Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout197-186 STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATIOL'21.,~J~[~¥LJ~S~...~ t~ 2003
WELL COMPLETION OR RECOMPLETION'~II~~~i~I~.O~~
Plugged Back for Sidetrack
1. Status of Well Classification of Service Well
[] Oil [] Gas [] Suspended [] Abandoned [] Service
2. Name of Operator 7. Permit Number
BP Exploration (Alaska) Inc. 197-186 302-223
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22818-00
4. Location of well at surface ~T 9. Unit or Lease Name
2920' NSL, 4142' WEL, SEC. 34, T13N, R10E, UM ia.~,.--,~.,~,...~~, ~
o, ,,..ne,o.n.
At total dopth ~H-~
1007' ~Sk, 4~25' Wfik, SfiG. ~5, TI~, ~10fi, ~M -~
11. Fiold and ~l
5. Elovation in foot (indicato KB, DF, ~tc.) ~. koaso Dosi~nation and Sorial ~o. Milno ~oint Unit / Schrader Bluff
KBfi = ~.2' ADk 025518
17. lotal Dopth (MD+~) ~ 18. ~lu~ ~ack Dopth (MD+~D) ~10. Diroctional8u ov 1 20. Dopth Whoro 888V12a. lhicknoss of ~ormafmst
9800 7439 FTI 6~3 4282 "'1 D Yes ~ NoI N/A MDI 1800' (Approx.)
22. Type Electric or Other Logs Run
MWD, LWD, EMSS, G~JB, G~CCL
23. CASING~ LINER ~D CEMENTING RECORD
CASING S~ING DEPTH HOLE
SIZE WT. PER FT. G~DE TOP BOSOM S~ZE CEMENTING RECORD AMOUNT PULLED
20" 91.1~ H-40 32' 112' 24" 250 SX Arcticset I (Approx.)
9-5/8" 40ff L-80 31' 6618' 12-1/4" 19~ sx PF 'E', 278 sx 'G', 200 sx PF 'C'
24. Pedomtions open to Pr~uction (MD+~D of Top and 25. TUBING RE. RD
BoEom and intewal, size and number) S~ZE DEPTH S~ (MD) PACKER S~ (MD)
None None
MD ~D MD ~D
26. ACID, F~CTURE, CEMENT SQUEAL, ~C.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
5902' Set ES~
5902' P~ with 61 Bbls Class G (below ES~)
3905' ~t ~SV Bddge Plug ~th ~ipst~k on Top.
27. PRODUCTION TEST
Date First Production Meth~ of Operation (Flowing, gas lift, etc.)
Not on Pr~uction N/A
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL ~TIO
TEST PERIOD
I
;Iow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL O~L G~w~-API (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.
samples taken. RE EIVED
No core were ~
OCT 1 5 2002
Form 10-407 Rev. 07-01-80 RB[ S BFL OCT 2l 2002 SubmitlnDuplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids recovered
Marker Name
Depth Depth and gravity, GOR, and time of each phase.
TSBF 6036' 3966'
SBF1 6072' 3994'
TSBD 6238' 4122'
TSBB 6320' 4186'
31. List of Attachments: Summary of Daily Drilling Reports
32. I hereby certify that the f~egoing is true and correct to the best of my knowledge
Signed Sondr~.r.,.- Titl_e Technical Assistant Date 1(,.~-[ ' ~ ~,,.~
MPH-13 197-186 302-223 Prepared By Name/Number: Sondra Stewrnan, 564-4750
Well Number Permit No. / Approval No. D#/ling Engineer: Robert Odenthal, 564-4387
iNSTRUCTIONS
GENEI~u~.: 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 A~D 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
Legal Well Name: MPH-13
Spud Date:
Common Well Name: MPH-13 ~C~i~N~a~AY ~ '~ '~2002 End: 7/25/2002
Event Name: TEMP ABANDON
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/25/2002
Rig Name: NABORS 4ES Rig Number: 4ES
Date From- To Hours TaSki~CO~
7/23/2002 06:00 - 12:00 6.00 RIGU p PRE MI/RD/& SAFE OUT EQUIPMENT, RIG ACCEPT @ 1200
HRS. 712312002
12:00-14:00 2.00 KILL P INTERV RIG LINES TO TREE & TIGER TANK & TEST TO 3000 PSI.
14:00 - 15:00 1.00 KILL iP INTERV RIG LUB & PULL BPV
15:00 - 18:00 3.00 KILL P INTERV CIRC WELL BORE INFLUX OUT WITH SEAWATER
18:00 - 19:30 1.50 i WHSUR P INTERV SET TWC & NIPPLE DN TREE.
19:30 - 21:00 1.50 BOPSUF P INTERV NIPPLE UP BOP
21:00 - 23:00 2.00 BOPSUF P INTERV TEST BOP TO 250~3500 BODY TEST ONLY. (TEST WAIVED
BY CHUCK SHEVE WITH AOGC.
23:00 - 00:00 1.00 BOPSUF P INTERV RIG LUB & PULL TWC
7~24~2002 00:00 - 01:30 1.50 PULL P INTERV MU LANDING JT. & PULL HANGER TO FLOOR & LAY DN
SAME.
01:30 - 11:00 9.50 PULL P INTERV POOH LAYING DN ESP COMPLETION TBG. Y-TOOL &
HEAT TRACE TAPE. ETC.
11:00 - 13:00 2.00 PULL P INTERV CLEAN RIG FLOOR OF EQUIPMENT USED TO PULL ESP
EQUIPMENT.
113:00 - 19:30 6.50 CLEAN P INTERV MU BHA # 1 MULE SHOE+I I-JTS. 2-7/8" PAC+9-5/8"
SCRAPER + UPPER WATER MELON MILL DRIFT FOR
SIDETRACK PURPOSE.& RIH & TAG @ 6010'
19:30 - 22:00 2.50 CLEAN P INTERV REVERSE ClRC THROUGH SCREENS ON "N" SANDS &
CLN-OUT TO BELOW BOTTOM PERF.@ 6335'
(RECOVERED LOST CIRC MATERIAL)
22:00 - 22:30 0.50 CLEAN P INTERV ESTABLISH INJECTION RATE INTO FORMATION OF 4-BPM
@ 1000 PSI. & MONITOR WELL (FLOWING SHUT IN GET
SIP )
22:30- 00:00 1.50 CLEAN P INTERV RAISE BRINE VVT. TO 9.0 PPG.
7/25/2002 00:00- 02:00 2.00 CLEAN P INTERV CIRC & RAISE BRINE W-F. TO 9.0 PPG. & MONITOR
(STATIC)
02:00 - 06:00 4.00 CLEAN P INTERV POOH & LAY DN CLN-OUTASSY. & 8.510" UPPER
WATERMELON MILL USED AS DRIFT FOR SIDE TRACK
PREP
06:00 - 08:30 2.50 TA P INTERV MU HES 9-5~8" ESZV & RIH TO 5902'
08:30 - 11:00 2.50 TA P INTERV SET ESZV @ 5902' ESTABLISH INJ. RATE @ 4-BPM 1200
PSI. & PUMP 61 BBL. CL. "G" 15.8 PPG. CMT. UNDER
RETAINER & UNSTING & REVERSE 2-DO'I-rOMS UP CMT
RETURNS APP 1-BBL. TEST RETAINER TO 2500 PSI.
(GOOD TEST)
11:00 - 13:00 2.00: TA P INTERV POOH LAYING DN DP TO 2200'
13:00 - 15:00 2.001 TA P INTERV FREEZE PROTECT WELL WITH DIESEL TO
SURFACE.O'-TO 2200'
15:00 - 16:30 1.50 TA P INTERV POOH LAYING DN 3.5" DP & RETAINER SETTING TOOL.
16:30 - 19:30 3.00 TA P INTERV RIG SWS & RIH WITH HES BRIDGE PLUG & GR/CCL & TIE
INTO ATLAS GR/CCL DATED 5/31/1998 AND LOG UP &
FIND THAT COLLAR THAT FIT PROGRAM BEST WAS AT
3910' & SET RETAINER WITH TOP @ 3905' POOH AND RIG
DN SWS. REF. LOG FOR SETTING IS SWS DATED
7~25~2002
t9:30 - 20:00 0.50 TA P INTERV SET HANGER & RILDS & TEST TO 5000 PSI.
20:00 - 21:00 1.00 BOPSUR P INTERV NIPPLE DN BOP
21:00 - 22:00 1.00 WHSUR P INTERV NIPPLE UP TREE & TEST TO 5000 PSI. & SECURE WELL.
RIG RELEASED @ 2200 HRS. 7/25/2002
Printed: 10/9/2002 5:57:47 PM
STATE OF ALASKA "'-'"~
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVAL
~[7"~ 7/p_/3
1. Type of Request:
[] Abandon
[] Alter Casing
[] Change Approved Program
2. Name of Operator
BP Exploration (Alaska) Inc.
[] Suspend
[] Repair Well
[] Operation Shutdown
3. Address
P.O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
2920' NSL, 4142' WEL, SEC. 34, T13N, R10E, UM
At top of productive interval
1740' NSL, 407' WEL, SEC. 34, T13N, R10E, UM
At effective depth
1684' NSL, 293' WEL, SEC. 34, T13N, R10E, UM
At total depth
1907' NSL, 4625' WEL, SEC. 35, T13N, R10E, UM
Type of well:
Ila Development
[] Exploratory
[] Stratigraphic
[] Service
[] Plugging [] Time Extension [] Perforate
[] Pull Tubing [] Vadance [] Other
[] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack
6. Datum Elevation (DF or KB)
KBE = 66.2'
7. Unit or Property Name
Milne Point Unit
8. Well Number
MPH-13
9. Permit Number
197-186
10. APl Number
50- 029-22818-00
11. Field and Pool
Milne Point Unit / Schrader Bluff
12.
Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
9800 feet
7439 feet
6443 feet
4282 feet
Length
Size
80' 20"
6587' 9-5/8"
Plugs (measured) 9-5/8" EZSV with 2 bbls of 'G' cement was set at 6443'.
Junk (measured)
Cemented MD
250 sx Arcticset I (Approx.) 112'
1948 sx PF 'E', 278 sx 'G', 374 sx PF 6618'
TVD
112'
4421'
RECEIVED
Perforation depth: measured 6082'- 6102', 6246' - 6266', 6324'- 6344'
true vertical 4002' - 4017', 4128' - 4144', 4189' - 4205'
Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 5879'
JUL 1 7 2002_
Alaska Oil & Gas Cons.
Anchora0je
Packers and SSSV (type and measured depth) 9-5/8" HES Versatrieve packer at 6024' and a 9-5/8" HES BWD sump packer at 6107'.
13. Attachments
[] Description Summary of Proposal [] Detailed Operations Program [] BOP Sketch
4. Estimated date for commencing operation 115. Status of well classifications as:
July 24, 2002 I [] Oil I"! Gas I-I Suspended
16. If proposal was verbally approved
Service
Name of approver Date Approved
Contact Engineer Name/Number: Robert Odenthal, 564-4387 Prepared By Name/Number: Sondra Stewman, 564-4750
117. I hereby certify that-fl:te.~regoing is true a.nd co),f~ct to the best of my knowledge
Signed RobertOden ~,~-~'~-'~~ Title Drilling Engineer Date
IConditionsof Approval: Notify Commission so representative m,a~ytwitness NO.
Approval
Plug integrity BOP Test ~ Location clearance __
J Mechanical lntegrity Test 'Subsequentformrequiredl0-d07 Q.,~+e-.v" ~.~,,~'~,.~ ~'~'~'~/~"'"'"'")l _
T~+ '~0~)/~ lLO01~lc~3~l~, Date
Approved by order of the Commission Commissioner .
Form 10-403 Rev. 06/15/88 ~;~'-~YC~'~i' ~ i j~! //~ J Submit InTripli~ate
bp
To: Winton Aubert, AOGCC Date: July 17, 2002
From: Robert Odenthal
Subject: Abandonment of H-13 for Sidetrack
Please find enclosed the application for Sundry and present and osed well diagram
for the abandonment and prep for sidetrack for MPH-13. lat/ease find below the
overview of the well program.
Operations to begin Wednesday July 24, 2000
SCOPE:
.
5.
6.
7.
8.
9.
10.
11.
12.
MIRU N4ES.
ND Tree/NU BOPE.
Retrieve ESPCP and heat trace.
RIH with scraper to 6000' MD.
RIH with cement retainer.
Set retainer at 5~920' MD.
Pump 60 bbls'of 15.9 ppg Class G cement (1.15 cuft/sk).
Unsting from cement retainer and test to 2500 psi. f
RIH and set CIBP at xxxx" (Drilling is determining KO point for ST and will inform
at a later date before starting operations)
Freeze protect well.
ND BOPE/NU Tree.
RDMO N4ES.
If you have any questions or need for any additional Information please call me at 564-
4387 or 440-0185.
Sincerely,
Robert Odenthal
ACT Workover Engineer
564-4387
Tree: Cameron 2 9/1
Wellhead: 11" x 11" ~ Gan 6,
W~ 11" x 2 7/8" FMC tb9. hng., 2
EUE NSCT T&B, 2.5" ClW BPV profile
MPU H-13
}Elev.: 66.0' (N 22E)
Bev. = 36.7'
Odg. DF to csg. hgt. = 30.62' (N 22E
20" 91.1 ppf, H~0
KOP ~ 400'
Max. hole angle = 68 to 40 deg,
f/3100' - 4900'
liole angle thru' peRs = 39 deg.
Camco 2 7/8" x 1"
sidepocket KBMM GLM
115' md I
Raychem heat trace cable to 2260'
Howco 7" "ES" Cementer [ 2113' md ]
2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.
(drift lB = 2,347", cap, = 0,00592 bpf )
Purer) Assembly:
Trico 3.5" "Y" tool
Centilift ESPCP pump
Type 200TP1800
Centrilif~ flex shaft adapter
Centrilift seal section
GSTDBIL
Gear reduction unit
Centrilift Motor GMF
(63 HP, 1560v/26amp)
5806' md
5817' md
[ 5846' md ]
1 5868' md I
] 5869' md I
9 5/8 40 ppf, L-80, BTC mod prod. csg.
( drift lb = 8.835", cap. = 0.0758 bpf )
Stimulation Summary
05/31/98- 'OB' Sand PropLok frac,
72.5 M# 12-20 Ottawa sand behind pipe
06/02/98 - 'OA' Sand PropLok frac,
17,8 M# 12~20 Ottawa sand behind pipe
06/07/98 ~ 'N' Sand Frac Pack, 75.0 M#
16/20 Carbolite behind pipe
Perforation Summary
Refloo: 5/31/98 Atlas GPJCCL
Size SPF Intervat (TVD)
4.5 12 'N' Sand'
6082' - 6102' 4002' - 4017'
'OA' Sand'
4.5 ~ 4 6246' - 6266' 4128' - 4144'
t
'OB' Sand'
4.5 4 6324' - 6344' 4189' - 4204'
IJumbo Jet ("big hole") charges @ 0 - 180
deg. phasing on 'OA' and 'OB' sands
Jumbo Jet ("big hole") charges @ 45/135
deg. phasing on 'N' sand
Camco 2 7/8" x 1" I I
5753'
md
sidepocket KBMM GLM
Y-Tool Assembly:
2-7/e" XN Nipple 2.313' ID [ 5815' md ]
2.205" no~3o
2-7/8" WLEG [5878' md--~
9 5/8" HES Versatrieve pkr. I 6024' md ]
J
Closing sleeve ass'biy
4.5", 12.6 ppf, N-80, NU [6076' md 1
blank pipe (ID = 3.958")
4.5", 0.020" Ga. pre-pack
screen (ID =3.958") [ 6106' md ]
tIES, seal unit (ID = 3.880")
4.5" .XN' npL (3.813" nogo)
9 5/8' HES 'BWD' sump pkr.[
9 5/8" HES EZSV retainer
W/2 Bbls cement above
9 5/8' landing collar
9 5/8' float collar
· 9 5/8' float shoe
Open hole
Cement plug 9,800' ~ 8.682'
Well TD C~. 9,800
6108' md
6112' md
6107' wlm
6538' md
6,532,' md
6,575, m~
I
DATE REV. BY COMMENTS
10-22-97 MDO Nabors 22-E
06/09/98 JBF Initial ESP Completion by Nabors 4ES
MILNE POINT UNIT
WELL No: H-13i
~S~ ~1 [,50-029-22818
BP EXPLORATION qAKI
;,
Tree: Cameron 2 9/16" 5M
Wellhead: 11" x 11" 5M FMC Gen 6,
w/11" x 2 7/8" FMC tbg. hng., 2 7/8"
EUE NSCT T&B, 2.5" ClW BPV profile
20" 91.1 ppf, H-40 I 112'
KOP @ 400'
Max. hole angle = 68 to 40 deg.
f/3100' - 4900'
Hole angle thru' perfs = 39 deg.
2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg.
(drift ID: 2.347", cap.: 0.00592 bpf )
MPU H-13 Proposed
Orig. DF Elev. = 66.0' (N 22E)
Orig. GL Elev. = 36.7'
Orig. DF to csg. hgr. = 30.62' (N 22E)
Howco 7" "ES" Cementer 12113' md I
Cast Iron Bridge Plug I ????? I
Cast Iron Bddge Plug I 5920' MD I
9 5/8 40 ppf, L-80, BTC mod prod. csg.
( ddff ID = 8.835", cap. = 0.0758 bpf )
.,S,,,timulation Summa ,ry
05/31/98- 'OB' Sand PropLok frac,
72.5 M# 12-20 Ottawa sand behind pipe
06/02/98- 'OA' Sand PropLok frac,
17.8 M# 12-20 Ottawa sand behind pipe
06/07~98- 'N' Sand Frac Pack, 75.0 M#
16/20 Carbolite behind pipe
Perforation Summary
Ref log: 5131198 Atlas GR/CCL
Size
4.5
4.5
4.5
SPF
12
4
4
Interval
'N' Sand'
6082' - 6102'
'OA' Sand'
6246' - 6266
'OB' Sand'
6324' - 6344
CrVD)
4002'-4017'
4128'-4144'
4189'-4204'
Jumbo Jet("big hole")cha~es@0-180
deg. phasing on'OA'and'OB'sands
Jumbo Jet("big hole")cha~es@4~135
deg. phasing on'N'sand
60 bbbls of Class "G" Cement
I
I
9 5/8" HES Versatrieve pkr. 16024' md I
Closing sleeve ass'bly
4.5", 12.6 ppf, N-80, NU
blank pipe (ID = 3.958")
6076' md I
4.5", 0.020" Ga. pre-pack
screen (ID =3.958")
I6106' md I
HES seal unit (ID = 3.880")
4.5". 'XN' npl. (3.813" no go)
9 5/8" HES 'BWD' sump pkr.
6108' md
6112' md
6107' wlm
9 5/8" HES EZSV retainer
WI 2 Bbls cement above
9 5/8" landing collar
9 5/8' float collar
9 5/8" float shoe
Open hole
Cement plug 9,800'- 8,682'
Well TD (~. 9,800'
6538' md
6,532' md
6,575' md
6,618' md
DATE REV. BY COMMENTS
10-22-97 MDO Nabors 22-E
06/09/98 JBF Initial ESP Completion by Nabors 4ES
7/16/2002 RSO H-13 Proposed
MILNE POINT UNIT
WELL No: H-13i
APl: 50-029-22818
BP EXPLORATION IAK!
0 F! I I_1_11~ r= SIz:FIVI C E S
WELL LOG TRANSM]3~AL
To: State of Alaska August 19, 1998
Alaska Oil and Gas Consevvafion Comm.
Atm.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs
MPH-13, AK-MM-70287
1 LDWG formatted LIS tape with verification listing.
API#: 50-029-22818-00
PLEASE ACKNOWLEDGE RECEIV[ BY SIGNING AND RETURNING THE ATFACHED COPIES
OF THE TRANSMrVFAL LE~FER TO THE ATTENTION OF:
Sperry-Stm Drilling Services
Attr~ Ali Turker
5631 Silverado Way, Suite G.
Anchorage, Alaska 99518
BP Exploration (Alaska) Inc.
Petro-technical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
RECE. VED
Anchorage
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252
A Division of Dresser Industries, In¢,
GeoQuest
500 W. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrle
NO. 11398
Company:
Field:
Alaska OII & Gas Cons Comm
Attn: LOrl'TaYlor
3001 porcupine Drive
Anchorage, AK 99501
:
MIIne Point (Cased Hole)
8/4/98
Well Job # Log Description Date BL RF Sepia LIS Tape
MP.-13 ~1~ ~~ 98397 GR/CCL 980531 1
MPL-40 ~~"~ J 98399 GR/CCL 980508 1
,
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:
REuE VED
Schlumberger GeoQuest
500 W. International Airport Road
Anchorage, Al~9618-119.~ ....,
Receive~ ~
Well Compliance Report
File on Left side of folder
197-186-0
50- 029-22818-00
BP EXPLORATION
M~POINT UNIT SB H-13
MD 09800 TVD 07439 b~Completion Date: 6/9/98 Completed Status: 1-OIL Current:
Name Interval Sent Received T/C/D
D 8498 ~ SPERRY MPT/GR/EWR4/CNP/SLD OH 8/19/98 8/19/98
L DGR/CNP/SLD-MD
L DGR/CNP/SLK-TVD
L DGR/EWR4-MD
L DGR/EWR4-TVD
L GR/CCL PERF
L GR/CCL-DEPTH
L STAT PRES SRVY
R MWD SRVY
T 8592
Daily Well Ops~/3¢?
Was the well cored? yes
~q~qAL 112-9800 OH 9/2/98 9/2/98
-~AL 112-7439 OH 9/2/98 9/2/98
~AL 112-9800 OH 9/2/98 9/2/98
~AL 112-7439 OH 9/2/98 9/2/98
h~AL 5940-6200 CH 5 6/12/98 6/15/98
~AL 4992-6535 CH 5 6/12/98 6/15/98
.~l~AL 6334 CH 5 6/12/98 6/15/98
~P'~E~Y 112-9800. OH 8/12/98 8/13/98
~ SCHLUM GR/CCL/PDC CH 8/4/98 8/6/98
__ 6/3v/c~ Are Dry Ditch Samples Required? ye~___.~-- And Receivedq-3, es no
Analysis Description Re~ yes no - Sampl~
Comments:
Tuesday, May 30, 2000 Page 1 of I
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
[~ Oil I--I Gas [--] Suspended F-I Abandoned [~ Service
2. Name of Operator 7. Permit Number
BP Exploration (Alaska) Inc, 97-186
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22818
4. Location of well at surface I~" 9. Unit or Lease Name
2920 NSL, 4142' WEL, SEC. 34, T13N, R10E, UM ; .,h~!/.'::~;.. :: i ~ . Milne Point Unit
At top of productive interval J.~__~/~ ...... i!!'~~.~ 10. Well Number
1788' NSL, 500' WEL, SEC. 34, T13N, R10E, UM '------~ i MPH-13
At total depth .ii u~n,~-,~, '-~ 11. Field and Pool
1908' NSL, 656' EWL, SEC. 35, T13N, R10E, UM,
Milne
Point
Unit/
Schrader
Bluff
,
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease'Et~'§~rtatiOr~-~nd Serial No.
KBE = 66.04'I ADL 025518
12. Date Spudded10/2/97 I 13' Date I'D' Reached ! 14' Date C°mp" Susp" °r Aband'l15' Water depth' if Offsh°re I 16' NO' Of COmpleti°nsl 0/12/97 6/9/98 N/A MSLI One
17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost
9800 7439 FTI 6443 4282 FTI [~Yes [~ NoI N/A MD 1800' (Approx.)
~22. Type Electric or Other Logs Run
MWD, LWD, EMSS, GR/JB, GR/CCL
23. CASING~ LINER AND CEMENTING RECORD
CASING SE'I-rING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED
20" 91.1# H-40 32' 112' 24" 250 SX Arcticset I (Approx.)
9-5/8" 40# L-80 31' 6618' 12-1/4" 1948 sx PF 'E', 278 sx 'G', 200 sx PF 'C'
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)
4-1/2" Gun Diameter, 4 spf 4-1/2" Gun Diameter, 12 spf 2-7/8", 6.5#, L-80 5879'
MD TVD MD TVD '.'
6246'-6266' 4128'-4144' 6082 '-6102' 4002'-4017'
6324'-6344' 4189'-4205' 26. AO~D, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
See Attachment
~ i--~ I ~ ~ ~ ~ , .
27. PRODUCTION TESTt J .i-( Ii ' 11\1/3 I
Date First Production I Method of Operation (Flowing, gas lift, etc.) - "' ' ~ "~ I L,,,
June 23, 1998I Electric Submersible Pump
Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-eEL CHOKE SIZE I GAs-OIL RATIO
TEST PERIOD
I
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.
-':\/as/~ 0ii ,%',
/4 nr,~.. - '-'."'
Form 10-407 Rev. 07-01-80
Submit In Duplfcate
D.
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.
TSBF 6036' 3966'
SBF1 6072' 3994'
TSBD 6238' 4122'
TSBB 6320' 4186'
:~1. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certify~ going ~s t.[ rrect tO-~l~est of my knowledge
... T. Drilling Engineering Supervisor Date
/
MP~-~3 -7 ' ' / ~" 97-186 Prepared By Name/Number: Kathy Campoamor, 564-5122
Well Number 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'.
Alaska Oil & Gas Cons. Commission
Anchorage
Form 10-407 Rev. 07-01-80
Progress Report
Facility M Pt H Pad
Well MPH- 13
Rig Nabors gt38 ~%~
Page 1
Date 03 August 98
Date/Time
30 Sep 97 21:01-21:30
21:30-22:00
22:00-00:00
01 Oct 97 00:00-04:00
04:00-06:00
06:00-08:30
08:30-09:00
09:00-15:30
15:30-20:00
20:00-20:30
20:30-21:00
21:00-02:00
02 Oct 97 02:00-06:00
06:00-01:00
03 Oct 97 01:00-02:00
02:00-04:00
04:00-05:00
05:00-06:00
06:00-07:00
07:00-08:00
08:00-10:00
10:00-20:30
20:30-23:30
23:30-00:00
04 Oct 97 00:00-00:30
00:30-01:00
01:00-01:30
01:30-02:00
02:00-03:00
03:00-06:00
06:00-13:30
13:30-15:30
15:30-19:00
19:00-19:30
19:30-22:00
22:00-06:00
05 Oct 97 06:00-09:00
09:00-09:30
09:30-10:30
10:30-22:00
22:00-00:00
06 Oct 97 00:00-02:30
02:30-03:30
03:30-06:00
06:00-08:00
08:00-11:00
11:00-14:00
14:00-15:30
15:30-22:30
22:30-01:30
07 Oct 97 01:30-02:30
02:30-03:30
03:30-06:00
06:00-08:00
Duration
1/4 hr
1/2 hr
2hr
4hr
2hr
2-1/2 hr
1/2 hr
6-1/2 hr
4-1/2 hr
1/2 hr
1/2 hr
5hr
4hr
19hr
lhr
2hr
lhr
lhr
lhr
lhr
2hr
10-1/2 hr
3hr
1/2 hr
1/2hr
1/2 hr
1/2 hr
1/2 hr
lhr
3hr
7-1/2 hr
2hr
3-1/2 hr
1/2hr
2-1/2 hr
8hr
3hr
1/2 hr
lhr
11-1/2 hr
2hr
2-1/2 hr
lhr
2-1/2 hr
2hr
3hr
3hr
1-1/2 hr
7hr
3hr
lhr
lhr
2-1/2 hr
2hr
Activity
Rig moved 0.00 %
Held safety meeting
Rig moved 15.00 %
Rig moved 60.00 %
Rig moved 75.00 %
Rig moved 100.00 %
Rig moved 100.00 %
Rigged up Divertor
Serviced Block line
Tested Divertor
Held safety meeting
Made up BHA no. 1
Drilled to 382.0 ft
Drilled to 2489.0 ft
Circulated at 2489.0 ft
Pulled out of hole to 0.0 ft
Downloaded MWD tool
Made up BHA no. 1
Set tool face
Serviced Top drive
R.I.H. to 2489.0 ft
Drilled to 3799.0 ft
Pulled out of hole to 2150.0 ft
Backreamed to 1844.0 ft
Pulled out of hole to 1016.0 ft
Serviced Top drive
R.I.H. to 2350.0 ft
Reamed to 2485.0 ft
R.I.H. to 3799.0 ft
Drilled to 4085.0 ft
Drilled to 4944.0 ft
Ckculated at 4944.0 ft
Pulled out of hole to 1016.0 ft
Serviced Top drive
R.I.H. to 4944.0 ft
Drilled to 5611.0 ft
Drilled to 5897.0 ft
Circulated at 5897.0 ft
Pulled out of hole to 4750.0 ft
Drilled to 6640.0 ft
Circulated at 6640.0 ft
Pulled out of hole to 1016.0 ft
Serviced Top drive
R.I.H. to 6640.0 ft
Circulated at 6640.0 ft
Pulled out of hole to 1016.0 ft
Pulled BHA
Rigged up Casing handling equipment
Ran Casing to 6617.0 ft (9-5/8in OD)
Circulated at 6617.0 ft
Mixed and pumped slurry - 374.300 bbl
Displaced slurry - 495.500 bbl
Circulated at 2229.0 ft
Circulated at 2229.0 ft
Facility
M Pt H Pad
Progress Report
Well MPH-13 Page 2
Rig Nabors ~Q~.~4~ Date 03 August 98
Date/Time
08 Oct 97
09 Oct 97
10 Oct 97
11 Oct 97
12 Oct 97
08:00-09:30
09:30-10:30
10:30-16:00
16:00-18:00
18:00-19:00
19:00-00:00
00:00-01:30
01:30-06:00
06:00-10:30
10:30-16:00
16:00-20:00
20:00-22:00
22:00-00:00
00:00-01:00
01:00-06:00
06:00-08:30
08:30-09:30
09:30-12:00
12:00-15:30
15:30-16:00
16:00-20:00
20:00-23:30
23:30-04:00
04:00-06:00
06:00-08:00
08:00-11:00
11:00-12:00
12:00-15:00
15:00-22:30
22:30-00:00
00:00-00:30
00:30-01:30
01:30-02:00
02:00-06:00
06:00-11:00
11:00-12:00
12:00-13:00
13:00-13:30
13:30-14:00
14:00-14:30
14:30-01:00
01:00-02:30
02:30-03:30
03:30-04:30
04:30-06:00
06:00-06:30
06:30-09:30
09:30-13:00
13:00-14:00
14:00-17:00
17:00-19:30
19:30-20:00
20:00-21:00
21:00-22:30
Duration
1-1/2 hr
lhr
5-1/2 hr
2hr
lhr
5hr
1-1/2 hr
4-1/2 hr
4-1/2 hr
5-1/2 hr
4hr
2hr
2hr
lhr
5hr
2-1/2 hr
lhr
2-1/2 hr
3-1/2 hr
1/2 hr
4hr
3-1/2 hr
4-1/2 hr
2hr
2hr
3hr
lhr
3hr
7-1/2 hr
1-1/2 hr
1/2hr
lhr
1/2 hr
4hr
5hr
lhr
lhr
1/2 hr
1/2 hr
1/2 hr
10-1/2 hr
1-1/2 hr
lhr
lhr
1-1/2 hr
1/2hr
3hr
3-1/2 hr
lhr
3hr
2-1/2 hr
1/2 hr
lhr
1-1/2 hr
Activity
Mixed and pumped slurry - 270.000 bbl
Circulated at 2229.0 ft
Circulated at 2229.0 ft
Mixed and pumped slurry - 513.800 bbl
Displaced slurry - 229.000 bbl
Wait on cement
Rigged down Cement head
Wait on cement
Wait on cement
Installed Rig services
R.I.H. to 1502.0 ft
Set Retrievable packer at 55.0 ft with 0.0 psi
Rigged down Divertor
Rigged up Casing head
Rigged up BOP stack
Installed BOP stack
Installed BOP stack
Mixed and pumped slurry - 30.000 bbl
Tested BOP stack
Pulled out of hole to 0.0 ft
Tested Other sub-surface equipment - Via annulus
Performed cement integrity test
Performed formation integrity test
Pulled out of hole to 885.0 ft
Pulled out of hole to 0.0 ft
Made up BHA no. 4
Serviced Top drive
R.I.H. to 3270.0 ft
Drilled to 7653.0 ft
Circulated at 7653.0 ft
Pulled out of hole to 6601.0 ft
Serviced Block line
R.I.H. to 7653.0 ft
Drilled to 8128.0 ft
Drilled to 8701.0 ft
Circulated at 8701.0 ft
Pulled out of hole to 6601.0 ft
Serviced Top drive
Held safety meeting
R.I.H. to 8701.0 ft
Drilled to 9800.0 ft
Circulated at 9800.0 ft
Pulled out of hole to 6601.0 ft
R.I.H. to 9800.0 ft
Circulated at 9800.0 ft
Dropped EMSS survey barrel
Pulled out of hole to 945.0 ft
Pulled BHA
Serviced Top drive
R.I.H. to 9800.0 ft
Mixed and pumped slurry - 78.500 bbl
Pulled Drillpipe in stands to 7800.0 ft
Circulated at 7800.0 ft
Pulled Drillpipe in stands to 3050.0 ft
Facility
Date/Time
13 Oct 97
M Pt H Pad
Progress Report
Well MPH- 13
Rig Nabors ~-~,~
Page
Date
Duration
Activity
22:30-00:30
00:30-06:00
06:00-07:00
07:00-08:00
08:00-09:00
09:00-10:00
10:00-11:00
11:00-13:00
13:00-14:00
14:00-15:30
15:30-17:00
17:00-21:00
21:00-02:00
2hr
5-1/2 hr
lhr
lhr
lhr
lhr
lhr
2hr
lhr
1-1/2 hr
1-1/2 hr
4hr
5hr
Laid down 3050.0 ft of 5in OD drill pipe
Ran Drillpipe in stands to 6528.0 fl
Ran Drill collar in stands to 6538.0 ft
Circulated at 6538.0 ft
Mixed and pumped slurry - 22.000 bbl
Circulated at 6443.0 ft
Circulated at 6443.0 ft
Pulled out of hole to 2800.0 ft
Circulated at 2800.0 ft
Circulated at 2800.0 ft
Pulled out of hole to 0.0 fl
Rigged down BOP stack
Installed Xmas tree primary components
3
03 August 98
Progress Report
Facility M Pt H Pad
Well MPH- 13
Rig Nabors 4ES
Page 1
Date 03 August 98
Date/Time
28 May 98 18:00-22:00
22:00-00:00
29 May 98 00:00-04:00
04:00-06:00
06:00-11:00
11:00-12:30
12:30-13:00
13:00-18:00
18:00-20:00
20:00-04:00
30 May 98 04:00-05:00
05:00-06:00
06:00-06:15
06:15-06:30
06:30-07:00
07:00-10:00
10:00-11:00
11:00-16:30
16:30-18:30
18:30-21:00
21:00-22:30
22:30-23:00
23:00-01:00
31 May 98 01:00-01:30
01:30-02:30
02:30-03:30
03:30-03:45
03:45-04:00
04:00-06:00
06:00-06:30
06:30-08:30
08:30-10:00
10:00-12:30
12:30-13:00
13:00-13:30
13:30-14:00
14:00-16:00
16:00-17:00
17:00-18:30
18:30-19:00
19:00-19:30
19:30-20:00
20:00-23:15
23:15-00:00
01 Jun 98 00:00-06:00
06:00-10:00
10:00-10:15
10:15-10:45
10:45-11:00
11:00-11:30
11:30-14:00
14:00-15:00
15:00-15:30
15:30-15:45
Duration
4hr
2hr
4hr
2hr
5hr
1-1/2 hr
1/2 hr
5hr
2hr
8hr
lhr
lhr
1/4 hr
1/4hr
1/2 hr
3hr
lhr
5-1/2 hr
2hr
2-1/2 hr
1-1/2 hr
1/2 hr
2hr
1/2 hr
lhr
lhr
1/4 hr
1/4hr
2hr
1/2 hr
2hr
1-1/2 hr
2-1/2 hr
1/2hr
1/2hr
1/2 hr
2hr
lhr
1-1/2 hr
1/2hr
1/2hr
1/2 hr
3-1/4 hr
3/4 hr
6hr
4hr
1/4 hr
1/2hr
1/4 hr
1/2 hr
2-1/2 hr
lhr
1/2 hr
1/4 hr
Activity
Rig moved 100.00 %
Rigged up Drillfloor / Derrick
Fill pits with Brine
Removed Tubing head spool
Removed Tubing head spool (cont...)
Installed Tubing head spool
Tested Tubing head spool
Installed BOP stack
Tested All functions
Installed BOP stack
Tested Annular preventor
Installed Wear bushing
Held safety meeting
Serviced Drillfloor / Derrick
Made up BHA no. 1
R.I.H. to 2400.0 ft
Reverse circulated at 2400.0 ft
R.I.H. to 6533.0 ft
Reverse circulated at 6533.0 ft
Reverse circulated at 6533.0 ft
Tested Casing - Via annulus
Laid down 438.0 ft of 3-1/2in OD drill pipe
Pulled out of hole to 10.0 ft
Pulled BHA
Installed Lubricator
Rigged up Lubricator
Test Lubricator unit
Held safety meeting
Conducted electric cable operations
Conducted electric cable operations (cont...)
Perforated from 6324.0 ft to 6344.0 ft
Conducted electric cable operations
Conducted electric cable operations
Rigged down Logging/braided cable equipment
Rigged up Bell nipple
Serviced Block line
Ran Tubing in stands to 6100.0 ft
Reverse circulated at 6100.0 ft
Rigged up High pressure lines
Held safety meeting
Tested High pressure lines
Injectivity test - 175.000 bbl injected at 3272.0 psi
FRAC job - 200.000 bbl injected at 3412.0 psi
FRAC job - 528.000 bbl injected at 3541.0 psi
Monitor wellbore pressures
Monitor wellbore pressures (cont...)
Bleed down well
Reverse circulated at 6100.0 ft
Monitor wellbore pressures
Ran Tubing to 6286.0 ft (3-1/2in OD)
Washed to 6300.0 ft
Reverse circulated at 6300.0 ft
Flow check
Circulated at 6300.0 ft
Facility
Date/Time
02 Jun 98
03 Jun 98
04 Jun 98
M Pt H Pad
15:45-16:00
16:00-16:30
16:30-18:00
18:00-19:00
19:00-20:00
20:00-21:30
21:30-22:15
22:15-22:30
22:30-00:30
00:30-03:00
03:00-03:30
03:30-04:00
04:00-06:00
06:00-06:15
06:15-07:00
07:00-09:00
09:00-09:30
09:30-10:30
10:30-10:45
10:45-11:00
11:00-12:00
12:00-13:00
13:00-13:30
13:30-15:30
15:30-16:00
16:00-16:15
16:15-16:30
16:30-17:00
17:00-17:30
17:30-18:00
18:00-21:00
21:00-22:30
22:30-06:00
06:00-10:30
10:30-11:00
11:00-15:00
15:00-15:30
15:30-15:45
15:45-16:00
16:00-21:00
21:00-21:30
21:30-22:00
22:00-22:15
22:15-02:30
02:30-06:00
06:00-06:15
06:15-12:00
12:00-13:00
13:00-16:00
16:00-16:30
16:30-21:15
21:15-21:30
21:30-22:30
22:30-23:30
Progress Report
Well MPH-13 Page 2
Rig Nabors 4ES Date 03 August 98
Duration
1/4 hr
1/2 hr
1-1/2 hr
lhr
lhr
1-1/2 hr
3/4 hr
1/4hr
2hr
2-1/2 hr
1/2 hr
1/2 hr
2hr
1/4 hr
3/4 hr
2hr
1/2 hr
lhr
1/4 hr
1/4 hr
lhr
lhr
1/2 hr
2hr
1/2 hr
1/4 hr
1/4 hr
1/2 hr
1/2 hr
1/2 hr
3hr
1-1/2 hr
7-1/2 hr
4-1/2 hr
1/2 hr
4hr
1/2 hr
1/4hr
1/4 hr
5hr
1/2 hr
1/2 hr
1/4 hr
4-1/4 hr
3-1/2 hr
1/4 hr
5-3/4 hr
lhr
3hr
1/2 hr
4-3/4 hr
1/4 hr
lhr
lhr
Activity
Flow check
Laid down 281.0 ft of Tubing
Pulled Tubing in stands to 4235.0 ft
Ran Tubing to 6274.0 ft (3-1/2in OD)
Monitor wellbore pressures
Circulated at 6274.0 ft
Monitor wellbore pressures
Bleed down well
Flow check
Circulated at 6274.0 ft
Flow check
Laid down 250.0 ft of Tubing
Pulled Tubing in stands to 3200.0 ft
Pulled Tubing in stands to 3200.0 ft (cont...)
Flow check
Pulled Tubing in stands to 0.0 ft
Installed Well control
Rigged up Lubricator
Test Lubricator unit
Held safety meeting
Perforated from 6246.0 ft to 6266.0 ft
Rigged down Lubricator
Removed Well control
Ran Tubing in stands to 5990.0 ft
Reverse circulated at 5990.0 ft
Rigged up High pressure lines
Held safety meeting
Tested High pressure lines
Injectivity test - 170.000 bbl injected at 4245.0 psi
FRAC job - 200.000 bbl injected at 3368.0 psi
Monitor pressures
FRAC job - 317.000 bbl injected at 3185.0 psi
Monitor wellbore pressures
Monitor wellbore pressures (cont...)
Bleed down well
Flow check
Circulated at 5990.0 ft
Flow check
Functioned Rotary table
Pulled Tubing in stands to 0.0 ft
Rigged down Tubing handling equipment
Rigged up Drillstring handling equipment
Made up BHA no. 2
Singled in drill pipe to 6125.0 ft
Washed to 6254.0 ft
Held safety meeting
Washed to 6503.0 ft
Reverse circulated at 6503.0 ft
Reverse circulated at 6503.0 ft
Flow check
Pulled out of hole to 2.5 ft
Pulled BHA
Removed Bell nipple
Rigged up Lubricator
Facility
Date/Time
05 Jun 98
06 Jun 98
07 Jun 98
M Pt H Pad
23:30-23:45
23:45-00:00
00:00-02:00
02:00-03:30
03:30-04:30
04:30-06:00
06:00-06:15
06:15-07:00
07:00-09:00
09:00-09:30
09:30-13:00
13:00-14:15
14:15-20:30
20:30-21:30
21:30-00:30
00:30-01:00
01:00-02:00
02:00-04:30
04:30-06:00
06:00-06:15
06:15-06:30
06:30-08:45
08:45-09:30
09:30-09:45
09:45-10:00
10:00-11:30
11:30-11:45
11:45-12:00
12:00-15:00
15:00-17:30
17:30-18:00
18:00-18:15
18:15-19:30
19:30-21:00
21:00-21:45
21:45-22:00
22:00-22:45
22:45-23:15
23:15-00:00
00:00-02:00
02:00-02:45
02:45-04:00
04:00-04:30
04:30-05:30
05:30-06:00
06:00-07:30
07:30-08:00
08:00-08:15
08:15-08:30
08:30-13:00
13:00-14:30
14:30-14:45
14:45-15:15
15:15-15:30
Duration
1/4 hr
1/4 hr
2hr
1-1/2 hr
lhr
1-1/2 hr
1/4 hr
3/4 hr
2hr
1/2 hr
3-1/2 hr
1-1/4 hr
6-1/4 hr
lhr
3hr
1/2 hr
lhr
2-1/2 hr
1-1/2 hr
1/4 hr
1/4 hr
2-1/4 hr
3/4 hr
1/4 hr
1/4hr
1-1/2 hr
1/4 hr
1/4 hr
3hr
2-1/2 hr
1/2hr
1/4hr
1-1/4 hr
1-1/2 hr
3/4 hr
1/4 hr
3/4 hr
1/2 hr
3/4 hr
2hr
3/4 hr
1-1/4 hr
1/2hr
lhr
1/2 hr
1-1/2 hr
1/2 hr
1/4hr
1/4 hr
4-1/2 hr
1-1/2 hr
1/4 hr
1/2 hr
1/4 hr
Progress Report
Well MPH-13 Page 3
Rig Nabors 4ES Date 03 August 98
Activity
Tested Lubricator
Held safety meeting
Perforated from 6082.0 ft to 6102.0 ft
Conducted electric cable operations
Conducted electric cable operations
Conducted electric cable operations
Conducted electric cable operations (cont...)
Rigged down Lubricator
Rigged up Bell nipple
Serviced Drillfloor / Derrick
Rest hole at 6107.0 ft
Made up BHA no. 3
Singled in drill pipe to 6057.0 ft
Fished at 6085.0 ft
Pulled out of hole to 348.0 ft
Pulled BHA
Laid down fish
R.I.H. to 6019.0 ft
Laid down 1197.0 ft of 3-1/2in OD drill pipe
Held safety meeting
Serviced Drillfloor / Derrick
Laid down 4540.0 ft of 3-1/2in OD drill pipe
Pulled BHA
Retrieved Wear bushing
Installed BOP test plug assembly
Tested All functions
Retrieved BOP test plug assembly
Installed Wear bushing
Serviced Other sub-surface equipment
Ran Tubing in stands to 4918.0 ft
Serviced Block line
Held safety meeting
Ran Tubing in stands to 6107.0 ft
Installed Packer assembly
Rigged up High pressure lines
Held safety meeting
Tested High pressure lines
Injectivity test - 150.000 bbl injected at 4200.0 psi
FRAC job - 210.000 bbl injected at 2400.0 psi
Monitor pressures
FRAC job - 459.000 bbl injected at 5700.0 psi
Reverse circulated at 6070.0 ft
Injectivity test - 4.000 bbl injected at 760.0 psi
Monitor wellbore pressures
Reverse circulated at 6070.0 ft
Reverse circulated at 6070.0 ft (cont...)
Flow check
Laid down 50.0 ft of Tubing
Flow check
Laid down 5904.0 ft of Tubing
Retrieved Other sub-surface equipment
Retrieved Wear bushing
Tested Variable ram
Retrieved BOP test plug assembly
Facility
! ·
M Pt H Pad
Progress Report
!
Well MPH- 13 Page
Rig Nabors 4ES Date
!
4
03 August 98
Date/Time
08 Jun 98
15:30-16:00
16:00-18:00
18:00-18:15
18:15-20:00
20:00-21:00
21:00-00:00
00:00-05:00
05:00-06:00
06:00-07:00
07:00-14:30
14:30-16:00
16:00-18:00
18:00-18:30
18:30-19:00
19:00-19:30
19:30-20:00
20:00-21:00
21:00-21:30
21:30-23:00
Duration
1/2 hr
2hr
1/4 hr
1-3/4 hr
lhr
3hr
5hr
lhr
lhr
7-1/2 hr
1-1/2 hr
2hr
1/2 hr
1/2 hr
1/2 hr
1/2hr
lhr
1/2 hr
1-1/2 hr
Activity
Rigged up Tubing handling equipment
Ran Tubing to 2316.0 ft (2-7/8in OD)
Held safety meeting
Pulled Tubing in stands to 0.0 ft
Rigged up sub-surface equipment - ESP
Installed Other sub-surface equipment
Ran Tubing to 3584.0 ft (2-7/8in OD)
Rigged up sub-surface equipment - Electric cable
Rigged up sub-surface equipment - Electric cable (cont...)
Ran Tubing in stands to 5880.0 ft
Space out tubulars
Installed Electric cable
Ran Tubing on landing string to 5880.0 ft
Installed Hanger plug
Removed BOP stack
Installed Xmas tree
Tested Tubing hanger
Installed Hanger plug
Freeze protect well - 160.000 bbl of Diesel
WELL NAME' MPH-13
26. (10-407) Attachment - Acid, Fracture, Cement Squeeze, Etc.
Depth Interval (MD)
.....
Amount & Kind of Material Used
Freeze protect with 160 bbls diesel
8682'-9800'
EZSV at 6538'
6443'-6538'
Frac, 6324'-6344'
Frac, 6246'-6266'
Frac, 6082'-6102'
P&A Kuparuk with 78-1/2 bbls 'G' Cement
Kuparuk P&A #2 with 20 bbls 'G' cement below EZSV
Cement above EZSV, 2 bbls 'G' Cement
72529# 12/20 Ottowa behind pipe
17790# 12/20 Brady behind pipe
74956# 16/20 Carbolite behind pipe
Performance Enquiry Report
Operator BP Exploration Date 00:23, 04 Aug 98
Page 1
The analysis is from - 04:00, 10 Oct 97 - to - 04:00, 10 Oct 97
Programs in Result Table: MPH-13 DRILL AND COMPLETE
Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight)
MPH-13 Event 04:00, 10 Oct 97 04:00, 10 Oct 97 0 hr 0 min Obtained leak off 13.4
Hole Size MDR
8-1/2
Milne Point Unit, Alaska
TO: MPU Telex Group
FROM: Kirby Walker
Well Name: IMPU H-13
Main Category: IPERF
Sub Category: IE-LINE
Operation Date: 15/31/98
Date: I May 31, 1998
Objective:
To use Atlas to run a tie-in GR log, perforate the OB sand from 6324' to
6344' (4189'-4204' TVD) and run a static BHP gauge. Atlas used 20' of 41/2''
guns at 4 spf, 180° phasing.
Sequence of Events:
O2OO
0300
0345
0615
0630
0730
O80O
0810
0925
O95O
1400
Well turned over to Atlas by rig.
RIH with GR, log from PBTD 9,800' to 5,000'
Log GR tool.
Out of hole w/GR
RIH with gun assembly.
Shoot perforations from 6324'-6344' (4189'-4204' TVD). Verify guns fired
on tension indicator.
Out of hole with gun assembly.
RIH with BHP gauge.
On bottom with gauge. Will only operate when sitting on bottom. POOH
and change out gauge.
RIH with second BHP gauge
Out of hole with
Results:
GR log was run from 9,800' to 5,000'. Perforations were shot from 6324'-6344'
(4189'-4204' TVD). BHP gauge was run to the depth of the OB perforations.
The tool was in place for .-.11/2 hours in which time pressure dropped from 1846
psi to 1835 psi where it stabilized.
Tie in log/date - May 31, 1998
.......... Interval Measured Depth .........
Top Ft. Base Ft. Gun Diameter
Shot Density Orientation Phasing
16,324 (4,189') I [6,344 (4,204')J [ 4.5 J[ 4 J[ N/A J[ o°/18o° I
Page 1
BP EXPLORATION (ALASKA)INC.
Milne Point Unit
TO: MPU Telex Group
FROM: Kirby Walker
DATE: May 31, 1998
RE- H-13 (OB) DataFRAC AND FRAC
SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors
JOB SUMMARY
Rig 4ES ran 6100' of 3¥2" tubing through which to pump the fracture treatment for the OB Sand.
A 100 BBL Injectivity Test was pumped followed by a 15 minute shutdown to monitor pressure. During the
Inj. Test the blender lost prime causing two of the pumps to shutdown. This happened while circulating
the 60# HEC to the perfs and rate was brought back to 23 BPM without detriment to the test. The blender
was having trouble maintaining the rate of 23 BPM and rate had to be adjusted periodically to account for
this. The same occurrence happened while pumping the DataFRAC. Half was through prime was lost
and pumps were shutdown for ~2 minutes before rate could be regained to 20 BPM. 200 BBL were
pumped, overdisplaced by 5 BBLs. Pumps were shutdown and pressure monitored for 25 minutes. A
leakoff of 0.007 ft2/min was determined and the sand schedule was designed accordingly. The volume of
sand called for about 48,000# with a ramp from 1 PPA to 8 PPA. The blender operator switched to the
backup side of the unit for the frac portion of the treatment. No problems were seen. Sand concentration
was kept at 8.0 PPA until a sign of screenout occurred or 75,0003 of sand had been pumped. The later
was the case with no noticeable pressure build. Rate was decreased from 20 BPM to 5 BPM in 5 BPM
increments within the last 30 BBLs of flush in an unavailing attempt to induce a screenout.
INJECTIVITY TEST
Design Rate, Bbls Max Rate, Final Ann psi ISIP, NWB friction, Treat grad,
BPM Pumped bpm PSI psi psi/ft
25 100 23 1035 2724 194 0.715
DATA FRAC
Bbls ISIP Closure CIosureTime Leakoff NWB friction, Treat grad,
Pumped psi Pressure observed psi psi/ft
200 2737 2670 2.5 0.007 124 0.709
FRAC
Page 2
Sand Prop Prop Proppant Liner Sand, Tresaver
pumped, behind pipe, left in csg, size/type M# rubber left in
Job was M# M# M# hole?
Flushed 76,729# 72,529# 4,200# 12/20 N/A N/A
Ottowa
Ft of sand Estimated Final ISIP, psi ISIP Incr % PAD TSO, TSO,
in Pipe sand top STP, over datafrac (pad/slurry) design, min Nolte
psi Plot
132' 6192' 1,665 2738 I 24% never
Operational problems
· The pH of the HEC was checked prior to the job and found to be 9.0. Halliburton's PropLOK requires
the pH to be between 6 and 7 so acid had to be added to lower the pH.
· The POD lost prime during the Injectivity Test and the DataFRAC. This was due to a worn impellar on
the road side of the POD. For the frac, mixing was switched over to the Deck side and no more
problems were seen.
TIME OPERATIONS SUMMARY
I'
1900 Pressure Test to 6736 psi
1932 Injectivity Test
2000 DataFRAC
2317 FRAC
PUMPING SUMMARY
TIME RATE ANNP WHP STAGE CUM
BPM PSIG PSIG BBL BBL
COMMENTS
INJECTIVITY TEST DISPLACEMENT = 67 BBLS
1932 27 1059 2464 100 - Start Injectivity Test 60# HEC
1934 0 53 S/D - Lost Prime
1937 23 1111 4236 53 Get back into Inj. Test
1939 23 105 3272 100 Switch to seawater flush
1941 20 980 3714 147 Slow Rate as per program
1942 0 829 1035 175 S/D ISlP - 2724 psi (ann) NWBF - 194 psi
Grad - 0.715
PUMPING SUMMARY
Page 3
IITIME RATEBPM
ANNP WHP STAGE I CUM
PSIG PSIG BBL BBL
COMMENTS
DATA FRAC DISPLACEMENT = 67 BBLS
2000 20 1051 3861 200 - Start DataFRAC 60# HEC
2007 0 Lost Prime
2010 20 984 2987 67 200 Displace HEC
2014 0 995 3412 267 S/D - ISIP - 2737 psi (ann) NWBF - 124.psi
Frac Grad. - 0.709
FRAC DISPLACEMENT = 52 BBLS
2317 20 1159 3747 93 Start Pad
2330 20 1035 3079 62 Pad on Zone
2331 20 1075 3115 38 93 Start 1 PPA
2333 20 1050 3015 12 131 Start 2 PPA
2324 20 1040 2983 12 143 Start 3 PPA
2324 20 1035 2983 12 155 Start 4 PPA - 1 PPA on Zone
2325 20 1046 2928 24 167 Start 5 PPA
2336 20 1033 2905 24 191 Start 6 PPA
2336 20 1028 2918 193 2 PPA on Zone
2337 20 1026 2928 205 3 PPA on Zone
2336 20 1028 2923 72 215 Start 7 PPA
2337 20 1024 2969 217 4 PPA on Zone
2337 20 1039 229 5 PPA on Zone
2339 20 1035 3317 253 6 PPA on Zone
2340 20 1100 3408 276 7 PPA on Zone
2341 20 1086 3445 189 287 Start 8 PPA
2343 20 1121 3541 348 8 PPA on Zone
2350 20 1101 3523 52 476 Start Flush
2351 15 1053 3042 490 Cut Rate
2352 15 1048 2969 498 Seawater
2353 10 995 2392 505 Cut Rate
2354 5 956 1769 514 Cut Rate
2356 0 938 1665 528 Shutdown
ISIP - 2738 psi NWBF - 30 psi
Grad - 0.69
0011 0 830 987 528 15 min ISIP
FLUIDS PUMPED DOWNHOLE
INJ TEST 175' Bbls
DATA FRAC: 267 Bbls
FRAC: 528 Bbls
* 53 Bbls were circulated back to the pits.
r~¥u ~
GEL OUALITY CONTFIOL CHECK
seawater seawater HEC HEC PIPE XL XL
pH TEMP pH VISCOSITY TIME TIME pH
DF/FRAC 7.2 95 6.9 '93 3.1 rain N/A N/A
FLUID ADDITIVES
2% KCI
2.5 #/bbl HEC gel
2 gal/lO00 F-75N (surfactant) run only in Injectivity Test and DataFRAC
Halliburton surfactant - run through frac
Page1
BP EXPLORATION (ALASKA)INC.
Milne Point Unit
TO: MPU Telex Group
FROM: Kirby Walker
DATE: June 2, 1998
RE- H-13 (OA)Injectivity Test, DataFRAC AND FRAC
SERVICE CO'S.: Doweil, Halliburton, Peak, Nabors
JOB SUMMARY
Dowell and Halliburton rigged up on the well and pressure tested lines to 6820 psi. An Injectivity
Test of 100 BBL of 60# HEC was circulated to the tubing tail at 8 BPM. The rate was dropped to 2 BPM
and the annular choke on the rig was closed. Once closed, rate was brought back to 8 BPM until the
HEC got to the perfs where it was increased to max possible (25 BPM). For the last 20 BBL injected rate
was dropped to 20 BPM until gel was displaced 5 BBL into the perfs. Pumps were shutdown and
pressure was recorded for 15 minutes. A 200 BBL DataFRAC followed. Gel was bullheaded to the perfs
at 8 BPM where rate was brought up to 20 BPM (job design rate). Again, gel was displaced 5 BBL into
the perfs when pumps were shutdown and pressure monitored for 30 minutes.
The design was sent from Anchorage and pumped. There was really no pressure build until 5.5 PPA was
on zone. The slope of the annular pressure plot increased as 6.5 PPA was on zone and screened out
just as 7 PPA hit the perfs.
INJECTIVITY TEST
Design Rate, Bbls Max Rate, Final lAP ISIP, NWB friction, Treat grad,
BPM Pumped bpm psi PSI psi psi/ft
25 100 25 1004 2796 209 0.67
DATA FRAC
Bbls ISIP Closure Closure Leakoff NWB Treat grad,
Pumped psi Pressure Time observed friction, psi psi/ft
200 2777 2701 8.70 0.0051 195 0.66
FRAC
Job was
Sand
pumped,
M#
Prop
behind
pipe, M#
Prop
left in
csg, M#
Proppant
size/type
Liner
Sand, M#
Treesaver
rubberleff
in hole?
Page 2
Screened out I 31570#I 17790# I 13780# I Brady12/20 N/A I
N/A
Ft of Estimated Final ISlP, psi ISIP Incr % PAD TSO, TSO,
sand in sand top STP, over (pad/slurry) design, min Nolte
Pipe psi datafrac Plot
8682 surface 3840 23t0 1519 23% 8.3
Comments
After flush was called enough fluid was pumped to clear the pumps of dirty fluid. The rig wanted to
reverse the PropLOK out of the tubing before it set up. As the rig pumps began to pump the
pressure increased through the treating lines back to the Iow pressure lines of the blender. The
pressure reached 1700 psi on these lines that normally see less than 100 psi. A hose burst causing a
spill.
.. TIME OPERATIONS SUMMARY
1705 Pressure Test Lines - 6820 psi
1712 Injectivity Test
1740 DataFRAC
2O52 FRAC
TIMEI RATEBPM
PUMPING SUMMARY
I
PSIG IPSIGI BBL BBL
COMMENTS
INJECTIVITY TEST DISPLACEMENT = 68.5 BBLS
1712 i 8 152 1240 100 - Start Injectivity Test 60# HEC
1717 I 3 28 699 44 Slow rate to close choke
1718 I 8 1322 2421 48 Increase rate
1720 [ 25 1099 4247 63.5 Start Iniectivit¥ Test at max rate
1722 I 25 1049 4206 69 100 Start Displacing HEC seawater
1724 20 1009 4655 149 Reduce rate for last 20 BBLs
1726 - 1010 5175 169 Shutdown - Monitor Pressure
ISIP - 2796 ps.i NWBF - 209 psi
t Grad.- 0.67
DATA FRAC DISPLACEMENT = 68.5 BBLS
1740 r 8 1 1026 2070 200 _ start DataFRAC 60# HEC
1748 I 20 I 1050 3368 64 Increase rate
1755 I 20 [ 1007 3280 69 200 Start Flush seawater
1758 - , 1000 4435 269 Shutdown - Monitor Pressure
! j ISIP-2777 psi NWBF-195 psi
! Grad. - 0.66
Page 3
FRAC DISPLACEMENT = 1 BBL
2052 ! 20 1033 5332 95 - Start PAD
2055 20 1007 3345 64 Pad on Zone
2057 20 1026 3295 38 95 Start 1 PPA
2059 20 1004 3226 24 133 Start 2 PPA
2100 20 996 3185 24 157 Start 3 PPA
2100 20 1048 3144 159 1 PPA on Zone
2101 20 1040 3158 24 181 Stad 4 PPA
2101 20 1007 3080 197 2 PPA on Zone
2102 20 1007 3080 24 205 Start 5 PPA
2103 20 985 3071 221 3 PPA on Zone
12103 20 985 3065 24 229 Start 6 PPA
2104 20 1005 3144 244 4 PPA on Zone
2104 20 1030 3185 64 253 Start 7 PPA
2102 20 1038 3281 268 5 PPA on Zone
2103 20 1084 3387 292 6 PPA on Zone
2107 , 2356 3840 317 Start Flush
2104 t - 1810 3854 317 S/D- screenout ISIP- 2935 psi (BH) .
I Grad.- 0.70
I
FLUIDS PUMPED DOWNHOLE
INJ TEST 169' Bbls
DATA FRAC' 269 Bbls
FRAC: 317 Bbls
TOTAL 755 Bbls Pumped
691 Bbls Injected
* 64 BBL of was circulated out to the pit
PETREDAT WINDOW
NONE
GEL QUALITy CONTROL CHECK
seawater HEC HEC HEC PIPE XL XL
pH TEMP pH VISCOSITY TIME TIME pH
DF/FRAC 7 90-92 6.5 63 3.42 N/A N/A
Page I
BP EXPLORATION (ALASKA)INC.
Milne Point Unit
TO: Bill Hill
FROM:
DATE:
RE:
Kirby Walker
June 6, 1998
H-13 (N) DataFRAC AND FracPACK
SERVICE CO'S.: Dowell, Halliburton, Peak, Nabors
JOB SUMMARY
The original TSO called for 75,000# of 16/20 CarboLite to be pumped to frac the H-13 N Sand. A
total of 91,336# were pumped due to extending the 10 PPA stage. Of the proppant pumped, 74,956# was
actually placed behind pipe. The job started with a calibration stage where circulation pressures were to
be recorded at 2 and 3 bpm while taking returns through the annulus. The frac pumps could not achieve
the 2 bpm rate so only the 3 bpm circulation pressure was recorded. Final pressure was not to exceed
this circulation pressure + 1400 psi. A 100 BBL Injectivity Test was circulated to the tubing tail at which
time the annular choke was closed and the fluid was bullheaded at BPM to the perfs. Once the 60# HEC
gel was 6 BBL into formation, rate was brought up to the maximum allowable while staying under 5,500
psi STP. 25 BPM was reached and maintained until, with 20 BBLs left until shutdown, rate was decreased
to 12 BPM. ISIP and falloff were recorded and briefly analysed.
The planned 200 BBL DataFRAC, using the same 60# HEC gel, was then pumped. With 160 BBL of the
DataFRAC pumped it was decided that enough information was obtained and the volume of gel could then
be flushed. As in the Injectivity Test, seawater was used to overdisplace the gel 5 BBLs into the
formation. Pumps were shutdown and data was analysed both on location and in Anchorage. A pumping
schedule was decided upon based on the determined leakoff value of 0.01 ft/min2. The proppant
concentration started at 1 PPA and ramped to 10 PPA where it was held until screenout occurred. After
reverse circulating 2 tubing volumes, the pack was restressed at 2.2 BPM and 775 psi showing that some
of the blank pipe had been covered with proppant.
I NJECTIVITY TEST
Design Rate, Bbls Max Rate, Final lAP psi ISIP, NWB friction, Treat grad,
BPM Pumped bpm PSI psi psi/ft
25 100 25 796 2548 68 0.66
DATA FRAC
Bbls ISIP Closure Closure Time Leakoff NWB friction, Treat grad,
Pumped psi Pressure observed psi psi/ft
160 2609 2625 2.24 0.01 98 0.65
Page 2
FRAC
Sand Prop Prop Proppant Liner Sand, Tresaver
pumped, Cf behind pipe, left in csg, size/type M# rubber left in
Job was Cf Cf hole?
Screened out 91336# 74956# 16380# 16/20 N/A N/A
CarboLite
Ft of sand Estimated Final ISIP, psi ISIP Incr % PAD TSO, design, TSO,
in Pipe sand top STP, over datafrac (pad/slurry) min Nolte
psi Plot
6082 surface 5548 1917 6948 18.5 13.8 23
Operational problems
· Operationally, everything went Yery well.
TIME OPERATIONS SUMMARY
6/6 22:55 Injectivity Test
23:27 DataFRAC
6/7 02:03 FRAC
PUMPING SUMMARY
TIME RATE IANNPI WHP ISTAGE I CUM COMMENTS
BPMIIIIPSIG PSlG BBL BBL
INJECTIVITY TEST DISPLACEMENT = 49 BBLS
2255 2.89 707 560 100 - Obtain 2 BPM circ pressure
2258 - 7 S/D - annulus pressured up
2300 2.72 440 38 18 Obtain 2 BPM circ pressure
2304 2.38 548 244 18 Close choke
2305 5 1537 906 22 Increase rate
2310 25 4211 963 50 6 BBL of gel thru perfs - increase rate
2313 25 4073 929 44 100 Start Displacement - seawater
2314 12 2270 789 130 Lower rate
2316 851 752 150 S/D - monitor pressure Grad - 0.66
NWBF - 68 psi ISIP - 673 psi (ann)
DATA FRAC DISPLACEMENT = 49 BBLS
2327 5 979 164 160 - Bullhead HEC to perfs
2337 - 1523 755 44 S/D - allow pressure to bleed to below ISIP
2338 12 2540 882 44 Begin DataFRAC
2348 12 2389 850 49 160 Displace HEC seawater
2352 2468 820 209 S/D - overdisplace by 5 BBL ISIP - 734psi (ann)
Grad. - 0.65 NWBF - 93 psi
Page 3
FRAC DISPLACEMENT = 29 BBLS
0203 12 2604 0 48 Stad Pad
0206 12 2471 757 44 Pad on Zone
0206 13 2347 750 43 48 Start 1 PPA Stage
0209 12 2224 807 12 91 Start 2 PPA Stage
0210 12 2210 810 92 I PPA on Zone
0211 12 2224 837 12 103 Start 3 PPA Stage
0212 12 2215 843 12 115 Start 4 PPA Stage
0213 12 2210 839 12 127 Start 5 PPA Stage
0213 12 2213 820 135 2 PPA on Zone
0214 12 2206 833 24 139 Start 6 PPA Stage
0214 12 2206 833 147 3 PPA on Zone
0215 12 2242 830 159 4 PPA on Zone
0216 12 2270 843 24 163 Start 7 PPA Stage - 5 PPA on Zone
0217 12 2306 845 183 6 PPA on Zone
0218 12 2347 854 48 187 Start 8 PPA Stage
0219 12 2375 862 207 7 PPA on Zone
0221 12 2434 882 231 8 PPA on Zone
0222 12 2503 944 72 235 Start 9 PPA Stage
0226 12 2659 982 278 9 PPA on Zone
0228 12 2706 1028 307 Start 10 PPA Stage
0232 12 2645 970 351 10 PPA on Zone
0241 3 5176 752 454 Lose pump - Start Flush
0243 1.4 5273 761 Open choke to pack screen
0244 4806 38 459 Shutdown - Screenout - Line up to Reverse out
ISIP - 4941 psi
0415 2.2 775 Restress Test on Pack - screen and part of blank
covered.
FLUIDS PUMPED DOWNHOLE
INJ TEST 150' Bbls
DATA FRAC: 209 Bbls
FRAC: 459 Bbls
· One tubing volume of this (44 Bbls) was circulated up annulus.
GEL QUALITY CONTROL CHECK
I seawater HEC HEC I PIPE XL XL
pH TEMP pH VISCOSITY TIME TIME pH
Tank #1 t 85 6.3 86 I 3.67 N/A N/A
Tank#21 I 83 6.5 82 I 3.67 N/A N/A
Tank #3 7.3 , 83 I . N/A N/A
,
FLUID ADDITIVES
J-134 (breaker) - run at 2.5 #/1000gal in all gel stages until final 50 BBLs of frac, increased to 3.75
#/1000gal
F-75N (surfactant) - run at 2 gal/1000 gal in all HEC stages
PAGE 1
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
SP~qRY-SUN DRILLING SERVICES
AlqCHOR3~GE ALASKA ~' I~
DATE OF SURVEY: 101297
MWD SURVEY
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. =
OPERATOR:
66.04 FT.
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.
112.00 112.00 45.96
213.51 213.51 147.47
304.16 304.15 238.11
393.47 393.44 327.40
485.12 484.99 418.95
0 0 N .00 E .00
0 40 S 18.80 W .67
0 26 S 71.18 E .89
1 49 N 71.01 E 1.69
3 14 N 64.08 E 1.57
.00N .00E .00
.57S .19W .08
1.19S .04W .51
.84S 1.63E 1.84
.77N 5.35E 4.42
576.24 575.81 509.77
664.75 663.59 597.55
757.35 754.90 688.86
849.17. 844.95 778.91
939.62 932.84 866.80
5 54 N 70.26 E 2.96
8 49 N 75.77 E 3.39
10 15 N 75.43 E 1.55
12 10 N 78.10 E 2.18
15 6 N 82.52 E 3.44
3.48N 12.07E
6.68N 22.94E
10.50N 37.79E
14.55N 55.18E
18.06N 76.21E
9.20
17.43
28.96
42.63
59.80
1029.48 1018.91 952.87
1121.02 1105.27 1039.23
1213.95 1192.12 1126.08
1308.07 1279.49 1213.45
1399.08 1363.50 1297.46
18 16 N 85.10 E 3.62
20 23 N 87.10 E 2.43
21 15 N 80.89 E 2.54
22 23 N 80.93 E 1.21
22 52 N 83.01 E 1.03
20.79N 101.87E
22.82N 132.10E
26.30N 164.91E
31.83N 199.45E
36.72N 234.12E
81.45
107.50
135.18
163.49
192.20
1491.13 1448.59 1382.55
1580.82 1531.47 1465.43
1674.25 1617.03 1550.99
1765.56 1699.66 1633.62
1856.26 1780.54 1714.50
21 57 N 84.96 E 1.28
23 1 S 88.35 E 3.09
24 21 S 84.35 E 2.23
25 59 S 82.83 E 1.93
27 47 S 82.01 E 2.03
40.40N 269.02E
41.37N 303.26E
38.95N 340.69E
34.60N 379.27E
29.18N 419.93E
221.66
251.76
286.24
322.61
361.33
1951.28 1863.88 1797.84
2044.23 1943.51 1877.47
2136.10 2019.65 1953.61
2228.11 2093.13 2027.09
2318.23 2162.70 2096.66
29 36 S 82.18 E 1.91
32 29 S 83.66 E 3.22
35 32 S 84.52 E 3.36
38 27 S 84.64 E 3.17
40 27 S 83.51 E 2.35
22.91N 465.11E
17.03N 512.68E
11.75N 563.79E
6.52N 618.91E
.60N 675.86E
404.46
449.54
497.52
549.04
602.51
2409.84 2231.11 2165.07
2503.28 2297.98 2231.94
2597.76 2362.15 2296.11
2688.29 2420.05 2354.01
2781.66 2475.43 2409.39
42 53 S 84.54 E 2.77
45 43 S 84.55 E 3.03
48 42 S 83.11 E 3.36
51 45 S 84.26 E 3.50
55 29 S 81.75 E 4.55
5.72S 736.42E
11.93S 801.38E
19.40S 870.31E
27.04S 939.46E
36.23S 1014.05E
659.39
720.13
784.98
850.11
920.79
2873.99 2525.74 2459.70
2966.65 2571.82 2505.78
3058.42 2612.40 2546.36
3151.44 2648.55 2582.51
3244.32 2682.48 2616.44
58 28 S 80.67 E 3.37
61 52 S 77.79 E 4.56
65 37 S 77.31 E 4.11
68 37 S 77.36 E 3.23
68 30 S 77.00 E .38
48.07S 1090.54E
63.12S 1169.48E
80.87S 1249.84E
99.66S 1333.45E
118.84S 1417.76E
994.37
1071.58
1151.28
1234.35
1318.21
ORIGINAL
SPeRRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 2
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
MWD SURVEY
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 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.
3339.93 2717.35 2651.31 68 42
3433.90 2750.52 2684.48 69 56
3529.40 2783.53 2717.49 69 36
3624.99 2817.20 2751.16 69 8
3720.37 2851.62 2785.58 68 33
S 75.02 E 1.94 140.36S 1504.13E
S 74.84 E 1.33 163.22S 1589.02E
S 75.73 E .94 185.98S 1675.69E
S 73.11 E 2.61 210.00S 1761.84E
S 71.16 E 2.00 237.28S 1846.49E
1404.98
1491.03
1578.62
1666.33
1754.16
3816.31 2886.56 2820.52 68 44
3910.70 2919.84 2853.80 69 58
4006.69 2952.47 2886.43 70 16
4102.22 2984.54 2918.50 70 29
4197.08 3017.63 2951.59 68 40
S 68.24 E 2.84 268.28S 1930.29E
S 65.10 E 3.38 303.26S 2011.38E
S 65.79 E .74 340.78S 2093.49E
S 64.24 E' 1.54 378.78S 2175.04E
S 61.86 E 3.03 419.06S 2254.29E
1842.91
1931.06
2021.26
2111.19
2200.08
4292.28 3052.39 2986.35
4387.71 3086.52 3020.48
4482.73 3119.89 3053.85
4578.24 3153.65 3087.61
4674.07 3187.90 3121.86
68 28
69 36
69 16
69 19
68 47
S 61.33 E .56 461.22S 2332.24E
S 61.70 E 1.24 503.72S 2410.57E
S 62.18 E .59 545.57S 2489.07E
S 62.33 E .16 587.16S 2568.15E
S 62.53 E .60 628.58S 2647.48E
2288.67
2377.75
2466.70
2556.03
2645.52
4769.40 3222.50 3156.46
4865.15 3257.59 3191.55
4961.25 3295.07 3229.03
5057.18 3336.75 3270.71
5151.20 3381.34 3315.30
68 39
68 20
65 43
62 45
60 36
S 62.01 E .53 669.91S 2726.11E
S 62.57 E .63 711.34S 2804.98E
S 62.52 E 2.73 752.13S 2883.49E
S 61.64 E 3.20 792.58S 2959.83E
S 62.69 E 2.49 831.22S 3033.01E
2734.34
2823.42
2911.89
2998.27
3081.01
5248.20 3431.04 3365.00
5344.08 3484.23 3418.19
5438.64 3540.61 3474.57
5533.50 3601.05 3535.01
5629.00 3665.42 3599.38
57 44
54 52
51 55
48 55
46 18
S 62.83 E 2.96 869.35S 3107.06E
S 61.23 E 3.30 906.74S 3177.51E
S 62.11 E 3.21 942.77S 3244.31E
S 63.55 E 3.37 976.16S 3309.34E
S 64.65 E 2.86 1006.99S 3372.78E
3164.30
3244.04
3319.92
3393.02
3463.54
5724.16 3732.46 3666.42 44 4
5819.86 3802.70 3736.66 41 28
5914.76 3874.17 3808.13 40 47
6010.12 3946.64 3880.60 40 16
6105.03 4019.35 3953.31 39 43
S 65.55 E 2.44 1035.42S 3434.00E
S 66.18 E 2.75 1062.00S 3493.31E
S 64.93 E 1.12 1087.83S 3550.14E
S 64.34 E .69 1114.38S 3606.14E
S 63.62 E .76 1141.13S 3660.96E
3531.00
3595.92
3658.29
3720.24
3781.24
6200.48 4093.03 4026.99
6296.55 4167.58 4101.54
6391.94 4241.99 4175.95
6487.50 4317.18 4251.14
6563.16 4377.21 4311.17
39 13
38 58
38 30
37 41
37 19
S 63.96 E .56 1167.93S 3715.40E
S 64.40 E .40 1194.32S 3769.94E
S 63.25 E .90 1220.65S 3823.51E
S 63.49 E .87 1247.08S 3876.22E
S 63.73 E .53 1267.56S 3917.48E
3841.91
3902.49
3962.18
4021.14
4067.20
SP~2RY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
MWD SURVEY
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 FT.
OPERATOR: BP EXPLORATION, INC.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS
INCLN
DG MN
COURSE DLS TOTAL
DIRECTION RECTANGUL~LR COORDINATES
DEGREES DG/100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
6638.84 4437.41 4371.37 37 16 S 63.35 E .31 1287.99S 3958.54E
6733.93 4515.31 4449.27 32 42 S 68.54 E 5.74 1310.32S 4008.22E
6827.02 4595.44 4529.40 28 27 S 70.41 E 4.68 1326.96S 4052.54E
6923.01 4680.43 4614.39 27 0 S 78.09 E 4.01 1339.13S 4095.41E
7018.55 4766.58 4700.54 24 16 S 85.57 E 4.42 1345.13S 4136.24E
4113.06
4167.47
4214.52
4258.26
4297.38
7113.13 4854.01 4787.97 20 32 N 89.97 E 4.34 1346.62S 4172.23E
7208.79 4943.74 4877.70 20 0 N 88.32 E .82 1346.13S 4205.36E
7304.50 5033.83 4967.79 19 28 N 81.51 E 2.46 1343.30S 4237.51E
7400.12 5123.90 5057.86 19 48 N 72.00 E 3.36 1335.93S 4268.69E
7496.21 5214.61 5148.57 18 49 N 61.65 E 3.70 1323.54S 4297.83E
4330.16
4359.49
4386.88
4411.36
4431.74
7591.93 5305.30 5239.26 18 29 N 54.68 E 2.35 1307.43S 4323.80E
7687.46 5396.00 5329.96 18 7 N 53.24 E .61 1289.78S 4348.06E
7781.85 5485.73 5419.69 18 2 N 51.79 E .48 1271.96S 4371.31E
7877.04 5576.31 5510.27 17 45 N 57.83 E 1.97 1255.11S 4395.18E
7972.50 5667.33 5601.29 17 19 N 56.09 E .71 1239.43S 4419.30E
4447.62
4461.28
4473.95
4487.62
4502.04
8067.95 5758.60 5692.56 16 40 N 56.08 E .69 1223.86S 4442.46E
8162.89 5849.65 5783.61 16 16 N 54.83 E .56 1208.60S 4464.63E
8258.61 5941.61 5875.57 15 55 N 54.41 E .38 1193.23S 4486.27E
8353.43 6032.98 5966.94 15 5 N 53.03 E .97 1178.23S 4506.72E
8448.88 6124.75 6058.71 16 47 N 57.12 E 2.13 1163.28S 4528.22E
4515.65
4528.52
4540.87
4552.32
4564.74
8545.29 6217.10 6151.06 16 35 N 58.17 E .38 1148.46S 4551.61E
8640.54 6308.47 6242.43 16 12 N 58.99 E .48 1134.44S 4574.55E
8736.27 6400.63 6334.59 15 11 N 59.91 E 1.09 1121.27S 4596.85E
8831.25 6492.42 6426.38 14 34 N 59.29 E .66 1108.93S 4617.89E
8926.12 6584.32 6518.28 14 10 N 60.11 E .47 1097.04S 4638.23E
4578.90
4593.02
4606.95
4620.13
4632.90
9022.74 6678.12 6612.08 13 34 N 60.30 E .62 1085.52S 4658.34E
9118.24 6771.08 6705.04 12 52 N 59.90 E .75 1074.63S 4677.29E
9212.57 6863.08 6797.04 12 38 N 60.83 E .32 1064.33S 4695.39E
9308.43 6956.71 6890.67 12 6 N 60.79 E .56 1054.31S 4713.33E
9403.93 7050.16 6984.12 11 41 N 61.26 E .44 1044.76S 4730.57E
4645.63
4657.60
4669.09
4680.55
4691.61
9499.21 7143.56 7077.52 11 3 N 63.61 E .83 103'6.06S 4747.23E
9594.10 7236.69 7170.65 11 1 N 64.35 E .15 1028.08S 4763.56E
9689.46 7330.36 7264.32 10 35 N 65.49 E .51 1020.50S 4779.76E
9744.75 7384.72 7318.68 10 27 N 65.34 E .24 1016.30S 4788.94E
9800.00 7439.05 7373.01 10 27 N 65.34 E .04 1012.11S 4798.06E
4702.53
4713.49
4724.50
4730.79
4737.03
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 4903.64 FEET
AT SOUTH 78 DEG. 5 MIN. EAST AT MD = 9800
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 116.89 DEG.
TIE-IN SURVEY AT 112.00' M~.
-I~OJECTED SURVEY AT 9800.00 D
SP=~=RY-SUN DRILLING SERVICES
AIqCHOR3AGE ALASKA
PAGE 4
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
JOB NI/MBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 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
112.00 112.00 45.96 .00 N .00 E .00
1112.00 1096.81 1030.77 22.66 N 128.96 E 15.19
2112.00 1999.94 1933.90 13.10 N 549.99 E 112.06
3112.00 2633.77 2567.73 91.65 S 1297.77 E 478.23
4112.00 2987.82 2921.78 382.80 S 2183.33 E 1124.18
15.19
96.87
366.17
645.95
5112.00 3362.10 3296.06 815.55 S 3002.66 E 1749.90
6112.00 4024.71 3958.67 1143.11 S 3664.95 E '2087.29
7112.00 4852.95 4786.91 1346.62 S 4171.83 E 2259.05
8112.00 5800.80 5734.76 1216.81 S 4452.94 E 2311.20
9112.00 6765.00 6698.96 1075.33 S 4676.08 E 2347.00
625.71
337.39
171.76
52.15
35.80
9800.00 7439.05 7373.01 1012.11 S 4798.06 E 2360.95
13.94
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD.
SPideRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 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
112.00 112.00 45.96
166.04 166.04 100.00
266.05 266.04 200.00
366.06 366.04 300.00
.00 N .00 E .00
.07 S .02 W ,00 .00
1.08 S .29 W .01 .01
1.12 S .81 E .02 .01
466.14 466.04 400.00
566.42 566.04 500.00
667.24 666.04 600.00
768.67 766.04 700.00
870.77 866.04 800.00
.30 N 4.38 E
3.15 N 11.17 E
6.78 N 23.32 E
11.01 N 39.74 E
15.47 N 59.78 E
.10 .O8
.38 .28
1.20 .82
2.63 1.44
4.73 2.10
974.11 966.04 900.00
1079.20 1066.04 1000.00
1185.96 1166.04 1100.00
1293.52 1266.04 1200.00
1401.84 1366.04 1300.00
19.18 N 85.49 E
22.06 N 117.62 E
24.70 N 154.89 E
30.96 N 193.98 E
36.85 N 235.18 E
8.07 3.34
13.16 5.09
19.93 6.77
27.48 7.55
35.80 8.32
1509.96 1466.04 1400,00
1618.39 1566,04 1500.00
1728.18 1666.04 1600.00
1839.87 1766.04 1700.00
1953.77 1866.04 1800.00
40.93 N 276.07 E
40.91 N 317.98 E
36.62 N 363.06 E
30.24 N 412.36 E
22.74 N 466.34 E
43.92 8.12
52.35 8.43
62.14 9.79
73.83 11.69
87.73 13.90
2071.08 1966.04 1900.00
2193.78 2066.04 2000.00
2322.62 2166.04 2100.00
2458.11 2266.04 2200.00
2603.70 2366.04 2300.00
15.45 N 527.19 E
8.50 N 597.92 E
.28 N 678.69 E
8.89 S 769.58 E
19.93 S 874.77 E
105.04 17.31
127.74 22.71
156.58 28.84
192.07 35.49
237.66 45.60
2765.27 2466.04 2400.00
2954.49 2566.04 2500.00
3199.42 2666.04 2600.00
3479.11 2766.04 2700.00
3759.87 2866.04 2800.00
34.37 S 1000.74 E
60.90 S 1159.02 E
109.46 S 1377.04 E
174.27 S 1630.02 E
249.54 S 1881.16 E
299.23 61.56
388.45 89.22
533.38 144.93
713.07 179.69
893.83 180.76
4046.92 2966.04 2900.00
4329.48 3066.04 3000.00
4613.32 3166.04 3100.00
4887.71 3266.04 3200.00
5120.02 3366.04 3300.00
356.30 S 2128.02 E
477.82 S 2362.60 E
602.40 S 2597.22 E
720.98 S 2823.54 E
818.76 S 3008.87 E
1080.88 187.05
1263.44 182.56
1447.28 183.85
1621.67 174.38
1753.98 132.31
5312.09 3466.04 3400.00 894.18 S 3154.38 E 1846.05 92.07
SP~--~RY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 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
5479.26 3566.04 3500.00
5629.89 3666.04 3600.00
5770.40 3766.04 3700.00
5904.02 3866.04 3800.00
6035.54 3966.04 3900.00
957.43 S 3272.39
1007.26 S 3373.36
1048.50 S 3462.98
1084.86 S 3543.'79
1121.49 S 3620.96
1913.22 67.17
1963.85 50.63
2004.36 40.51
2037.98 33.62
2069.50 31.52
6165.64 4066.04 4000.00
6294.57 4166.04 4100.00
6422.68 4266.04 4200.00
6549.12 4366.04 4300.00
6674.41 4466.04 4400.00
1158.26 S 3695.60
1193.78 S 3768.82
1229.27 S 3840.60
1263.79 S 3909.85
1297.15 S 3977.54
E
E
E
E
E
2099.60 30.09
2128.53 28.93
2156.64 28.11
2183.08 26.44
2208.37 25.29
6793.33 4566.04 4500.00
6906.84 4666.04 4600.00
7017.95 4766.04 4700.00
7125.98 4866.04 4800.00
7232.52 4966.04 4900.00
1321.34 S 4037.07
1337.50 S 4088.22
1345.09 S 4135.97
1346.62 S 4176.74
1345.89 S 4213.48
2227.29 18.93
2240.80 13.51
2251.91 11.11
2259.94 8.03
2266.48 6.54
7338.68 5066.04 5000.00
7444.83 5166.04 5100.00
7550.53 5266.04 5200.00
7655.94 5366.04 5300.00
7761.15 5466.04 5400.00
1341.25 S 4248.73
1330.72 S 4282.69
1314.99 S 4313.07
1295.65 S 4340.21
1275.92 S 4366.27
2272.64 6.16
2278.79 6.15
2284.49 5.70
2289.90 5.41
2295.11 5.21
7866.26 5566.04 5500.00
7971.15 5666.04 5600.00
8075.71 5766.04 5700.00
8179.96 5866.04 5800.00
8284.01 5966.04 5900.00
1256.86 S 4392.39
1239.65 S 4418.97
1222.61 S 4444.31
1205.84 S 4468.54
1189.17 S 4491.94
2300.22 5.11
2305.11 4.89
2309.67 4.56
2313.93 4.25
2317.97 4.05
8387.67 6066.04 6000.00
8492.01 6166.04 6100.00
8596.35 6266.04 6200.00
8700.43 6366.04 6300.00
8803.99 6466.04 6400.00
1172.87 S 4513.84
1156.51 S 4538.68
1140.80 S 4563.98
1125.98 S 4588.72
1112.43 S 4611.99
2321.63 3.66
2325.97 4.34
2330.31 4.34
2334.39 4.08
2337.95 3.56
8907.27 6566.04 6500.00
9010.32 6666.04 6600.00
9113.07 6766.04 6700.00
9215.60 6866.04 6800.00
9317.97 6966.04 6900.00
1099.34 S 4634.23
1086.97 S 4655.81
1075.21 S 4676.29
1064.01 S 4695.97
1053.33 S 4715.08
2341.23 3.28
2344.28 3.05
2347.03 2.75
2349.56 2.53
2351.93 2.37
Sr~ ~RY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE 7
BP EXPLORATION INC.
MILNE POINT ~ MPH - 13
500292281800
NORTH SLOPE BOROUGH
COMPUTATION DATE: 10/15/97
DATE OF SURVEY: 101297
JOB NUMBER: AK-MM-70287
KELLY BUSHING ELEV. = 66.04 FT.
OPERATOR: BP EXPLOP~ATION, 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
9420.15 7066.04 7000.00 1043.18 S 4733.45 E 2354.11 2.18
9522.11 7166.04 7100.00 1034.10 S 4751.16 E 2356.07 1.96
9624.00 7266.04 7200.00 1025.61 S 4768.72 E 2357.96 1.88
9725.75 7366.04 7300.00 1017.74 S 4785.80 E 2359.71 1.75
9800.00 7439.05 7373.01 1012.11 S 4798.06 E 2360.95 1.23
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS
0 Ft I I--I--I I~ G S E I::1~1 ~- E S
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.' Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs - MPH-13,
AK-MM-70287
September2.1998
MPH-13:
- 2"x 5"MD Resistivity and Gamma Ray Logs:
50-029-22818-00
2" x 5" TVD Resistivity and Gamma Ray Logs:
50-029-22818-00
2"x 5" MD Neutron & Density Logs:
50-029-22818-00
2"x 5" TVD Neutron & Density Logs:
50-029-22818-00
1 Blueline
1 Folded Sepia
1 Bluelme
1 Folded Sepia
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ~ ATYACHED COPIES
OF THE TRANSMITTAL LETTER TO Tlt-E ATTENTION OF:
Sperry-Sun Drilling Services
Attn: Ali Turker
5631 Silverado Way, Suite G.
Anchorage, Alaska 99518
_._
..~-
.... . .~-' ~- ~ -~:_.
BP Exploration (Alaska) Inc.
Petro-technical Data Cemer, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Si
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252
A Division of Dresser Industries, Inc.
State of Alaska
Alaska Oil & Gas Conservation Comm.
Atten' Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
12-Jun-98
Transmittal of Final Prints. Please sign and return copy to the following'
Western Altas Logging Services
Pouch 340013
Prudhoe Bay, AK 99734-0013
and
BP Exploration (Alaska) Inc.
Petrotechnicai Data Center MB 3-3
900 E. Benson Blvd.
Anchorage, AK 99519-6612
p ell Name Services Bluelines
G-13 SBT/GR/CCL 1
~CVIPG-13 CCL/GR PERF, PACKER 1
R/F Sepia Film
1
MPH-13 CCL PERF 1 1
MPH-13 CCL PERF 1 1
/'MPH-13 GR/CCL DEPTH REF 1. 1
/fVJPH-13 STATIC PRESS SRVY 1
1
/~vlPI-05
/MPB-25
PK-30
PH-13
/~MPH-08
/~1'PG-13
/,', I (--- INJ PROFILE 1
~/¢.-.-INJ PROFILE 1
CCL PERF 1
GR/CCL PERF, PACKER 1
1
GR/CCL PERF 1
GR/CCL PERF
Contact Rebecca Lange if you have a question concerning this transmittal
at (907) 659-2816 or Fax (907) 659-2602.
OCT ~6 '97 OS:19PM ~H~R~ERVICE~ DRILLEHg P.2/2
eare.d
rvIces
riliing
APPLICATION FOR SUNDRY- SUMMARY OF PROCEDURE, MPH-13
MIIne Point well #MPH-13 was drilled by Nabors Rig fl"22E to a depth of 9800' MD. LWD logs
revealed the Kuparuk Sands were non-commercial. Therefore, the Kuparuk Sands are to be
abandoned by placing a cement plug from TD to 500 feet above the top hydrocarbon bearing
sand at 9125' MD. This will place the calculated Top of Cement at 8625' MD. A hole
washout of 30% will be utilized in determining volume.
A 9-5/8", 40# EZSV will then be placed 50 feet above the 9-5/8' casing shoe. The 9-5/8"
cased wellbore will then be used as Schrader Bluff production well.
9-5/8', 40~, L-80, BTC casing was set at 6618' MD during drilling of MPH-13.
Verbal approval was obtained from Blair Wondzell with AOGCC in ~ phone conversation with
G.L. Alvord at BPXA Shared Services Drilling on or about October 12, 1997 at 1000 hours to
adandon the Kuparuk Sands and set the EZSV as outlined below,
PU 5" muleshoe. RIH to TD at 9800' MD. Circulate and condition wellbore. Spot a 65 bbl
balanced cement plug. Slowly puli 20 stands above the calculated top of the cement
plug. CBU. POOH.
NOTE: Calculated Top of Cement Is 8625' MD which is 500 feet above the highest
hydrocarbon bearing sand at 9125' MD.
NOTE: Volume based on 8-1/2" hole from 'ID to 500 feet above Kuparuk 'C' Sand.
Premium G + .2% CFR-3 + HR-5 retarder as required
WT: 15.8 PPG YIELD; 1.15 FT3/SK
1
PU 9-5/8", 40# EZSV. RIH and set same at 6538' MD. Pump 15 bbl cement down
through the EZSV. Unsling and leave 2 bbl on top of EZSV. Calculated TOC inside
casing will be~l' MD. Deepest possible perf will be 6361' MD. POOH to 6450' MD.
csu., '~
3. Displace will with seawater. POOH LDDP. Stop at base of permafrost and displace well
with diesel. Finish POOH LDDP.
4. Test casing to 3500 psig.
S. ND BOPE, NU and test tree, RDMO Ne. bom 22E ddlling to drill next well.
:5 ~/~ ~ I= L) I- ALAS KA
ALASKa...,1 AND GAS CONSERVATION CQMk :SION
APPliCATION FOR ,SUNDRY APPROVAL
1. Type of Request; ~Abanclon t--ISuspend [] Plugging .L-~,T~me Extension ~. Per/orate
[] Alter Casing ~ Repair Well [] Pull Tubing [] Variance .F~ Other
[] Change Approve~l Program ~ Operation Shutdown ~ Re-Enter Suspended Wall ~ Stimulate C~ang~ t~ ,.~l~rs~e~ B~uff Pra~ucer
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P,O. Box 196612, Anchorage, Alaska 99519-6612
Type of well:
~ Development
~ Exploratory
___j Stratigraphlc
~ Set'vice
4. Location of well at surface
2920' NSL, 4142' WEL, SEC. 34, T13N, R10E, UM
At top' of productive interval
N/A
At effective depth
1661' NSL, 241' WEL, SEC. 34, T13N, R10E, UM
At total depth
....... 1908' NSL, 656' EWL, SEC. 35, T13N, R10E, UM
O IGINA£
6. Datum Elevation (DF or KB)
Plan KBE = 66.2'
7. Unit or Property Name
Milne Point Unit
8. Well Number
MPH-13
9, Permit Number
97-186
10. APl Number
50-029-22818
11. Field and Pool
MIIne Point Unit / Kuparuk River
Sands
12. Present well condition summary
Total depth: measured 9800 feet
true vertical 7439 feet
Effective depth: measured 6532 feet
true vertical 4353 feet
Casing Length Size
Structural
Conductor
Surface
Intermediate
Production
Liner
80' 20"
6587' 9-5/8"
Plugs (measured)
Junk (measurecl)
Cemented
2.~0 sx Arcticset I (Approx.)
1946 sx PF 'E', ~78 sx 'G', 374 sx PF 'C'
MD 'I-VD
112' 112'
6618' 4421'
Perforation depth: measured N/A
true vertical
Tubing (size, grade, and measured depth) N/A
Packers and SSSV (type and measured depth) N/A
13. Attach-men~;- .~ Description summary of proposal
Detailed operations program [] BOP sketch
4. Estimated date for commencing operation 15. Status of well classifications as:
October 13, 1997
16. If proposal was verbally approved [] Oil [] Gas {~ Suspended
Blair Wondzell 10/12/97
Service
Name of a prover/~ Date approved
Contac~ Engineer Name/Numbe~_d_~_j~ ?_~..(Ja S ~obe o r; ~-6169 Pmpsmd ~ Name/Numbe~
17.1 hereby ce~i~ that ~he~[~goin~ i~e and co~t to th~best of ~y~nowl~ge
c~[~a ~/~.~" / IXJ ~ v v ~ Title Senior Drilling Engin~r
Commission Use Only
K~tl~y Cernpoarnor, 564.5122
Conditions of Approval: Notify Commission/so representative may witness
Plug integrity b,/ BOPTest ~ Location clearance
Mechanical Integrity Test ~ Subsequent form required 10-
J Approval No, ,.~ ~'~--/~ b
AP__Er_?~ecl bY o_rder of the Commission
Form 10-403 Rev. 06/15/88
Original Si,g_neo ~a~
David W. Johnstc, r, oo~'~
P,~?' . ~.,~e(~ ,-.,,1
Commissioner
Submit In Triplicate
Milne Point Unit, Alaska
TO:
FROM'
Well Name:
Main Category:
Sub Category:
Operation Date:
MPU Telex Group
Kirby Walker
IMPU H-13
PERF
E-LINE
6/2/98
Date: I June 2, 1998
Objective:
To perforate the OA sand from 6,246'-6,266' (4,128'-4,144' TVD) using
4.5" guns (0° / 180° phasing, 4 spf).
Sequence of Events:
10:00
10:35
11:25
11:40
11:41
11:44
12:15
RU Atlas - pre-job safety meeting
RIH w/gun assembly
On bottom w/assembly- log into position
Logged onto depth (6,246')
Fire gun - Indication of guns fired by tension loss
POOH
On surface w/assembly- shots fired - RDMO Atlas
Results:
Atlas was used to perforate the OA sand from 6,246'-6,266'
(4,128'-4,144' TVD).
It jJ
Tie in log/date 5/31/98
.......... Interval Measured Depth .........
Top Ft. Base Ft. Gun Diameter
Shot Density
6246' (4128')I 1 6266' (4144') J[ 4.5" J[ 4
Orientation Phasing
11 N/A IL o°/18o° J
MEMORANDUM
TO:
THRU:
Blair Wondzell,
P. !. Supervisor
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: October 9 1997
FILE NO: awokjiee.doc
FROM: Chuck Scheve, c .5 SUBJECT:
Petroleum Inspector
BOPE Test
Nabors 22E
PTD # 97-186
Thursday~ October 9, !997: I traveled to BPX's MPU H-13 Well being drilled by
Nabors Rig 22E and witnessed the initial BOPE test on this well.
As the attached AOGCC BOPE test report shows, the test lasted 2.5 hours with one
failure. The Hydraulic Choke controls were not working, this was repaired and was
functioning properly by the time the test was completed. The test went well with
good test procedures being employed by the Nabors crews.
The rig was clean and all related equipment appeared to be in good working order.
The location though crowded was well organized.
Summary: I witnessed the initial BOPE test on Nabors Rig 22E drilling BPXs MPU
H-13 well.
Nabors 22E, 1019/97, test time 2.5 hours, 1 failure
Attachment: awokjiee.xls
X Unclassified
Confidential (Unclassified if doc. removed )
Confidential
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg: X
Drlg Contractor:
Operator:
Well Name:
Casing Size: 9 5/8
Test: Initial X
Workover:
Nabors Rig No. 22E PTD# 97-186
BPX Rep.:
MPU H-13 Rig Rep.:
Set@ 6617 Location:Sec. 34 T.
Weekly Other
DATE: 10/9/97
Rig Ph.# 659-4446
Paul Lockwood
Leonard Schiller
13N R. 'i OE Meridian UM
MISC. INSPECTIONS:
Location Gen.' OK
Housekeeping: OK (Gen)
PTD On Location Yes
, ,
Standing Order Posted Yes
Well Sign OK
Drt. Rig OK
Hazard Sec. Yes
FLOOR SAFETY VALVES: Quan.
Upper Kelly/IBOP 1 I
Lower Kelly / IBOP I
!
Ball Type 1
Inside BOP 1
Test
Pressure P/F
250/5, 000 P
250/5, 000 P
250/5, 000
250/5, 000
BOP STACK:
Annular Preventer
Pipe Rams
Lower Pipe Rams
Blind Rams
Choke Ln. Valves
HCR Valves
Kill Line Valves
Check Valve
Quan. Test Press. P/F
I 250/3500 P
I 250/5, 000 P
1 250/5, 000 P
250/5, 000
250/5, 000
P
2 250/5, 000
1 250/5,000
N/A N/A N/A
P
P
P
MUD SYSTEM: Visual Alarm
Trip Tank OK OK
Pit Level Indicators OK OK
Flow Indicator OK OK
Meth Gas Detector OK OK
H2S Gas Detector OK OK
CHOKE MANIFOLD:
No. Valves 18 I
No. Flanges 36
Manual Chokes 2
Hydraulic Chokes 1
Test
Pressure
250/5, 000
P/F
250/5, 000 P
Functioned P
Functioned ,,F/P
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
200 psi Attained After Closure
System Pressure Attained
Blind Switch Covers: Master:
Nitgn. Btl's: 8 Bott/es
1900
3000 I'
1400
minutes 30 SeO.
2 minutes 45 sec.
Yes Remote: YES
Psig.
Number of Failures: '/ ,TestTime: 2.5 Hours. Number of valves tested 26 Repair or Replacement of Failed
Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to
the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687
If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433
REMARKS:
Remote choke controfler not working repaired latter this date
Distribution:
orig-Well File
c - Oper.tRig
c - Database
c - Tdp Rpt File
c- Inspector
F1-021L (Rev.12/94)
STATE WITNESS REQUIRED?
YES X NO
24 HOUR NOTICE GIVEN
YES X NO
Waived By:
Witnessed By:
AWOKJIEE.XLS
Chuck Scheve
TONY KNOWLES, GOVERNOR
~LASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
September 25.1997
Chip Alvord
Senior Drilling Engineer
BP Exploration (Alaska) Inc.
P O Box 196612
Anchorage, AK 99519
Re:
Milne Point MPH-13
BP Exploration (Alaska) Inc.
Permit No. 97-186
Sur. Loc. 2920'NSL. 4142'WEL, Sec. 34, T13N. R10E, U~I
Btmnhole Loc. 1890'NSL. 4648'WEL, Sec. 35. T13N, R10E, UM
Dear Mr. Alvord:
Enclosed is the approved application for permit to drill the above referenced xvell.
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 hours) of the BOPE test performed before drilling below the
surface casing shoe must be given so that a representative of the Commission may witness the
test. Notice may be given by contacting the Commission petroleum field inspector on the North
Slope pager at 659-3607.
Robert N. Christenson
Commissioner
BY ORDER OF THE COMMISSION
dlf/Enclosures
CC:
Department of Fish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
" STATE OF ALASKA
ALASKA ~JIL AND GAS CONSERVATION COIV,,~,ISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work C~ Drill [--IRedrill Ilb. Typeofwell I--IExploratory I--IStratigraphicTest C~ Development Oil
[] Re-Entw [] 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 KBE = 66.2' Milne Point Unit / Schrader Bluff
........
3. Address 6. Property Designation
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 025518
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
2920' NSL, 4142' WEL, SEC. 34, T13N, R10E, UM Milne Point Unit
At top of productive interval 8. Well Number Number 2S100302630-277
1835' NSL, 4729' WEL, SEC. 35, T13N, R10E, UM MPH-13
At total depth 9. Approximate spud date Amount $200,000.00
1890' NSL, 4648' WEL, SEC. 35, T13N, R10E, UM 09/30/97
1"~. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 025906, 632'I No Close Approach 2560 9696' MD / 7331' TVD
1'"8. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 300' MD Maximum Hole Angle 67.8° Maximum surface 2754 psig, At total depth (-I-VD) 6900' / 3444 psig
18. Casing Program Setting Depth
Size Specifications Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.)
12-1/4" 9-5/8" 40# L-80 Btrc 6568' 31' 31' 6599' 4401' 1644 sx PF 'E'. 278 sx 'G', 100 sx PF 'C'
8-1/2" 7" 26# L-80 Btrc-Mod 9666' 30' 30' 9696' 7331' 238 sx Class 'G'
........
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented M D TVD
Structural
Conductor
Surface
Intermediate
Production
Liner~-~i~ E'-~.~
· '". i-
Perforation depth: measured
true vertical ~=l~.qk~ ~)il ~
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling
[] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: James Robertson, 564-5159 Prepared By Name/Number: Kathy Carnpoamor, 564-5122
21. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed
ChipAIvord ,..,/r~..~, ~, ~ Title Senior Drilling Engineer Date
Commission Use Only
.......
Permit Number I APl Number A p,~ro~v al D,a_t e I See cover lottor
~'?-- ,,/~' 50- ~ 2.. ¢ -.- 2- 2_ ~//~' c~ i ~-~B"') for other requirements
Conditions of Approval: Samples Required []Yes ~No Mud Log Require~ ! []Yes [~ No
Hydrogen Sulfide Measures []Yes ,J~ No Directional Survey Required [~Yes [] No
Required Working Pressure for BOPE 1--12M; [-13M; 1~SM; E]10M; I--I15M
Other: ORIGINAL SIGNED' BY
F~ol;~rt N. Christen$0rl Commissioner bY order of
Approved
By
the commission Date !
Form 10-401 Rev. 12-01-85 Submit h Tri te
Shared Services Drilling Contact: James E. Robertson 564-5159
I Well Name: IMP H-13
Well Plan Summary
IType of Well (producer or injector):
ISCHRADER BLUFF
PRODUCER
Surface Location: 2920 FSL, 4142 FEL, S34 T13N R10E UM
Target Location: 1835 FSL, 4729 FEL, S35 T13N R10E UM
Bottom Hole Location: 1890 FSL, 4648 FEL, S35 T13N R10E UM
I AFE Number: 1337098 I I Rig: I Nabors22E I
Estimated Start Date: I 30 SEPT 97 I
Operating days to complete: I 9.0
IMD: 19,696, I ITvD: 17,331' I I KBE: 166.2 ft I
I we, Design: I Kuparuk Producer I
Formation Markers:
Formation Tops MD TVD (bkb)
base permafrost 1957 1866
Top Ugnu
Top "M" Sands 5961 3847
NA 6030 3966 Top of Schrader Bluff Sands (8.3 ppg)
Seabee Shale 6349 4210 Base of Schrader Bluff Sands/8.3 ppg)
HRZ 8604 6276 High Resistivity Zone
MK-19 8806 6471
Top Kuparuk 8982 6641 Kuparuk Cap Rock
Target Sand -Target 9319 6966 Target Sand (9.6 ppg)
Total Depth 9696 7331 TD at 300' MD past base of Schrader
Casing/Tubing Program: A/as, k~. Oil,?,
Hole Size Csg~ WtJFt Grade Conn Length Top Btm
4I~c!
Tbg O,D, MD/I'VD MD/TVD
24" 20" 91.1# H-40 Weld 80 32/32 112 / 112
12 1/4" 9-5/8" 40# L-80 btm 6568 31/31 6599 / 4401
8-1/2" 7" 26# L-80 btrc- 9666 30/30 9696 / 7331
mod
Pipe Specifications:
O.D. WtJFt Grade Conn. ID Area Maximum Pull = Collapse Burst
(bbl/ft) 80% Tensile Rating (psi) (psi)
(1000 lbs)
20" 94# H-40 Weld 19.124" 0,3552 1077 520 1530
9-5/8" 40# L-80 BTC 8,835" 0.0758 917 3090 5750
7" 26# L-80 BTC-Mod 6.276" 0.0382 604 5410 7240
5" 19.5# G (Pr) 4-1/2" IF 4.276" 0.0178 436.15 8765 12163
5" 19.5# E/Pr) 4-1/2" IF 4,276" 0.0178 311.54 7041 8688
Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full
column of gas to the reservoir at _+6900 TVDSS. Maximum anticipated surface pressure in this case assuming a
reservoir pressure of 3444 psi (9.66 ppg EMW) is 2754 psi, well below the internal yield pressure rating of the 7"
casing.
Logging Program:
Open Hole Logs:
Surface MWD Directional surface to TD. LWD Gamma Ray/Resistivity surface to TD.
Intermediate N/A
Final MWD Directional and LWD Triple Combo CDR/CDN (GR/RES/Dens/Neu).
Cased Hole Logs: N/A
Mudloggers are NOT required for this well.
Mud Program:
Special design considerations I None-SPUD MUD
Surface Mud Properties: I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
8.6 50 15 8 10 9 4
to to to to to to to
9.8 150 35 15 30 10 6
Intermediate Mud Properties: N/A I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
Production Mud Properties: I LSND freshwater mud
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
8.6 35 6 3 7 8.5 6-12
to to to to to to to
10.0 50 20 10 20 9.5 4-6
Well Control:
Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter
Line. Completion Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be installed and
is capable of handling maximum potential surface pressures.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
Directional:
I KOP: l eoo' MD
Maximum Hole Angle:
Close Approach Well:
67.8
NONE
Waste Management:
Cuffings Handling: All cuttings will be hauled to the CC-2A facility.
Fluid Handling: All drilling and completion fluids will be hauled to CC-2A for injection.
Annular Injection: No wells on H-pad have been permitted for annular injection.
MP H-13
Proposed Summary of Operations
.
2.
3.
4.
5.
.
.
11.
12.
13.
14.
15.
Drill and Set 20" Conductor. Weld a starting head on conductor.
Prepare location for rig move.
MIRU Nabors 22E drilling rig.
N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud.
Drill 12-1/4" surface hole as per directional plan. Run Directional MWD and LWD GR/Res from surface to
TD.
Run and cement 9-5/8" casing.
ND 20" diverter. NU and test 13-5/8" BOP.
MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out
Float Equipment and 20' of new formation. Perform LEAKOFF TEST. If LOT EMW is less than 12.5 ppg
contact appropriate superintendent.
Drill 8.5" hole to TD as per directional plan.
Run and Cement 7", 26#, L-80, Buttress-Modified casing. Displace cement with completion fluid and
enough diesel to cover from the base of permafrost to surface.
Test casing to 3500 psig for 30 min.
ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well.
MIRU completion rig. NU & Test BOPE to 5000 psig.
Complete well with 2-7/8" tubing.
Install Surface Lines and Wellhouse and turn well over to production.
DRILLING HAZARDS AND RISKS:
See the latest Milne Point H-Pad Data Sheet prepared by Pete Van Dusen for information on H pad.
Particularly close attention should be paid to hydrate experiences on previous H-Pad wells.
The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills
and completes them. This will make the near rig area congested and as a result potentially hazardous.
Ensure personnel use caution moving around adjacent production activities.
1. Hydrates:
HYDRATES WERE ENCOUNTERED ON THE WELLS RECENTLY DRILLED ON MILNE POINT 'H' PAD
DURING THE SUMMER OF 1997. PLAN ON LECITHIN TREATMENT AS WELL AS WEIGHTING UP TO
AN APPROPRIATE MUD WEIGHT TO MANAGE THE HYDRATES. 9.8 PPG WORKED ON MP H-14, MP
H-10, H-11i, AND H-12 THROUGH THE HYDRATE ZONE.
The cement program will be modified to include a Permafrost C tail on the second stage to ensure a high
quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement
displacement to maintain the hydrostatic head on the formation so as to minimize the movement of hydrates
into the wellbore.
2. Close Approach:
There are no close approach problems with MP H-13.
3. Lost Circulation:
Lost circulation has been experienced when drilling the Schrader sands and can be countered by having
LCM on hand. MPH-05 experienced lost returns at 3708' TVDSS while drilling with heavy 11.5 ppg mud that
was used to deal with hydrates. LCM should be kept on hand, particularly if the mud is weighted up to
counteract gas cut mud due to hydrates.
There has not been any appreciable amount of lost circulation on any of the H Pad wellls to date when drilling
from the Seabee down through the Kuparuk reservoir.
4. Stuck Pipe Potential:
No stuck pipe incidents have occurred on H Pad to date. If heavy gravels are encountered while drilling the
surface hole section, operations should be immediately stopped while the mud funnel viscosity is increased
to 150 cp and maintained through the gravel section.
The past few wells on Milne Point 'H' Pad have encountered severe tight hole problems; especially swabbing
problems while POOH. A few changes will be noted in the mud discussion of the final wellplan as an effort to
alleviate some of the tight hole/packing off problems.
5. Formation Pressure:
The expected pore pressure for this well is 9.6 ppg EMW in the Kuparuk sands.
6. Cement
Plan on using a 'C' cement for the second stage tail surface casing cement due to probability of hydrates in
surface hole.
MP H-13
9-5/8" SURFACE CASING
CEMENT PROGRAM - HALLIBURTON
CASING SIZE: 9-5/8" CIRC. TEMP: ~ 80°F
SPACER: 50 BBL Weighted Spacer (Weighted to TD mudweight).
STAGE1 LEAD: TYPE 'E' PERMAFROST
ADDITIVES:
WEIGHT:
APPROX #SACKS:
FLOCELE (0.25 #/sk)
12.0 ppg YIELD: 2.17 ft3/sk
MIX WATER: 11.63 gal/sk
706 SACKS THICKENING TIME: Greater than 4 hrs at 50° F.
ANNULAR VOLUME FROM THE TOP OF THE STAGE1 TAIL AT 5461'
MD TO THE ES CEMENTER STAGE TOOL (2200' MD > 200' MD
BELOW BASE OF PERMAFROST) + 50% EXCESS.
STAGE1 TAIL CEMENT TYPE:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
FLUID LOSS:
PREMIUM
SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%), CBL (0.1 #/sk),
FLOCELE (0.1 #/sk)
13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk
278 SACKS THICKENING TIME: Greater than 4 hrs at 50° F.
0-55 cc/30 mins @ 80°F FREE WATER:
TAIL CEMENT FROM TD (6599' MD) TO 500' MD ABOVE THE TOP
OF THE UGNU "M" SANDS (5961' MD) + 50% EXCESS + 80' OF 9-
5/8" 40# CASING CAPACITY FOR SHOE TRACK. EST TOC 5461' MD
SPACER:
STAGE2 LEAD:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
50 BBL Weighted Spacer (To weight of mud circulated before pumping Stage2).
TYPE 'E' PERMAFROST
Retarder
12.0 ppg
938 SACKS
YIELD:2.17 ft3/sk MIX WATER' 11.63 gal/sk
THICKENING TIME: Greater than 4 hrs at 50° F.
ANNULAR VOLUME FROM TOP OF STAGE2 TAIL AT 1625' MD TO
SURFACE +300% EXCESS.
STAGE2 TAIL:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
TYPE 'C' PERMAFROST
YIELD:0.95 ft3/sk MIX WATER: 3.60 gal/sk
100 SACKS THICKENING TIME: Greater than 4 hrs at 50° F.
575' OF ANNULAR VOLUME AT 30% EXCESS FROM ES CEMENTER
AT 2200' MD. EST TOP 'C' 1625' MD
Retarder
15.6 ppg
WELLHEAD STABILITY CEMENT TYPE: Permafrost E
NOTE:
ADDITIVES: Retarder
WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY THE
CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE
SHUT DOWN.
WEIGHT: 12.0 ppg
YIELD:2.17 ft3/sk
MIX WATER: 11.63 gal/sk
APPROX NO SACKS: 150
RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL
CENTRALIZER PLACEMENT:
1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 9-5/8" x 12" Rigid Straight
Blade Centralizers - one (1) per joint on the bottom eighteen (18) joints of
9-5/8" casing. Run two (2) straight blade centralizers on the bottom joint of casing and on the top
centralized joint of casing as well.
2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. Total
centralizers required is 18 + 2 + 2 =22.
OTHER CONSIDERATIONS:
.
Perform any necessary laboratory tests on samples of the water to be used in the cement job to
ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure
compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job
requirement. Displace at 8.0-10.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the
fly -- batch mixing is not necessary.
MP H-13 Well
7" PRODUCTION CASING
CEMENT PROGRAM- HALLIBURTON
SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL:
CIRC. TEMP:
SPACER:
140° F BHST 170i F at 7040' TVDSS.
20 bbls fresh water
70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current
mud weight.
CEMENT TYPE: Premium G
ADDITIVES:
WEIGHT: 15.8ppg
APPROX # SACKS:
FLUID LOSS:
CENTRALIZER PLACEMENT:
1.
2.
0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344
YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk
238 SACKS
THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140i F
< 50cc/30 min @ 140i FREE WATER: 0cc @ 45 degree angle.
:R~I~R~ ~:~IN~STRING~WHILE CEMENTING IF
7"x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 17 joints of 7" casing (34). This
will cover _+300' above the KUPARUK Sand.
Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing
shoe.
OTHER CONSIDERATIONS:
Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job.
Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-11 bpm. Batch
mixing is not necessary.
CEMENT VOLUME:
1. Single stage cement job is calculated to cover 1000 FT MD above the Kuparuk 'C' Sand with 30% excess.
89/17/1997 14:10 907-344-21G0 ANADRILL DPC PAGE
:
mi
' ':S
SHAREDE VICES
DRILLING
i i ii i
· i
MPH- 3 (P7)
VERTICAL SECTION VIEW
i !
· c .
; TVO Scale.' t inch : 1600 feet
Oep Scale.' I inch = JCO0 feet
Drawn · I6 Sep 1997
~0--- t Harker Identification MD BKB SECTN INCLh
, i~.~ Al Ka 0 0 0 O.OC
~ B) KOP/BUILD t,5/100 300 300 0 O.OC
I
, d ~ C) BUILD 2/100 500 500 ~ 3.OC
, D]- 8UILD 2.5/t00 700 699 tB 7.0C
' K E) CURVE 2.5/100 1163 1150 97 18.5~
' F) BUILD 8 5/~00 ~780 17~6 5~4 30.
' ...... ~ ~0~-~I [~Bi~O~.~OIBUILD t827 8841 387
O- ~-"~ ......... ~'-- H) BUILD 3/100 1987 189t 4~8 33.8Z
'~~~;;; ;~'~;';~;~ ;;~ I1 CURVE 3/i00 31t9 2596 1226 67.80
' J) END 3/t00 CURVE 3763 2841 1808 67.80
O- K) DROP 3/100 4904 3272 2865 67.80
L) END 3/t00 DROP 5831 38i3 3606 aO,O0
' P ' N) SCHRADER TARGET 6031 3986 3735 40.00
I
' N) g-5/8" CASING POINT 6599 4aO~ 4100 40.00
; PI END a/tOO CURVE 7471 5181 4446 14.99
, ~) KUPARUK TARGET 93~g 6966 ~677 14.9~
3 ~~~ ~ R) 7' C~SING POINT 9697 7331 4724 14.99
~¢~ ........ PARUK T6T (RaOius 200 Ceet )
, .... . .
I
~ , ANAl;KiLL
~ FI~ASI 3ILl" 'Y PI.AN
) ~ k ~ A ~~,/~
~ EXECUITIO~
I
I ~,,~ ,L-.'~'- A-----J- ,.-~ -~-.... , ,. .
I
,~____ I . . ~ ....
I
I
I
' ,' .... ~-: ~ .,~ ?.;,~ ,.,/ .L': .?,
I : .- ./ ]..':,.
I
~" ~'"
, At'~i' oi'::~r;,'~,I
, , . i ,, - ~.-,
I
.... i . . 11
- I
400 ~200 2000 2800 3600 4400 5200 6000 6800 7600 8400 9200 10000
S,e,c t i,o,,n, Depanture i
·
l~Hl.~7 3.06 9:2E ~ ~ m
06
907-344-2160
ANADRILL DPC PAGE
Marker Identification
A) KB
B) KOP/BUILO 1.5/100
C] BUILD 2/i00
BUILD 2.5/100
E) CURVE 2.5/100
F) BUILD 2.5/100
G) END 2.5/100 BUILD
H) BUILD 3/100
I) CURVE 3/100
J) END 3/~00 CURVE
K) O~OP 3/t00
L) END 3/100 DROP
M) SCHRADER TARGET
N) 9-5/8' CASING POINT
O) CURVE 4/~00
P) END 4/'100 CURVE
KUPARUK TARGET
R) 7" CASING POINT
S) TD
MD
0
300
500
700
1163
1780
1927
1987
3763
4904
5331
6031
6§93
6599
747I
9319
9697
9697
N/S
ON
ON
1N
5N
26 N
20 :N
t2 N
8N
82 S
250 S
727 S
~1063 S
1121 S
~283 $
~286 S
1352 S
1083 S
1028 S
t0~8 S
OE
5E
~2 E
122 E
362 E
44O E
473 E
t333 E
t901E
2843 E
3504 E
36~9 E
3g45 E
3945 E
4299 E
4694 E
4775 E
4775. E
MPH- .3 (P7)
PLAN VIEW
CLOSURE ..... ; 4885 feet at Azimuth 102.1!.
DECLINATIDN.: +27.972
SCALE ....... ; I 1nch = 800 feet
DRAWN ....... ; 17 Sep J997
i
/nadri ]1 Schlumberger
400 0 400- BO0 1200' J600 2000 2400' 2800 3200 3600 4000 4400 4800
<- WEST ' EAST -> -
,m
~_o0
u,, 2
15'40'59'
/
/
/
/
/
/
/
/
/
1
1U'
m
m
m. H.6
.-m:: i.i~- ?
:-m -t i-8
.m.- i~- ~'
m il-:'/
JUL Ib'UF
·
' MPU :H'pAD · ",
· ·
.
.
·
. .
.
. .
.+ AS'BUlLT WELL CONDucTOR-'
m EXISTING WELL..cONDUCTOR
-.
_
.
·
.
·
·
LOCATED wITHIN"PROTRACTEO SECTION"'54. T. 13'N.;.R, 10 E.;.UM!AT MERIDIAN.:'ALASKA' ' '
lJ'bb NO.UUJ P.U2
......... ~/I" ~ I ~Z'''/ '
VICINITY MAP
'N.;
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND. LICENSED
TO PRACTICE LAND .SURVEYING IN
THE STATE OF' ALASKA AND THAT--
THIS PLAT REPRESENTS A SURVEY
·'~ADE BY ME' OR UNDER MY; DIREC1 .
SUPERVISION AND THAT ALL
·DIMENSIONS AND' OTHER DETAILS ARF
CORRECT AS OF AJLY 13, 1997.
NOTES
1. DATE OF SURVEY: ,dULY 9-13. I~.q7..
2. REFERENCE FIELD BOOK:'
MP97-O§ (PGS. 31--37, '6.3-67).
3. ALASKA STATE PLANE COORDINATE5 -
ARE ZONE 4, NAD 27. ..
-4. GEODETIC COORDINATES ARE NAD 192'/.
5. PAD SCALE FACTOR. IS' 0.9999036.
'6. HORIZONTAI:/~I[I~lCAL CONTROl: I.~-'-
· ';"-' BASEl:) ON MONUMENTS FI-1 .AND H-2.
7. ELEVATIONS ARE BPX MPU M,S.L. ·
NO. COORDINATES cooRDINATES POSITION(DMS) pOSIIION(D.OD)' BOx ELEV. OFFSETS
- · - 2,86'3' FSL
iH-11 y= 6,010,013.33 'N= 1,295.29 70"26'16.828" 7.0.4380078* 37.0'
X=. '556r487.05 E= 760.41 149%3.2'21;905" -149.5394181° 4~158' FEL
y= 6,010,041.75 N-'1,324,83' 70'26-'-17.107" - 70.4.380853' .'37.0'- ' 2,891' FSL
H-12 X= 556,495.12- E= 760.50 -14'9'32,21;662". t49..5393506~ ' 4~150' FEL
' Y--6,010,070.40 N, 1,354.57 ..70s26.17.368~: '- 70;4581633" - 2,920~'FSL
H,13 X=- 556r503.05 E= '760.-39- .149..52,21;422- :.1a,9;5392839o' " '56'7" 4,142' FEL
H~14!Y=6,010,099.83 N= 1,385.08 ' 70"26'17.677"i' 70.'4362456; - 36~6~ ' 2,949' FSL
X= 556,511.12 E= 760.20 :.149'32'21.179" -'149.5392164~ '4;'133' FEL
__
DATE
g' BP.- EXPLORATION
MILNE POINT UNIT fl-PAD I
AS-BUILT WELL CONDUCTORS
I DATE I
VENDOR ALASKC-,,ST 'i 4 O0
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET
(2,72997 CKO72997L i00. O0 i00. O0
,,~
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS OESCRIBEO ABOVE. ~l[e]lf;lll ] ~ OO. O0 ~_ OO. OO
· WELL PERMIT CHECKLIST COMPANY
FIELD & POOL ._,4~2_~'/_5,z~ INIT CLASS
WELL NAME ./ti¢. P~- /~._,'~
//- ,~,,~// GEOL AREA
PROGRAM: exp [] dev./~ redrll [] serv [] wellbore seg D ann. disposal para req []
O UNIT# _ //,.~.2_.~ ON/OFF SHORE
ADMINISTRATION
,
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
A R D TE 12.
~ :~;~/.~.,~'_/~,,~ 13.
~E~
Permit fee attached .......................
Lease number appropriate ...................
Unique well name and number ..................
Well located in a defined pool ..................
Well located proper distance from drilling unit boundary ....
Well located proper distance from other wells ..........
Sufficient acreage available in drilling unit ............
If deviated, is wellbore plat included ...............
Operator only affected party ...................
Operator has appropriate bond in force .............
Permit can be issued without conservation order ........
Permit can be issued without administrative approval ......
Can permit be approved before 15-day wait ...........
14.
15.
16.
17.
18.
19.
20.
21.
22.
23.
24.
25.
26.
27.
28.
29.
Conductor string provided ................... k.~NN
Surface casing protects all known USDWs ...........
CMT vol adequate to circulate on conductor & surf csg ..... ,"~..
CMT vol adequate to tie-in long string to surf csg ........
CMT will cover all known productive horizons ..........
Casing designs adequate for C, T, B & permafrost .......
Adequate tankage or reserve pit .................
If a re-drill, has a 10-403 for abandonment been approved... N /LJ,~r-
Adequate wellbore separation proposed .............
If diverter required, does it meet regulations ..........
Drilling fluid program schematic & equip list adequate .....
BOPEs, do they meet regulation ..... ,~--".~-¢¢-, ......
BOPE press rating appropriate; test to ~.~,..--,---o-- psig.
Choke manifold complies w/APl RP-53 (May 84) ........
Work will occur without operation shutdown ........... (~ N
Is presence of H2S gas probable ................. (~ N
GEOLOGY
30. Permit can be issued w/o hydrogen sulfide measures .....
31. Data presented on potential overpressure zones ....... Y
32. Seismic analysis of shallow [las zones ............. N
33. Seabed condition survey (if off-shore) ............. / N
34. Contact name/phone for weekly progress reports ...... / Y N
[exploratory only]
REMARKS
GEOLOGY:
ENGINEERING: COMMISSION:
JDH .......~ RNC~
CO L~
Comments/Instructions:
HOWlfjt - A:\FORMS\chekhst rev 09~97
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 *
* ..... WESTERN ATI. dtS LOG .... *
* ....... PROCESSED BY ....... *
.
....... SCHLUMBERGER .......
COMPANY NA~E : BP EXPLORATION (ALASKA)
WELL NAME : MPH- 13
FIELD NAME : MILNE POINT
BOROUGH : NORTH SLOPE
STATE : ALASKA
API NUMBER : 500292281800
REFERENCE NO : 98397
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
3-AUG-1998 11:40
PAGE:
**** REEL HEADER ****
SERVICE NAME : EDIT
DATE : 98/08/ 3
ORIGIN : FLIC
REEL NAM~ : 98397
CONTINUATION # :
PREVIOUS REEL :
COf~_2TT : BP EXPLORATION, MILNE POINT, MPH-13, API #50-029-22818-00
**** TAPE HEADER ****
SERVICE NA~E : EDIT
DATE : 98/08/ 3
ORIGIN : FLIC
TAPE NAME : 98397
CONTINUATION # : 1
PREVIOUS TAPE :
COf~IE2~T : BP EXPLORATION, MILNE POINT, MPH-13, API #50-029-22818-00
TAPE HEADER
MILNE POINT
CASED HOLE WIRELINE LOGS
WELL NAME: MPH-13
API NUMBER: 500292281800
OPERATOR: BP EXPLORATION (ALASKA)
LOGGING COMPANY: WESTERN ATLAS
TAPE CREATION DATE: 3-AUG-98
JOB NUFIBER: 98397
LOGGING ENGINEER: RECK
OPERATOR WITNESS: R ORYALL
SURFACE LOCATION
SECTION: 34
TOWNSHIP: 13N
RANGE: 10E
FNL:
FSL: 2920
FEL: 4142
FWL:
ELEVATION(FT FROM MSL O)
KELLY BUSHING:
DERRICK FLOOR: 66.04
GROUND LEVEL: 36.70
WELL CASING RECORD
OPEN HOLE CASING DRILLERS CASING
BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT)
1ST STRING 9. 675 6532.0 40. O0
2ND STRING
3RD STRING
PRODUCTION STRING
CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH)
LIS Tape Verification Listing
Schlumberger Alaska Computing Center
3-AUG-1998 11:40
BASELINE CURVE FOR SHIFTS
LDWG TOOL CODE:
LDWG CURVE CODE:
RUN NUFiBER :
PASS NUFiBER :
DATE LOGGED:
LOGGING COMPANY:
BASELINE DEPTH
$
.......... EQUIVALENT UNSHIFTED DEPTH ..........
GR
CONTAINED HEREIN IS THE LDWG FORMATTTED CASED HOLE
GR/CCL DATA AQUIRED ON BP EXPLORATION'S MPH-13 WELL.
THE GR IS THE PRIMARY DEPTH CONTROL FOR THIS WELL.
THIS IS A WESTERN ATLAS LOG PROCESSED BY
SCHLUmbERGER.
$
PAGE:
**** FILE HEADER ****
FILE NAME : EDIT .001
SERVICE · FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NI]blBER: 1
EDITED CURVES
Depth shifted and clipped curves for each pass in separate files.
PASS NUMBER: 1
DEPTH INCREFiE~VT: 0.5000
FILE SUFk~ARY
LDWG TOOL CODE START DEPTH STOP DEPTH
GR 6534.0 4994.5
$
CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH)
BASELINE CURVE FOR SHIFTS
LDWG CURVE CODE:
PASS NUM~ER:
BASELINE DEPTH
$
.......... EQUIVALENT UNSHIFTED DEPTH ..........
GR
REMARKS: THIS FILE CONTAINS THE CASED HOLE MAIN PASS GR/CCL
LIS Tape Verification Listing
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3-AUG-1998 11 '. 40
PAGE:
DATA. THE CURVES HAVE BEEN CLIPPED AT FIRST AND LAST
READINGS.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 0.5
9 65 FT
11 66 64
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 0
** SET TYPE - CHAN **
NAlViE 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 194698 O0 000 O0 0 1 1 1 4 68 0000000000
CCL GR V 194698 O0 000 O0 0 1 1 1 4 68 0000000000
GRCH GR GAPI 194698 O0 000 O0 0 1 1 1 4 68 0000000000
TEND GR LBF 194698 O0 000 O0 0 1 1 1 4 68 0000000000
** DATA **
DEPT. 6533.992 CCL.GR 0.000 GRCH. GR 39.193 TEND.GR
DEPT. 4994.492 CCL. GR 171.250 GRCH. GR 35.684 TEND.GR
322. 227
-5. 963
** END OF DATA **
LIS Tape Verification Listing
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PAGE:
* * * * FILE TRAILER * * * *
FILE NAME : EDIT .001
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE iFUM~ER: 2
EDITED CURVES
Depth shifted and clipped curves for each pass in separate files.
PASS NUM~ER: 2
DEPTH INCREMENT: 0.5000
FILE SU~IARY
LDWG TOOL CODE START DEPTH STOP DEPTH
GR 6534.0 6324.5
$
CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH)
BASELINE CURVE FOR SHIFTS
LDWG CURVE CODE:
PASS NUMBER:
BASELINE DEPTH
..............
.......... EQUIVALENT UNSHIFTEDDEPTH ..........
GR
THIS FILE CONTAINS THE CASED HOLE REPEAT PASS GR/CCL
DATA. THE CURVES HAVEBEENCLIPPEDAT FIRST ANDLAST
READINGS.
$
LIS FORMAT DATA
LIS Tape Verification Listing
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3-AUG-1998 11:40
PAGE: 5
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 16
4 66 1
5 66
6 73
7 65
8 68 O. 5
9 65 FT
11 66 64
12 68
13 66 0
14 65 FT
15 66 68
16 66 1
0 66 1
** SET TYPE - CHAN **
NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS
ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELE~ CODE (HEX)
DEPT FT 194698 O0 000 O0 0 2 1 1 4 68 0000000000
CCL GR V 194698 O0 000 O0 0 2 1 1 4 68 0000000000
GRCH GR GAPI 194698 O0 000 O0 0 2 1 1 4 68 0000000000
TEND GR LBF 194698O0 000 O0 0 2 1 1 4 68 0000000000
** DATA **
DEPT. 6533.992 CCL.GR 0.000 GRCH. GR 30.577 TEND. GR
DEPT. 6324.492 CCL.GR 18.320 GRCH. GR 27.984 TEND. GR
429.537
23.168
** END OF DATA **
LIS Tape Verification Listing
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3-AUG-1998 11:40
PAGE:
**** FILE TRAILER ****
FILE NAME : EDIT .002
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** FILE HEADER ****
FILE NA~E : EDIT .003
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NTgM~ER 3
RAW CURVES
Curves and log header data for each pass in separate files; raw background pass in last file
PASS NUMBER: 1
DEPTH INCREMENT: 0.25
FILE SUMMARY
VENDOR TOOL CODE START DEPTH STOP DEPTH
6546.9 4987.5
GR
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
DEPTH CONTROL USED (YES/NO):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
GR GAF~A RAY
CCL CASING LOCATOR
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
31-MAY-98
JO01 VERI.1
9532.0
9536.0
4994.0
6534.0
TOOL NUMBER
GR 8262XA
CCL 8248EA
LIS. Tape Verification Listing
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3-AUG-1998 11:40
PAGE:
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT):
BOREHOLE CONDITIONS
FLUID TYPE:
FLUID DENSITY (LB/G):
SURFACE TEMPERATURE (DEGF) :
BOTTOM HOLE TEMPERATURE (DEGF):
FLUID SALINITY (PPM) :
FLUID LEVEL (FT) :
FLUID RATE AT WELLHEAD (BPM) :
WATER CUTS (PCT) :
GAS~OIL RATIO:
CHOKE (DEG) :
6532.0
BRINE
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT) :
BASE NORMALIZING WINDOW (FT) :
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT RATE LOW SCALE (CPS):
FAR COUNT RATE HIGH SCALE (CPS):
NEAR COUNT RATE LOW SCALE (CPS):
NEAR COUNT RATE HIGH SCALE (CPS):
TOOL STANDOFF (IN):
REMARKS: LOG WAS RUN WITH MARKED LINE FOR PRIMARY DEPTH CONTROL.
REFERENCE LOG MWD DATED 03-0CT-97 THROUGH 12-0CT-97.
THIS FILE CONTAINS THE RAW MAIN PASS DATA.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE- 64EB **
TYPE REPR CODE VALUE
1 66 0
2 66 0
3 73 20
4 66 1
5 66
6 73
7 65
LISb Tape Verification Listing
Schlumberger Alaska Computing Center
3-AUG-1998 11:40
PAGE: 8
TYPE REPR CODE VALUE
8 68 0.25
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 **
NA~E 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 194698 O0 000 O0 0 3 1 1 4 68 0000000000
CCL GR V 194698 O0 000 O0 0 3 1 1 4 68 0000000000
GR GR GAPI 194698 O0 000 O0 0 3 1 1 4 68 0000000000
TEN GR LBF 194698 O0 000 O0 0 3 1 1 4 68 0000000000
SPD GR F/HR 194698 O0 000 O0 0 3 1 1 4 68 0000000000
** DATA **
DEPT. 6546.992 CCL.GR
SPD.GR 0.000
DEPT. 4987.492 CCL. GR
SPD.GR 0.000
300. 000 GR. GR
59.670 GR.GR
0.000 TEN. GR
0.000 TEN. GR
-500.000
-500.000
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .003
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
LIS_ Tape Verification Listing
Schlumberger Alaska Computing Center
3-AUG-1998 11:40
PAGE:
**** FILE HEADER ****
FILE NAF~E : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
FILE HEADER
FILE NUMBER 4
RAW CURVES
Curves and log header data for each pass in separate files; raw background pass in last file
PASS NUMBER: 2
DEPTH INCREM~a%Uf : 0.25
FILE SUMY~ARY
VENDOR TOOL CODE START DEPTH
...........................
GR 6546.9
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
LOGGING SPEED (FPHR) :
DEPTH CONTROL USED (YES/NO):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
.........................
GR GAMMA RAY
CCL CASING LOCATOR
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLERS CASING DEPTH (FT) :
LOGGERS CASING DEPTH (FT) :
BOREHOLE CONDITIONS
FLUID TYPE:
FLUID DENSITY (LB/G):
SURFACE TEMPERATURE (DEGF) :
BOTTOM HOLE TEMPERATURE (DEGF) :
FLUID SALINITY (PPM) :
FLUID LEVEL (FT) :
STOP DEPTH
..........
6320.3
31-MAY-98
JO01 VERi.1
9532.0
9536.0
4994.0
6534.0
TOOL NUMBER
...........
GR 8262XA
CCL 8248EA
6532.0
BRINE
LIS_ Tape Verification Listing
Schlumberger Alaska Computing Center
3-AUG-1998 11:40
PAGE:
10
FLUID RATE AT WELLHEAD (BPM):
WATER CUTS (PCT) :
GAS~OIL RATIO:
CHOKE (DEG) :
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT) :
BASE NORMALIZING WINDOW (FT):
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT RATE LOW SCALE (CPS):
FAR COUNT RATE HIGH SCALE (CPS):
NEAR COUNT RATE LOW SCALE (CPS):
NEAR COUNT RATE HIGH SCALE (CPS):
TOOL STANDOFF (IN):
REMARKS: LOG WAS RUN WITHMARKEDLINEFOR PRIMARY DEPTH CONTROL.
REFERENCE LOG MWDDATED 03-0CT-97 THROUGH 12-0CT-97.
THIS FILE CONTAINS THE RAW REPEAT PASS DATA.
$
LIS FORMAT DATA
** DATA FORMAT SPECIFICATION RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
i 66 0
2 66 0
3 73 20
4 66 1
5 66
6 73
7 65
8 68 0.25
9 65 FT
11 66 51
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
3-AUG-1998 11:40
PAGE:
11
** SET TYPE - CHAN **
NAM~ 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 194698 O0 000 O0 0 4 1 1 4 68 0000000000
CCL GR V 194698 O0 000 O0 0 4 1 1 4 68 0000000000
GR GR GAPI 194698 O0 000 O0 0 4 1 1 4 68 0000000000
TEN GR LBF 194698 O0 000 O0 0 4 1 1 4 68 0000000000
SPD GR F/HR 194698 O0 000 O0 0 4 1 1 4 68 0000000000
** DATA **
DEPT. 6546.992
SPD.GR 0.000
DEPT. 6320.242
SPD.GR 2660.453
CCL.GR 200.000 GR.GR 0.000 TEN. GR
CCL.GR 28.125 GR.GR 51.828 TEN. GR
-500.000
26.004
** END OF DATA **
**** FILE TRAILER ****
FILE NAME : EDIT .004
SERVICE : FLIC
VERSION : O01CO1
DATE : 98/08/ 3
MAX REC SIZE : 1024
FILE TYPE : LO
LAST FILE :
**** TAPE TRAILER ****
SERVICE NAME : EDIT
DATE : 98/08/ 3
ORIGIN : FLIC
TAPE NAME : 98397
CONTINUATION # : 1
PREVIOUS TAPE :
COf4FiFJFT : BP EXPLORATION, MIL1VE POINT, MPH-13, API #50-029-22818-00
**** REEL TRAILER ****
SERVICE NAME : EDIT
DATE : 98/08/ 3
ORIGIN : FLIC
REEL NAME : 98397
CONTINUATION # :
PREVIOUS REEL :
COMFiENT : BP EXPLORATION, MILNE POINT, MPH-13, API #50-029-22818-00
Sperry-Sun Drilling Services
LIS Scan Utility
Wed Aug 12 21:25:37 1998
Reel Header
Service name ............. LISTPE
Date ..................... 98/08/12
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 ..................... 98/08/12
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Previous Tape Name ....... UNKNOWN
Comments ................. STS LIS Writing Library. Scientific Technical
Services
Physical EOF
Comment Record
TAPE HEADER
MILNE POINT UNIT
MWD/MAD LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB DATA
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION (FT FROM MSL 0)
MWD RUN 1
AK-MM-70287
B. ZIEMKE
P. LOCKWOOD
RECEIVED
AUG 1 9 1998
500292281800
BP EXPLORATION (ALASKA) , INC.
SPERRY-SUN DRILLING SERVICES
12-AUG- 98
MWD RUN 2
AK-MM-70287
B. ZIEMKE
P. LOCKWOOD
MWD RUN 3
AK-MM-70287
G. TOBIAS
P. LOCKWOOD
34
13N
10E
2920
4142
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
1ST STRING
2ND STRING
3RD STRING
PRODUCTION STRING
REMARKS:
.00
66.00
36.70
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
20.000 112.0
12.250 9.625 6578.0
8.500 9800.0
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY
(DGR) UTILIZING
GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE
RESISTIVITY
PHASE-4 (EWR4) .
3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR)
UTILIZING GEIGER
MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY
PHASE-4 (EWR4),
COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO
DENSITY (SLD) .
4. DUE TO CASING AND CEMENTING PROBLEMS, THE 9 5/8"
CASING WAS DRILLED OUT
WITH A ROTARY ASSEMBLY AND A LEAK OFF TEST COMPLETED
AFTER DRILLING DOWN TO
6658'MD, 4453'TVD. THIS RUN DID NOT INCLUDE MWD TOOLS.
5. ALL MWD RUNS REPRESENT MPH-13 WITH API#
50-029-22818-00. THIS WELL REACHED
A TOTAL DEPTH {TD) OF 9800'MD, 7439'TVD.
SROP= SMOOTHED RATE OF PENETRATION WHILE DRILLING.
SGRC= SMOOTHED GAMMA RAY COMBINED.
SEXP= SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA
SHALLOW SPACING).
SESP= SMOOTHED PAHSE 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 FOR RESISTIVITY
SENSOR.
SPSF= SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE
MATRIX FIXED HOLE SIZE)
SNNA= SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES.
SNFA= SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES.
SBDC= SMOOTHED BULK DENSITY -COMPENSATED.
SCOR= SMOOTHED STANDOFF CORRECTION.
SFPE= SMOOTHED FAR DETECTOR ONLY PHOTOELECTRIC
ABSORPTION FACTOR.
ENVIRONMENTAL PARAMETERS USED FOR NUCLEAR LOG PROCESSING:
HOLE SIZE= 8.5".
MUD FILTRATE SALINITY= 1600 PPM.
MUD WEIGHT= 9.8 PPG.
FORMATION WATER SALINITY= 14545 PPM.
FLUID DENSITY= 1.0 G/CC.
MATRIX DENSITY= 2.65 G/CC.
LITHOLOGY= SANDSTONE.
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/08/12
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.
.5000
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
GR
RPD
RPM
RPS
RPX
FET
ROP
FCNT
NCNT
NPHI
PEF
DRHO
RHOB
$
START DEPTH
47 5
51 5
51 5
51 5
51 5
103 5
104 5
6552 0
6552 0
6552 0
6587 5
6587 5
6587 5
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
47 5
4997
5034
5072
5103
5133
5156
5179
5180.5
5184.0
5195.5
5199.0
GR
5O 0
5OOO 0
5037 0
5076 0
5106 0
5132 5
5161 0
5183 5
5186 5
5188 5
5201 0
5203 5
STOP DEPTH
9736 0
9716 5
9716 5
9716 5
9716 5
9716 5
9801 0
9690 5
9690 5
9690 5
9725 5
9725 0
9725 0
EQUIVALENT UNSHIFTED DEPTH --
0'98~g
O'~II
I
OM NflH ,T,I~
0086
LIS9
I0~9
I~99
9~9
E0£9
88E9
I8E9
8E~9
9819
0¥19
LII9
qII9
L609
~809
8L09
8E09
6109
LI09
0009
816~
016~
~06g
~88~
998~
0'g98~
~'LES~
O'~gS~
~'998~
~08~
~9LS
09£~
I~t~
6~g~
L89~
8~9~
Lg~
0~
SIPS
66£S
I6£S
Ig~S
OIlS
£0~S
ZCOD %00J, fl~cI
I086
8IS9
99~9
EEC9
£0C9
68E9
08E9
8£¥9
L819
6II9
9119
~II9
8609
E809
LL09
LEO9
L109
~I09
666S
916S
806S
668q
E88S
~98~
098S
SESS
I£8S
g¥8S
gOSS
~9LS
L~L~
69L~
~EL~
8ILS
~89S
g~9q
LS~S
I8~S
E9~S
09~
8I~S
9I~S
~6g~
8SgS
LIgS
LOgq
gOES
MWD
MWD
REMARKS:
MERGED MAIN PASS.
$
2486.0 6640.0
6658.0 9800.0
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
Name Service Order Units Size Nsam
DEPT FT 4 1
ROP MWD FT/H 4 1
GR MWD API 4 1
RPX MWD OHMM 4 1
RPS MWD OHMM 4 1
RPM MWD OHM~ 4 1
RPD MWD OHMM 4 1
FET MWD HOUR 4 1
NPHI MWD P.U. 4 1
NCNT MWD CNTS 4 1
FCNT MWD CNTS 4 1
RHOB MWD G/CC 4 1
DRHO MWD G/CC 4 1
PEF MWD BARN 4 1
Rep Code Offset Channel
68 0 1
68 4 2
68 8 3
68 12 4
68 16 5
68 20 6
68 24 7
68 28 8
68 32 9
68 36 10
68 40 11
68 44 12
68 48 13
68 52 14
Name Min Max Mean Nsam
DEPT 47.5 9801 4924.25 19508
ROP 9.787 2471.48 202.223 19394
GR 7.3618 424.872 72.3759 19341
RPX 0.0983 117.857 13.2962 19331
RPS 0.0705 2000 18.9464 19331
RPM 0.0871 2000 34.2865 19331
RPD 0.05 2000 29.0142 19331
FET 0.0929 115.172 1.43736 19227
NPHI 20.8719 81.7622 46.8014 6267
NCNT 2048 3426.96 2537.81 6267
FCNT 402 1017 617.722 6267
RHOB 1.0792 2.996 2.3799 6276
DRHO -0.087 0.3772 0.0773102 6276
PEF 1.67 16.7717 2.41718 6277
First
Reading
47 5
104 5
47 5
51 5
51 5
51 5
51 5
103 5
6552
6552
6552
6587.5
6587.5
6587.5
Last
Reading
9801
9801
9736
9716 5
9716 5
9716 5
9716 5
9716 5
9690 5
9690 5
9690 5
9725
9725
9725.5
First Reading For Entire File .......... 47.5
Last Reading For Entire File ........... 9801
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/08/12
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 ........... 1.0.0
Date of Generation ....... 98/08/12
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: 1
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR
RPD
RPM
RPS
RPX
FET
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
5O 0
54 0
54 0
54 0
54 0
106 0
107 0
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:
STOP DEPTH
2423 5
2433 5
2433 5
2433 5
2433 5
2433 5
2486 0
03-OCT-97
5.07
5.46
MEMORY
2486.0
112.0
2486.0
.4
MAXIMUM ANGLE:
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GA/V94_A RAY
EWR4 ELECTROMAG. RESIS. 4
$
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY S) :
MUD PH:
MUD CHLORIDES PPM) :
FLUID LOSS (C3 :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN) :
EWR FREQUENCY (HZ) :
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
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
42.9
TOOL NUMBER
P0815CGR8
P0815CGR8
12.250
12.3
SPUD / LSND
9.80
80.0
9.5
8OO
6.5
3.600
3.645
2.700
5.400
22.8
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 1 API 4 1 68 4 2
RPX MWD 1 OHMM 4 1 68 8 3
RPS MWD 1 OHMM 4 1 68 12 4
RPM MWD 1 OHMM 4 1 68 16 5
RPD MWD 1 OHMM 4 1 68 20 6
ROP MWD 1 FT/H 4 1 68 24 7
FET MWD 1 HOUR 4 1 68
28
Name Min Max Mean
DEPT 50 2486 1268
GR 13.5372 99.4249 50.2764
RPX 0.0983 117.857 31.2235
RPS 0.0705 2000 51.1896
RPM 0.0871 2000 112.757
RPD 0.05 2000 90.8472
ROP 13.239 603.031 176.242
FET 0.1354 0.9781 0.50037
Nsam
4873
4748
4760
4760
4760
4760
4759
4656
First
Reading
50
50
54
54
54
54
107
106
Last
Reading
2486
2423.5
2433.5
2433.5
2433.5
2433.5
2486
2433.5
First Reading For Entire File .......... 50
Last Reading For Entire File ........... 2486
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/08/12
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 ....... 98/08/12
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.002
Comment Record
FILE HEADER
FILE NUMBER: 3
RAW MWD
Curves and log header data for each bit run in separate files.
BIT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 2425.0
FET 2434.5
RPD 2434.5
RPM 2434.5
STOP DEPTH
6577.5
6587.5
6587.5
6587.5
RPS 2434.5
RPX 2434.5
ROP 2487.5
LOG HEADER DATA
DATE LOGGED:
S O FTWARE
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:
6587.5
6587.5
6640.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
DGR DUAL GAMMA RAY
EWR4 ELECTROMAG. RESIS. 4
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE (IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS MUD TYPE:
MUD DENSITY (LB/G):
MUD VISCOSITY (S) :
MUD PH:
MUD CHLORIDES (PPM) :
FLUID LOSS (C3) :
RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)
MUD AT MEASURED TEMPERATURE (MT):
MUD AT MAX CIRCULATING TERMPERATURE:
MUD FILTRATE AT MT:
MUD CAKE AT MT:
NEUTRON TOOL
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
TOOL STANDOFF (IN):
EWR FREQUENCY (HZ) :
REMARKS:
$
Data Format Specification Record
Data Record Type .................. 0
Data Specification Block Type ..... 0
05-OCT-97
5.07
5.46
MEMORY
6640.0
2486.0
6640.0
37.3
70.5
TOOL NUMBER
P0815CGR8
P0815CGR8
12.250
12.3
SPUD / LSND
9.30
74.0
9.0
800
4.2
3.400
2.725
2.55O
5.100
34.5
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
DEPT
GR
RPX
RPS
RPM
RPD
ROP
FET
Name Service Order Units Size Nsam Rep
FT 4 1 68
MWD 2 AP1 4 1 68
MWD 2 OHMM 4 1 68
MWD 2 OHMM 4 1 68
MWD 2 OHMM 4 1 68
MWD 2 OHMM 4 1 68
MWD 2 FT/H 4 1 68
MWD 2 HOUR 4 1 68
Code Offset Channel
0 1
4 2
8 3
12 4
16 5
2O 6
24 7
28 8
Name Min Max Mean
DEPT 2425 6640 4532.5
GR 7.3618 114.009 58.5094
RPX 0.8569 80.6947 11.2819
RPS 0.9046 2000 12.9578
RPM 0.9118 2000 13.3576
RPD 0.6096 2000 13.6119
ROP 9.787 1828.54 204.342
FET 0.0929 9.6231 0.856014
Nsam
8431
8306
8307
8307
8307
8307
8306
8307
First
Reading
2425
2425
2434 5
2434 5
2434 5
2434 5
2487 5
2434 5
Last
Reading
6640
6577.5
6587.5
6587.5
6587.5
6587.5
6640
6587.5
First Reading For Entire File .......... 2425
Last Reading For Entire File ........... 6640
File Trailer
Service name ............. STSLIB.003
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/08/12
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 ....... 98/08/12
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: 3
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
FCNT
NCNT
NPHI
FET
RPD
RPM
RPS
RPX
PEF
DRHO
RHOB
GR
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
6551 0
6551 0
6551 0
6576 5
6576 5
6576 5
6576 5
6576 5
6586 5
6586 5
6586 5
6596 5
6643 0
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
EWR4
CNP
SLD
$
9715
9724
9724
9724
9735
9800
DUAL GAMMA RAY
ELECTROMAG. RESIS. 4
COMPENSATED NEUTRON
STABILIZED LITHO DEN
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE {IN):
DRILLER'S CASING DEPTH (FT) :
BOREHOLE CONDITIONS
MUD TYPE:
STOP DEPTH
9689 5
9689 5
9689 5
9715 5
9715 5
9715 5
9715 5
5
0
0
0
0
0
12-OCT-97
5.07
5.46
MEMORY
9800.0
6658.0
9800.0
10.5
32.7
TOOL NUMBER
P0833CRDGP6
P0833CRDGP6
P0833CRDGP6
P0833CRDGP6
8.500
8.5
LSND
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
9.80
46.0
9.5
1600
4.2
1.300
.900
1.200
1.500
Name Service Order Units Size Nsam Rep Code Offset Channel
DEPT FT 4 1 68 0 1
GR MWD 3 API 4 1 68 4 2
RPX MWD 3 OHMM 4 1 68 8 3
RPS MWD 3 OHMM 4 1 68 12 4
RPM MWD 3 OHMM 4 1 68 16 5
RPD MWD 3 OHMM 4 1 68 20 6
NPHI MWD 3 P.U. 4 1 68 24 7
ROP MWD 3 FT/H 4 1 68 28 8
FET MWD 3 HOUR 4 1 68 32 9
FCNT MWD 3 CNTS 4 1 68 36 10
NCNT MWD 3 CNTS 4 1 68 40 11
RHOB MWD 3 G/CC 4 1 68 44 12
DRHO MWD 3 G/CC 4 1 68 48 13
PEF MWD 3 BARN 4 1 68 52 14
50.0
First
Name Min Max Mean Nsam Reading
DEPT 6551 9800 8175.5 6499 6551
GR 24.6664 424.872 107.444 6278 6596.5
Last
Reading
9800
9735
RPX 0.5841 18.5404 2.29161
RPS 0.593 18.7429 2.32591
RPM 0.594 29.5545 2.34626
RPD 0.6358 2000 3.18896
NPHI 20.8719 81.7622 46.7913
ROP 23.4908 2471.48 219.109
FET 0.1975 115.216 3.31826
FCNT 402 1017 617.696
NCNT 2048 3426.96 2538.07
RHOB 1.0792 2.996 2.3799
DRHO -0.087 0.3772 0.0773102
?EF 1.67 16.7717 2.41723
6279 6576.5 9715.5
6279 6576.5 9715.5
6279 6576.5 9715.5
6279 6576.5 9715 . 5
6278 6551 9689.5
6315 6643 9800
6279 6576.5 9715.5
6278 6551 9689.5
6278 6551 9689.5
6276 6586.5 9724
6276 6586.5 9724
6276 6586.5 9724
First Reading For Entire File .......... 6551
Last Reading For Entire File ........... 9800
File Trailer
Service name ............. STSLIB.004
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/08/12
Maximum Physical Record..65535
File Type ................ LO
Next File Name ........... STSLIB.005
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 98/08/12
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Reel Trailer
Service name ............. LISTPE
Date ..................... 98/08/12
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Services
Scientific Technical
Scientific Technical
Physical EOF
Physical EOF
End Of LIS File
