test of the tubing and IA. Eric Dickerman was the
BP representative on location. The wireline tool string for the tag consisted of weight bars and a large bailer with a hanging
weight of 325lbs. I was told the cement was pumped down the tubing and out through perfs 3657 - 3662 ft MD on 7/4/2019 to
abandon the reservoir and isolate a production casing leak. The tag was solid @ 3058 ft MD and a very nice sample in the bailer ✓
of firm cement was returned to surface. The pressure test passed (charted).
Attachments: none
rev. 11-28-18 2019-0803_Plug_Verification_PBU_H-34_ae
MEMORANDUM State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Jim Regg �jl%f tri DATE: February 13, 2019
P.I. Supervisor
SUBJECT: Well Bore Plug & Abandonment
PBU H-34 -
FROM: Adam Earl BPXA
Petroleum Inspector PTD 1971640; Sundry 318-365
Section: 21 Township:
Drilling Rig: NA Rig Elevation:
Operator Rep: Jeremy Grimes
Casing/Tubing Data (depths are MD)
Conductor:
20"
- O.D.
Shoe@
Surface:
9 5/8"
O.D.
Shoe@
Intermediate:
7"
O.D.
Shoe@
Production:
Cut@
O.D.
Shoe@
Liner:
41/2"
O.D.
Shoe@
Tubing:
41/2"
O.D.
Tail@
Plugging Data:
Test Data:
11N Range: 13E
NA Total Depth: 10,710' MD
Suspend:
111 Feet
3643
Feet
9167
Feet
Cut@
Feet
10709
Feet
9011
Feet
Meridian: Umiat
Lease No.: ADL 028284
P&A: X
Type Plug
Casing
Removal:
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Csg
Cut@
Feet
Tbg
Cut@
Feet
Type Plug
Founded on
Depth Btm
Depth To
MW Above Verified
Fullbore
Retainer
8,680 ftMD
4,067 ft MD
Wireline tag
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Initial 15 min 30 min 45 min Result
Tubing
IA
OA
Remark
I traveled out to PBU H-34 to witness a plug tag with wire line. Jeremy Grimes was the BP rep. on the job. The tool string (3251b
down wt.) had a big sample bailer. They tagged the top of cement several times @ 4,067 ft MD. Sampler contained a good ✓
amount of interface up high with chips of hard cement on very bottom. No pressure test was witnessed.
Attachments: none
rev. 11-28-18 2019-0213_Plug_Verification_PBU_H-34_ae
THE STATE
°fALASKA
GOVERNOR BILL WALKER
Eric Dickerman
Wells Engineer
BP Exploration (Alaska), Inc.
P.O Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU H-34
Permit to Drill Number: 197-164
Sundry Number: 318-365
Dear Mr. Dickerman:
Alaska Oil and Gas
Conservation Commission
333 west Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.a1a5ka.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,
Cathy P. Foerster
Commissioner
Vla
DATED this 2 day of October, 2018.
RBDMS
OCA 011010
KtUEIVED
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION AUG 2 3 2018
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1 Type of Request: Abandon ® • Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ 4=Gfu
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑
2. Operator Name: BP Exploration (Alaska), Inc
4. Current Well Class
Exploratory ❑ Development
S. Permit to Drill Number: 197-164 -
3, Address. P.O. Box 196612 Anchorage, AK
9951 M612
Stratigraphic ❑ Service ❑
6. API Number. 50-029-22803-00-00
7. If perforating.
8 Well Name and Number:
What Regciatlon or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes ❑ No M
PBU H-34 '
9. Property Designation (Lease Nambef)I
10 FieM/Pools:
ADL 028284'
PRUDHOE BAY, PRUDHOE OIL-
11 PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD(m: Effective Depth MDI Effective Deoth TVD: MPSP (psi) Plugs (MD)'. Junk (MD):
10710 9111 2126 2123 2726 None
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 80 20" 31-111 31-111 1530 520
Surface 3613 9-5/8" 30-3643 30-3639 5750 3090
Intermediate 9139 7' 28-9167 28-8670 7240 5410
Production
Liner 1714 4-1/2" 8995 - 10709 1 8552-9110 8430 1 750D
Perforation Depth MD (fp
Perforation Depth TVD (ft)'
1
Tubing Size:
Tubing Grade:
Tubing MD (ft):
9440-10170
8780- 8832
4-1/2" 12,6#
L-80
26-9011
Packers and SSSV Type: 4.1a" Baker S-3 Perm Packer
Packers and SSSV MD (ft) and TVD (ft): 8956 / 8524
No SSSV Installed
No SSSV Installed
12. Attachments: Proposal Summary m Wellbore Schematic m
13 Well Class after proposed work.
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stretigraphic ❑ Development 10 ' Service ❑
14. Estimated Dale for Commencing Operations: September 10, 2018
15 Well Status after proposed work'.
Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑
16. Verbal Approval: Date.
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned m °
17 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Dickerman, Eric
be deviated from without prior written approval.
Contact Email' Eric. Dickerman(Mbp.com
Authorized Name: Dickerman, Enc
Contact Phone'. +1 9075644277
Authorized Title: Wells Engineer
Authorized Signature: P 1 Date:
COMMISSION USE ONLY
Conditions of approval. Notify Commission so that a representative may witness Sundry Number.
Plug Integrity Lq' BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance
Other'
Post Initial Injection MIT Req d? Yes ❑ No L7
Spacing Exception Required? Yes ❑ No fg" Subsequent Fortn Required: III
N ' " l.1 F APPROVED BYTHE
Approved by: OMMISSI NER COMMISSION r�
Date
VI,Z_ g1;Z_g11q_ ORIGINAL V15
RBDM�ti�� 0 7 2U16 vD�2�1�
Submit Form and
Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval Attachments in Duplicate
/� �� /A ¢.27 Ik
H-34 Permanent Plug and Abandonment Revision 1
Intervention Engineer
Eric Dickerman (907) 564-4277
Production Engineer
Julie Wellman (907) 564-4657
History
H-34 was drilled in October 1997. In 2004, an obstruction was discovered in the tubing that
prevented access to the perforated interval. An increase in watercut and a produced water sample
analysis indicated a production casing leak communicating with the Cretaceous zone. This was
confirmed by failing mechanical integrity testing and a leak detect log.
Due to obstructed reservoir access and well integrity failures, the well has no future utility and has
been approved for permanent abandonment.
Current Status
The well is classified as Not Operable and is secured with a wireline retrievable plug in the tubing.
Tubing
The tubing is obstructed at 8,664'slm preventing access to the perforated interval. A spinner log,
run as part of a leak detection logging toolstring, verified no downward flow into the tubing
obstruction. A drift and tag performed August 2016, tagged fill at 8,678'slm.
Inner Annulus
The leak detection log, indicated a production casing leak at 5,210'elmd based on the temperature
response, and a possible tubing leak at the same depth from a slight spinner response. A
mechanical integrity test on the inner annulus failed with a liquid leak rate of 4bpm at 800psi.
Outer Annulus
The outer annulus has an open casing shoe and has an injectivity of 2bpm at 1,350psi.
Objective
This procedure is to permanently abandon the well by cementing the tubing and annuli. The well
will remain in suspended status until final removal of the casings and welding of a marker plate 3'
below original tundra level.
Procedural steps
Slickline
1. Pull tubing plug.
2. Attempt to establish injectivity down control and balance lines (may require pumping warm fluid down
the inner annulus taking returns to formation).
3. Drift for Electric line to top of fill.
4. Pressure test TBG, and troubleshoot gas lift valves as necessary.
5. Dickerman to discuss pressure test results with AOGCC prior to Electric line rigging up to set cement
retainer and punch TBG.
Electric line
6. Set cement retainer just above top of fill in tubing–8680'elmd.
7. Pressure test tubing.
8. Shoot holes in tubing above cement retainer to establish communication to inner annulus.
9. Verify communication to inner annulus through circulation.
Coiled Tubing
10. Prepare wellbore for cement job.
11. Sting in to cement retainer, and test injectivity into perforated zone. If injectivity is present,
downsqueeze cement into perforated interval. If no injectivity, move to stepx. l2
12. Unsting from cement retainer and begin laying in cement plug in TBG and IA from cement retainer to
–4000'md.
Fullbore
13. Wait on cement. Pressure test tubing and inner annulus cement plug to 2,500psi. ffU& CG
14. Determine injectivity down outer annulus. Wi f w55 P/
Slickline
15. Drift and tag top of cement with AOGCC witness.
16. Drift for Electric line.
Electric line
17. Jet cut tubing above top of cement. Maximum depth = 3,643'md (surface casing shoe) Minimum depth
= 1,300'md.
18. Verify injectivty from tubing to inner annulus.
Special Proiects
19. Cement control and balance lines.
Fullbore
20. Prep wellbore for cement plugs.
21. Fill outer annulus with cement using downsqueeze method.
22. Circulate cement plug in tubing and inner annulus by pumping down the tubing, through jet cut, and up
inner annulus.
Special Proiects
23. Notify AOGCC of wellhead removal.
24. Photo document all steps. J r
25. Cut all strings and remove wellhead. FAF GLISpenr6on, wellhead will be out If
current pad / activity situation allows cut wellhead off 3' below original tundra level for full P&A.
26. Top off wellbore with cement as needed. ✓YO G G c ter 41-c S s-
27.
27. Install marker plate with BP Exploration, well's permit to drill number, well name, and well's API
number.
Current Wellbore Schematic
1I -
9.111. V\NQWI\
V.aLFOW
FARC
ACTATOR=
OAKQ7
KB. HFI -
74.8
BF. HFI -
46.65
KOP=
540(Y
W. An.L =
91' 9D 9706
10341
8800 ,x-
9-518- CSC. 408. L80. ID
Minimum ID = 3.726" @ 8999'
4-112" HES XN NIPPLE
3ACK 5LV, D - 5.25-
LNR HGR O = 4.438'
T CSG- 260. L-60, D - 6.276' 9/ 67
PERFORA TUN SUMARY
R1E LOG: Ste' AMID ON 1010397
ANGLE AT TOP FEFF- 81@9"0'
Nate: Refer to P.dwfion DB for hctomai cert data
2-718-
6
9470 -9555
O
01/0603
2-78-
4
9555-9580
O
05/06W
2-78'
6
9580 - 9725
O
0106/03
2-718-
4
9725 - 9750
O
05/0602
2-314'
4
9810-9960
O
100897
H-34
SAFETY NOTES. WELL > 70 @ 9330' AND> 900
9671' • •• W NVF72 CANCELLED 122804 BY
JLW '•'
[�yraia'\7 F;� tr
ST
MD
I TVDIDEVI
TYPE
I VLV
jLATCHJPGRTj
DATE
4
3832
3753
2
KBG2LS
DOA£
DO
16
1024197
3
5877
5729
20
KBG2L5
DOME
OKI
16
1024197
2
7539
7244
29
1BG2LS
DOME
DO
16
1024/97
1
8795
8329
39
KDWLS
SIO
DO
20
01/31103
x M.. D = JAId"
BKR S3 PKR D = 3.87
%NP, D=3.813'
12&1, L-80, .0152 bpf
D8
CM7YPI W � n=
8014'IELMD rT LOGG®8824/98
7
Proposed Wellbore Schematic
Surface cement
plug
9 L6' MG 40 1 W 11 4 61';' 3643'
Minimum ID = 3.726" @ 8999' !i
4-112" HES XN NIPPLE J �2•t2o
Lateral / reservoir plug -
-4,000' to 8,680' �<l
Cement retainer just above top of fill
Top of fill in TBG = •
8684'elmd (LDL 11-7-06)
Confirmed with SL tag
8/8/18)
I IOPO! HAFT -ft IHAcKSLv a=52�-
2'X 5•BAX, IO IW�HGR D..«3' 4-1019•..
7-(- :2W, 1.601)=6276•-
FIRE MA 101511.4Mnv
F4+ 1(Y: 9410E MND ON I(V0397
ANALAITOPR33 51@9440
7-814
4
9140 -9170
WELL a 70° 9330' ANO s 90°H-34
O
10108!97
7M'
8
9470
9555
O
0199H):1
2 7f6'
4
905
9.160
O
05106!02
2-118'
6V
-IW
9725
O
019603
2118'
4
9725
9750
O
astm 2
2-314'
4
9610-
998.0
O
10!0&97
2-718'
6
9960-10090
O
01106103
2-118'
i 6
10120-
70110
O
DIN603
J
OLV TYR'. VLV
LA101
WELL a 70° 9330' ANO s 90°H-34
Mff
@SmimNOES:
•WAIVECANCELLED 1226/04 BY
2 KEI(.7LS DOME
JEW•'•
16
1004197
35627 5729
20 IKBG2L5 DOME
I
OKI
16
2126'—j -a 1.?"rES i-IXti SSSUN 0-=3.613_
.....,,....
29 KBG2Ls DOME
-
2126' 4 1 1' OSSSV lilt (17)0616)
10124197
1 495 ��
Sm
mi
Z
GAS LFI AMeUB 5
Si MO rvD
OLV TYR'. VLV
LA101
PM
Mff
a-'3632.3753
2 KEI(.7LS DOME
U(1
16
1004197
35627 5729
20 IKBG2L5 DOME
I
OKI
16
1004!97
7539 7244
29 KBG2Ls DOME
D(1
16
10124197
1 495 ��
Sm
mi
213
0113303
TOS behind 7" = 8644'elmd
9� (&(f"10-8-97)
9945• .-l.-t:✓�ir
—' 995G ATX. t?nfl1t S]1x1t D f9/v
8919' �._ 10'14SXW.0' 3813•.
-- 6999' ;4-10'YEBXI4 NP.0=3.m'
9010 41Y1 ,17N.(F0.01526P1.0�391
-- 9011•—.1-'"1"A.EG. 0=1956•
9013• —?' X 5' BAKER ZX P LW PKR 0=4436'_
9014' �f3.W)n LOCCW060496
Q 75'b'
�� ly
wit) �-{._1051.3
M
141n•LW, 126Y_1-80. 0152bpl 0-391110709'--
M
Proposed Wellbore Schematic
Surface cement
plug
Minimum ID = 3.726' @ 6999'
4112' HES XN NIPPLE
Lateral / reservoir plug — l
4,000' to 8,680'
Cement retainer just above top of fill
Top of fill in TBG =
8684'elmd (LDL 11-7-06)
Confirmed with SL tag
8/8/18)
ruwoeATONSU&VJT(
r8F LOG SSR/ 1AAD ON 109307
A7GLEA7TOPPUi SIGMA
Nb fuel 0 Rodm0 W Id 1990cfidpfff MY
SIZE
SF
I HTHNAL
OpY59z
I DATE
2-3W
4
9440.94M
O
,00897
27/8'
6
9470.9555
O
0110693
2.716'
4
9555 95W
O
050&02
2-7Ar
6
95W - 91'15
O
0110693
2-718'
4
9725-9750
O
8510692
2-314*
4
9810-9960
0
100697
2-778'
6
9960- 10060
O
MMM
2-79'
6
10120-10170
O
010603
H-34 NOS: WELL>7V4J9310'AND>90`
987,'.'— W AiVSt CANCELLED 1272810/ BY
JLW "•
1 587715729 20 I®G2LS DO►E IXt 16 102497
2 7519 7244 29 03G2L5 001.E IXt 16 142497
TOC behind 7" = 8644'elmd
(USIT 10-8-97)
80,1' f3 ULOGGM 4198
4 1? LW 12 M. L 80. 0152 bp1_ D • 3 958'
4
by
H-34 Permanent Plug and Abandonment
Intervention Engineer
Eric Dickerman (907) 564-4277
Production Engineer
Julie Wellman (907) 564-4657
History
H-34 was drilled in October 1997. In 2004, an obstruction was discovered in the tubing that
prevented access to the perforated interval. An increase in watercut and a produced water sample
analysis indicated a production casing leak communicating with the Cretaceous zone. This was
confirmed by failing mechanical integrity testing and a leak detect log.
Due to obstructed reservoir access and well integrity failures, the well has no future utility and has
been approved for permanent abandonment.
Current Status
The well is classified as Not Operable and is secured with a wireline retrievable plug in the tubing.
Tubing
The tubing is obstructed at 8,664'slm preventing access to the perforated interval. A spinner log,
run as part of a leak detection logging toolstring, verified no downward flow into the tubing
obstruction. A drift and tag performed August 2018, tagged fill at 8,678'slm.
Inner Annulus
The leak detection log, indicated a production casing leak at 5,210'elmd based on the temperature
response, and a possible tubing leak at the same depth from a slight spinner response. A
mechanical integrity test on the inner annulus failed with a liquid leak rate of 4bpm at 800psi.
Outer Annulus
The outer annulus has an open casing shoe and has an injectivity of 2bpm at 1,350psi.
Objective
This procedure is to permanently abandon the well by cementing the tubing and annuli. The well
will remain in suspended status until final removal of the casings and welding of a marker plate 3'
below original tundra level.
Procedural steps
Slickline
1. Pull tubing plug.
2. Attempt to establish injectivity down control and balance lines (may require pumping warm fluid down
the inner annulus taking returns to formation).
3. Drift for Electric line to top of fill.
Electric line
4. Set cement retainer just above top of fill in tubing --8680'elmd.
5. Pressure test tubing.
6. Shoot holes in tubing above cement retainer to establish communication to inner annulus.
7. Verify communication to inner annulus through circulation.
Coiled Tubing y
8. Prepare wellbore for cement job.
9. Sting in to cement retainer, and test injectivity into perforated zone. If injectivity is present,
downsqueeze cement into perforated interval. If no injectivity, move to step 10.
10. Unsting from cement retainer and begin laying in cement plug in TBG and IA from cement retainer to
-4000'md.
Fullbore
111..
Wait on cement. Pressure test tubing and inner annulus cement plug to 2,500psi. - 067 e, C-
12.
12. Determine injectivity down outer annulus. wiVr r55
P T
Slickline
13. Drift and tag top of cement with AOGCC witness. ✓
14. Drift for Electric line.
Electric line
15. Jet cut tubing above top of cement. Maximum depth = 3,643'md (surface casing shoe) Minimum depth
= 1,300'md.
16. Verify injectivty from tubing to inner annulus.
Special Proiects
17. Cement control and balance lines.
Fullbore
18. Prep wellbore for cement plugs.
19. Fill outer annulus with cement using downsqueeze method.
20. Circulate cement plug in tubing and inner annulus by pumping down the tubing, through jet cut, and up
inner annulus.
Special Proiects
21. Notify AOGCC of wellhead removal.
22. Photo document all steps.
23. Cut all strings and remove wellhead. I.
current pad / activity situation allows cut wellhead off 3' below original tundra level for full P&A.
24. Top off wellbore with cement as needed. A -0L1 CG Wl -P'�55
25. Install marker plate with BP Exploration, well's permit to drill number, well name, and well's API
number.
BP Exploration Alaska, Inc
PTD: 197-164
Well: H-34
API: 50-029-22803-00-00
Current Wellbore Schematic
ITa1
4 1116' CAkM
WTLLTiAD _
n
ACRATOR-
BA KJ
KB [ EV -
74
BF. LLEV -
46.1
KOP=
541
Aba Anole =
91-097(
&54T' CSG. 400. -UM—U-- 8 835• 3643'
Minimum ID = 3.726" @ 8999'
I4-112-' NES XN NIPPLE
TOP OF BAKER TACK SLV_D - 5_25'
7'X5'BAKERHMCLNRMIFtU 4488'
7- CSG. 260, L-80, D = 6.276' 916T
PEWORA TION SLKWRY
SLOG- SFEMW MWD ON 10M0 97
ANGLE AT TOP 81 @3W0'
NNe. fbfer to Rodu Uon DB for historical cert data
2-718'
6
9470-9555
O 01/06/03
2-716•
4
9555 - 9560
O 05106/02
2-71W
6
9580-9725
O 01!06/03
2-718'
4
9725-9750
O 05/06/02
2-314•
4
9810 - 9960
O 70/08197
Q
H-34 TY NOTES: WELL > 700 @ 9330' AND> 900
9671'. "• W AMER CANCEi..LED1 M6104 BY
JLW
212$_---4`1.2" FES r0(O SSSV N• D - 3 8, 3'
2126' _1 `4-12•DSSSV_PLOG(08108?1a) ,
y
sy
GAS LFT h4A1DI;03-S
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TYPE
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'
4
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7539
8795
3753
7244
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2
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16
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1024/97
10/24/97
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10623'
K
Loepp Victoria T (DOA)
From:
Sent:
To:
Cc:
Subject:
Attachments:
Follow Up Flag:
Flag Status:
Hey Victoria,
Dickerman, Eric <Eric.Dickerman@bp.com>
Thursday, September 27, 2018 11:16 AM
Loepp, Victoria T (DOA)
Worthington, Aras J
RE: H-34 P&A
H-34 Sundry -P&A Revl.doc
Follow up
Flagged
Per our phone call today, I have updated the steps in the Sundry program for H-34 to include a step to pressure test the
TBG while slickline is on the well, and then have a discussion with you (AOGCC) on the plan forward prior to electric line
setting a cement retainer and punching the TBG.
Please let me know if you have any other questions.
Thank you,
Eric
From: Dickerman, Eric
Sent: Wednesday, September 26, 2018 12:32 PM
To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> (victoria.loepp@alaska.gov) <victoria.loepp@alaska.gov>
Cc: Worthington, Aras J <Aras.Worthington@bp.com>
Subject: H-34 P&A
Hey Victoria,
It was nice meeting you yesterday. Sorry, but I never did receive your previous emails. Must be something with my
outlook. Aras mentioned you reached out to him about H-34.
Summarizing our phone conversation. Internally we had discussed attempting to mill fill from 8,684' across the
perforations to 10,120'. Indicators are pointing to the fill being barium sulfate scale, which is normally successfully
removed by milling. However, we felt that attempting to mill up to 1400' of barium sulfate scale increased the risk of
this job in the form of stuck coiled tubing.
The data indicating barium sulfate scale:
• Between the final two well tests, the water cut suddenly increased from around 70% to 99% and total fluid
production increased from 694bpd to 9,629bpd. Analysis of a produced water sample on 11/11/2004 confirmed
increased concentrations of Barium above typical Ivishak produced water levels indicating production from the
Cretaceous zone through a production casing leak.
The LDL log on 11/7/2006 confirmed a production casing leak at 5,210' (in Cretaceous zone), and a spinner
response was not seen while logging at the top of fill indicating no flow passed the top of fill. Increasing gamma
ray response at the top of fill when compared to previous logs is also an indication of possible scale formation.
• Tag depths have consistently been about 100' above the orifice gas lift valve, which would be the easiest point
for Cretaceous water to enter the TBG. According to our production chemists, the barium in the Cretaceous
water reacts with the sulfate in the Ivishak water to form barium sulfate scale.
Please let me know if you have any additional questions.
Eric Dickerman
BP Alaska Wells Engineer
Office: 907-564-4277
Cell: 307-250-4013
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BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT H-34 (197-164)
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• •
bp
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB -20
Post Office Box 196612
Anchorage, Alaska 99519 -6612
May 18, 2012 I 6 1 rl 61-1
Mr. Jim Regg
f„IVOINED AUG 0 8 202
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of GPB H -Pad
Dear Mr. Regg,
Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad
H 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
• •
BP Exploration (Alaska ) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off
Report of Sundry Operations (10 -404)
Date: 03/17/2012
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # cement pumped cement date inhibitor sealant date
ft bbls ft na gal
H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010
H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010
H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010
H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010
H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010
H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010
H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010
H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010
H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011
H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010
H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010
H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010
H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010
H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010
H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010
H -16 2000650 50029205920200 0 NA NA NA NA NA
H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011
H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010
H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010
H -20 1830070 50029208960000 8.7 NA 6.7 NA 47.60 2/22/2010
H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010
H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010
H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010
H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010
H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010
H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010
H -27A 2030590 50029214560100 0.1 NA _ 0.1 NA 0.85 2/21/2010
H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010
H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010
H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010
1-1-31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010
H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010
H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010
._�
1-1-34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010
H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010
H -36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010
H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010
H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012
e 0 Log Description Date BL Co or D
H-34 11477963 LDURST 11/07/06 1
Y-01B 11485468 MPPROF W/DEFT & GHOST 11/07/06 1
2-08/K-16 11487771 LDL 11/12/06 1
X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1
DS 09-51 11477933 INJECTION PROFILE 11/06/06 1
15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1
N-o-7A 11296715 PROD PROFILE W/GHOST 09/10/06 1
DS 09-31C 11483591 INJECTION PROFILE 11/20/06 1
G-06A 11422979 SCMT 11/01/06 1
P2-59A 11414775 SCMT 11/05/06 1
NGI-06 11414773 USIT 11/01/06 1
A-43 11414774 USIT 11/03/06 1
01-26A 11001225 RST-SIGMA OS/24/05 1 1
I~
Schlumberger
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
WII
J b#
107-/01
11/28/06
NO. 4058
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
C
.
.
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
Date Delivered:
NO\! 9. 9 7n0[1
Alaska Data & Consulting Services
2525 Gambell S~ S"~ È
""0_, AK ""~E
ATTN: Beth ê
Received by: I / "-----.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
FCO/MILL/ADD PERFS
Operation shutdown_ Stimulate_ Plugging _
Pull tubing _ Alter casing _ Repair well _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
5. Type of Well:
Development ._X
Explorato~.__
Stratigraphic_
Service__
4. Location of well at surface
2055' FNL, 1265' FEL, Sec. 21, T11N, R13E, UM
At top of productive interval
2288' FNL, 3175' FEL, Sec. 21, T11N, R13E, UM
At effective depth
1687' FNL, 4144' FEL, Sec. 21, T11N, R13E, UM
At total depth
1659' FNL, 4175' FEL, Sec. 21, T11N, R13E, UM
(asp's 643340, 5958733)
(asp's 641435, 5958464)
(asp's 640453, 5959046)
(asp's 640423, 5959074)
Perforate _X
Other_X FCO/MILL
6. Datum elevation (DF or KB feet)
RKB 75 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
H-34
9. Permit number / approval number
197-164
10. APl number
50-029-22803-00
11. Field / Pool
Prudhoe Bay Field / Prudhoe Bay Pool
12. Present well condition summary
Total depth: measured
true vertical
10710 feet
9111 feet
Effective depth: measured 10623 feet
true vertical 9034 feet
Plugs (measured)
Casing Length
Conductor 82'
Surface 3615'
Intermediate 9139'
Liner 1714'
Junk (measured)
Size Cemented
20" 260 sx Arcticset (Aprox)
1637 sx Clodset, 500 sx
9-5/8"
Class 'G'
7" 250 sx Class
4-1/2" 178 sx Class 'G'
Measured Depth True Ve~icalDepth
110' 110'
3643' 3639'
9167' 8671'
8995'-10709' 8553'-9110'
Perforation depth:
measured Open Perfs 9440'-9750', 9810'-10080', 10120'-10170'
REC !VED
true vertical Open Perfs 8780'-8794', 8796'-8822', 8826'-8832'
Tubing (size, grade, and measured depth)
Packers & SSSV (type & measured depth)
4-1/2", 12.6#, L-80 TBG @ 9011' MD. A~aska 0il & Gas 00i15. 001?lltlissJor,
Anchor~e
7" x 4-1/2" BKR S-3 PKR @ 8956'. 7" x 5" BKR ZXP LNR PKR @ 9013'.
4-1/2" HES HXO SSSVN @ 2126' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14.
OiI-Bbl
Prior to well operation 12/26/2002 211
Subsequent to operation 01/13/2003 405
Representative DaiIv Averaqe Production or Injection Data
Gas-Mcf Water-Bbl
919 317
489 881
Casing Pressure
Tubing Pressure
275
275
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
6. Status of well classification as:
Oil __X Gas __ Suspended __
Service
17. I hereby certify that the foregoing is truce and correct to the best of my knowledge.
SCANNED FEB 0 zj: 2003
DeWayne R. Schnorr
Form 10-404 Rev 06/15/88 ·
T~tle: Technical Assistant
Date January 16, 2003
Prepared by DeWayne R. Schnorr 564-5174
SUBMIT IN DUPLICATE
12/24/2002
1 2/27/2OO2
01/04/2003
01/05/2003
01/06/2003
01/12/2003
01/13/2003
01/14/2003
12/24/02
12/27/02
01/04/03
01/05/03
01/06/03
01/12/03
H-34
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
PERFORATING:
PERFORATING:
PERFORATING:
PERFORATING:
PERFORATING:
FILL CLEAN OUT; MILL
FLUID SWAP
PERFORATING
PERFORATING
PERFORATING
ANN-COMM (AC-EVAL AND REPAIR): AC-MONITOR
TESTEVENT --- BOPD: 405, BWPD: 881, MCFPD: 3,589, AL Rate:
ANN-COMM (AC-EVAL AND REPAIR): AC-EVAL; AC-TIFL
3,100
EVENT SUMMARY
RIH WITH 3.25 JUNK MILL. WELL IS IN TEST SPERATOR. TAGGED FILL 9949'
CTMD. CUT GL RATE TO GET BETTER EFFICIENCY ON MOTOR. JET TO 9959'
AND TAGGED UP. MILLED THROUGH. CLEAN OUT TO 10300. PUMP SLUG OF
FLO-PRO, SHEAR CIRC SUB AND CHASED OUT OF HOLE. WELL TURNED
BACK TO PCC FOR PRODUCTION WITH REQUEST TO TEST AFTER 24 HOURS.
FREEZE PROTECT TUBING AND FLOW LINE.
BLEED AND FLUID PACK IA. PERFORM BOPE TEST. KILL AND LOAD WELL
WITH FILTERED 2% KCL. RIH WITH PDS MEMORY GR/CCL.
RIH WITH PDS MEMORY GR/CCL. LOGGED INTERVAL 10,500' to 9,300' CTMD.
LAID IN 20 BBLS FLOPRO ACROSS PERFORATED INTERVAL. FLAGGED PIPE
AT 10,000' CTMD AND AT 9,500' CTMD. POOH WITH MEMORY TOOLS. TIED
MEMORY LOG INTO SWS BHCS LOG DATED 10/04/1997. MADE 12'
CORRECTION, MAKING EOP AT FLAGS 10,001.8' AND 9,550.8'. RIH WITH 2.88:
HSD 34J, 6 SPF, 60 DEGREE PHASING (GUN RUN #1). CORRECTED TO TOP
SHOT AT UPPER FLAG (9,544.4'). RIH PUMP 20 BBLS FLOPRO AHEAD OF BALL
AND SHOT INTERVALS 9,960' - 10,080' AND 10,120' - 10,170'. POOH. ASF. RIH
WITH GUN RUN #2. CORRECT DEPTH TO TOP SHOT AT UPPER FLAG
(9,550.8'). PUH AND POSITIONED GUNS TO SHOOT INTERVALS 9,470' - 9,555'
AND 9,580'- 9,725'.
LAUNCHED 5/8" BALL WITH 20 BBLS FLOPRO. PUMPED TWO COIL VOLUMES,
BALL DID NOT SEAT. LAUNCHED SECOND BALL WITH ADDITIONAL 25 BBLS
FLOPRO. BALL SEATED AFTER 31 BBLS. GOOD INDICATIONS GUNS FIRED
AT 4200 PSIG. SHOT INTERVALS 9470'-9555'. AND 9580'-9725'. POOH.
CIRCULATED HOLE AT MINIMUM RATE TO CIRCULATE OUT SMALL GAS
BUBBLE AT SURFACE. LD GUNS. ASF. RIH, LAY 60/40 FREEZE PROTECT
FROM 2500'. JOB COMPLETED. NOTIFIED PAD OPERATOR AND PCC OF
WELL STATUS AND WOULD LIKE TO POP WELL AFTER WWP REMOVED AND
WELL HOUSE INSTALLED.
T/I/O= 30/270/220 SI @ WING VALVE MONITOR WHP's (PREP FOR TIFL).
SCANNED FEB 0 4 2003
Page I
01/13/03
01/14/03
H-34
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
TESTEVENT --- BOPD: 405, BWPD: 881, MCFPD: 3,589, AL RATE: 3,100
TIC= 260/1050/240. TIFL FAILED (EVAL POSSIBLE T X IA COMM). SI WELL AND
STACKED OUT TBG TO 1750 PSI. IA FL @ 8795' (155 BBLS) BOTTOM STATION.
BLED lAP FROM 1800 PSI TO 400 PSI IN 1.5 HOURS. TP PRESSURE DROPPED
TO 1400 PSI. IA FL INFLOWED 1635' IN THE FIRST HOUR BLEED. MONITOR
FOR 30 MINUTES. TP REMAINED @ 1400 PSI, lAP INCREASED 80 PSI. IA FL
REMAINED @ 7160'. FINAL WHP's= 1400/480/240. <<< POP WELL >>>
Fluids Pumped
BBLS
6 NEAT METHANOL
10 METHANOL
318 60/40 METHANOL WATER
40 50/50 METHANOL WATER
187 DIESEL
176 CRUDE
450 2% KCL WATER
608 2% EXTRA SLICK KCL WATER
95 FLOPRO
1892 TOTAL
ADD PERFS
01/05-06/2003
THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" HSD 34J, 6 SPF, 60
DEGREE PHASING, RANDOM ORIENTATION.
9470'-9555'
9580'-9725'
9960'-10080'
10120'-10170'
SCANNED FEB 0 & 2003
Page 2
~ ~:E = 4-1/16" CAMERON
WI~LHEAD = FMC
ACTUATOR=
KB. ~ = 74.8' ~
~ 9~t'.
~F. ~L~ = 4~.~5'
K~ = 5~0'
M~ Angle = 91 ~ 9706'
Datum MD: ~ 0~'
B~um ~D = 8800' SS
GAS LIFT MAND~LS
ST ~ ~D ~ TY~ VLV ~T~ ~ ~TE
4 3~2 37~ 2 KBG2LS DOME DK1 16 10~4/97
Minimum ID = 3.725" ~ 8999'. 3 5827 5729 20 K~2LS D~E DK1 16 10~4/97
B 2 7~9 72~ 29 K~2LS g~E UN1 16 10~4/97
4-1~"
HES
XN
NIPPLE
1 8795 8329 39 KBG2LS ~O DK1 20 10~4/97
I II 8979' ~4-1/2"H~XNIRID=3.813"I
I 8999' H4-1/2"H XN P,D=3.725"I
{ ~ ~ q/2" WLEG, ID = 3.958" {
I ~14' H~MDWLOmm~/24/9OJ
I 7" ~G, 2~, L-80, ID = 6.276" ~ 91
PE~O~TION SUM~ RY
R~ LOG: SPE~Y MWD ON 10/03/97
AN~EATT~ ~RR 81 ~ 9~0'
~te: Refer to ~oduc~on DB for his~rical ~rf data 10623'
S~E S~ INT~VAL ~n/~z DATE
2-3/4" 4 ~40 - ~70 O 10~8/97
2-7~" 6 ~70- 9555 O 01~6/03
2-7~" 4 ~ ~55- ~80 O 05~6/02
2-7~" 6 ~80- 9725 O 01~6/03
2-7~" 4 9725- 9750 O 05~6/02
2-3/4" 4 ~10- ~60 O 10~8/97
2-7~" 6 ~60- 100~ O 01~6/03 I 4-1/2"
2-7~" 6 10120- 10170 O 01~6/03
DATE ~ BY C~S ~TE R~ BY ~TS ~U~OE BAY U~
10/10/97 ORIGINAL ~ION W~L: H-34
02/19/01 SIS-SLT ~NVE~EDTOCANVAS ~No: 1971~0
03/01/01 SIS-LG RNAL APl ~: 5¢029-22803-00
08/26/01 ~/~K ~R~I~S S~21, Tl1~ R13E, 3~4'NSL& 12~'~
~/~/02, ~/~K ADP~FS
01/~/03 ~F/KK ADP~ ~ ~plor~ion {Alaska)
PERi:ORATION SUMMA RY
RB= LOG: SPERRY MWD ON 10/03/97
ANGLEATTOP PERF: 81 @ 9440'
Note: Refer to RroduclJon DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
2-3/4" 4 9440 - 9470 O 10/08/97
2-7/8" 6 9470- 9555 O 01/06/03
2-7/8" 4 9555- 9580 O 05/06/02
2-7/8" 6 9580- 9725 O 01/06/03
2-7/8" 4 9725- 9750 O 05/06/02
2-3/4" 4 9810- 9960 O 10/08/97
2-7/8" 6 9960- 10080 O 01/06/03
2-7/8" 6 10120- 10170 O 01/06/03
DATE ~ BY COMMENTS DATE REV BY COIVNIENTS
10/10/97 ORIGINAL COIVPL ErlON
02/19/01 SIS-SLT CONVERTEDTOCANVAS
03/01/01 SIS-LG FINAL
08/26/01 CH/KAK CORRECTIONS
05106102 JPIKAK ADPERFS
01/06/03 JAF/KK ADPERFS
SCANNED FEB 0 20D3
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X
ADD PERFS Pull tubing _ Alter casing _ Repair well _ 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
2055' FNL, 1265' FEL, Sec. 21, T11N, R13E, UM
At top of productive interval
2288' FNL, 3175' FEL, Sec. 21, T11N, R13E, UM
At effective depth
1687' FNL, 4144' FEL, Sec. 21, T11N, R13E, UM
At total depth
1659' FNL, 4175' FEL, Sec. 21, T11N, R13E, UM
5. Type of Well:
Development __X
Exploratow__
Stratigraphic__
Service__
(asp's 643340, 5958733)
(asp's 641435, 5958464)
(asp's 640453, 5959046)
(asp's 640423, 5959074)
6. Datum elevation (DF or KB feet)
RKB 75 feet
7. Unit or Property name
Prudhoe Bay Unit
8. Well number
H-34
9. Permit number / approval number
197-164
10. APl number
50-029-22803-00
11. Field / Pool
Prudhoe Bay Field / Prudhoe Bay Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Conductor 82'
Surface 3615'
Intermediate 9139'
Liner 1714'
10710 feet Plugs (measured)
9111 feet
10623 feet Junk (measured)
9034 feet
Size Cemented Measured Depth True Vertical Depth
20" 260 sx Arcticset (Approx) 110' 110'
9-5/8" 1637 sx Coldset, 500 sx 3643' 3639'
Class 'G'
7" 250 sx Class 'G' 9167' 8671'
4-1/2" 178 sx Class 'G' 8995' - 10709' 8553' - 9110'
Perforation depth:
measured Open Perfs 9440'- 9750', 9555'- 9580', 9725'- 9750', 9810'- 9960'
true vertical Open Perfs 8780' - 8794', 8789' - 8791', 8795' - 8794', 8796' - 8809'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 9011' MD.
Packers & SSSV (type & measured depth) 7" x 4-1/2" BKR S-3 PKR @ 8956'. 7" x 5" BKR ZXP LNR PKR @ 9.01
4-1/2" HES HXO SSSVN @ 2126' MD.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure ..... t.-., !'~[[
14. Representative Daily Averaqe Production or I niection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation 05/03/2002 215 932 285 328
Subsequent to operation 05/07/2002 222 946 299 304
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.
~,~~~~~ Title: Technical Assistant
DeWayne R. Schnorr
Form 10-404 Rev 06/15/88 ·
Date May 08, 2002
Prepared by DeWayne R. Schnorr 564-5174
SUBMIT IN DUPLICATE
04/13/2OO2
05/O6/2O02
04/13/02
05/06/02
H-34
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
PERFORATING: DRIFT/TAG
PERFORATING: PERFORATING
EVENT SUMMARY
DRIFT TBG W/2 7/8" DUMMY GUN TO 9427'SLM, STOPPED DUE TO
DEVIATION. RDMO. ***RELEASE WELL TO PRODUCTION***
MIRU DS CTU#3. RIH W/PDS GR/CCL, WELL FLOWING & ON GL. LOG 9850' TO
9300', PAINT FLAG AT 9700'. RIH W/GUN #1 - 25' SWS GUN, (2-7/8" HSD P J, 4
SPF) SHOOT INTERVAL 9725'-9750'. RIH W/GUN #2 - 25' (SAME SPECS), SHOOT
INTERVAL 9555'-9580'. RDMO, **NOTIFY DSO - LEAVE WELL FLOWING.**
Fluids Pumped
1 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL (
1 TEST)
63 60/40 METHANOL WATER
64 TOTAL
ADD PERFS
05/O6/2OO2
THE FOLLOWING INTERVALS WERE PERFORATED USING THE 2-7/8" PJ2906, 4 SPF, 60
DEGREE PHASING, RANDOM ORIENTATION.
9555'-9580'
9725'-9750'
Page 1
MEMORANDUM
TO:
THRU:
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: April 22, 2001
SVS Misc. tests
BPX H pad
Prudhoe Bay Field
Sunday, .April. 22, 2001; I witnessed the first of the one-month retests of the SVS
systems on BPX H pad wells in the CC-2 area of the Prudhoe Bay Field.
Merv Liddelow (BP Rep.) performed the SVS tests today. All components
functioned propedy and held their pressure tests. The new style pilot boxes were
installed on most of the wells, which combined with the reliability of the electronic
pilots helped to produce these great results.
The well houses were all clean with pilot valves in proper position.
SUMM,A. Ry: I witnessed the SVS test on twenty BPX H pad wells in the Prudhoe
Bay Field.
20 wells, 40 components, No failures.
Wellhouse Inspections;
33 wellhouses, No problems noted.
Attachments: SVS PBU H-pad 4-22-01 LG.XLS
NON-CONFIDENTIAL
SVS PBU H-pad 4-22-0t LG
AlaS~ka Oil and Gas Conservation Commi~/~]°n
Safety Valve System Test Report
Operator: BPX
Operator Rep: Merv Liddelow
AOGCC Rep: Lou Grimaldi
Submitted By: Lou G. Date:
Field/Unit/Pad: Prudhoe Bay field, H-pad
Separator psi: LPS 157 HPS
22-Apr
650
Well
Permit Separ Set L/P Test Test Test Date Off, WAG, GINJ,
Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE
H-01A 1951100
H-02 1710160
H-04 1710220
H-05 1710240 650 550 550 P P OIL
H-06 1770020 157 125 125 P P OIL
H-07A 2001280
H-08 1770230
H-11 1800680 157~ 125 100 P P " ' 0IL
H-12 1800670
H-13 1810170 650 550 525 P 'P OIL
H-14A 1980680
H-15 1810610 157 125 125 P P OIL
H-16B 2000650
H-17A 1971520 650 550 510 P P OIL
H-18 1822100
H-19B 1980940 650 550 540 P P oil
H-20 1830070
H-21 1860710 650 550 525 e P OIL
H-22A 1970480 157 125 125 P P OIL
,
H-23A 1950850 650 550 550 P P OIL
H-24 1853050 157 125 115 P P OIL
H-25 1852680 650 550 550 P P OIL
H-26 1852770 157 125 95 P P OIL
,
H-27 1852360
H-28 1880440
H-29A 19803801 650 550 530 P P OIL
H-30 1880350 650 550 525 P P OIL
H-31 1940140:
H-32 1940250 157 125 100 P P OIL
H-33 1940380 650 550 515 P P OIL
H-34 1971640 157 125 125 P P OIL
,
H-35 1951490 650 550 5151 P P OIL
H-36A 2000250
H-37 1971020 157 125 125 P P OIL
tKt~' 1/16/01 20 Components: ~O.F~a~l~es: 0
F~tl~~ padO .aO_5~_~ ~v
'Well Permit I Separ Set L/P I Test
Number Number [ PSI PSI Trip I Code
Remarks:
Great test, no failures.
Test
Code
Test
Code
Date /Oil, WAG, GINJ,
Passed / GAS or C¥CLW
RJF 1/16/01 Page 2 of 2 SVS PBU H pad 4-22-01 LG
STATE OF ALASKA
ALASKA L AND GAS CONSERVATION COl' ISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: []Operation Shutdown [~Stimulate I--I Plugging ~i Perforate
[] Pull Tubing []Alter Casing [] Repair Well [] 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
3224' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM
At top of productive interval
2991' NSL, 3175' WEL, SEC. 21, T11N, R13E, UM
At effective depth
3591' NSL, 4144' WEL, SEC. 21, T11N, R13E, UM
At total depth
3621' NSL, 4175' WEL, SEC. 21, T11N, R13E, UM
]5. TypeE~ ~eelvl;Iopment
~ [] Exploratory
I [] Stratigraphic
I I--I Service
6. Datum Elevation (DF or KB)
KBE = 74.80'
7. Unit or Property Name
Prudhoe Bay Unit
8. Well Number
H-34
9. Permit Number / Approval No.
197-164
10. APl Number
50- 029-22803
11. Field and Pool
Prudhoe Bay Field / Prudhoe Bay
Pool
12. Present well condition summary
Total depth: measured 10710 feet Plugs (measured)
true vertical 9111 feet
Effective depth: measured 10623 feet Junk (measured)
true vertical 9034 feet
Casing Length Size Cemented
Structural
Conductor 82' 20" 260 sx Arctic Set (Approx.)
Surface 3615' 9-5/8" 1637 sx Coldset, 500 sx Class 'G'
Intermediate 9139' 7" 250 sx Class 'G'
Production
Liner 1714' 4-1/2" 178 sx Class 'G'
MD TVD
110' 110'
3643' 3639'
9167' 8671'
8995'-10709' 8553'-9110'
Perforation depth: measured 9440'-9740'; 9810'-9960'
true vertical 8780'-8794'; 8796'-8809'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 @ 9011'
Packers and SSSV (type and measured depth) Packer @ 8956'
SSSV @ 2126'
13. Stimulation or cement squeeze summary
Intervals treated (measured)
See Attachment
Treatment description including volumes used and final pressure
14.
Prior to well operation:
Subsequent to operation:
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl
179 1003 202
Casing Pressure
0
Tubing Pressure
270
360 1540 324 0 270
15. Attachments 16. Status of well classifications as:
[] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended
[] Daily Report of Well Operati s
j7. I hereby,c,~!fy~at thEfore~;~if~.q is true .an~rrect to the best of my knowledge
! Title Technical Assistant IV
i
i
Service
Prepared By Name/Number:
Date/'//~~ _~__':. ~
Submit In Duplicat~.,~
Form 10-404 Rev. 06/15/88
H-34
DESCRIPTION OF WORK COMPLETED ~-'
Stimulation Operation
08/19/99
A Xylene/Acid Stimulation Treatment was performed using the
following fluids:
SUMMARY
Shut gas lift in on arrival. Rih w/3" jetting nozzle and began circulating well over
to kcl water. Tagged td @ 9,962' ctmd; hard and clean tag. Pu and closed wing
and loaded well. Injection test was 2.4 bpm at 430 psi. Jetted 83 bbls acid over
the interval 9,390 - 9,962 in four passes with 20 min soak periods between each
pass, keeping coil pressure below 2500 psi while keeping whp below 1500 psi.
During the first acid pass there was a response to the acid seen in gradual
decline of whp of about 80 psi. After the last acid pass, shut down and soaked 1
hour. Flush 150 bbls kcl water, performing 1 reciprocating pass over same
interval; Post injection was 2.5 bpm at 335 psi. Pooh and put well on production.
Fluids Pumped
BBLS. Description
436 Freshwater w/2% KCL
83 Acid
519 Total Pumped
THE MATER/AL UNDER THIS coVER HAs BEEN
ON OR BEFORE
PL E
M _w
---TH ER
IS M ARK ER
C:LORI~F/LI~.DOC
AOGcC Geological Materials Inventory
PERMIT
Log
8156 D
8317 T
BHC/S L
CN L
MWD SRVY R
NGP/DGR/EWR4-TVD L
NGP/EWR4-MD L
PIL L
RFT L
SSTVD L
USIT L
10-407 Completion Date
Are dry ditch samples required?
Was the well cored? ..... yes
Are tests required? yes
Well is in compliance
Initial
Comments
9 7- ! 64 BP EXPLORATION
Data Sent Recieved
SPERRY GR/EWR4 10/22/1997 10/22/1997
SCHLUM TDTP 2/5/1998 2/6/1998
9165-10630 2/5/1998 2/6/1998
8950-10650 2/5/1998 2/6/1998
SPERRY 0-10710. 12/5/1997 12/8/1997
3674-9110 10/29/1997 10/30/1997
3678-10710 10/29/1997 10/30/1997
9167-10700 2/5/1998 2/6/1998
9181 - 10695 2/5/1998 2/6/1998
9167-10700 2/5/1998 2/6/1998
BL(C)8050-9006 2/5/1998 2/6/1998
Daily svell ops
yes no And received? yes
no Analysis description recieved? :
no Received? yes no
Box
no
yes no
Friday, October 08, 1999
Page 1 of 1
AOGCC Geological Materials Inventory
PERMIT
Log
97-164
97-164
97-164
97-164
97-164
97-164
97-164
9 7-164 BP EXPLORATION
Data Sent Recieved
~- SCHLUMTDTP ~ '5 i '7 2/5/1998 2/6/1998
'L-/'' 9181-10695 ¢[g:r 2/5/1998 2/6/1998
y BL(C)8050-9006 ~ [4,~ ~xi6 fvr, c..t] ~ ~- 2/5/1998 2/6/1998
L'/~ 9165-10630 ~ ~4 ~ ;) 2/5/1998 2/6/1998
~ 9167-10700. ~0 IL- 2/5/1998 2/6/1998
~ 9167-10700 -,5.~ 'Fq/~. 2/5/1998 2/6/1998
~ 8950-10650 ~ ~,_) 2/5/1998 2/6/1998
97-164 SPERRY 0~10710. 12/5/1997 2/8/1997
'.
97-164 kg/' 3674-9110 ~._t~","~ '/ (17 q (x } 10/29/1997 /30/1997
97-164 --C/ 3678-10710 ~ 'fi la q (-(q~ 10/29/1997 /30/1997
97-164 ~,t~~ SPERRY GR/EWR4 i~/ aka 10/22/1997 /22/1997
4-~-407 Completion Date ~_lto/lq7 Dailywel, ops q/'~/q? ]of(o/q/7
Are dry ditch samples required? yes ~,ano And received? ..... yes .............. no
Was the well cored?
Are tests required?
Well is in compliance
Comments
yes ~-no
yes. no
Initial
Analysis description recieved?
Received? ~y..& ............ no
Box
Thursday, October 07, 1999 Page 1 of 1
/
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 11780
Company: Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Prudhoe Bay (Open Hole)
2/5/98
LIS
Well Job # Log Description Date BL RF Sepia Tape
R'19A ~ '~,,°~;;~ [ 98038 MWDGR-CDR-IMPULSE 971025 I ,,
R-19A 98038 CDR/IMPULSE 971025 I 1
R-19A 98038 CDR/IMPULSE TVD 971025 I 1
E-11A 'J~ ~,_~! (O 97544 PEX/AIT/BCS 971018 1
E-11A-r 97544 PEX-AIT 971018 1 1
E-11A 97544 PEX-CNL 971018 1 1
E-11 A 97544 PEX-CNL 3 DET. DENSITY 971018 1 1
E-11A 97544 PEX-BCS 971018 I 1
E- 11 A 97544 PEX-BOREHOLE PROFILE 971018 I 1
E-11A 97544 PEX-SSTVD 971018 I 1
H-34 ~. ~[r) 97481 DTE,BHC,CNTG 971004 1
H- 34 97481 PHASOR INDUCTION 971004 I 1
H-34 97481 CNL 971004 I 1
H-34 97481 BCS 971004 I 1
H-34 97481 !SSTVD 971004 I 1
H-34 97481 RFT 971004 1 1
H-34 97481 USIT 971004 I COLOR- 1
PRINT
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
·
;. . .
Schlumberger GeoQuest
500 W. International Airport Road
Anchorage, Alaska 99618-1199
, , STATE OF ALASKA ._, R E C E IV E D
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LO~£0~
1. Status of Well Classification~~8~_~,UOriS,
[~ Oil I--I Gas I~ Suspended [] Abandoned I~ Service/4J'lt~llOra~8
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 97-164
13. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 i" :'.-..-, '-'~-:_~ ...... ~ 50-029-22803
4. Location of well at surface : ....... ;"~ ~ i 9. Unit or Lease Name
3224' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM i ~,~,./<~ .~. ! ~~_! Prudhoe Bay Unit
At top of productive interval ' - ' 10. Well Number
2991' NSL, 3175' WEL, SEC. 21 T11N, R13E, UM
At total depth ................ '*~ ! ~iH ~i 11. Field and Pool
3621' NSL, 4175' WEL, SEC. 21, T11 N, R13E, UM ~~_.¢ Prudhoe Bay Field / Prudhoe Bay
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool
KBE = 74.80'I ADL 028284
12. Date Spudded9/16/97 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband't15' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl 0/3/97 10/10/97 N/A MSL One
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost
10710 9111 FT 10623 9034 FTI [~Yes F-INoI (Nipple) 2126' MDt 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, GR, RES, RLL, RFT, USIT
23. CASING, LINER AND CEMENTING RECORDU'~"~. ! t..~ ! !'~_ ~ l
CASING SETFING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP DO'II-OM SIZE CEMENTING RECORD AMOUNT PULLED
20" 94# H-40 Surface 110' 30" _~60 sx Arctic Set (Approx.)
9-5/8" 40# L-80 30' 3643' 12-1/4" i1637 sx Coldset, 500 sx Class 'G'
7" 26# L-80 28' 9167' 8-1/2" 250 sx Class 'G'
4-1/2" 12.6# L-80 8995' 10709' 6" 178 sx Class 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD)
2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9011' 8956'
MD TVD MD TVD
9440' - 9740' 8780' - 8794'
9810' - 9960' 8796' ~ 8809' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
_~7. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.)
October 25, 1997 I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-OIL RATIO
TEST PERIOD
Flow Tubing Casing Pressure CALCULATED OIL-DEL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR)
Press. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name Depth Depth recovered and gravity, GOR, and time of each phase.
Sag River 9166' 8669'
!Shublik 9202' 8691'
Shublik 'B' 9273' 8729'
Shublik 'C' 9325' 8750'
Top of Sadlerochit 9409' 8774'
Zone 3 10539' 8972'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify tha~the foregoing is ~ct to the best of my knowledgeSigned l?~ ' /C~/~/Z)
James Smith i/~/"'~'~ ~---'-' Title Senior Drilling Engineer, Acting Date
!
H-347" 97-164 Prepared By Name/Number: Terrie Hubble, 564-4628
Well Num~fer Permit No. / Approval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
ITEM 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 cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Performance Enquiry Report
Operator BP Exploration Date 00:0l, 21 Nov 97
Page 1
The analysis is from - 18:30, 21 Sep 97 - to - 18:30, 21 Sep 97
Programs in Result Table: H-34 Drill and Complete
Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight)
H-34 Event 18:30, 21 Sep 97 18:30, 21 Sep 97 0 hr 0 min Obtained leak off 14.400
Hole Size MDR
8-1/2
Progress Report
Facility PB H Pad
Well H-34
Rig Nabors 2ES
Page 1
Date 24 October 97
Date/Time
16 Sep 97 06:00-07:00
07:00-10:00
10:00-18:30
18:30-19:00
19:00-20:00
20:00-20:30
20:30-21:00
21:00-00:30
17 Sep 97 00:30-02:30
02:30-03:30
03:30-04:00
04:00-04:30
04:30-06:00
06:00-06:00
18 Sep 97 06:00-12:30
12:30-13:30
13:30-15:00
15:00-16:00
16:00-16:30
16:30-19:30
19:30-01:30
19 Sep 97 01:30-03:00
03:00-06:00
06:00-13:00
13:00-14:00
14:00-15:30
15:30-16:30
16:30-19:00
19:00-21:00
21:00-00:00
20 Sep 97 00:00-02:00
02:00-02:30
02:30-06:00
06:00-10:00
10:00-11:30
11:30-12:00
12:00-12:15
12:15-12:30
12:30-13:00
13:00-15:30
15:30-16:30
16:30-17:30
17:30-18:00
18:00-20:30
20:30-00:00
21 Sep 97 00:00-03:00
03:00-03:30
03:30-06:00
06:00-06:30
06:30-07:00
07:00-09:30
09:30-10:00
10:00-10:30
10:30-11:00
Duration
1 hr
3hr
8-1/2 hr
1/2 hr
lhr
1/2 hr
1/2 hr
3-1/2 hr
2 hr
lhr
1/2 hr
1/2 hr
1-1/2 hr
24 hr
6-1/2 hr
lhr
1-1/2 hr
lhr
1/2 hr
3 hr
6hr
1-1/2 hr
3hr
7hr
lhr
1-1/2 hr
lhr
2-1/2 hr
2 hr
3 hr
2hr
1/2 hr
3-1/2 hr
4hr
1-1/2 hr
1/2 hr
1/4 hr
1/4 hr
1/2 hr
2-1/2 hr
lhr
1 hr
1/2 hr
2-1/2 hr
3-1/2 hr
3hr
1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
1/2 hr
Activity
Rig moved 100.00 %
Rigged up Drillfloor / Derrick
Rigged up Divertor
Held safety meeting
Made up BHA no. 1
Tested Divertor
Circulated at 102.51 ft
Drilled to 311.51 ft
Serviced Shaker discharge line
Serviced Block line
R.I.H. to 311.51 ft
Serviced Fluid system
Drilled to 400.51 ft
Drilled to 1970.51 ft (cont...)
Drilled to 2510.51 ft (cont...)
Circulated at 2510.51 ft
Pulled out of hole to 1000.51 ft
Pulled BHA
Made up BHA no. 2
R.I.H. to 2510.51 ft
Drilled to 3056.51 ft
Circulated at 3056.51 ft
Drilled to 3300.51 ft
Drilled to 3658.51 ft (cont...)
Circulated at 3658.51 ft
Pulled out of hole to 1000.51 ft
R.I.H. to 3658.51 ft
Circulated at 3658.51 ft
Pulled out of hole to 1000.51 ft
Pulled BHA
Rigged up Casing handling equipment
Held safety meeting
Ran Casing to 9-5/8in (1500.51 ft OD)
Ran Casing to 3642.51 ft (9-5/8in OD) (cont...)
Circulated at 3642.51 ft
Pumped Water spacers - volume 75.000 bbl
Mixed and pumped slurry - 94.000 bbl
Mixed and pumped slurry - 102.000 bbl
Displaced slurry - 270.000 bbl
Circulated at 2016.51 ft
Mixed and pumped slurry - 466.000 bbl
Displaced slurry - 154.000 bbl
Rigged down Casing handling equipment
Rigged down Divertor
Installed Casing spool
Rigged up BOP stack
Installed BOP test plug assembly
Tested BOP stack
Tested BOP stack (cont...)
Installed Wear bushing
Made up BHA no. 3
R.I.H. to 1800.51 ft
Serviced Block line
R.I.H. to 2018.51 ft
Facility
PB H Pad
Progress Report
Well H-34 Page 2
Rig Nabors 2ES Date 24 October 97
Date/Time
22 Sep 97
23 Sep 97
24 Sep 97
25 Sep 97
26 Sep 97
27 Sep 97
28 Sep 97
11:00-12:00
12:00-13:30
13:30-14:00
14:00-17:30
17:30-18:00
18:00-18:30
18:30-20:00
20:00-21:00
21:00-22:30
22:30-00:00
00:00-01:00
01:00-02:00
02:00-06:00
06:00-06:00
06:00-12:00
12:00-13:00
13:00-14:00
14:00-15:00
15:00-16:30
16:30-06:00
06:00-02:00
02:00-03:00
03:00-04:30
04:30-06:00
06:00-15:00
15:00-16:00
16:00-19:30
19:30-21:00
21:00-22:30
22:30-23:30
23:30-00:00
00:00-02:30
02:30-06:00
06:00-13:30
13:30-14:30
14:30-03:00
03:00-04:00
04:00-05:00
05:00-06:00
06:00-06:30
06:30-07:00
07:00-09:00
09:00-16:00
16:00-18:30
18:30-20:30
20:30-21:15
21:15-21:30
21:30-03:30
03:30-04:00
04:00-06:00
06:00-11:00
11:00-15:00
15:00-15:30
15:30-15:45
Duration
1 hr
1-1/2 hr
1/2 hr
3-1/2 hr
1/2 hr
1/2 hr
1-1/2 hr
1 hr
1-1/2 hr
1-1/2 hr
1 hr
1 hr
4hr
24 hr
6hr
lhr
1 hr
lhr
1-1/2 hr
13-1/2 hr
20 hr
1 hr
1-1/2 hr
1-1/2 hr
9hr
1 hr
3-1/2 hr
1-1/2 hr
1-1/2 hr
lhr
1/2 hr
2-1/2 hr
3-1/2 hr
7-1/2 hr
lhr
12-1/2 hr
lhr
lhr
lhr
1/2 hr
1/2 hr
2 hr
7 hr
2-1/2 hr
2 hr
3/4 hr
1/4 hr
6 hr
1/2 hr
2hr
5hr
4hr
1/2 hr
1/4 hr
Activity
Drilled installed equipment - DV collar
R.I.H. to 3552.51 ft
Tested Casing - Via annulus and string
Drilled installed equipment - Landing collar
Circulated at 3678.51 ft
Performed formation integrity test
Pulled out of hole to 1000.51 ft
Pulled BHA
Made up BHA no. 4
Pulled BHA
Made up BHA no. 4
R.I.H. to 3678.51 ft
Drilled to 4104.51 ft
Drilled to 5932.51 ft (cont...)
Drilled to 6184.51 ft (cont...)
Circulated at 6184.51 ft
Pulled out of hole to 3620.51 ft
Serviced Block line
R.I.H. to 6184.51 ft
Drilled to 7047.51 ft
Drilled to 8512.51 ft (cont...)
Circulated at 8512.51 ft
Pulled out of hole to 5210.51 ft
R.I.H. to 8512.51 ft
Drilled to 8704.51 ft
Circulated at 8704.51 ft
Pulled out of hole to 1000.51 ft
Pulled BHA
Made up BHA no. 5
R.I.H. to 3587.51 ft
Serviced Block line
R.I.H. to 8704.51 ft
Drilled to 8752.51 ft
Drilled to 8909.51 ft (cont...)
Serviced Mud pumps
Drilled to 9177.51 ft
Circulated at 9177.51 ft
Circulated at 9177.51 ft
Pulled out of hole to 8000.51 ft
Pulled out of hole to 6810.51 ft (cont...)
R.I.H. to 9177.51 ft
Circulated at 9177.51 ft
Laid down 8177.00 ft of 5in OD drill pipe
Pulled BHA
Tested Top ram
Rigged up Casing handling equipment
Held safety meeting
Ran Casing to 3570.51 ft (7in OD)
Circulated at 3570.51 ft
Ran Casing to 7in (5000.51 ft OD)
Ran Casing to 9167.51 ft (7in OD) (cont...)
Circulated at 9167.51 ft
Pumped Water based mud spacers - volume 70.000 bbl
Mixed and pumped slurry - 51.000 bbl
Progress Report
Facility PB H Pad
Well H-34
Rig Nabors 2ES
Page 3
Date 24 October 97
Date/Time
15:45-17:00
17:00-18:30
18:30-20:00
20:00-22:30
22:30-01:30
29 Sep 97 01:30-02:00
02:00-04:30
04:30-06:00
06:00-11:00
11:00-12:30
12:30-14:30
14:30-15:30
15:30-19:00
19:00-21:30
21:30-06:00
30 Sep 97 06:00-05:00
01 Oct97 05:00-06:00
06:00-06:30
06:30-11:00
11:00-12:00
14:00-14:30
14:30-19:00
19:00-20:30
20:30-21:00
21:00-06:00
02 Oct 97 06:00-06:00
10:00-11:00
11:00-15:30
15:30-16:30
16:30-19:00
19:00-22:00
22:00-06:00
03 Oct 97 06:00-08:00
08:00-09:00
09:00-11:30
11:30-13:00
13:00-17:00
17:00-17:30
17:30-19:00
19:00-21:30
21:30-03:30
04 Oct 97 03:30-05:00
05:00-06:00
06:00-06:15
06:15-15:00
15:00-21:30
21:30-04:00
05 Oct 97 04:00-04:30
04:30-06:00
06:00-06:15
06:15-19:45
19:45-21:00
21:00-03:30
06 Oct 97 03:30-06:00
Duration
1-1/4 hr
1-1/2 hr
1-1/2 hr
2-1/2
3hr
1/2 hr
2-1/2 hr
1-1/2 hr
5 hr
1-1/2 hr
2hr
1 hr
3-1/2 hr
2-1/2 hr
8-1/2 hr
23 hr
lhr
1/2 hr
4-1/2 hr
1 hr
1/2 hr
4-1/2 hr
1-1/2 hr
1/2 hr
9hr
24 hr
lhr
4-1/2 hr
lhr
2-1/2 hr
3 hr
8hr
2 hr
lhr
2-1/2 hr
1-1/2 hr
4hr
1/2 hr
1-1/2 hr
2-1/2 hr
6hr
1-1/2 hr
lhr
1/4 hr
8-3/4 hr
6-1/2 hr
6-1/2 hr
1/2 hr
1-1/2 hr
1/4 hr
13-1/2 hr
1-1/4 hr
6-1/2 hr
2-1/2 hr
Activity
Displaced slurry - 348.000 bbl
Installed Seal assembly
Rigged up Top ram
Rigged up Kelly
Tested BOP stack
Installed Wear bushing
Made up BHA no. 6
Singled in drill pipe to 1500.51 ft
Singled in drill pipe to 6500.51 ft (cont...)
Serviced Block line
Singled in drill pipe to 9018.51 ft
Tested Casing - Via annulus and string
Drilled cement to 9197.51 ft
Circulated at 9197.51 ft
Drilled to 9375.51 ft
Drilled to 10346.51 ft (cont...)
Circulated at 10346.51 ft
Circulated at 10346.51 ft
Pulled out of hole to 200.51 ft
Downloaded MWD tool
Serviced Swivel
R.I.H. to 10024.51 ft
Tested Swivel
R.I.H. to 10346.51 ft
Drilled to 10405.51 ft
Drilled to 10405.51 ft (cont...)
Circulated at 10449.51 ft
Pulled out of hole to 200.51 ft
Downloaded MWD tool
Made up BHA no. 8
R.I.H. to 10449.51 ft
Drilled to 10621.51 ft
Drilled to 10621.51 ft (cont...)
Circulated at 10710.51 ft
Pulled out of hole to 9150.51 ft
Circulated at 10710.51 ft
Pumped out of hole to 5000.51 ft
Serviced Service lines
Pulled out of hole to 200.51 ft
Downloaded MWD tool
Ran logs on tubulars
Circulated at 8869.51 ft
Conducted electric cable operations
Conducted electric cable operations (cont...)
Ran logs on tubulars
Conducted electric cable operations
Ran logs on tubulars
Circulated at 8979.51 ft
Conducted electric cable operations
Conducted electric cable operations (cont...)
Ran logs on tubulars
Pulled out of hole to 8960.51 ft
Pulled out of hole to 0.51 ft
Ran Liner to 4-1/2in (10710.51 ft OD)
Progress Report
Facility PB H Pad
Well H-34 Page 4
Rig Nabors 2ES Date 24 October 97
Date/Time
07 Oct 97
08 Oct 97
09 Oct 97
10 Oct 97
06:00-07:00
07:00-12:00
12:00-20:00
20:00-21:15
21:15-22:15
22:15-00:00
00:00-01:30
01:30-04:30
04:30-06:00
06:00-11:30
11:30-16:00
16:00-21:00
21:00-00:00
00:00-01:00
01:00-06:00
06:00-08:00
08:00-11:30
11:30-16:00
16:00-19:30
19:30-23:00
23:00-00:30
00:30-06:00
06:00-07:30
07:30-12:00
12:00-12:30
12:30-13:30
13:30-03:00
03:00-04:00
04:00-06:00
06:00-09:30
09:30-13:30
13:30-17:00
17:00-22:00
Duration
1 hr
5 hr
8 hr
1-1/4 hr
lhr
1-3/4 hr
1-1/2 hr
3hr
1-1/2 hr
5-1/2 hr
4-1/2 hr
5 hr
3hr
lhr
5hr
2hr
3-1/2 hr
4-1/2 hr
3-1/2 hr
3-1/2 hr
1-1/2 hr
5-1/2 hr
1-1/2 hr
4-1/2 hr
1/2 hr
1 hr
13-1/2 hr
lhr
2 hr
3-1/2 hr
4 hr
3-1/2 hr
5hr
Activity
Ran Liner to 10710.51 ft (4-1/2in OD) (cont...)
Ran Tubing to 1607.51 ft (2-7/8in OD)
Ran Drillpipe in stands to 9004.51 ft
Circulated at 10710.51 ft
Batch mixed slurry - 37.800 bbl
Circulated at 10620.51 ft
Pulled Drillpipe in stands to 8838.51 ft
Cleared Trip tank
Circulated at 8838.51 ft
Repaired Mechanical brake
Pulled out of hole to 1700.51 ft
Laid down 1700.00 ft of 2-7/8in OD drill pipe
Tested BOP stack
Tested Casing head
Conducted electric cable operations
Conducted electric cable operations
Space out tubulars
Ran Drillpipe to 8940.51 ft (3-1/2in OD)
Removed Bell nipple
Ran Drillpipe to 8940.51 ft (3-1/2in OD)
Flowed well - oil 0.00 bbl/min, water -0.50 bbl/min, gas 0.00000 mmsc
Laid down 8940.00 ft of 3-1/2in OD drill pipe
Laid down 8940.00 ft of 3-1/2in OD drill pipe (cont...)
Laid down 1800.00 ft of Tubing
Retrieved Wear bushing
Rigged up Completion string handling equipment
Ran Tubing to 9115.51 ft (4-1/2in OD)
Installed Tubing hanger
Reverse circulated at 9115.51 ft
Reverse circulated at 9123.51 ft (cont...)
Tested Packer & tailpipe assembly - Via string
Rigged down BOP stack
Installed All tree valves
/day
SPF~RY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION, INC.
PBU ~ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
MWD SURVEY
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPEP~ATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
.00 .00 -74.80
158.33 158.33 83.53
243.45 243.45 168.65
332.73 332.73 257.93
422.20 422.19 347.39
0 0
0 21
0 13
0 24
0 25
N .00 E .00 .00N .00E
N 4.90 E .22 .48N .04E
N 18.90 W .20 .90N .01E
N 16.30 W .20 1.36N .13W
N 36.83 E .42 1.93N .02W
.00
.01
.08
.27
.21
512.73 512.72 437.92
602.61 602.59 527.79
690.44 690.41 615.61
780.56 780.48 705.68
871.97 871.78 796.98
0 39
0 54
1 13
2 7
3 24
N 67.37 E .39 2.39N .66E
N 66.57 E .28 2.87N 1.78E
N 69.93 E .38 3.47N 3.30E
N 75.69 E 1.00 4.21N 5.82E
N 75.13 E 1.40 5.33N 10.08E
- .42
-1.48
-2.93
-5.37
-9.50
959.91 959.45 884.65 5
1056.68 1055.81 981.01 5
1151.93 1150.67 1075.87 5
1247.68 1246.08 1171.28 4
1343.19 1341.30 1266.50 4
19
20
0
35
21
N 82.18 E 2.27 6.55N 16.64E
N 82.60 E .04 7.74N 25.56E
N 78.30 E .54 9.16N 34.02E
N 79.20 E .44 10.72N 41.87E
N 78.60 E .25 12.15N 49.18E
-15.91
-24.67
-32.94
-40.60
-47.73
1437.50 1435.33 1360.53 4 27
1533.47 1531.05 1456.25 3 52
1628.01 1625.38 1550.58 3 46
1719.56 1716.73 1641.93 3 43
1816.14 1813.11 1738.31 3 35
N 80.70 E .20 13.45N 56.32E
N 77.90 E .65 14.74N 63.17E
N 76.70 E .13 16.12N 69.31E
N 78.90 E .16 17.39N 75.16E
N 78.10 E .14 18.62N 81.21E
-54.70
-61.39
-67.36
-73.06
-78.96
1910.13 1906.95 1832.15
2003.70 2000.40 1925.60
2093.94 2090.55 2015.75
2190.97 2187.51 2112.71
2286.17 2282.69 2207.89
2 53
2 52
2 23
1 38
1 0
N 81.18 E .78 19.59N 86.44E
N 79.87 E .07 20.36N 91.08E
N 80.25 E .53 21.08N 95.16E
N 80.99 E .77 21.64N 98.52E
N 85.81 E .68 21.91N 100.69E
-84.06
-88.60
-92.59
-95.88
-98.01
2379.00 2375.51 2300.71 0 43
2472.39 2468.89 2394.09 0 42
2565.10 2561.58 2486.78 1 27
2660.42 2656.87 2582.07 1 35
2754.61 2751.02 2676.22 1 38
N 81.42 E .30 22.06N 102.09E
S 85.75 E .17 22.11N 103.24E
N 64.81 W 2.29 22.56N 102.75E
N 66.69 W .16 23.60N 100.44E
N 65.94 W .06 24.67N 98.01E
-99.39
-100.53
-99.99
-97.60
-95.07
2846.41 2842.78 2767.98 1 43
2940.29 2936.62 2861.82 1 49
3034.39 3030.66 2955.86 1 57
3129.26 3125.48 3050.68 1 57
3224.12 3220.28 3145.48 2 7
N 68.64 W .12 25.70N 95.53E
N 65.39 W .15 26.84N 92.86E
N 61.56 W .20 28.23N 90.09E
N 61.95 W .02 29.76N 87.23E
N 63.01 W .17 31.32N 84.23E
-92.50
-89.73
-86.83
-83.84
-80.70
ORIGINAL
SPF-'~Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION, INC.
PBU ~ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
MWD SURVEY
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
3319.23 3315.34 3240.54
3413.14 3409.23 3334.43
3507.18 3503.24 3428.44
3588.80 3584.84 3510.04
3658.00 3654.01 3579.21
1 21 N 89.87 W 1.15 32.12N 81.54E
1 19 S 67.72 W .56 31.71N 79.42E
1 19 S 71.45 W .09 30.96N 77.39E
1 34 S 74.35 W .31 30.35N 75.41E
1 42 S 74.35 W .19 29.82N 73.51E
-77.94
-75.87
-73.92
-72.02
-70.18
3697.17 3693.16 3618.36
3788.43 3784.38 3709.58
3879.13 3875.04 3800.24
3973.90' 3969.77 3894.97
4070.27 4066.11 3991.31
1 34 S 76.61 W .35 29.54N 72.42E
1 48 S 71.45 W .30 28.79N 69.83E
1 36 S 62.64 W .36 27.75N 67.34E
1 40 S 65.50 W .11 26.56N 64.90E
0 57 S 76.20 W .79 25.78N 62.83E
-69.13
-66.62
-64.25
-61.93
-59.95
4160.40 4156.23 4081.43
4252.55 4248.36 4173.56
4347.15 4342.95 4268.15
4440.78 4436.57 4361.77
4532.30 4528.08 4453.29
1 6 S 56.18 W .43 25.12N 61.37E
1 4 S 80.92 W .51 24.48N 59.77E
0 41 S 49.04 W .65 23.97N 58.46E
0 48 S 62.43 E 1.32 23.30N 58.61E
0 42 S 57.05 E .12 22.69N 59.66E
-58.57
-57.04
-55.79
-56.01
-57.10
4623.87 4619.65 4544.85
4716.96 4712.74 4637.94
4811.24 4807.01 4732.21
4902.87 4898.64 4823.84
4995.89 4991.64 4916.84
0 26 S 64.40 E .31 22.23N 60.45E
0 22 S 62.85 E .07 21.94N 61.05E
0 44 S 31.96 E .49 21.28N 61.65E
0 46 N 84.04 E .87 20.84N 62.57E
0 57 S 27.33 W 1.63 20.22N 62.84E
-57.94
-58.56
-59.22
-60.19
-60.52
5088.97 5084.60 5009.80
5183.53 5178.76 5103.96
5275.50 5270.09 5195.29
5370.14 5363.62 5288.82
5463.31 5455.25 5380.45
4 35 S 57.47 W 4.08 17.53N 59.34E
5 52 S 62.43 W 1.44 13.25N 51.86E
7 33 S 61.08 W 1.83 8.15N 42.39E
9 56 S 67.41 W 2.72 1.99N 29.39E
10 56 S 71.44 W 1.32 3.91S 13.58E
-57.31
-50.29
-41.37
-29.04
-13.90
5557.27 5547.11 5472.31
5650.23 5637.08 5562.28
5740.34 5723.17 5648.37
5834.15 5811.65 5736.85
5927.58 5898.51 5823.71
13 12 S 73.19 W 2.45 9.86S 5.15W
15 54 S 73.61 W 2.91 16.52S 27.55W
18 21 S 72.35 W 2.75 24.31S 52.92W
20 22 S 73.79 W 2.20 33.35S 82.68W
22 52 S 79.24 W 3.43 41.28S 116.14W
4.15
25.77
50.24
78.95
111.45
6022.65 5985.52 5910.72
6116.16 6069.81 5995.01
6205.15 6149.07 6074.27
6299.86 6233.33 6158.54
6394.42 6317.28 6242.48
24 38 S 77.63 W 1.98 48.97S 153.64W
26 38 S 77.72 W 2.14 57.61S 193.17W
27 27 S 77.56 W .91 66.27S 232.69W
26 51 S 77.77 W .63 75.51S 274.92W
27 56 S 77.22 W 1.17 84.93S 317.40W
148.01
186.48
224.94
266.04
307.38
SPF-RY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION, INC.
PBU ~ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
MWD SURVEY
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGUL~R COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
6483.36 6395.50 6320.70
6576.63 6477.09 6402.29
6666.91 6556.31 6481.51
6762.20 6639.73 6564.93
6854.44 6719.93 6645.13
28 54 S 75.73 W 1.35 94.84S 358.56W
29 2 S 77.26 W .81 105.39S 402.49W
28 15 S 76.95 W .89 115.05S 444.69W
29 32 S 77.55 W 1.38 125.21S 489.61W
29 38 S 77.27 W .19 135.14S 534.06W
347.34
390.01
431.04
474.72
517.97
6948.72 6802.35 6727.55
7042.07 6884.06 6809.26
7136.02 6966.11 6891.31
7231.56 7050.35 6975.55
7324.97 7132.75 7057.95
28 27 S 75.69 W 1.50 145.83S 578.58W
29 21 S 74.26 W 1.22 157.53S 622.16W
28 57 S 75.39 W .73 169.52S 666.33W
27 19 S 74.23 W 1.80 181.31S 709.80W
28 51 S 74.44 W 1.65 193.18S 752.15W
561.20
603.40
646.16
688.24
729.20
7415.92 7211.89 7137.09
7509.46 7293.29 7218.49
7602.07 7373.86 7299.06
7696.12 7455.27 7380.47
7791.59 7538.24 7463.44
30 10 S 75.26 W 1.52 204.89S 795.40W
28 50 S 75.12 W 1.43 216.66S 839.95W
30 13 S 74.56 W 1.53 228.60S 884.00W
29 51 S 74.66 W .40 241.10S 929.40W
29 26 S 74.64 W .44 253.60S 974.95W
771.07
814.22
856.87
900.80
944.88
7884.77 7619.80 7545.00
7977.86 7701.03 7626.23
8068.87 7779.72 7704.92
8162.81 7861.06 7786.26
8256.93 7943.07 7868.27
28 23 S 73.60 W 1.25 265.92S 1018.28W
30 2 S 74.20 W 1.81 278.52S 1061.94W
30 16 S 74.83 W .42 290.73S l106.00W
29 45 S 74.55 W .56 303.13S 1151.33W
29 0 S 74.44 W .80 315.48S 1195.83W
986.77
1028.96
1071.59
1115.45
1158.51
8350.29 8025.39 7950.59
8445.33 8109.26 8034.46
8535.09 8187.43 8112.63
8628.55 8267.90 8193.10
8648.92 8285.27 8210.47
27 16 S 73.65 W 1.91 327.57S 1238.16W
28 49 S 73.97 W 1.64 340.03S 1281.07W
30 2 S 72.77 W 1.51 352.65S 1323.32W
31 6 S 75.44 W 1.85 365.65S 1369.03W
31 49 S 74.63 W 4.10 368.40S 1379.31W
1199.42
1240.88
1281.67
1325.86
1335.81
8683.07 8314.01 8239.21
8714.72 8340.13 8265.33
8752.37 8370.50 8295.70
8782.10 8393.86 8319.06
8814.19 8418.55 8343.75
33 31 S 74.07 W 5.06 373.38S 1397.06W
35 11 S 76.09 W 6.36 377.97S 1414.32W
37 19 S 81.13 W 9.73 382.34S 1436.13W
39 6 S 85.24 W 10.46 384.50S 1454.38W
40 21 N 88.74 W 12.60 385.12S 1474.87W
1352.98
1369.69
1390.96
1408.91
1429.23
8844.92 8441.84 8367.04
8876.02 8465.16 8390.36
8907.63 8488.57 8413.77
8938.12 8510.94 8436.14
8969.57 8533.81 8459.01
41 4 N 83.73 W 10.89 383.79S 1494.86W
41 47 N 80.64 W 6.96 380.99S 1515.24W
42 38 N 78.01 W 6.20 377.06S 1536.10W
43 0 N 76.20 W 4.20 372.43S 1556.30W
43 40 N 73.97 W 5.32 366.87S 1577.15W
1449.25
1469.81
1490.97
1511.53
1532.83
SPF~.Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 4
BP EXPLORATION, INC.
PBU [ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
MWD SURVEY
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGULAR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
8999.92 8555.71 8480.91
9032.02 8578.77 8503.97
9063.04 8600.91 8526.11
9095.00 8623.21 8548.41
9114.07 8636.15 8561.35
43 55 N 71.64 W 5.38 360.66S 1597.22W
44 13 N 70.50 W 2.64 353.42S 1618.34W
44 42 N 69.28 W 3.16 345.95S 1638.74W
46 45 N 67.70 W 7.33 337.55S 1660.03W
47 49 N 69.17 W 7.94 332.40S 1673.06W
1553.41
1575.15
1596.19
1618.21
1631.69
9140.00 8653.16 8578.36
9173.33 8674.09 8599.29
9203.37 8692.19 8617.39
9235.58 8710.33 8635.53
9267.83 8726.62 8651.82
50 7 N 68.56 W 9.08
52 4 N 67.95 W 6.02
53 47 N 67.34 W 5.95
57 37 N 67.69 W 11.92
61 41 N 67.64 W 12.59
325.35S 1691.30W
315.74S 1715.39W
306.62S 1737.56W
296.45S 1762.15W
285.87S 1787.89W
1650.54
1675.47
1698.43
1723.91
1750.57
9298.33 8740.04 8665.24
9330.43 8752.03 8677.23
9361.19 8761.66 8686.86
9393.40 8770.44 8695.64
9425.88 8777.68 8702.88
66 3 N 67.62 W 14.33
70 4 N 68.13 W 12.58
73 25 N 67.12 W 11.36
74 56 N 63.86 W 10.82
79 18 N 63.25 W 13.52
275.45S 1813.20W
264.24S 1840.78W
253.12S 1867.79W
240.26S 1895.98W
226.17S 1924.32W
1776.80
1805.36
1833.34
1862.67
1892.27
9456.34 8782.20 8707.40 83 37
9488.56 8784.84 8710.04 86 57
9520.10 8786.67 8711.87 86 24
9551.69' 8788.82 8714.02 85 46
9582.47 8791.09 8716.29 85 45
N 62.46 W 14.44
N 61.25 W 10.99
N 61.35 W 1.80
N 61.20 W 2.02
N 61.13 W .24
212.42S 1951.12W
197.28S 1979.43W
182.16S 2007.05W
167.01S 2034.69W
152.21S 2061.58W
1920.31
1949.98
1978.97
2007.98
2036.21
9640.37 8794.82 8720.02 86 51
9671.04 8795.41 8720.61 90 56
9705.86 8794.71 8719.91 91 20
9736.44 8794.07 8719.27 91 3
9764.97 8793.73 8718.93 90 18
N 61.08 W 1.92
N 60.63 W 13.42
N 59.58 W 3.23
N 59.05 W 1.99
N 58.88 W 2.66
124.29S 2112.16W
109.36S 2138.94W
92.01S 2169.12W
76.41S 2195.41W
61.70S 2219.85W
2089.32
2117.45
2149.20
2176.92
2202.70
9801.13 8794.90 8720.10 86 0
9833.29 8797.32 8722.52 85 20
9865.50 8800.17 8725.37 84 31
9895.57 8803.01 8728.21 84 37
9927.96 8806.11 8731.31 84 23
N 59.43 W 12.02
N 59.83 W 2.37
N 64.17 W 13.67
N 64.44 W .97
N 63.91 W 1.79
43.17S 2250.88W
26.96S 2278.54W
11.90S 2306.86W
1.08N 2333.84W
15.12N 2362.86W
2235.41
2264.56
2294.23
2322.37
2352.64
9960.26 8809.23 8734.43
9992.59 8812.39 8737.59
10024.89 8815.69 8740.89
10055.84 8818.94 8744.14
10093.91 8823.04 8748.24
84 3O
84 15
84 0
83 56
83 40
N 63.52 W 1.26
N 63.70 W .95
N 63.68 W .78
N 63.81 W .46
N 64.31 W 1.49
29.36N 2391.68W
43.66N 2420.51W
57.90N 2449.31W
71.52N 2476.91W
88.07N 2510.95W
2382.74
2412.84
2442.92
2471.74
2507.25
SPt' ri.Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 5
BP EXPLORATION, INC.
PBU [ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
MWD SURVEY
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS COURSE DLS
INCLN DIRECTION
DG MN DEGREES DG/10
TOTAL
RECTANGULAR COORDINATES
0 NORTH/SOUTH EAST/WEST
VERT.
SECT.
10124.41 8826.43 8751.63 83 34 N 65.50 W 3.89 100.93N 2538.40W
10156.53 8830.06 8755.26 83 25 N 63.25 W 6.98 114.73N 2567.17W
10188.85 8833.91 8759.11 82 52 N 62.60 W 2.64 129.33N 2595.74W
10221.14 8838.92 8764.12 79 18 N 60.08 W 13.45 144.63N 2623.72W
10253.31 8845.88 8771.08 75 40 N 57.18 W 14.31 160.97N 2650.54W
2535.84
2565.84
2595.73
2625.10
2653 40
10284.16 8854.36 8779.56 72 24 N 54.64 W 13.23 177.58N 2675.10W
10323.78 8867.72 8792.92 68 13 N 47.40 W 20.18 201.00N 2704.09W
10355.97 8880.39 8805.59 65 24 N 46.22 W 9.39 221.25N 2725.66W
10388.18 '8893.92 8819.13 64 52 N 46.44 W 1.76 241.43N 2746.80W
10426.23 8910.46 8835.66 63 37 N 46.44 W 3.31 265.05N 2771.64W
2679 49
2710.67
2734 15
2757.19
2784 25
10451.22 8921.91 8847.11 61 47 N 46.44 W 7.32 280.35N 2787.73W
10484.15 8938.67 8863.87 57 1 N 46.44 W 14.45 299.88N 2808.26W
10514.63 8956.09 8881.29 53 12 N 46.44 W 12.53 317.11N 2826.38W
10547.00 8976.71 8901.91 47 36 N 46.44 W 17.30 334.29N 2844.45W
10579.16 8999.61 8924.81 41 31 N 46.44 W 18.91 349.83N 2860.79W
2801 79
2824.16
2843 90
2863.59
2881.41
10608.76 9022.55 8947.75 36 50 N 46.44 W 15.81 362.72N 2874.34W
10641.14 9049.27 8974.47 31 53 N 46.44 W 15.32 375.31N 2887.59W
10682.14 9085.39 9010.59 24 27 N 46.44 W 18.15 388.64N 2901.60W
10710.00 9110.75 9035.95 24 27 N 46.44 W .07 396.59N 2909.96W
2896.17
2910.60
2925.87
2934.98
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 2936.86 FEET
AT NORTH 82 DEG. 14 MIN. WEST AT MD = 10710
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 275.71 DEG.
TIE-IN SURVEY AT 0.00' MD
PROJECTED SURVEY AT 10710.00' MD
SPF' ri.Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
·
PAGE
BP EXPLORATION, INC.
PBU k H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA TOTAL
MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE
VERTICAL
CORRECTION
.00 .00 -74.80 .00 N .00 E .00
1000.00 999.37 924.57 7.06 N 20.33 E .63
2000.00 1996.71 1921.91 20.33 N 90.89 E 3.29
3000.00 2996.29 2921.49 27.67 N 91.12 E 3.71
4000.00 3995.86 3921.06 26.24 N 64.20 E 4.14
.63
2.66
.41
.43
5000.00 4995.75 4920.95 20.15 N 62.80 E 4.25
6000.00 5964.93 5890.13 46.95 S 144.42 W 35.07
7000.00 6847.39 6772.59 151.94 S 602.30 W 152.61
8000.00 7720.20 7645.40 281.54 S 1072.61 W 279.80
9000.00 8555.77 8480.97 360.65 S 1597.27 W 444.23
.11
30.82
117.54
127.20
164.43
10000.00 8813.13 8738.33 46.93 N 2427.12 W 1186.87
10710.00 9110.75 9035.95 396.59 N 2909.96 W 1599.25
742.63
412.39
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPF-~Y-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 7
BP EXPLORATION, INC.
PBU ~ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
JOB N-/MBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
.00 .0
74 . 80 74 . 8
174 . 80 174 . 8
274 . 80 274 . 8
374 . 80 374 . 8
-74.8
.0
100.0
200.0
300.0
.00 N .00 E .00
.00 N .00 E .00 .00
.58 N .05 E .00 .00
1.01 N .03 W .00 .00
1.64 N .20 W .01 .00
474.81 474.8
574.82 574.8
674.83 674.8
774.87 774.8
874.99 874.8
400.0
500.0
600.0
700.0
800.0
2.23 N .27 E .01 .00
2.70 N 1.38 E .02 .01
3.35 N 2.98 E .03 .02
4.16 N 5.62 E .07 .04
5.37 N 10.25 E .19 .12
975.32 974.8
1075.76 1074.8
1176.15 1174.8
1276.49 1274.8
1376.79 1374.8
900.0
1000.0
1100.0
1200.0
1300.0
6.75 N 18.06 E
7.97 N 27.32 E
9.58 N 36.09 E
11.15 N 44.14 E
12.66 N 51.69 E
.52 .33
.96 .44
1.35 .40
1.69 .34
1.99 .30
1477.09 1474.8
1577.32 1574.8
1677.54 1674.8
1777.75 1774.8
1877.94 1874.8
1400 . 0
1500.0
1600.0
1700.0
1800.0
13.95 N 59.35 E
15.36 N 66.06 E
16.86 N 72.48 E
18.12 N 78.85 E
19.34 N 84.83 E
2.29 .30
2.52 .23
2.74 .22
2.95 .21
3.14 .19
1978.07 1974.8
2078.18 2074.8
2178.25 2174.8
2278.28 2274.8
2378.29 2374.8
1900.0
2000.0
2100.0
2200.0
2300.0
20.14 N 89.81 E
20.97 N 94.51 E
21.58 N 98.16 E
21.90 N 100.56 E
22.06 N 102.08 E
3.27 .13
3.38 .11
3.45 .07
3 .48 .03
3 .49 .01
2478.30 2474.8
2578.32 2574.8
2678.36 2674.8
2778.40 2774.8
2878.44 2874.8
2400.0
2500.0
2600.0
2700.0
2800.0
22.10 N 103.32 E
22.70 N 102.45 E
23.80 N 99.98 E
24.94 N 97.39 E
26.05 N 94.63 E
3.50 .01
3.52 .02
3.56 .04
3.60 .04
3.64 .04
2978.49 2974.8
3078.55 3074.8
3178.61 3174.8
3278.68 3274.8
3378.70 3374.8
2900.0
3000.0
3100.0
3200.0
3300.0
27.34 N 91.76 E
28.95 N 88.76 E
30.56 N 85.73 E
32.11 N 82.51 E
32.01 N 80.16 E
3.69 .05
3.75 .06
3.81 .O6
3.88 .06
3.90 .03
SPT ~.Y-SUN DRILLING SERVICES
· ANCHORAGE ALASKA
PAGE 8
BP EXPLORATION, INC.
PBU [ H-34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
3478.73 3474.8
3578.76 3574.8
3678.80 3674.8
3778.84 3774.8
3878.89 3874.8
0 3400.00 31.17 N 78.01
0 3500.00 30.43 N 75.68
0 3600.00 29.66 N 72.92
0 3700.00 28.89 N 70.12
0 3800.00 27.75 N 67.35
E 3.93 .03
E 3.96 .03
E 4.00 .04
E 4.04 .04
E 4.09 .05
3978.93 3974.8
4078.96 4074.8
4178.98 4174.8
4278.99 4274.8
4379.00 4374.8
0 3900.00 26.50 N 64.76
0 4000.00 25.75 N 62.69
0 4100.00 24.92 N 61.07
0 4200.00 24.40 N 59.28
0 4300.00 23.72 N 58.17
4.13 .04
4.16 .03
4.17 .02
4.19 .02
4.20 .01
4479.01 4474.8
4579.02 4574.8
4679.02 4674.8
4779.02 4774.8
4879.03 4874.8
0 4400.00 23.05 N 59.09
0 4500.00 22.38 N 60.14
0 4600.00 22.05 N 60.82
0 4700.00 21.63 N 61.43
0 4800.00 20.80 N 62.25
4.21 .01
4.22 .01
4.22 .00
4.23 .00
4.23 .01
4979.04 4974.8
5079.14 5074.8
5179.55 5174.8
5280.25 5274.8
5381.49 5374.8
0 4900.00 20.47 N 62.97
0 5000.00 17.93 N 59.97
0 5100.00 13.44 N 52.22
0 5200.00 7.84 N 41.84
0 5300.00 1.24 N 27.58
4.24 .01
4.34 .10
4.75 .41
5.45 .71
6.69 1.24
5483.23 5474.8
5585.77 5574.8
5689.49 5674.8
5794.86 5774.8
5901.91 5874.8
5400.00
5500.00
5600.00
5700.00
5800.00
5.12 S 9.99
11.79 S 11.60
19.60 S 37.96
29.53 S 69.61
39.33 S 106.51
E
W
W
W
W
8.43 1.74
10.97 2.54
14 . 69 3 . 72
20.06 5.37
27.11 7.05
6010.86 5974.8
6121.74 6074.8
6234.15 6174.8
6346.38 6274.8
6459.72 6374.8
5900.00
6000.00
6100.00
6200.00
6300.00
47.92 S 148.84
58.14 S 195.62
69.15 S 245.75
79.99 S 295.52
92.02 S 347.48
36.06 8.95
46.94 10.89
59.35 12.41
71.58 12.23
84.92 13.34
6574.01 6474.8
6687.90 6574.8
6802.51 6674.8
6917.39 6774.8
7031.44 6874.8
6400.00
6500.00
6600.00
6700.00
6800.00
105.11 S 401.25
117.29 S 454.37
129.50 S 509.02
142.14 S 564.11
156.12 S 617.14
99.21 14.29
113.10 13.89
127.71 14.61
142.59 14.87
156.65 14.06
SP~ ~.Y-SUN DRILLING SERVICES
._~ ANCHORAGE ALASKA
PAGE 9
BP EXPLORATION, INC.
PBU [ H- 34
500292280300
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 100397
JOB NUMBER: AK-MW-70272
KELLY BUSHING ELEV. = 74.80 FT.
OPERATOR: BP EXPLORATION, INC.
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
7145.96 6974.80 6900.00 170.73 S 670.98 W 171.16 14.51
7259.08 7074.80 7000.00 184.74 S 721.96 W 184.28 13.13
7373.07 7174.80 7100.00 199.40 S 774.65 W 198.27 13.98
7488.36 7274.80 7200.00 214.05 S 830.11 W 213.56 15.29
7603.16 7374.80 7300.00 228.75 S 884.53 W 228.36 14.81
7718.64 7474.80 7400.00 244.07 S 940.22 W 243.84 15.48
7833.56 7574.80 7500.00 259.07 S 994.82 W 258.76 14.92
7947.55 7674.80 7600.00 274.39 S 1047.33 W 272.75 13.99
8063.17 7774.80 7700.00 289.97 S 1103.23 W 288.37 15.62
8178.63 7874.80 7800.00 305.22 S 1158.90 W 303.83 15.46
8293.21 7974.80 7900.00 320.20 S 1212.78 W 318.41 14.58
8406.00 8074.80 8000.00 334.79 S 1262.84 W 331.20 12.79
8520.50 8174.80 8100.00 350.49 S 1316.34 W 345.70 14.50
8636.62 8274.80 8200.00 366.71 S 1373.08 W 361.82 16.13
8757.80 8374.80 8300.00 382.80 S 1439.42 W 383.00 21.18
8889.00 8474.80 8400.00 379.47 S 1523.79 W 414.20 31.20
9026.48 8574.80 8500.00 354.71 S 1614.70 W 451.68 37.48
9174.49 8674.80 8600.00 315.40 S 1716.24 W 499.69 48.01
9412.14 8774.80 8700.00 232.17 S 1912.31 W 637.34 137.65
10342.16 8874.80 8800.00 212.56 N 2716.50 W 1467.36 830.03
10544.04 8974.80 8900.00 332.73 N 2842.80 W 1569.24 101.87
10670.33 9074.80 9000.00 385.04 N 2897.81 W 1595.53 26.29
10710.00 9110.75 9035.95 396.59 N 2909.96 W 1599.25 3.72
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
0 I:11 I__1--11M G S I::: FIL/I C E S
WELL LOG TRANSMITTAL
To: State of Alaska October 29, 1997
Alaska Oil and Gas Conservation Comm.
Attn.' Lori Taylor
3001 Porcupine Drive (~D7f
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs H-34, AK-MW-70272
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a
signed copy of this of this transmittal letter to the attention of.'
Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518
H-34: q
2" x 5" MD Resistivity & Gamma Ray Logs:
50-029-22803-00
2"x 5" TVD Resistivity & Gamma Ray Logs:
50-029-22803-00
1 Blueline
1 Rev Folded Sepia
1 Blueline
1 Rev Folded Sepia
OCT ,50 1997
,~:~C~sr' ~.,~,, . · .
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
OIR I I--/I I~ G
WELL LOG TRANSMITFAL
To: State of Alaska October 22, 1997
Alaska Oil and Gas Conservation Comm.
Attn.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
RE: MWD Formation Evaluation Logs H-34, AK-MW-70272
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a
signed copy of this transmittal letter to the attention of.'
Tun Gal~ Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518
1 LDWG formatted Disc with verification listing.
API#: 50-029-22803-00.
ECE!V iJ o
OCT 2
Oil & Gas C~.
5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252
A Dresser Industries, Inc. Company
TONY KNOWLE$, GJOVEFINOFt
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
September I 1. 1997
Dan Stoltz
Senior Drilling Engineer
BP Exploration ('Alaska.) Inc.
POBox 196612
Anchorage. AK 99519-6612
Re:
Prudhoe Bav Unit H-34
BP Exploration (Alaska) Inc.
Permit No: 97-I 64
Sur. Loc.: 3224'NSL. 1265'WEL. Sec. 21. T1 IN. RI3E. UM
Btmhole Loc: 3507'NSL. 4097'WEL. Sec. 21. T11N. R13E. UM
Dear Stoitz:
Enclosed is the approved application for permit to drill the above referenced ,,',,ell.
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.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hoursl of the BOPE test pertbrmed before drilling below the
surface casing shoe must be given so that a representative of the Commission may xvitness the
test. Notice may be given by contacting the Commission petroleum field inspector on the North
David W. ~on
Chairman
BY ORDER OF THE COMMISSION
dlt' enclosures
cc: Department or' Fish & Game. Habitat Section x~,o encl.
Department ot' gnvinornment Conservation xv:o encl.
STATE OF ALASKA
ALASKA'~,-~L AND GAS CONSERVATION CON,wIISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] Deepenl [] Service [] Development Gas []Single Zone [] Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan 74.97' Prudhoe Bay Field / Prudhoe
3. Address 6. Property Designation Bay Pool
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028284
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
3224' NSL, 1265' WEL, SEC. 21, T11N, R13E, UM Prudhoe Bay Unit
At top of productive interval 8. Well Number Number 2S100302630-277
2991' NSL, 3256' WEL, SEC. 21, T11N, R13E, UM H-34
At total depth 9. Approximate spud date Amount $200,000.00
3507' NSL, 4097' WEL, SEC. 21, T11N, R13E, UM 09/16/97
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 028283, 1183'I No Close Approach 2560 10565' MD / 8975' TVD ss
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 700' MD Maximum Hole Angle 86° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
30" 20" 94# H-40 Weld 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.)
12-1/4" 9-5/8" 40# L-80 BTC 3550' 29' 29' 3579' 3500' 1700 sx Coldset, 440 sx Class 'G'
8-1/2" 7" 26# L-80 BTC-Mod 9157' 28' 28' 9185' 8605' 170 sx Class 'G'
6" 4-1/2" 12.6# L-80 BTC-Mod 1530' 9035' 8517' 10565' 8975' 170 sx Class 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: truemeasuredvertical feetfeet Plugs (measured)
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented MD TVD
Structural
Conductor
Surface
Intermediate
Production .~, E~ '~' ! V ~~
Liner
AUG 997
Perforation depth: measured ~ ~ ~ ~$ .~.0Q$,. ~_¢~
true vertical "'--"'~ ~~
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Winton Aubert, 564-4825 Prepared By Name/Number: Torrid Hubble, 564-4628
21.1 hereby certify that~e~for~~e ~d correct to the best of my knowledge
Signed/ / --,--~"~-~ '~-
DanStoltz V J~'"~ /~'/~/~,//' Title Senior Drillin~l Engineer Date
Commission Use Only
Permit Number APl Number I Approval Date See cover letter
?,~-,,,/~ ~,/ 50- O ~. ~ -' ~--- ~ ~,.~, ~/-' / /" ¢'~' for other requirements
Conditions of Approval: Samples Required []Yes [] No Mud Log Required []Yes [~ No
Hydrogen Sulfide Measures [~]Yes [] No Directional Survey Required ~Yesr-INo
Required Working Pressure for DOPE I-I2M; 1-13M; []5M; [] 10M; [] 15M
Other:
Original Signed By by order of
Approved By David W. Johnston Commissioner the commission Date
Form 10-401 Rev. 12-01-85 Submit In Triplicate
I Well Name:
]H-34
Type of Well:
HAW Well Plan Summary
[Pre-Produced Injector
Surface Location:
Start Target:
BHL Target:
3224' FSL, 1265' FEL, S21, Ti IN, R13E, UM
2991' FSL, 3256' FEL, S21, TI IN, R13E, UM
3507' FSL, 4097' FEL, S21, TI IN, R13E, UM
I Estimated Start Date:
[Well Design:
1 9/16/97 I
[Rig: I Nabors 2ES
[Operating days to complete: 127
I TVD: 18975'ss I
[KB Elev. 174.97'
IHAW
Objective:
Well H-A (H-34) is an S-shaped pre-produced Ivishak water and MI injection well on the northeast
flank of the keystone graben. This well is proposed as a new well due to the lack of nearby well
available for sidetracking. Injection support is necessary because the keystone graben forms an
effective barrier to fluid movement from south to north in the H Pad waterflood area. Injection into H-
34 will support current updip producing wells H-24, H-11, H-33 and future sidetrack H-1 lA. Before
converting H-34 to injection, the proposal is to pre-produce it for approximately one year. Based on
the predicted oil column, 500Mstb should be produced within one year, yielding signifi.cant accelera-
tion benefits. Precise timing of the H-34 conversion will be decided following the first 3-6 months of
production.
Formation Markers
Formation Tops MD TVD (ss)
Sag River 9176' 8600'
Shublik 9228' 8630'
TSAD 9431' 8710'
TD 10,565' 8975'
Cement Calculations
Lead Cement Tail Cement
Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments
Cold Set Lead to surface (350% excess through
9-5/8" 1700 / 12.2 / 1.92 440 / 15.8 / 1.15permafrost, 100% excess to TD); Class G Tail;
Pump time-4+ hr.; TOC -- Surface
CI G; Tail FW=0;
7" N/A 170 / 15.8 / 1.1430% excess; Pump time-4+ hr.;
TOC = _+8150' MD (_+1,000' above Sag River)
4-1/2" N/A 170 / 15.7 / 1.19Class G: 30% excess; Pump time = 4 hr.;
TOC 150' above TOL ..... , -?, ~ ~
Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as desi~l~l~ ~, ~ ¥ ~
__
Casing/Tubing Program
Hole Size Tubular Wt/Ft Grade Conn Length Top Btm
O.D. MD/TVD MD/TVD
30" 20" 94# H-40 Weld 80' 30'/30' 110'/110'
12-~/4" I 9-5/8" I 40#l L-80 I BTC 1355o'1 29'/29' 13579'/3500'
~-~/2" I 7" I 2~# I L-~o I BTC-MOD I 9157' I 28'/28' 19185'/8605'
~" I 4-1/2" 112.6#I L-80 I BTC-MOD I ~530' 19035'/8517'110565'/8975'
NA I 4-1/2" 12.6# L-80 BTC-MOD 9009' 26'/26' 9035'/8517'
Logging Program
Open Hole Logs:
12-1/4" Hole
8-1/2" Hole
6" Hole
Cased Hole Logs:
MWD/GR
MWD/GR
MWD/GR/Resistivity
CBL
I KOP:
Directional
1700' MD I
IMaximum Hole Angle:
Rig Move Close Approach Wells:
]Drilling Close Approach Wells:
86° through targets
H-09 and H-37/L1 are approx. 55' away
None
Mud Program
Surface (12-1/4" hole) Section: Spud Mud I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
Initial 9.6 _+ 300 35-50 25-45 50-80 9-10 15-20
Final 9.8 300 20-40 15-30 30-50 9-10 15-20
Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning.
IIntermediate (8-1/2" hole)Section: Gel-free 6% KCl Biizan [I I
Density, ppg I Funnel Vis, sec LSR YP Gels pH HPHT FL, cc
10.0 I 50 - 65 8 - 13 15-25 / 20-35 9 - 10 <10
Hazards/Concerns Potential high torque could require lubricant use.
Be alert for lost circulation, differential sticking due to higher MW.
Production (6" hole) Sections: Quickdriln (viscosified SW)
Density, ppg I FunnelVis, sec LSRYP I
8.6 - 8.8 55 - 65 14 - 20
LSR Vis pH I APl FL, cc
> 45,000 8.5- 9.0 I NC
Hazards/Concerns
Potential high torque could require lubricant use.
Be alert for lost circulation, differential sticking due to overbalanced MW.
Maximize solids control to keep fluid as clean as possible.
Max mud weight 8.8 ppg.
Well Control
Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre-
venter will be installed and is capable of handling maximum potential surface pressures. Di-
verter, BOPE and mud fluid system schematics on file with AOGCC.
Hazards
· H-Pad is a known shallow hydrocarbon area.
· Stuck pipe, tight hole, and swabbing have occurred in H-Pad wells through Kingak shale.
· Lost circulation through conductive faults is a possibility on H-Pad.
No annular injection is planned for H-34.
Operations Summary
,
,
,
,
Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring.
Secure rig move close approach wells. MIRU Nabors 2ES. NU and function test di-
verter.
Drill 12-1/4" hole to _+3579' MD (_+3500' TVD) per directional plan. Hold diverter drill while
drilling surface hole.
Run and cement 9-5/8", 40#, L-80 casing to TD.
5. Test 9-5/8" casing to 3,000 psi for 30 minutes. Drill shoe joint and 20' of new formation.
Perform and record LOT.
6. Drill 8-1/2" hole directionally to 9185' MD (8605' TVD).
7. Run and cement 7" liner to TD.
8. Drill 6" horizontal lateral per directional plan.
9. Run and cement 4-1/2" solid liner.
10.
11.
12.
13.
Log well with CBL.
Perforate 4-1/2" solid liner with DPC guns.
Run 4-1/2" L-80 completion. Have AOGCC representative witness annulus test.
Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO.
: '
· ..
Alaska D£a~rict
.~!££ Za's~ ~Oth Avenue
'Anchorage).AK 9~5i.8
(90?) 349-4Sll Pax
DZRECTIONAB WH~L'IPLJ%Iq 'For 'S}~RED SHR¥!C~S DRILLING
NeLl .........
Field ........ : Prudh°e Bay, H-Pad
Cotlrputatio~..~ Min£mum Curvature
Un£~s ........ : PBHT
'Surface Lat..: 70.29475022 N
Surface Lon9.: 148,83933902
Legal Descr~pC~on
Surface ...... : 3224 FSB 1264 FE~ S21 T11N R13B UM
Target S~art,: 2991 ~SL 3256 FE~ ~21 Tl1~ R13H U~
Target D~op..: 3309 FSL 3824 ~ .$21 Tl~NR13~ ~'
B~ / TG~ End: 3507 PSL 4097 ~ S2~ TL.~N R13H ~
__
IX)CATIONS - ALASKA Zone: ..4
X-Coord ¥-Coord
643340.69. 5958732.67
64£355.00 5958462.50
640980.00 5958770,00
', .
640503.00 5'95896~.50
STATION
IDENT£~ICAT~ 0N
..
mmmm~mw~ ms mm m ~
MHASUR~D ~N~ D~cTION
DBPTH ANGLE AZIMUTH
0.00 0.00 0.00
qO0.O0 0.00 65.00
800.00 k~50 65.00
900.00 3.00 65.00
1000.00 4,50 65.00
PROPOSED
~m~m~{~smmmmmm m~m~s=m
VHRTICAL-DEPTHS SRC~ION
TVD BUB-S~A DB~ART
0.00 -74.9~ 0.00
700~00 625.03 -0.00
799.99 725.02 -1,13
~99.91 824,94 -4.50
999.6~ .924..72
PrePared ..... : 02 Jun 1997
V~rt sect az.: 275.72
KB elev&t£on.= 74.97 Et
Ma~e~lc Dcln: +28.~41
Scale Factor,: 0.99992334
Conversence.,, +£.09270930
ANADRILL AKA-DPC
,FEASIBILITY PLAN
NOT APPROVED FOP,
X£CUTION
PLAN
'. .
..... __ ........ -- ........... ~_-_ -,',?:-_ _
m~mmmmmmmmmmmm mm= m ~mmm mm mmmm m mmmm ~mm mmm
mm :~ m m m mm m mm '
OOORDKNATSS-FROM
W~.~HAD
m m mm mmmmm mmmm m m=mmm ~m m mmmmm
O,O0 1~ 0.00 Il
0.00 19 0.00 Il
0,55 N L.19 ~
2.21 N 4.~4 H
4.98 N L0.67 Il
ALASKA Zone 4
Y
643340.69 5955732.a?
643340.69 5958732.67
6%334£.87 5958733.45
643345.39 5958735.17
643351.26 5958738.05
mmm~
TO0~ DL/
PAC~ 100
65R 0.00
65R 0.00
65R .1,50
65R 1,50
65R ~.50
.1100,00 6.00
1200.00 7.50
1250.00 8.25
t25[,00 ., 0;,25 ,.-
1300.00 7.'50 .....
1400.00 6.00
65,00 1099.27 1024.30
65.00 1198.67 1123,60
65,00 12~8.,10 1173,~3
'~5'2~0..~ ~,24,8.~0
65,00 1396.93 132L296
-17.99
-28.09
-33.98
'-.39.87
8.84 N L8.96
16,71 N 35.83
~. ~o ~ 4~:. 0~
-49.98 24.59 N 52,69
643359.48 5950742,07 H9 t.50
643370.04 5958747,24 HS 1,50
643376.19 59587S0.~5 LB 1,50
~43376.19 59587~ 25 ~ ,L.50
~:~3382.34 59587~?.2~' LS :L,SO
643392.89 5958758,%4 LS 1,50
(Anadrtll (c) 97 :.L14P5 3,0C 0:30.AM P)
r-
-o
02 JUn 1997. Da~e 2
STAT/ON
ID~N~TIFICATION
END 1.S/LO0 DROg
NHASURED
m~mnmm~n
LS00.00
1600.00
3700.00
3800.00
1858.77
AN(~LE
4 ,$0
3.00 '
'L.50
0.00
0.00
~ROPO~SD WE~L VRO~IL8
m mm
'DIREcT[oN V~RT£CAL-DgPTRg
65.00 1496.$1 [421.54
65.00 ~596.29 152~.32
.
65.00 £696.2~ ]621.~4
65.00 1996.~0 ~721.23
65.00
· .
SHCTI0~
D~ DA~
~ .84
-63.46
-66
~67
~m m m Am m {m mmmm~{ mmmmm ! mmm~
m mmmmm mm . ~ mm m m m m
.,.
28.43 N 60.98
3L.20 N 66.91
32.86 N
33..41 N
33.41 N
mmnm {mum
RId~Srd~ Zone 4-
X Y FACE 100
64~401,LL ~958762~46 ~R 1.~0
643406.98 5958765,34 6~ l.S0
~0.46 E 6434£0,5~ 5958~67.06 65R £.S0
71.65 E 6434L1.68 5958767.64 }{S [.50
7L·,65 ~ 6434~3.68 S958767.64 ~S 0,00
100~ CURV~ 2.5/100
3578.77
5000.00
5100.00
S2OO.O0
5300.00
O. 00
0.00
2.50
5
7.50
65.00 3574.97 3500,00 :67.96 33.'4L N 7L.65
0.00 4996,20 492L.23 ,67.96 33.4~ N ?1,65
254.66 5096.~7 S02L.20 -65.93 32.~4 N 69.54
254.86 5195.95 5[20.98 -59.81 31:L3 N 63.23
254,86 S295.35 5220.38 -49~64 28,29 N 52.~2
643411.68 6958V67.64 HS' 0.00
643411,68 S~58q6q.64 lOSb 0.00
6434Q9.59 595876?.03 LOSL 2.50
643403.3£ 5958765.20 I%5 2.50
645392.86 5958762.~6 RS 2.50
.5500.00
5600.00
5700.00
5800.00
L0.00
12.50
15.00
27.50
20.00
254,0.6
254,86
254.86
· .
254.86
254.86
5394.i8 5319.21 -35.43
5492.25 54~?.28 -17.20
5589.37 5534.40' S.01
5685,37 '5610.40 3i. L6
$?80.06 5705!09 61.L9
24-32
L9.22
5~70.N
2.69
38.04 E
3.73 W
30.74 W
6L.77 tt
643318'.26 5958q$9.91 ~8 2.50
64'3359.53 5958~52.45 RS 2.50
643336~1 5958945,8L HS 2.50
643.309.85 S958~37.99 HS 2.50
643'278.99 5958729.00 HS 2.50
HND 2,5/300 CURVH
5900.00
6000.00
6~0o.oo
6L67.02
22.50
25,.00
· 27.50
2~.[0
29.~8
254'.86
254,86
254,86
254.86
CURVE 6/300
8656.42 29:L8 254.86
8700.00
·
sSoo,oo
8900.00'
9000.00
, ,
,
. ,
~1'15.55 54.23"
918~.35 , 54.69 ,
,,
30.92 258.T5
35.30 266.28
(0.05 272.29
· ;/~.'2.3'~, ~ 281.2~ ,
.
'284.00.
2S4.29 ,
5873.25
5964.V?,
6054.45
6113,4~
6113.44
5798.28 95.05
5889.80 132.69
5979.48 174.01
6038.46 ' 203.93
6038.47 203.74
0287.03 82L2.~4 L337 ;7'4
83'24.74' 8249.77 L358.37
8408.53 8333.54 L4~1.S0
8487.67 '84L2~70 .~:L472.L7
856L.33 8486,36 /539,~2
. ',
aG~a.70,,~ess~ 73.* rs~3
8674.9? 86~.00 .L672,67'
8679.97
12.16
22.68.
34,23
42.54
42.54
,
96.75
135.62
·
lq8,31
209,01
2o9.o~
359,53 $ 138'0.43
.,
364.49 s ~40~.67
,
,
37L'97 8 ' t516.~9
' , ·
366.25'S, L584.;10
8605.0
, . ,
643244.20 5950718.87
641205.54 5958707.61 HS
6431.63.08 5958695,.25
643132.~4 5958686.36 H$
643332.5~ 5958686.36
,
64L967.47 5958347.1L
641946.33 5958341.75
643892.{0 5958333.82
64~83£.39 5958332.0?
6{1763.99 6958336.S0
,*
6{Z632.~3 595835~.09
2 .SO
2 .S0
2,S0
2.50
50R 0.00
,46R 6.00
4OR 6.00
3SR 6.00
32R 6.00
29R 6:.,.:.00
2'?~ 6.00
ANADR:ILL AKA-DPC
FEASIBILITY, PLAN
'NOT APPROVED FOR
,'EXECUTION'
'DI ~kl ~ .___ _~,,,.
Z
'O
6')
rtl
,.
STATION
'l DH N?I PICAT I ON
~ 6/100
Cu R'v"li 32/la0
'TOP ~]HUBLIK
R~A.~rJJ~D: X NCI.,N
· .
,
9L84.64 54.72
9227.53 55.65
9300.00 63.47 .
9400.00 ?4.45
8699.97 8625.0~ 1707.54
284,59 8~04.9~ 8630.00 1714.64
289.31 5741.67 8666.70 1775,81
294.52 67~7.54 8702.57 1865.21
TOp SADLB~DC~IT 9431.05 77.88 . 296.01 "'9784.97 6710.00
9500,00 85.53 .299.20 8994.9l 871~.94
END ~2/100 CURVE 9500.76 8~'62 ~99.23 8794.9~ 8~20.00
TARG]~T ST2tRT *k~*~* 9500.76 85.62 299.23 8794~97 6720.00
DROp ~3.45/~00 10154.78 85,62 299.23 8844.97' 6~70.00
· , .
1893,62
1956,87
1957,56
1957,56
2555;54
.02 Jun 1997. ' gage 3
,.,
O00]~D£NAT~S-pROM ALASKA Zone ~
' ' WHh~<W'AD . X Y
339.17 S 1722.38 N 641625.22 595836~.75
332.48 S L749,38 ~ 641596.L0 5958367.L2
330,67 ~ 1756.34 W 641591,~1 5958368,~9
312,22 8 1815.96 ~ 641531,16 5958386,10
277.3~ 8 1902.32 ~ 64L444.15 9958419.36
264,4~ 8 1929,58 W 641436,65 5955431:70 23R 12,00
232,84 g 1989.98 W 641355,67 5958462,t4 22R 12,00
232,47 8 1990,64 W 641355,00 5958462.50 H9 12,00
232,47 '8 1990,64 W 641355.00 5958462.5Q H9 t2.00
85,96 ~ 2559.7L N 640780.00 5958770,00 368R 0.00
TARGET DROP PO~iNT
,TOP 7..ONE 3
101~4.78 85.62
'.10200.~0 79167
10300.00 66.55
10400.00 53;51
10455;.00-
'/X)P 2~:)NE 2C
TOP HO'~
4-~/~- ~ ~11~
u~ ~.~/~oo ~o~
10500.00 40,65
10534,97 36.23
10947,25 34,69
10565.25 32,46
10565.25 32.46'
~ARGRT END ~****'i** 10565.25 32.46.
'I'D 10565~25 32.46
8:30 A~
299:23
300.55
303170
307.56
310.26
312,99
315.50
316,64
318,33
318,33
318 -33
33:8.33
8844.97 eT~o.oo
ees0~76 8778.7·9
8879.7S 8804.78
6~29.60 8854.'63
8964.97 8890.00
8997.59 8922.61
9024.97 0950.00
9034.97 8960,00
9049,97 8975.00
9049.97 8975.00
9049.97 8975,00
9049.93 8975.00
2555,54
2596,43
2681,98
..
2756.90
2?92.22
28~7[33
2834.33
2839,~6
204771'9
2847.19
2847.19
2847.19
85.96 N 2559.7L W 640780.00 5958770.00 168R 0.00
1'08,30 ~ 2598.58 W 640740',~2 5958793.59 167R 33.46
L58.'98 N 2679,47 ~ 640659,88 5958840,72 167R 13,46
209,17 N 2749,83 U 640587,59 ~958889,55 165~ 13.46
235.56 N 278~,60 H 640554,32 5958915,3~ tg3R 13,46
256,10 N 2805,78 W 640530,76 5958935,40 /61R 13.46
271,26 ~ 282L,35 W 640514,90 5958950.26 159R L3.46
276.39 N 2826.28 W 640509.87 5958955,30 1586 L3,46
283.73 N 2633.01 W 640603.00 5958962,50 13,46
263.73 ~ 2833.0l W 640503.00 5958962.50 33.46
283.73 N 2833.0L ~ 640503,00 5958962,50 13.46
283.73 N 2633.01 ~ 640503.00 5958962,S0 13',46
ANADRILL AKA-DPC
FEASIBILITY 'PLAN
NOT APPROVED FOR
'EXECUTION
PLAN #
Z
'SHARED SERVIC 'S DRILLING .... ..-- i
,,., - . H-34 (PS):
VERTICAL SECTION VIEW
600 ....
~-- Section al.: 275.72
TVD Scale ' ~ ~nch -- ~.200 feet
~2o~ ........ Dep Scale.' J inch = ~.200 feet
D '' Drawn · 02 dun ~.997
·
:
I
moo- :-. ,.~ - ---~.- : '- ...... ~ '~',~w~r - r~ - Anadr.~ ] ] ~cfl ~ um[J~ ge~-~ '--~-P - -r
Harker. Zdentif~cat~on - MD BKB ~¢TN ~NCI.N
2400 · ·
-. -'A] KB 0 0 '0. 0.00
- B] NUD6E 8UILO 1,5/100 700- 700 -0 0.00
.. - CJ END 1-5/100 .BUILD 1250 ~248' -34 8.25
3000 .... D) START' 1.5/100 DROP t250 I248'.; -34 8.25
E) END t.5/t00 DROP 1800 1795 -68 0,00
-.' F) 9-5/8' CSG PT <11>.' 3579' 3575 ,61] 0.00
~ -
V 3600 ~ ir _ :. ,-.;. .G). KOP CURVE: 2.5/~00 5000 499&" -68 0.00
" . -.-- H) :END:2,5/t~O0 CURVE 6t67 BtI;3;~.~ -204 2.9,18
I).OJRVE_~6/IO0 .8656 8287,~ 1338 29.t8
B '.. . .. ~) 7'-' CS$ PT <11> 9184 8680 J680 54.69
- Y,) END 6/;~00 CURVE 9185 8680 ;1680]: . 54.72" .
4200 ': " ~" ' L) CUF~E ~2/~00 · '9219' 8700 1708 64.72
.
H) END t2/100 CURVE 950t 8795 1958 85.62
" · -'· ' .N} TARGET START ~*~, 9501 . R795 lq58 '85,E2
.48,00'. .. ' ' . .~ ,. . 0). DROP ~3.45/100 -~015§ - 8845 2556 85.62 -
.
·
- "' G' . ." ' " P) TARGET D~OP POINT *~ 10155 8845 .2556. -85.62
'~ ' ' . ' ~ Q).4.-t/2" LI~ PT'<II> t0565 9050. 2847' 32,46
'" " _... ' R) .END ~3,45/100 DROP ~0565. 9050 2847'-:.. 32,46 -.
- 5400 . ' -'I ' · '.': .-' ' - ,.~ '~' ' " -S] TARGET ENO ~*~*~' ~0565' .9050" ;~847 "32.45 -"
::' ' :'" 'Ti 'TO. ~0565' -9050 2847--' 32.46
..
·
. . ..
.
6000 ' - ·
.... .."' '~ '.' .. 'AN,~,DRiLL - . AKA.~p.~
-.--- ", -' :EAS iB/L TM I,>LAF'J-
6600- " " ..... . : '
.... '-"' . \ · . : -'--~ ' ~-- .... _ NOT i~,PPF.OvE D FC)R''
·.. ., · .... . . ..... .. :- __E:4ECtJTId)N :. .....--
., ,~oo ..... . ....... .:.. .pL/~,N.~L ~.-.
""-- ' · .-~.':,---.... '__S'¢-.-&~2_ _ '~ ~ ---'
: .
; : .' %- ' ".~ -,,~.m..m~. mmmmm.mmmm...
:: 7800' . .. .. ' ....... ' -" .':
·
....84oo I · - ' .
., .. . ¢,~ .........
~ooo' ~.,~ ~: ...... :. - ' ...... --
~¢o ......
10200 -"
0 600 :~200 :1800 2,400 3000 3600 4;~00 4800 5400 6000 6600 7200 7800
Section Oep,a,rt, ur,,e,, ..
_ _ _
ii i ' " i i iii i i ....... , ~ ...... i i iii ·
,. H-34
· .. VERTICAL SECTION VIEW
.,'.' ,. SectiOn at: 275.72
:~ I ']' ' ' ........ ""iiTVD'Scale': ..'] inch : 200 feet
_ IoeP Scale,: 1 inch : 200 feet'
_ .. . ,,,,, ,.,,,,.. iora~n'..; .'.: 12 Jun ~997
.
~ ,~ ~ A %mm~'X/~r.;~ C~l) " Narker Identification ffi ~8 SECTN INet
' ~ . I~ I ~ - r ~ Y ~ t ~ ~x Al CURVE 6/100 8~ 8~7 1338 29.
~ A ~'1 ~ ~.,.; C) END6/IO0 CURVE 9185 8~0 t~O 54.1
~~ ~. ~ ,~~ ~ O) CURVE. 12/tO0 9219 8700 1708 54.'
5 ·
· -- ~,- ' - - - ~' 'El END t2/100 CURVE 950~ '8795 t~8 85.1
. ' ........ '~ ..' FI'TA~ET SIART ~x~xx 950t 8795 1~8 85.1
.. ,Gl DR~.13.45/t00 tOt~ 6845 '2556 85.t
' ' .. ' H] TA~ET.DROP POINT x~ lOi~ 8B45 2556 85.t
., ' ' " I). 4-1/2" LNfl PT <l I> 105~ 90~. 2847 32.,
'.. dl END 13.451t00 ~OP 105~ 90~ ~7 38.,
. .~} llg~[l. [~ ~~ 105~5 .0050 ~7
- ~~. :." ',., ." ' '.' .' ....'~..'. . . . . ..' ., .U.. 1~, .... . : .', ~05~ ~0~.,, ~7.,. 3~,.
~ . .
~ . ..... .. ~. ..
~~ - 3~ ................ ~ .........
,
' 'E ,. ' . ~ ~~arget Drip (Point)
', , , ,& . .
.
.
. . . . .
· q~37~:: ,~ ....... ~. . :' . ,...,,. .. ::::' ,: : ,,"::: , :::::,.
.. . : "
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. . : . . . ., . . .
. . . ~ . . : .
. .
.
;. . .
. . . . ~ .
. .. .
.
.
.
.
.
..
............ ' ......... .~,nn ~nn. ~ann ~ann ~nn 'gAd~ PTBfl PAOO 2~00 300(
~8
72
62
46
46
46
46
1200 !300 t400 t500 1600 1700 tBO0 ~900 . 2000. '2t00 2
Section De :ute
. ,
Cloadri]l (c)97 H34P5 3.0C 8:48 AH P) ,, ..
..,
-B
m
SHARED
!
SER'VICES ' DR.iLLiN6·
· · iii ii i i ii
i
~nadril] Scb]umbe¢ge¢
H-34 .(PS)
PLAN
VIEW
.... . ,
CLOSURE .... · 2847 feet at /~zi~uth'~75.72
' ',' ~ .... I ~ .... ' 1 IDECLiNAT]ON.-: +28.341 iE)
· ISCALE .... '....: ! inch'= 400 feet
~._ 'IDRA~N ....... : 02 Jun ~997
) · ~,NADI,~ILL i_A CA-DPt: Napier Identification ND ~S E/~
XB '. 0 ' 0N 0E
FEJ~S! B L I~ K PL ~N ~J~E BBILD i.5/i00 '700 .ON 0E
,. NO" APPRO' VEDFOR c) E~ 1,5/~00 BUILD1250 i7 N
EXE CU1 ION ~/?oo D~,
CS6 P1 41> ~79 .33 N 7~ E
· ' · . 'E~ 2,5/~00 C~VE
' LI .C~VE.12/J00
J ,,,
..... ' ~) 4-~/2" LNR PI <11>,
' , . R). E~ ~3,45/300 8ROP ~0~5. "284 N 2833~
~ ', ~ . . '
,.
3~00 3000 ~800 2BO0 ~400 2200 2000 tSO0 lBO0' ..1400 l~O0, ~0~0 aO0. BOO 400 200 ~ 200 400
<- ~EST ' EASI ->
lc)CJi I.i34P5 3.0C 1~47 N4 P)
o,
i
z
I Well Name:
IH-34
I TYpe of Well:
HAW Well Plan Summary
I Pre-Produced Injector I
Surface Location:
Start Target:
BHL Target:
3224' FSL, 1265' FEL, S21, Ti IN, R13E, UM
2991' FSL, 3256' FEL, S21, TI IN, R13E, UM
3507' FSL, 4097' FEL, S21, T1 iN, R13E, UM
]Estimated Start Date:
iUD: 1~0,565' I
I Well Design:
{Rig: I Nabors 2ES
19/x6/97 I [Operating days to complete: 127
I TVD: 18975'ss I I KBElev. 174.97'
I HAW
Objective:
Well H-A (H-34) is an S-shaped pre-produced Ivishak water and MI injection well on the northeast
flank of the keystone graben. This well is proposed as a new well due to the lack of nearby well
available for sidetracking. Injection support is necessary because the keystone graben forms an
effective barrier to fluid movement from south to north in the H Pad waterflood area. Injection into H-
34 will support current updip producing wells H-24, H-11, H-33 and future sidetrack H-1 lA. Before
converting H-34 to injection, the proposal is to pre-produce it for approximately one year. Based on
the predicted oil column, 500Mstb should be produced within one year, yielding significant accelera-
tion benefits. Precise timing of the H-34 conversion will be decided following the first 3-6 months of
production.
Formation Markers
Formation Tops
Sag River
Shublik
MD
9178'
9228'
TSAD 9431'
TD 10,565'
TVD (ss)
8600'
8630'
.AUG 2G 1997
Cement
"' ' ' : ",.,a,cu,at,on~,/~ mJ ~.~ ~::
Lead Cement Tail Cement
Casing/Liner Sk / Wt / Yield Sk / Wt / Yield Comments ' ' ~ch0_rage
Cold Set Lead to surface (350% excess through
9-5/8" 1700 / 12.2 / 1.92 440 / 15.8 / 1.15permafrost, 100% excess to TD); Class G Tail;
Pump time=4+ hr.; TOC = Surface
CI G; Tail FW=0;
7" N/A 170 / 15.8 / 1.1430% excess; Pump time=4+ hr.;
TOC = +8150' MD (_+1,000' above Sag River)
4-1/2" N/A 170 / 15.7 / 1.19Class G: 30% excess; Pump time = 4 hr.;
TOC 150' above TOL
Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as designated. ' ....
Casing/Tubing Program
Hole Size Tubular Wt/Ft Grade Conn Length · Top Btm
O.D. MD/TVD MD/TVD
30" 20" 94# H-40 Weld 80' 30'/30' 110'/110'
12-1/4"I 9-5/8" 140#1 L-80 I BTC I 3550' I 29'/29' 13579'/3500'
~-~/2" I 7" I 26# I L-80 I BTC-MODI 9157' I 28'/28' 19185'/8605'
S" I 4-1/2" 1~2.6#1 L-80 I BTC-MOD ! 1530' 19035'/8517'110565'/8975'
Pr°ducti°n Tubing I I I I I
NA ] 4-1/2" 12.6# L-80 BTC-MOD 9009' 26726' 9035'/851 '7'
Logging Program
Open Hole Logs:
12-1/4" Hole
MWD/GR
8-1/2" Hole MWD/GR
6" Hole
Cased Hole Logs:
MWD/GR/Resistivity
CBL
Directional
I KOP: 170°' MD
IMaximum Hole Angle:
Rig Move Close Approach Wells:
Drilling Close Approach Wells:
I
86° through targets
H-09 and H-37/L1 are approx. 55' away
None
Mud Program
Surface (12-1/4" hole) Section: Spud Mud I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
Initial 9.6 +_. 300 35-50 25-45 50-80 9-10 15-20
Final 9.8 300 20-40 15-30 ~ 30-50 9-10 15-20
Hazards/Concerns Gravel beds, bridging, lost circulation. Frequent sweeps to aid hole cleaning.
Intermediate (8-1/2" hole) Section: Gel-free 6% KCI Biozan I
Density, ppg FunnelVis, sec I LSRYP I Gels I pH I HPHTFL,cc
10.0 50- 65 8- 13 15-25./20-35 9- 10 <10
Hazards/Concerns I Potential high torque could require lubricant use.
I
Be alert for lost circulation, differential sticking due to higher MW.
Production (6" hole) Sections: Quickdriln (viscosified SW) I
Density, ppg ! Funnel Vis, sec LSRYPI LSR Vis I pH APl FL, cc
8.6 - 8.8 I 55 - 65 14 - 20 > 45,000 8.5 - 9.0 NC
Hazards/Concerns Potential high torque could require lubricant use.
Be alert for lost circulation, differential sticking due to overbalanced MW.
Maximize solids control to keep fluid as clean as possible.
Max mud weight 8.8 ppg.
Well Control
Well control equipment consisting of 5000 psi w.p. pipe rams, blind rams, and annular pre-
venter will be installed and is capable of handling maximum potential surface pressures. DJ-
verter, BOPE and mud fluid system schematics on file with AOGCC.
Hazards
· H-Pad is a known shallow hydrocarbon area.
· Stuck pipe, tight hole, and swabbing have occurred in H-Pad wells through Kingak shale.
· Lost circulation through conductive faults is a possibility on H-Pad.
No annular injection is planned for H-34.
Operations Summary
1. Pre-rig: Set and cement 80' of 20" conductor. Install cellar ring.
2. Secure rig move close approach wells. MIRU Nabors 2ES.
verter.
.
i
1
NU and function test di-
Drill 12-1/4" hole to __.3579' MD (_+3500' TVD) per directional plan. Hold diverter drill while
drilling surface hole.
Run and cement 9-5/8", 40#, L-80 casing to TD.
Test 9-5/8" casing to 3,000 psi for 30 minutes. Drill shoe joint and 20' of new formation.
Perform and record LOT.
6. Drill 8-1/2" hole directionally to 9185' MD (8605' TVD).
7. Run and cement 7" liner to TD.
8. Drill 6" horizontal lateral per directional plan.
9. Run and cement 4-1/2" solid liner.
10.
11.
12.
13.
AUG 2G 1997
~0~ & 6as Cons.
Log well with CBL.
Perforate 4-1/2" solid liner with DPC guns.
Run 4-1/2" L-80 completion. Have AOGCC representative witness annulus test.
:..
Freeze protect well, set packer, set BPV, ND BOPE, NU and test tree, RDMO.
Computa~io~.,: Minimum Curvature
Un£~$ ........ : PERT
· Surface La~.,: 70.29~95022. N
Sturface ~ong.: 148.03933902~
STAT~0N
ID~NT£FICAT]0N
...'.! ' "a~adrLtl.. '~¢hl~3eX~e~. :..
"" , .". : ' ~,,k~' ~t.~¢t '"""' '
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· ' .'.' . ...~o~.,'.'~x ...~s~'d'.
'".: .:'.'.': .. '": . (90,! a4~L4S~l':: tax' 3i*-2t60 '
..
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, .; . . .: ..
,
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.
'' DIRge'IOlAb HR~ 'P~."for'~}~RgD G~Rv~s DRILLINO
... . ',..' ~ ~'... ..
' 'i '.' . ..
LOC. qTION$ - AI~q~l~ 'Zone.t ..'4 . '-- .. ,.
..
·
,.
· . . .'
Sub,ace ...... : 3224 ~Sb 1254 ~ 'S2i ~I[~.RilR UM' '643'340;.~9. S'95a732'.87
T~e~ D~..: 3309.P~' 382~ ~ '.S23. TZ~:R13K'~' .. ~4078.0'.00' 5~5'8~0,00
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1250.o0
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'65.00' '1099'.2T.'1024.30
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.., .', , , .
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·
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.'7.'50" .':?': 6~'-"00 ,:' 1~9"/,63. '1'22'-:.66., .... ,;39.87
.. ',** ....., ,,, ,' ,,, . ,, - ,: . , ,,:,, .,' . .,..:.'., ,
'¢.,00. 6.5200 ]32~.93 ~32£',9~' ' .... ;49.98
, ',.
.
, ,,
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b-"'~.~,~.T 1.;5/,n~,DRDp'
~400.00
.. .
(Anadrlli (c)97 R34~5 3,0C ~=30.AM 9)
Prepared. '..: 02 Jun'1997
V~t sect az.= 27S.72
l~...elevaC£on.~ 74..97 .gt .
;cale. P&cCor.~ 0;9999233~
.C0~v~rgenee .:,, ~L,09270930
ANADRILL AKA.DP.C:
.. .FEASIBIL!TY PLAN"
NOT.APPROVED FOR
EXECUTION '"
· ."
'O00RDINATBg-FRO~ ' A1d~lO~ zone..4
~/.~o ,' ' x
, ,
mmllllllmlllJlr film mill 'm l
m.. il I Il mllllSl Imm.uti. mm, imm
,o.o0
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0,55' N
;2.2:/
4.90
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. t.19 H ;433'4t.e? S958733.4~
4.V4 ~ 6~3345.39 ~958~35.17
.
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, ,
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'1~3,61 "N
t0.96 s 64335~.4a sgse?42',o? xa
29.62 S G433qO.04 $gse.?47,24 Ha
35.83.K 64337;;19 ~2sa~so.2s LB
'1~.~0 'H '" ~2:,~3',I ~ ~:~3382...34 S9587~.'. 2~.~ ~.~
24.~? N $2,69~ . 6433e2,a9 s2se?s8.4'4
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65R .1.50
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STATION
1DDNT IFICAT ION
-~ ·
END 1,5/L00 DROP
HST RkSR PRP,~4AFROST
9-s/s,, cso ~
103P CLU~VIi 2.5/X00
EbTD 2.5/:00 CURVE
cu~w 6/:oo
TOP
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mmmmmmsm
L500..O0
1600.00
1700.00
1800..00
·
18S8.77
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I ' -SHARED SERVICES BRILLING ...... - ..... I
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VERTICAL SECTION VIEW
600~ - ..
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]>
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DATE CHECK NO.
H 1-2 5 9'G 2 o~/o4/77 ooI~-~76~
VENDOR ALASKgST i 4 O0
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET
r:-~-~ ~'7 CK073'i 97A i00. O0 lOC).
HANDLTNA .... INST' s/h ter-r-i=~ h~Jbbl=~ × 462=, ~,
THE A~ACHED CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. m~]~il~
· WELL PERMIT CHECKLIST COMPANY
FIELD & POOL ,~' ~'/'4::~} ¢~'~_~ INIT CLASS
ADMINISTRATION
GEOL AREA ~,~(:~ UNIT#. J/Z'~/'~,~O ON/OFF SHORE
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
N
:N
N
N
N
N
N
N
N
N
N
N
N
ENGINEERING
APPR _~_
14. Conductor string provided ...................
15. Surface casing protects all known USDWs ........... ~ N
16. CMT vol adequate to circulate on conductor & surf csg ..... ~L.
17. CMT vol adequate to tie-in long string to surf csg ........
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved... Y N ¢J~-~
22. Adequate wellbore separation proposed ............. ,~ N
23. If diverter required, does it meet regulations .......... N
24. Drilling fluid program schematic & equip list adequate ..... ~ N
25. BOPEs, do they meet regulation N
26. BOPE press rating appropriate; te'st't~ ' '.~':~¢:~4:::~ ' ' ' ~s;g: N
27. Choke manifold complies w/APl RP-53 (May 84) ........ ('-~N ~-'~'
28 Work will occur without operation shutdown ...........
29 Is presence of H2S gas probable .................
GEOLOGY
30. Permit can be issued w/o hydrogen sulfide measures .....
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones ............. Y.Y/'/N / -
33. Seabed condition survey (if off-shore) .............
34. Contact name/phone for we,ekly,progress repqrts .......
lexwora ~ory omy]
RE,MARKS
GEO,~GY:
R
ENGINEERING:
COMMISSION:
BEW .. DW~
Comments/Instructions:
HOW/Ijt - A:\FORMS\chekhst rev 07~97
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process ·
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information-of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
* ALASKA COMPUTING CENTER *
....... SCHLUMBERGER .......
COMPANY NAME : BP EXPLORATION (ALASKA), INC.
WELL NAME : H-34
FIELD NAME : PRUDHOE BAY
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 500292280300
REFERENCE NO : 97481
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
**** REEL HEADER ****
SERVICE NAME : EDIT
DATE : 98/02/ 4
ORIGIN : FLIC
REEL NAME : 97481
CONTINUATION # :
PREVIOUS REEL :
COM~4ENT · B.P. EXPLORATION, H-34, PRUDHOE BAY, API #50-029-22803-00
**** TAPE HEADER ****
SERVICE NAME : EDIT
DATE : 98/02/ 4
ORIGIN · FLIC
TAPE NAME : 97481
CONTINUATION # : 1
PREVIOUS TAPE :
COI~4ENT : B.P. EXPLORATION, H-34, PRUDHOE BAY, API #50-029-22803-00
TAPE HEADER
Prudhoe Bay
OPEN HOLE WIRELINE LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DA TA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
RUN 1
97481
E. Bartz
D. Stearns
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2NDSTRING
H-34
500292280300
BP Exploration ~laska), Inc.
SCHLUMBERGER WELL SERVICES
4-FEB-98
RUN 2 RUN 3
21
llN
13E
3224
1264
75.36
45.40
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
6.000 7.000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
3RD STRING
PRODUCTION STRING
REMARKS:
CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE DATA
AQUIRED ON BP EXPLORATION'S H-34 WELL. CNTG, BHC,
DIT-E/LDT WERE RUN INTO THE HOLE. LDT AND EPITHERMAL
CNTG TOOLS FAILED AND ARE NOT PRESENTED ON THIS TAPE.
THESE ARE THE PRIMARY DEPTH CONTROL LOGS FOR THIS WELL.
$
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION · O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 1
EDITED OPEN HOLE MAIN PASS
Ail tool strings; clipped curves; all runs merged; no cased hole data.
DEPTH INCREMENT: 0.5000
FILE SU~4MARY
LDWG TOOL CODE
..............
DTE
BCS
CNTG
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
START DEPTH STOP DEPTH
.....................
10696.0 9180.0
10705.0 9165.0
10648.0 9165.0
BASELINE DEPTH
..............
$
MERGED DATA SOURCE
LDWG TOOL CODE
$
REMARKS:
.......... EQUIVALENT UNSHIFTED DEPTH ..........
DTE BCS CNTG
.....................
RUN NO. PASS NO.
~IERGE TOP MERGE BASE
...................
THIS FILE CONTAINS THE EDITED OPEN HOLE MAIN PASS.
DATA WAS NOT DEPTH CORRECTED BECAUSE THIS IS THE
PRIMARY DEPTH CONTROL LOG. THE DATA HAS BEEN CLIPPED
OF INVALID READINGS BEFORE FIRST READING AND AT CASING
POINT.
$
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 80
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 12
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE - CHAN **
NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
IDPH DTE 0t~4M1022696 O0 000 O0 0 1 1 1 4 68 0000000000
IMPH DTE OH~M1022696 O0 000 O0 0 1 1 1 4 68 0000000000
ILD DTE OHMM1022696 O0 000 O0 0 1 1 1 4 68 0000000000
ILM DTE OHMM1022696 O0 000 O0 0 1 1 1 4 68 0000000000
SFL DTE OHI~M1022696 O0 000 O0 0 1 1 1 4 68 0000000000
GR BCS GAPI 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
TENS BCS LB 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
MTEMBCS DEGF 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
MRES BCS 0Iflv~I1022696 O0 000 O0 0 1 1 1 4 68 0000000000
TEND BCS LB 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
DT BCS US/F 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
NPHI CNTG PU-S 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
NRAT CNTG 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
CPHI CNTG PU-S 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
CRAT CNTG 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
NCNT CNTG CPS 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
FCNT CNTG CPS 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
CNTC CNTG CPS 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
CFTC CNTG CPS 1022696 O0 000 O0 0 1 1 1 4 68 0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
** DATA **
DEPT. 10705.000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE
ILM. DTE -999.250 SFL.DTE -999.250 GR.BCS -999.250 TENS.BCS
MTEM. BCS 216.249 M~ES.BCS 0.034 TE1VD.BCS 1566.949 DT.BCS
NPHI.CNTG -999.250 NRAT. CNTG -999.250 CPHI.CNTG -999.250 CRAT. CNTG
NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG
DEPT. 9165.000 IDPH. DTE -999.250 IMPH. DTE -999.250 ILD.DTE
ILM. DTE -999.250 SFL.DTE -999.250 GR.BCS 152.410 TENS.BCS
MTEM. BCS 194.278 MRES.BCS 0.043 TEND.BCS 1227.467 DT.BCS
NPHI.CNTG 29.071 NRAT. CNTG 2.324 CPHI. CNTG 25.647 CRAT. CNTG
NCNT. CNTG 2498.288 FCNT. CNTG 984.906 CNTC. CNTG 2411.704 CFTC. CNTG
-999.250
1774.000
-999.250
-999.250
-999.250
-999.250
1027.000
78.200
2.326
1058.875
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE . FLIC
VERSION · O01CO1
DATE · 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER: 2
EDITED CASED HOLE MAIN PASS
Depth shifted and clipped curves for open hole logs run into casing.
PASS NUMBER: 1
DEPTH INCREMENT: 0.5000
FILE SU~4MARY
LDWG TOOL CODE START DEPTH STOP DEPTH
BCS 9165.0 8884.0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
CNTG 9165.0 8884.0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
.......... EQUIVALENT UNSHIFTED DEPTH ..........
BASELINE DEPTH BCS CNTG
$
REMARKS: THIS FILE CONTAINS THE EDITED MAIN PASS IN CASING.
DATA WAS NOT DEPTH CORRECTED BECAUSE THIS IS THE
PRIMARY DEPTH CONTROL LOG. THE DATA HAS BEEN CLIPPED
AT CASING POINT. TOOLS NOT VALID IN CASING ARE NOT
INCLUDED IN THIS FILE.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 48
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 21
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 PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
GRCH BCS GAPI 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
TENS BCS LB 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
TEND BCS LB 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
NPHI CNTG PU-S 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
NRAT CNTG 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
CPHI CNTG PU-S 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
CRAT CNTG 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
NCNT CNTG CPS 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
FCNT CNTG CPS 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
CNTC CNTG CPS 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
CFTC CNTG CPS 1022696 O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT. 9165.000 GRCH. BCS 152.410 TENS.BCS 1027.000 TEND.BCS 1227.467
NPHI.CNTG 29.071 NRAT. CNTG 2.324 CPHI.CNTG 25.647 CRAT. CNTG 2.326
NCNT. CNTG 2498.288 FCNT. CNTG 984.906 CNTC. CNTG 2411.704 CFTC. CNTG 1058.875
DEPT. 8884.000 GRCH.BCS 101.140 TENS.BCS 182.000 TEND.BCS
NPHI.CNTG 61.584 NRAT. C1FTG 4.143 CPHI.CNTG 53.321 CRAT. CNTG
NCNT. CNTG 1575.786 FCNT. CNTG 339.891 CNTC. CNTG 1535.623 CFTC. CNTG
1350.358
4.152
380.133
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE ' FLIC
VERSION ' O01CO1
DATE · 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION ' O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 3
RAW OPEN HOLE MAIN PASS
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51 PAGE: 7
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:
PASS NUMBER: 1
DEPTH INCREMENT: 0.5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
...........................
DTE 10706.0
BHC 10706.0
CNTG 10706.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR):
STOP DEPTH
..........
9165.0
9165.0
9165.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DTE PHASOR INDUCTION
GR GAMMA RAY
BHC SONIC CARTRIDGE
CNTG COMPENSATED NEUTRON
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF) :
RESISTIVITY (OHP~q) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT) :
04-0CT-97
8C0-609
1400 03-0CT-97
700 04-0CT-97
10710.0
10706.0
8884.0
10705.0
TOOL NUMBER
DIC-EB 262
SGC-SA
SDC-CB
CNC-GA 125
6.000
9167.0
9165.0
Quikdriln
8.70
50.0
8.9
230.0
O. 140 66.0
O. 127 66.0
O. 211 66.0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
NEUTRON TOOL
TOOL TYPE (EPITHERMAI~ OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
THERMAL
SANDSTONE
2.65
TOOL STANDOFF (IN): O. 5
REMARKS: Ail tools run in combination & conveyed by drill pipe.
Three .5"standoffs run on Induction.
Four .5" standoffs run on Sonic.
Two tool turners run on Nuclear tools in order to
orient them pad-side down.
Sandstone matrix; 14DEN = 2.65 g/cc used for all
porosity computations. DENSITY TOOL FAILED DOWNHOLE.
Neutron calibrations entered by hand - software
did not update jig ratios. Thermal detectors are
in good working order & in tolerance. Epithermal
detectors are suspect but not used for logging.
Maximium recorded temperature w/RFT on second run.
AMS validated the RFT temperature of 230 deg F @TD.
20 KHz frequency used to generate Phasor log.
THIS FILE CONTAINS THE RAW MAIN PASS, CLIPPED AT
CASING, AQUIRED AT O . 5 ' SAMPLE RATE.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
..............................
1 66 0
2 66 0
3 73 136
4 66 1
5 66
6 73
7 65
8 68 O. 5
9 65 FT
11 66 7
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
CIDP DTE l~vpHO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IDPH DTE 0H~941022696 O0 000 O0 0 3 1 1 4 68 0000000000
CIMP DTE ~4~HO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IMPH DTE 0tfl~I41022696 O0 000 O0 0 3 1 1 4 68 0000000000
CDER DTE MMHO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IDER DTE 0H~941022696 O0 000 O0 0 3 1 1 4 68 0000000000
CMER DTE 14~IO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IMER DTE 0HI~41022696 O0 000 O0 0 3 1 1 4 68 0000000000
CDVR DTE l~4~tO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IDVR DTE Otff4~1022696 O0 000 O0 0 3 1 1 4 68 0000000000
CMVR DTE I~4~IO1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IMVR DTE OH~IM 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
CILD DTE l~4~IO1022696 O0 000 O0 0 3 1 1 4 68 0000000000
ILD DTE 0tfi~41022696 O0 000 O0 0 3 1 1 4 68 0000000000
CILMDTE ~4~PHO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
ILM DTE OH~M 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IDQF DTE 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IMQF DTE 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IIRD DTE ~94~t0 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IIXDDTE l~4~IO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IIRMDTE ~vl~IO1022696 O0 000 O0 0 3 1 1 4 68 0000000000
IIXI4DTE I~4HO 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
SFLU DTE OPi~4~1022696 O0 000 O0 0 3 1 1 4 68 0000000000
DT BHC US/F 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
NPHI CNTG PU 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
RTNR CNTG 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
TNPH CNTG PU 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
TNRA CNTG 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
NPOR CNTG PU 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
RCNT CNTG CPS 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
RCFT CNTG CPS 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
CNTC CNTG CPS 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
CFTC CNTG
CPS 1022696 O0 000 O0 0 3 1 1 4 68 0000000000
** DATA **
DEPT. 10706. 000 CIDP.DTE
IMPH. DTE 1. 912 CDER.DTE
IMER . DTE 1.911 CDVR . DTE
IMVR . DTE 1. 911 CILD. DTE
ILM. DTE 1 . 912 IDQF. DTE
IIXD.DTE 80. 686 IIRM. DTE
DT. BHC 73. 000 NPHI. CNTG
TNRA. CNTG 1.786 NPOR. CNTG
CNTC. CNTG 4241 . 448 CFTC. CNTG
471. 119
470 690
471 211
469 262
0 000
481 558
20 987
17 831
2412 002
IDPH.DTE 2.123 CIMP.DTE 523.106
IDER. DTE 2. 125 CMER. DTE 523.256
IDVR. DTE 2. 122 CMVR. DTE 523. 285
ILD.DTE 2. 131 CILM.DTE 523. 093
IMQF.DTE O. 000 IIRD.DTE 378. 745
IIXM. DTE 39. 230 SFLU. DTE 1. 780
R TN~R. CNTG 1.842 TNPH. CNTG 17.831
RCNT. CNTG 4294. 742 RCFT. CNTG 2283. 846
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14 '.51
PAGE:
10
DEPT. 9165
IMPH.DTE 0
IMER. DTE 0
IMVR . DTE 0
I LM. DTE 1
IIXD. DTE - 631
DT. BHC 78
TNRA. CNTG 2.
CNTC. CNTG 2411.
000 CIDP.DTE 2619. 406 IDPH.DTE O. 382 CIMP.DTE
915 CDER.DTE 3017.614 IDER.DTE 0.331 CMER.DTE
659 CDVR. DTE 4222. 066 IDVR. DTE O. 237 CMVR. DTE
362 CILD.DTE 1898. 092 ILD.DTE O. 527 CILM. DTE
043 IDQF.DTE O. 000 IMQF. DTE O. 000 IIRD.DTE
568 IIRM. DTE 858. 475 IIXM. DTE -1009. 306 SFLU. DTE
200 NPHI. CNTG 29. 071 RTN-R. CNTG 2.324 TNPH. CNTG
326 NPOR. CNTG 24. 876 RCNT. CNTG 2498. 288 RCFT. CNTG
704 CFTC. CN~G 1058. 875
1092 643
1517 279
2759 443
958 339
1067 943
9700 000
25 647
984. 906
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION ' O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 4
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: 1
DEPTH INCREMENT: 0.1667
FILE SUAg~ARY
VENDOR TOOL CODE START DEPTH
...........................
BHC 10706.33
$
STOP DEPTH
..........
9165.0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE: 11
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
BHC SONIC
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF) :
RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT) :
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
REMARKS:
04-0CT-97
8C0-609
1400 03-0CT-97
700 04-0CT-97
10710.0
10706.0
8884.0
10705.0
TOOL NUMBER
DIC-EB 262
6.000
9167.0
9165.0
Quikdriln
8.70
50.0
8.9
230.0
O. 140 66.0
O. 127 66.0
O. 211 66.0
THERMAL
SANDSTONE
2.65
0.5
Ail tools run in combination & conveyed by drill pipe.
Three .5"standoffs run on Induction.
Four .5" standoffs run on Sonic.
Two tool turners run on Nuclear tools in order to
orient them pad-side do~zn.
Sandstone matrix; ~4DEN = 2.65 g/cc used for all
porosity computations. DENSITY TOOL FAILED DOWNHOLE.
Neutron calibrations entered by hand - software
did not update jig ratios. Thermal detectors are
in good working order & in tolerance. Epithermal
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
12
detectors are suspect but not used for logging.
Maximium recorded temperature w~ RFT on second run.
AMS validated the RFT temperature of 230 deg F @TD.
20 KHz frequency used to generate Phasor log.
THIS FILE CONTAINS THE RAW MAIN PASS, CLIPPED AT
CASING, AQUIRED AT 0.1667' SAMPLE RATE.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
..............................
TYPE REPR CODE VALUE
..............................
1 66 0
2 66 0
3 73 20
4 66 1
5 66
6 73
7
8
9
11
12
13
14
15
16
0
0.166
FT
51
65
68
65
66
68
66 0
65 FT
66 68
66 1
66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUIZiB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 4 1 1 4 68 0000000000
TT1 BHC US 1022696 O0 000 O0 0 4 1 1 4 68 0000000000
TT2 BHC US 1022696 O0 000 O0 0 4 1 1 4 68 0000000000
TT3 BHC US 1022696 O0 000 O0 0 4 1 1 4 68 0000000000
TT4 BHC US 1022696 O0 000 O0 0 4 1 1 4 68 0000000000
** DATA **
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
13
DEPT. 10706. 334
TT4 . BHC -999. 250
TT1.BHC -999.250 TT2.BHC
-999.250 TT3.BHC
-999.250
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION · O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
RUN NUMBER:
TOOL STRING NUMBER:
PASS NUMBER:
DEPTH INCREMENT:
FILE SUMMARY
FILE HEADER
FILE NUMBER 5
RAW OPEN HOLE REPEAT PASSES
Curves and log header data for each pass, tool string, and run in separate files.
1
1
1
0.5000
VENDOR TOOL CODE START DEPTH STOP DEPTH
.....................................
DTE 10705.0 10430.5
BHC 10705.0 10430.5
CNTG 10705.0 10430.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
04-0CT-97
C80-069
1400 03-0CT-97
700 04-0CT-97
10710.0
10706.0
8884.0
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
14
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR):
10705.0
1800.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DTE PHASOR INDUCTION
GR GA~f~A RAY
BHC SONIC CARTRIDGE
CNTG COMPENSATED NUETRON
$
TOOL NUMBER
...........
DIC-EB 262
SG C - SA
SDC-CB
CNC-GA 125
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
6.000
9167.0
9165.0
BOREHOLE CONDITIONS
MUD TYPE: Quikdriln
MUD DENSITY (LB/G): 8.70
MUD VISCOSITY (S) : 50.0
MUD PH: 8.9
FLUID LOSS (C3): 6.4
MAXIMUM RECORDED TEMPERATURE (DEGF) : 230.0
RESISTIVITY (OH~) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT): O. 140
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT): O. 127
MUD FILTRATE AT (BHT):
MUD CAKE AT (MT): O. 211
MUD CAKE AT (BHT) :
66.0
66.0
66.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
THERMAL
SANDSTONE
2.65
TOOL STANDOFF (IN):
0.5
REMARKS:
Ail tools run in combination & conveyed by drill pipe.
Three .5" standoffs run on Induction.
Four .5" standoffs run on Sonic.
Two tool turners run on Nuclear tools in order to
orient them pad-side down.
Sandstone matrix; MDEN = 2.65 g/cc used for all
porosity computations. DENSITY TOOL FAILED DOWNHOLE.
Neutron calibrations entered byhand - software
did not update jig ratios. Thermal detectors are
in good working order & in tolerance. Epithermal
detectors are suspect but not used for logging.
Maximium recorded temperature w/RFT on second run.
AMS validated the RFT temperature of 230 deg F @TD.
20 KHz frequency used to generate Phasor log.
THIS FILE CONTAINS THE RAWREPEAT PASS
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE: 15
AQUIRED AT 0.5' SAMPLE RATE.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1
2
3
4 66
5 66
6 73
7 65
8 68
9 65
11 66
12 68
13 66
14 65
15 66
16 66
0 66
66 0
66 0
73 160
1
0.5
FT
6
0
FT
68
1
1
** SET TYPE - CHAN **
NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CIDP DTE I4M}tO 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IDPH DTE Otfi~M1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CIMP DTE I¢k4~0 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IMPH DTE 0HI4~1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CDER DTE i¢k4~0 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IDER DTE 0H~1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CMER DTE 14MHO 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IMER DTE 0~1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CDVRDTE ~vi~O 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IDVR DTE OH~ff41022696 O0 000 O0 0 5 1 1 4 68 0000000000
CMVR DTE ~4~0 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IMVR DTE 0tfl~41022696 O0 000 O0 0 5 1 1 4 68 0000000000
CILD DTE ~IO 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
ILD DTE 0t~4M1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CILMDTE f4M~O 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
ILM DTE 0H~I1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IDQF DTE 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
16
NAME SERV UNIT SERVICE API API API API FILE NUAIB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
IMQF DTE 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IIRD DTE ~4~4~t0 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IIXDDTE ~4HO 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IIRMDTE ~0 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
IIXI4DTE Nfl~IO1022696 O0 000 O0 0 5 1 1 4 68 0000000000
SFLU DTE OH~fl~1022696 O0 000 O0 0 5 1 1 4 68 0000000000
SP DTE MV 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
GR BHC GAPI 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
TENS BHC LB 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
MTEMBHC DEGF 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
MRES BHC OH~4M1022696 O0 000 O0 0 5 1 1 4 68 0000000000
HTEN BHC LB 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
DT BHC US/F 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
NPHI CNTG PU 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
RTNR CNTG 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
TNPH CNTG PU 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
TNRA CNTG 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
NPOR CNTG PU 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
RCNT CNTG CPS 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
RCFT CNTG CPS 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CNTC CNTG CPS 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
CFTC CNTG CPS 1022696 O0 000 O0 0 5 1 1 4 68 0000000000
** DATA **
DEPT. 10705.000 CIDP.DTE 460.945 IDPH. DTE
IMPH.DTE 1.812 CDER.DTE 461.502 IDER.DTE
IMER.DTE 1.809 CDVR.DTE 462.933 IDVR.DTE
IMVR.DTE 1 . 806 CILD.DTE 457. 719 ILD.DTE
ILM. DTE 1. 812 IDQF.DTE O. 000 IMQF.DTE
IIXD.DTE 80. 733 IIRM. DTE 507. 012 IIXM. DTE
SP.DTE 0.000 GR.BHC 23.610 TENS.BHC
MRES.BHC 0.030 HTEN. BHC 1631.464 DT.BHC
RTNR.CNTG 2.278 TNPH. CNTG 24.421 TNRA.CNTG
RCNT. CNTG 5075.074 RCFT. CNTG 2160.319 CNTC. CNTG
DEPT.
IMPH.DTE
IMER. DTE
IMVR . DTE
I LM. DTE
I IXD. DTE
S P . DTE
MRES. BHC
RTNR. CNTG
RCNT. CNTG
10430.500
11. 414
11. 725
11. 733
4 409
12 967
3 063
0 033
2 339
3816 969
2 169 CIMP.DTE
2 167 CMER.DTE
2 160 CI~VR.DTE
2 185 CILM. DTE
0 000 IIRD.DTE
41 296 SFLU. DTE
2200. 000 MTEM. BHC
71.200 NPHI. CNTG
2.208 NPOR. CNTG
5012. 097 CFTC. CNTG
CIDP.DTE 100. 028 IDPH. DTE 9. 997 CIMP.DTE
CDER.DTE 91. 407 IDER.DTE 10.940 CMER.DTE
CDVR.DTE 92. 440 IDVR.DTE 10. 818 CMVR.DTE
CILD.DTE 187. 063 ILD.DTE 5. 346 CILM. DTE
IDQF.DTE O. 000 IMQF. DTE O. 000 IIRD.DTE
IIRM. DTE 185. 152 IIXM. DTE 4. 309 SFLU. DTE
GR.BHC 32.232 TENS.BHC 2350.000 MTEM. BHC
HTEN. BHC 1228. 489 DT.BHC 84.500 NPHI. CNTG
TNPH. CNTG 24.067 TNRA. CNTG 2.231 NPOR. CNTG
RCFT. CNTG 1826. 547 CNTC. CNTG 3906. 628 CFTC. CNTG
552.024
552.789
553.832
551.759
370.466
1.735
216.283
27.292
24.421
2281.544
87. 615
85. 290
85. 228
226. 803
131. 626
5.507
213. 018
27. 642
22. 945
1847. 588
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
17
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .005
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .006
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 6
RAW OPEN HOLE REPEAT PASSES
Curves and log header data for each pass, tool string, and run in separate files.
RUN NUMBER: 1
TOOL STRING NUMBER: 1
PASS NUMBER: 1
DEPTH INCREMENT: 0.1667
FILE SUb~NIRY
VENDOR TOOL CODE START DEPTH STOP DEPTH
10705.0 10430.5
BHC
$
LOG HEADER DATA
DATE LOGGED: 04-0CT-97
SOFTWARE VERSION: C80 - 069
TIME CIRCULATION ENDED: 1400 03-0CT-97
TIME LOGGER ON BOTTOM: 700 04-0CT-97
TD DRILLER (FT) : 10710.0
TD LOGGER (FT) : 10706.0
TOP LOG INTERVAL (FT) : 8884.0
BOTTOM LOG INTERVAL (FT) : 10705.0
LOGGING SPEED (FPHR) : 1800.0
TOOL STRING (TOP TO BOTTOM)
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
18
VENDOR TOOL CODE TOOL TYPE
.........................
BHC SONIC
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT):
LOGGERS CASING DEPTH (FT) :
BOREHOLE CONDITIONS
MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
FLUID LOSS (C3):
MAXIMUM RECORDED TEMPERATURE (DEGF) :
RESISTIVITY (Oink4) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT):
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT):
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT):
MUD CAKE AT (BHT):
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL NUMBER
SDC-CB
6.000
9167.0
9165.0
Quikdriln
8.70
50.0
8.9
6.4
230.0
O. 140 66.0
O. 127 66.0
O. 211 66.0
THERMAL
SANDSTONE
2.65
TOOL STANDOFF (IN): O. 5
REMARKS: Ail tools run in combination & conveyed by drill pipe.
Three .5" standoffs run on Induction.
Four .5" standoffs run on Sonic.
Two tool turners run on Nuclear tools in order to
orient them pad-side down.
Sandstone matrix; ~9EN = 2.65 g/cc used for all
porosity computations. DENSITY TOOL FAILED DOWNHOLE.
Neutron calibrations entered by hand - software
did not update jig ratios. Thermal detectors are
in good working order & in tolerance. Epithermal
detectors are suspect but not used for logging.
Maximium recorded temperature w/ RFT on second run.
AMS validated the RFT temperature of 230 deg F @TD.
20 KHz frequency used to generate Phasor log.
THIS FILE CONTAINS THE RAW REPEAT PASS
AQUIRED AT 0.1667' SAMPLE RATE.
$
LIS FORMAT DATA
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE: 19
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 20
4 66 1
5 66
6 73
7 65
8 68 0.166
9 65 FT
11 66 51
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 6 1 1 4 68 0000000000
TT1 BHC US 1022696 O0 000 O0 0 6 1 1 4 68 0000000000
TT2 BHC US 1022696 O0 000 O0 0 6 1 1 4 68 0000000000
TT3 BHC US 1022696 O0 000 O0 0 6 1 1 4 68 0000000000
TT4 BHC US 1022696 O0 000 O0 0 6 1 1 4 68 0000000000
** DATA **
DEPT. 10705.334 TT1.BHC -999.250 TT2.BHC -999.250 TT3.BHC -999.250
TT4.BHC -999.250
** END OF DATA **
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14 ..51
PAGE: 20
**** FILE TRAILER ****
FILE NAME : EDIT .006
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .007
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 7
RAW CASED HOLE MAIN PASS
Curves and log header data for open hole logs run into casing.
PASS NUMBER: 1
DEPTH INCREMENT.. O. 5000
FILE SUNk4ARY
VENDOR TOOL CODE START DEPTH
BHC 9165.0
CNTG 9165.0
$
LOG HEADER DATA
STOP DEPTH
..........
8882.5
8882.5
DATE LOGGED:
SOFTWARE VERSION:
TIME CIRCULATION ENDED:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) '.
TD LOGGER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT)
LOGGING SPEED (FPHR) :
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
GR GAi~MA RAY
CNTG COMPENSATED NUETRON
$
BOREHOLE AND CASING DATA
04-0CT-97
8C0-069
1400 03-0CT-97
700 04-0CT-97
10710.0
10706.0
8884.0
10705.0
TOOL NUMBER
SGC-SA
CNC-GA 125
LIS Tape verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
21
OPEN HOLE BIT SIZE (IN) :
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
6. 000
9167.0
9165.0
BOREHOLE CONDITIONS
MUD TYPE: Quikdriln
MUD DENSITY (LB/G): 8.70
MUD VISCOSITY (S) : 50.0
MUD PH: 8.9
FLUID LOSS (C3): 6.4
MAXIMUM RECORDED TEMPERATURE (DEGF) : 230.0
RESISTIVITY (OH~q) AT TEMPERATURE (DEGF) :
MUD AT MEASURED TEMPERATURE (MT): O. 140
MUD AT BOTTOM HOLE TEMPERATURE (BHT) :
MUD FILTRATE AT (MT): O. 127
MUD FILTRATE AT (BHT) :
MUD CAKE AT (MT): O. 211
MUD CAKE AT (BHT) :
66.0
66.0
66.0
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
THERMAL
SANDSTONE
2.65
TOOL STANDOFF (IN): O. 5
REMARKS: Ail tools run in combination & conveyed by drill pipe.
Three .5"standoffs run on Induction.
Four .5" standoffs run on Sonic.
Two tool turners run on Nuclear tools in order to
orient them pad-side down.
Sandstone matrix; MDEN = 2.65 g/cc used for all
porosity computations. DENSITY TOOL FAILED DOWNHOLE.
Neutron calibrations entered by hand - software
did not update jig ratios. Thermal detectors are
in good working order & in tolerance. Epithermal
detectors are suspect but not used for logging.
Maximium recorded temperature w~ RFT on second run.
AMS validated the RFT temperature of 230 deg F @TD.
20 KHz frequency used to generate Phasor log.
THIS FILE CONTAINS THE RAW MAIN PASS AQUIRED INTO
CASING, AQUIRED AT 0.5' SAMPLE RATE.
$
LIS FORMAT DATA
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
22
** 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 1
** SET TYPE - CHAN **
NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX)
DEPT FT 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
NPHI CNTG PU 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
RTNR CNTG 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
TNPH CNTG PU 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
TNRA CNTG 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
NPOR CNTG PU 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
RCNT CNTG CPS 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
RCFT CNTG CPS 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
CNTC CNTG CPS 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
CFTC CNTG CPS 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
GR BHC GAPI 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
TENS BHC LB 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
HTEN BHC LB 1022696 O0 000 O0 0 7 1 1 4 68 0000000000
** DATA **
DEPT. 9165.000 NPHI.CNTG 29.071 RTNR.CNTG 2.324 TNPH. CNTG 25.647
TNRA.CNTG 2.326 NPOR.CNTG 24.876 RCNT. CNTG 2498.288 RCFT. CNTG 984.906
CNTC. CNTG 2411.704 CFTC. CNTG 1058.875 GR.BHC 152.410 TENS.BHC 1027.000
HTEN. BHC 1227.467
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
4-FEB-1998 14:51
PAGE:
23
DEPT. 8882.500 NPHI.CNTG
TNRA.CNTG 4.062 NPOR.CNTG
CNTC. CNTG 1551.848 CFTC. CNTG
HTEN. BHC 1350.917
59.925 RTNR.CNTG 3.877 TNPH. CNTG 53.020
54.687 RCNT. CNTG 1646.941 RCFT. CNTG 394.293
404.934 GR.BHC 98.654 TENS.BHC 167.000
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .007
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/02/ 4
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 98/02/ 4
ORIGIN : FLIC
TAPE NAME : 97481
CONTINUATION # : 1
PREVIOUS TAPE :
CO~4ENT : B.P. EXPLORATION, H-34, PRUDHOE BAY, API #50-029-22803-00
**** REEL TRAILER ****
SERVICE NAME : EDIT
DATE : 98/02/ 4
ORIGIN : FLIC
REEL NAME · 97481
CONTINUATION # :
PREVIOUS REEL :
CO~4ENT : B.P. EXPLORATION, H-34, PRUDHOE BAY, API #50-029-22803-00
Sperry-Sun Drilling Services
LIS Scan Utility
Mon Oct 20 09:38:46 1997
Reel Header
Service name ............. LISTPE
Date ..................... 97/10/20
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Previous Reel Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific
Technical Services
Tape Header
Service name ............. LISTPE
Date ..................... 97/10/20
Origin ................... STS
Tape Name ................ UNKNOWN
Gontinuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific
Technical Services
Physical EOF
Comment Record
TAPE HEADER
PRUDHOE BAY UNIT
MWD/MAD LOGS
WELL NAME:
APi NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
MWD RUN 5
AK-MW-70272
CHIP JACKSON
CHARLEY DIXO
H-34
500292280300
BP EXPLORATION (ALASKA), INC.
SPERRY-SUN DRILLING SERVICES
20-OCT-97
MWD RUN 6
AK-MW-70272
CHIP JACKSON
CHARLEY DIXO
MWD RUN 7
AK-MW-70272
P. ROBERTS
CHARLEY DIXO
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FN L:
FSL:
FEL:
MWD RUN 8
AK-MW-70272
P. ROBERTS
CHARLEY DIXO
MWD RUN 9
AK-MW-70272
P. ROBERTS
DAVID REED
21
liN
13E
3224
1265
RECE v U
OCT 22 t997
FWL:
ELEVATION (FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
75.30
73.90
45.40
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
1ST STRING
2ND STRING 12.250 9.625 3642.0
3RD STRING 9.875 7.000 9167.0
PRODUCTION STRING 6.000 10710.0
REMARKS:
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT
REPRESENTED.
3. MWD RUNS 3 AND 4 MADE NO FOOTAGE AND ARE NOT
PRESENTED.
4. RUNS 5 AND 6 ARE DIRECTIONAL WITH NATURAL GAMMA RAY
PROBE (NGP)
UTILIZING SCINTILLATION DETECTOR.
5. MWD RUNS 7 THROUGH 9 ARE DIRECTIONAL WITH DUAL GAMMA
RAY (DGR) UTILIZING
-GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE
RESISTIVITY PHASE-4
(EWR4) .
6. A CHANGE FROM SCINTILLATION DETECTOR TO GEIGER
MEULLER DETECTORS
OCCURS AT 9108'MD, 8632'TVD.
7. MWD RUNS 1, 2 AND 5 THROUGH 9 REPRESENT WELL H-34
WITH API#:50-029-22803-00
THIS WELL REACHED A TOTAL DEPTH (TD) OF 10710'MD,
9110'TVD.
SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRD = SMOOTHED GAMMA RAY.
SGRC = SMOOTHED GAMMA RAY COMBiNED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITy (EXTRA
SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(SHALLOW SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM
SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE
GR
ROP
FET
RPD
RPM
RPS
RPX
$
START DEPTH
3615 0
3684 0
9153 0
9153 0
9153 0
9153 0
9153 0
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
3615
8958
8962
8968
8970
8972
8973
8976
8977
8982
8983
8992
8993
8995
8999
9010
9013
9016
9018
9019
9033
9067
9069
9157
9158
9160
9162
9163
9167
9170
9193
9200
9203
9207
9210
9212
9215
9216
9221
9222
0
0
0
0
5
0
5
0
5
0
0
5
5
0
0
0
.5
0
0
5
0
0
0
5
5
0
0
5
0
5
0
5
5
5
0
5
0
5
5
5
GR
3610.5
8953.5
8957.0
8963.5
8966.5
8968.0
8969.5
8971.5
8973.5
8980.5
8981.5
8987.0
8988.5
8991.5
8993.5
9007.0
9009.5
9012.5
9014.5
9016.5
9028.0
9063.0
9064.0
9162 0
9163 5
9164 5
9166 5
9168 0
9171 0
9175 0
9197 5
9206 0
9209 0
9212 5
9216.0
9218.5
9221.0
9223.0
9227.0
9228.5
STOP DEPTH
10646.0
10707.5
10653.0
10653.0
10653.0
10653.0
10653.0
EQUIVALENT UNSHIFTED DEPTH
9227
9230
9232
9235
9237
9244
9246
9249
9250
9252
9254
9257
9260
9263
9266
9279
9282
9287
9289
9300
9302
9304
9310
9314
9316
9319
9322
9326
9328
9329
9332
9334
9335
9350
9351
9353
9356
9358
9360
9363
9366
9369
9370
9372
9378
9383
9390
9393
9418
9420
9423
9427
9428
9429
9432
9434
9447
9449
9452
9534
.0
.0
.5
.5
.5
.5
5
0
5
0
0
5
5
0
0
0
.0
5
5
0
5
5
5
0
5
5
0
5
.0
.0
.0
.5
.0
.0
.0
.5
.5
.5
.5
.0
.5
.0
.0
.5
.5
.5
0
5
5
5
0
0
5
5
5
5
5
5
0
0
9232.0
9236.0
9238.0
9241.0
9243.0
9249.5
9252.0
9255.0
9256.0
9257.5
9259.5
9263.0
9265.5
9268.5
9271.5
9284.5
9286.5
9292.5
9294.0
9305.0
9307.0
9310.5
9315.0
9319.0
9322.0
9324.0
9326.5
9330.5
9332.5
9334.5
9337.5
9339.5
9340.0
9353.5
9356.5
9358.5
9362.0
9363.0
9364.5
9367.0
9372.0
9374.0
9376.5
9377.5
9383.5
9388.5
9393.0
9398.0
9423.0
9425.0
9426.5
9431.0
9432.0
9433.5
9437.0
9439.0
9451.0
9453.0
9455.0
9537.5
9535
9768
9923
9924
9947
9987
10040
10053
10071
10171
10176
10178
10180
10204
10211
10286
10295
10299
10299
10303
10325
10334
10341
10343.
10345.
10402.
10404.5
10411.0
10414.0
10417.5
10420.0
10422.5
10424 0
10450 0
10465 5
10470 0
10476 0
10478 0
10480 0
10482.0
10484 5
10486 5
10504 5
10514 5
10519 0
10520 5
10521 5
10523 0
10525 0
10527 0
10528 0
10533 5
10535 5
10537 0
10564 0
10568 5
10570 5
10707 5
$
9539.0
9769.5
9925.5
9926.5
9950.5
9990.5
10044.5
10056.5
10075.0
10175.5
10181.0
10183.0
10184.0
10208.5
10214.5
10290.0
10300.5
10301.5
10303.0
10306.0
10327.5
10335.5
10344.5
10346.0
10349.0
10403.0
10406.0
10412.5
10416.0
10419.5
10422.0
10425.0
10426.5
10453.0
10468.5
10471.5
10478.0
10480.5
10483.0
10484.5
10487.0
10488.5
10505.0
10516.5
10523.0
10523.5
10524.5
10525.5
10527.5
10529.5
10531.0
10536.5
10538.5
10541.0
10566.5
10570.5
10573.0
10710.0
MERGED DATA SOURCE
PBU TOOL CODE BIT RUN NO
MWD 5
MWD 6
MWD 7
MWD 8
MWD 9
REMARKS: MERGED MAIN PASS.
$
MERGE TOP
3678.0
8705.0
9177.0
10347.0
10449.0
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
MERGE BASE
8705.0
9177.0
10347.0
10449.0
10710.0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
ROP MWD FT/H 4 1 68
GR MWD AAPI 4 1 68
RPX MWD OHMM 4 1 68
RPS MWD OHMM 4 1 68
RPM MWD OHMS4 4 1 68
RPD MWD OHMM 4 1 68
FET MWD HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max Mean Nsam
DEPT 3615 10707.5 7161.25 14186
ROP 3.7578 2081.25 125.276 14048
GR 6.4134 549.451 69.7694 14063
RPX 0.1705 2000 34.3607 3001
RPS 0.187 2000 43.1269 3001
RPM 2.0187 2000 48.3046 3001
RPD 2.1069 2000 79.9991 3001
FET 0.5563 67.635 3.12243 3001
First Last
Reading Reading
' 3615 10707.5
3684 10707.5
3615 10646
9153 10653
9153 10653
9153 10653
9153 10653
9153 10653
First Reading For Entire File .......... 3615
Last Reading For Entire File ........... 10707.5
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.002
Physical EOF
File Header
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... t.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.001
Comment Record
FILE HEADER
FILE NUMBER: 2
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 5
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 3610.5
ROP 3679.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
8635.0
8704.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
25-SEP-97
1.32
5.03
MEMORY
8705.0
3678.0
8705.0
.4
31.1
TOOL NUMBER
NGP SPC 176
8.500
8.5
LSND
10.00
42.0
9.0
1000
4.0
.000
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ):
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .lin
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
.000
.000
.000
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 5 AAPI 4 1 68 4 2
ROP MWD 5 FT/H 4 1 68 8 3
13.5
First
Name Min Max Mean Nsam Reading
DEPT 3610.5 8704 6157.25 10188 3610.5
GR 6.4134 286.63 72.5374 10050 3610.5
ROP 9.9576 1049.41 150.124 10056 ' 3679.5
Last
Reading
8704
8635
8704
First Reading For Entire File .......... 3610.5
Last Reading For Entire File ........... 8704
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.003
Physical EOF
File Header
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 6
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 8637.0 9108.0
ROP 8706.0 9177.0
$
LOG HEADER DATA
DATE LOGGED: 27-SEP-97
SOFTWARE
SURFACE SOFTWARE VERSION: 1.32
DOWNHOLE SOFTWARE VERSION: 5.03
DATA TYPE (MEMORY OR REAL-TIME): MEMORY
TD DRILLER (FT): 9177.0
TOP LOG INTERVAL (FT) : 8705.0
BOTTOM LOG INTERVAL (FT): 9177.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 31.8
MAXIMUM ANGLE: 47.8
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
NGP NATURAL GAMMA PROBE
$
TOOL NUMBER
PCG 50
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
8.500
8.5
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
LSND
.00
.0
.0
0
.0
.000
.000
.000
.000
-17.7
NEUTRON TOOL
PLATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 6 AAPI 4 1 68 4 2
ROP MWD 6 FT/H 4 1 68 8 3
First
Name Min Max Mean Nsam Reading
DEPT 8637 9177 8907 1081 8637
GR 52.082 126.4 95.7847 943 8637
ROP 8.1645 170.415 40.9984 943 8706
Last
Reading
9177
9108
9177
First Reading For Entire File .......... 8637
Last Reading For Entire File ........... 9177
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.004
Physical EOF
File Header
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.003
Comment Record
FILE HEADER
FILE NUMBER: 4
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 7
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
STOP DEPTH
GR 9108.5 10301.0
FET 9157.0 10308.0
RPD 9157.0 10308.0
RPM 9157.0 10308.0
RPS 9157.0 10308.0
RPX 9157.0 10308.0
ROP 9177.5 10347.5
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
01-OCT-97
1.32
5.03
MEMORY
10347.0
9177.0
10347.0
50.1
91.3
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
TOOL NUMBER
P0717SP4
P0717SP4
6.000
6.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
6% KCL QUICK DR
8.70
45.0
8.9
30000
6.5
.100
.053
.110
.240
61.5
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
.0
Name Service Order Units Size Nsam Rep
DEPT FT 4 1 68
GR MWD 7 AAPI 4 1 68
RPX MWD 7 OHMM 4 1 68
RPS MWD 7 OHMM 4 1 68
RPM MWD 7 OHM~ 4 1 68
RPD MWD 7 OHMM 4 1 68
ROP MWD 7 FT/H 4 1 68
FET MWD 7 HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max Mean Nsam
DEPT 9108.5 10347.5 9728 2479
GR 18.8267 549.451 58.8001 2386
RPX 0.1705 2000 42.0612 2303
RPS 0.187 2000 54.0556 2303
RPM 2.0187 2000 62.5253 2303
RPD 1.1311 2000 103.686 2305
ROP 10.605 2081.25 73.8438 2341
FET 0.5563 67.635 2.30378 2303
First Last
Reading Reading
9108.5 10347.5
9108.5 10301
9157 10308
9157 10308
9157 10308
9157 10308
9177.5 10347.5
9157 10308
First Reading For Entire File .......... 9108.5
Last Reading For Entire File ........... 10347.5
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
Physical EOF
File Header
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.004
Comment Record
FILE HEADER
FILE NUMBER: 5
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 8
DEPTH INCREMENT: .5000
FILE SUPR~ARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
GR 10301.5 10403.0
FET 10308.5 10410.0
RPD 10308.5 10410.0
RPM 10308.5 10410.0
RPS 10308.5 10410.0
RPX 10308.5 10410.0
ROP 10348.0 10449.5
$
LOG HEADER DATA
DATE LOGGED: 02-OCT-97
SOFTWARE
SURFACE SOFTWARE VERSION: 1.32
DOWNHOLE SOFTWARE VERSION: 5.03
DATA TYPE (MEMORY OR REAL-TIME): MEMORY
TD DRILLER (FT) : 10449.0
TOP LOG INTERVAL (FT) : 10347.0
BOTTOM LOG INTERVAL (FT): 10449.0
BIT ROTATING SPEED (RPM):
HOLE INCLINATION (DEG
MINIMUM ANGLE: 63.6
MAXIMUM ANGLE: 65.4
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE TOOL NUMBER
DGR DUAL GAMMA RAY P0717SP4
EWR4 ELECTROMAG. RESIS. 4 P0717SP4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN): 6.000
DRILLER'S CASING DEPTH (FT): 6.0
BOREHOLE CONDITIONS
MUD TYPE: 6% KCL QUICK DR
MUD DENSITY (LB/G): 8.70
MUD VISCOSITY S) : 45.0
MUD PH: 8.9
MUD CHLORIDES PPM) : 30000
FLUID LOSS (C3 : 6.5
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
Dat
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION
(IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
a Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
.O9O
.040
.100
.210
.0
Name Service Order
DEPT FT 4 1 68
GR MWD 8 AAPI 4 1 68
RPX MWD 8 OHMM 4 1 68
RPS MWD 8 OHMM 4 1 68
RPM MWD 8 OHMM 4 1 68
RPD MWD 8 OHM~ 4 1 68
ROP MWD 8 FT/H 4 1 68
FET MWD 8 HOUR 4 1 68
Units Size Nsam Rep Code Offset Channel
0 1
4 2
8 3
12 4
16 5
20 6
24 7
28 8
Name Min Max Mean Nsam
DEPT 10301.5 10449.5 10375.5 297
GR 20.8978 97.5991 36.7823 204
RPX 3.2787 17.2077 7.22936 204
RPS 3.798 22.1069 8.7786 204
R?M 4.1532 24.0106 9.25841 204
RPD 4.7275 24.1465 10.1588 204
ROP 3.7578 200 34.794 204
FET 4.1134 20.7817 10.4595 204
First
Reading
10301.5
10301.5
10308.5
10308.5
10308.5
10308.5
10348
10308.5
69.4
Last
Reading
10449.5
10403
10410
10410
10410
10410
10449.5
10410
First Reading For Entire File .......... 10301.5
Last Reading For Entire File ........... 10449.5
File Trailer
Service name ............. STSLIB.005
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.006
Physical EOF
File Header
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.005
Comment Record
FILE HEADER
FILE NUMBER: 6
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 9
DEPTH INCREMENT: .5000
FILE SUMbiARY
VENDOR TOOL CODE START DEPTH
STOP DEPTH
GR 3615.0 10646.0
ROP 3648.0 10707.5
FET 9153.0 10653.0
RPD 9153.0 10653.0
RPM 9153.0 10653.0
RPS 9153.0 10653.0
RPX 9153.0 10653.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT):
· 03-OCT-97
1.32
5.O3
MEMORY
10710.0
10449.0
10710.0
68.2
24.4
TOOL NUMBER
P0717SP4
P0717SP4
6.000
6.0
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S):
MUD PH:
MUD CHLORIDES (PPM):
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ) :
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
Logging Direction ................. Down
Optical log depth units ........... Feet
Data Reference Point .............. Undefined
Frame Spacing ..................... 60 .liN
Max frames per record ............. Undefined
Absent value ...................... -999.25
Depth Units .......................
Datum Specification Block sub-type...0
6% KCL QUICK DR
8.70
50.0
8.8
31000
6.4
.090
.046
.100
.200
61.4
.0
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 ' 0 1
GR MWD 9 AAPI 4 1 68 4 2
RPX MWD 9 OHMM 4 1 68 8 3
RPS MWD 9 OHMM 4 1 68 12 4
RPM MWD 9 OHMM 4 1 68 16 5
RPD MWD 9 OHMM 4 1 68 20 6
ROP MWD 9 FT/H 4 1 68 24 7
FET MWD 9 HOUR 4 1 68 28 8
Name
DEPT
GR
RPX
RPS
RPM
RPD
ROP
FET
2
2
16
1
Min
10403.5
16 8009
2 1884
2 3779
4328
5827
0955
1403
Max Mean Nsam
10710 10556.8 614
86.3941 31.5761 491
20.4435 5.40608 491
24.3645 6.02469 491
22.5261 6.05782 491
20.8629 6.46944 491
168.246 62.3948 520
18.486 4.16887 491
First
Reading
10403.5
10403 5
10410 5
10410 5
10410 5
10410 5
10450 5
10410 5
Last
Reading
10710
10648.5
10655.5
10655.5
10655.5
10655.5
10710
10655.5
First Reading For Entire File .......... 10403.5
Last Reading For Entire File ........... 10710
File Trailer
Service name ............. STSLIB.006
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 97/10/20
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.007
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 97/10/20
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 97/10/20
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Technical Services
Physical EOF
Scientific
Scientific
Physical EOF
End Of LIS File
