Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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OVERSIZED
r~ Logs of vadous kinds
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Date: '~/~./ Is~
TO RE-SCAN
Notes:
Re-Scanned by: Beverly Mitdmd Daretha ~ Lowell
PLUGGi~'G & LOCATION CLE~_R3_~CE REPORT
StaUa cf Alaska
.Lease
.Harkar ~cs= c= pla=a:
Locau£on Clearamca:
Conclusions:
Code
·
STATE OF ALASKA
ALASKA'01L AND GAS CONSERVATION COl~i~ilSSlON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
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. 198-139 301-013
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22903-00
9. Unit or Lease Name
4. Location of well at surface~ ~'~
3853' NSL, 1923' WEL, SEC. 25, T13N, R10E, UM l-~_-
Milne
Point
Unit
At top of productive interval
1643' NSL, 693' EWL, SEC. 19, T13N, R11 E, UM
At total depth 10. Well Number
1910' NSL, 942' EWL, SEC. 19, T13N, R11 E, UM . . MPE-30
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. ;11. Field and Pool
Milne Point Unit / Schrader Bluff
KBE = 57.05' ADL 047438
12. Date Spudded 113. DateT.D. Reached114. Date Comp., Susp., or Aband. 115. Water depth, if offshore ,16. Nc. of Completions
7/25/98 7/29/98 3/13/2001 N/A MSL I Zero
17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV setI 21. Thickness of Permafrost
7200 4744 FTI 7169 4725 FTI [] Yes [] NoI N/A MDI 1800' (Approx.)
22. Type Electric or Other Logs Run
MWD/LWD, G R/CCL/CBL
23. CASING, LINER AND CEMENTING RECORD
CASING SE'I-FING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED
13-3/8" 72# L-80 36' 120' 16" 250 sx Arcticset I (Approx.)
5-1/2" 15.5# J-55 34' 7169' 6-3/4" ;'47 sx Coldset Ill. 158 sx Foamed, 70 sx 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD)
None None
MD TVD MD TVD
26. Ac~D, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
6754' Set CIBP
6754' P&A with 25 Bbls Class 'G' below CIBP
6737' Set Whipstock
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
Not on Production N/A
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAWTY-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.
RECEIVED
JUL 1 0 ?_001
Alaska 0il & Gas Cons. Commission
A~chorage
Form 10-407 Rev. 07-01-80
ORIGINAL
Submit In Duplicate
29.
Marker Name
Schrader Bluff 'D3'
Schrader Bluff 'C'
Schrader Bluff
Geologic Markers
Measured
Depth
6739'
6790'
6835'
True Vertical
Depth
4494'
4522'
30.
Formation Tests
Include interval tested, pressure data, all fluids recovered
and gravity, GOR, and time of each phase.
,EiVED
JUL 1 0 Z00]
9nts:
Summary of Daily Drilling Reports
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed Terrie Hubble ~ Technical Assistant
MPE-30 198-139 301-013 ---
Well Number
Permit ~oval No.
Alaska Oil & Gas Cons. Commission
Anchorage
Date ~1~./O'O~
Prepared By Name/Number: Terrie Hubble, 564-4628
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation,
injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any
attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the
producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data
Pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Legal Well Name: MPE-30A
Common Well Name: MPE-30A Spud Date: 7/25/1989
Event Name: PLUG+ABANDON Start: 3/9/2001 End:
Contractor Name: Rig Release:
Rig Name: Rig Number:
I ' : .:~::~:~ : % ~: ~ ~ :~} ::. ~.~ -:, i~ .... ; :~::~::~s ~:~c ;: 4~L~ :
3/9/2001 12:00 - 13:30 1.50 MOB P PRE Scope and Lower derrick
13:30 - 18:00 4.50 MOB P ;PRE Move Rig from H-04 to MPE-30
18:00 - 20:00 2.00 RIGU P PRE Raise and scope derrick
20:00 - 00:00 4.00 RIGU P PRE Spot and berm tiger tank, rig up lines to tree, & tiger tank, fill
pits with 9.0 ppg fluid
3/10/2001 00:00 - 01:30 1.50 RIGU P PRE Spot and berm tiger tank, rig up lines to tree, & tiger tank, fill
pits with 9.0 ppg fluid
01:30 - 02:00 0.50 RIGU P PRE PU Lubr. and Pull BPV LD Lubr.
02:00 - 06:00 4.00 RIGU P PRE Test lines to 3,500 psi. Circulate well
06:00 - 06:30 0.50 RIGU P PRE Monitor well, well static.
06:30 - 07:00 0.50 WHSUR P DECOMP Install ~C and Test to 3,500 psi.
07:00 - 08:00 1.00 WHSUR P DECOMP Nipple down Tree
08:00 - 12:00 4.00 WHSUR P DECOMP Nipple up BOP and Change out rams. Install 2 3/8" rams
12:00 - 14:00 2.00 WHSUR P DECOMP Test BOPE to 250 psi/3,500 psi.
14:00 - 15:30 1.501 WHSUR P DECOMP Make up Lubricator and pull ~CV
15:30 - 17:00 1.50 WHSUR P DECOMP Make up Landing joint and Back out Lock down Screws
17:00 - 18:00 1.00 PULL P DECOMP Rig up double sheave and ropes. Pull Hanger to the floor
18:00 - 00:00 6.00 PULL P DECOMP Lay down hanger, test heat tra~ and ESP. Hang drain hose
on sheave. TOH with 2 3/8" tbg Haet tra~ and ESP
Completion
3/11/2001 ~00:00 - 10:30 10.50 PULL P DECOMP TOH with 2 3/8" tbg Haet trace and ESP Completion. Bottom
of HT on joint 112 ~ 3,388'.
10:30 - 11:30 1.00 PULL ;P DECOMP Inspect and Lay down ESP
11:30 - 16:00 4.50 PULL i P DECOMP Clear and clean rig floor. Lay down elephant Trunk and double
sheave. Install 2" stand pipe.
16:00 - 18:30 2.50 CLEAN P DECOMP Rig up floor and make up 4.75" mill w/BHA. BHA co~ists of
Mill, 2 JB, Bumper Sub, and Jars.
18:30 - 00:00 5.50 CLEAN P DECOMP Pick up 2 3/8" HT drill pipe and TIH
3/12/2001 00:00 - 02:00 2.00 CLaN = DECOMP Pick up 2 3/8" DP and TIH. Tag fill at 6,737'
02:00 - 06:00 4.00 CLEAN P DECOMP Pick up kelly and wash and ream from 6,737' to 6,930'.
06:00 - 07:30 1.50 CLEAN = DECOMP Circulate boEoms up and establish injection rate. 1 bbl./min ~
500 psi / 2.5 bbl./min ~ 2000 psi
07:30 - 11:00 3.50 CLEAN ~ DECOMP Monitor well well stati. Pull out of the hole with 2 3/8" drill pipe
11:00 - 12:30 1.50 CLEAN ~ DECOMP Break out and LD BHA. Clean rig floor
12:30 - 13:30 1.00 P~ DECOMP Rig up Schlumberger
13:30 - 15:30 2.00 P~ ~ ABAN Run in the hole with Jb and GR to 6760'
15:30 - 18:00 2.50 P~ ~ ABAN RIH with EZSV and set at 6,754' WL Measurement. Set with
GR and CCL Log Pedorating Record Sept 07,1998.
18:00 - 18:30 0.50 P~ ~ ABAN Rig down Schlumberger
18:30 - 23:00 4.50 P~ ~ ABAN Make up EZSV stinger and rih with same on 2 3/8" HT drill
pipe. Pressure up to 600 psi on the annulus and test packer.
23:00 - 23:30 0.50 P~ ~ ABAN Establish injection rate initial 1 bbl./min at 400 psi final 2.5
bbl./min at 1900 psi.
23:30 - 00:00 0.50 P~ ~ ABAN Held PJSM with co. man, Schlumberger and rig crews.
3/13/2001 00:00 - 01:00 1.00 P~ P ABAN Pump 25 bbls of abandonment cement. Displace with 19. bbls
of water. Cement in pla~ Stung out of ezsv
01:00 - 01:30 0.50 P~ P ABAN Reversed circulated with 45 bbls. recovered 2 bbls ~ment.
clean returns
01:30 - 02:00 0.50 P~ P ABAN Close annular and test ezsv to 2,500 psi. Held OK
~02:00 - 08:30 6.50 P~ P ABAN Pull out of the Hole with 2 3/8" HT drill pipe t0 2,200'
08:30 - 10:00 1.50 P~ P ABAN RU HBR and Freeze protect well with 52 bbls.
10:00 - 12:30 2.50 P~ P ABAN Continue POOH and LD drillpipe
12:30 - 13:00 0.50 P~ P ABAN lay down ~mnet stinger BHA and clear rig floor
Printed: 512412001 2:45:56 PM
OperationsSum
Legal Well Name: MPE-30A
Common Well Name: MPE-30A Spud Date: 7/25/1989
Event Name: PLUG+ABANDON Sta~: 3/9/2001 End:
Contractor Name: Rig Release:
.Rig Name: Rig Number:
Date From- To Hours Activi~ Code NPT ~Phase:
3/13/2001 13:00 - 16:00 3.00 WHSUR P ABAN i aEempt to install False bowl with ~C and RILDS, would not fit
properly pulled out
16:00 - 17:00 1.00 WHSUR P ABAN Nipple Down BOP ( Remove Flow Nipple, Choke and Kill
HCR's)
17:00 - 19:30 2.50 WHSUR P ABAN Wait while machine shop reworks false bowl protector
19:30 - 20:00 0.50 WHSUR P ABAN Install false bowl protector and ~C RILDS exit 1 Lock down
screw stripped.
20:00 - 21:00 1.00 WHSUR P ABAN Nipple down BOP test spool and flange
21:00 - 23:30 2.50 WHSUR P ABAN Remove bad Lock down screw, redress and reinsall in head
unable to s~w all the way in. Installed packing and gland nut.
seal effective.
23:30 - 00:00 0.50 WHSUR P ABAN install frac tree and shell test to 5,000 psi
3/14/2001 00:00 - 01:00 1.00 WHSUR P ABAN Rig down lines and Secure Tree and Cellar
Rig released at 01:00 Hrs.
Printed: 5/24/2001 2:45:56 PM
BP EXPLORATION Alaska, Inc.
m WELL SERVICE REPORT
K1 (MPE-30(W4-6))
WELL JOB SCOPE JOB NUMBER
MPE-30
DATE DALLY WORK UNIT NUMBER
04/13/01 WHIPSTOCK 2145
DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR
72 NOI NO SWS-GARCIA
FIELD AFC# CC# DALLY COST ACCUM COST Signed
ESTIMATE $10,005.00 $800,232.75
Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann Final Outer Ann
0 PSI 0 PSI 0 PSI 0 PSI 0 PSI 0 PSI
DALLY SUMMARY
SET WHIPSTOCK AT 6737 FT. RA TAGS AT 6745.9CCL-TOP OF WHIPSTOCK: 15 FTSTOP CCL AT 6722 FT.TO SET THE
WHIPSTOCK SAT DOWN IN CEMENT RETAINER PICKED UP TENSION PLUS 2 FT.
TIME
16:00
18:15
19:21
LOG ENTRY
MIRU SWS UNIT 2145
HOLD SAFETY MEETING
RIH WITH HEAD/SW/ROLLER/WEIGHT/POS/PGGTD/ROLLERS/SAFE/BAKER10/WHIP. TW: 1500 LBS, TL:56 FT,
MOD:4.5 INCH (ROLLERS)
20:00 LU TO CORRELATE WITH TWO SHORT JOINTS BETWEEN 6250 FT AND 6450 FT.
21:20 SAT DOWN IN CEMENT RETAINER, LOG UP PICK-UP TENSION PLUS 2 FT.STOP AT 6722 FT CCL DEPTH AND
SET THE WHIPSTOCK AT 6737 FT 10 DEG TO THE RIGH OF THE HIGHSIDE. POOH
22:00 START TO RD.
23:00 CALL DSO. LEAVE LOCATION
Conclusion: Whip stock was set approx. 8' the 6745' asked for In the program. The bottom was solid. The top of the
whipstock Is approx. 17' below the collar at 6720'
AFE# 337221 9335-070-770 Drlg / Sidetrack / E-Line SWS = $10,000 / 795 Baker = $ 40M
STATE OF ALASKA
ALASK ...... IL AND GAS CONSERVATION COM, .... .j,SlON
APPLICATION FOR SUNDRY APPROVAL
1. Type of Request:
[] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate
[] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other
[] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack
2. Name of Operator
BP Exploration (Alaska) Inc.
5. Type of well: [] Development
[] Exploratory
[] Stratigraphic
[] Service
3. Address
P.O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
3853' NSL, 1923' WEL, SEC. 25, T13N, R10E, UM
At top of productive interval
1643' NSL, 693' EWL, SEC. 19, T13N, R11E, UM
At effective depth
At total depth
1910' NSL, 942' EWL, SEC. 19, T13N, R11E, UM
6. Datum Elevation (DF or KB)
KBE - 57.05'
7. Unit or Property Name
Maine Point Unit
8. Well Number
MPE-30
9. Permit Num~j~r
198-139
10. APl Number
50- 029-22903-00
11. Field and Pool
Maine Point Unit / Schrader Bluff
12.
Present well condition summary
Total depth: measured
Effective depth:
Casing
Structural
Conductor
Surface
Intermediate
Production
Liner
true vertical
measured
true vertical
7200 feet k/,/
4744 feet
7169 feet
4725 feet
Length Size
84' 13-3/8"
7135' 5-1/2"
Plugs (measured)
Junk (measured) Fish at 7086'
Cemented MD TVD
250 sx Arcticset I (Approx.) 120' 120'
747 sx CS III, 158 sx Foamed, 70 sx 'G'
7169' 4725'
Perforation depth: measured
true vertical
6758'-6778', 6845'-6865'
4474'-4487', 4528'-4540'
Tubing (size, grade, and measured depth) 2-3/8", 4.7#, J-55 to 6596
Packers and SSSV (type and measured depth) None
RECEIVED
Alaska Oil & Gas Cons. Commissbn
Ar~"hora~
13. Attachments
[] Description Summary of Proposal
14. Estimated date for commencing operation
February 7, 2001
16. If proposal was verbally approved
Name of approver
Date Approved
Contact Engineer Name/Number: Mark Johnson, 564-5666
15.
[] Detailed Operations Program [] BOP Sketch
Status of well classifications as:
[]Oil [] Gas [] Suspended
Service
Prepared By Name/Numbec Terrie Hubble, 564-4628
17. I hereby certify that th~foregoing is truC'""aod correct to the best of my knowledge
Signed /',//?// // //~'~,. ~../.~"/ Title CT Drilling Engineer Date
Mark Johnson //"~C/, ,~//t,/~'L¢~,---'---" /
Conditions of Approval: Notify Commissio¢~'o representative may,~,itness c.-~_~ .~'[ ?'-~,~ .~_%_1~_ I Approval No.._~)~, -- C)[ ..~
Plug integrity__ BOP Test ~ Location clearance
Mechanical Integrity Test __ Subsequent form required 10-
Approved by order of the Commission
Form 10-403 Rev. 06/15/88
Commissioner
Date ~//¢;~/~/~,/
Submit · -~ripl~ate
bp
January 11, 2001
To:
Attention:
Subject:
Alaska Oil & Gas Conservation Commission
3001 Porcupine Ddve
Anchorage, Alaska 99501
Tom Maunder
Petroleum Engineer
MPE-30 CTD Sidetrack Prep
BP Exploration Alaska Inc.
Drilling & Wells
Coiled Tubing Drilling Team
Well MPE-30 is scheduled for a multilateral sidetrack to be drilled with coiled
tubing. The following summarizes the procedure required to prep MPE-30 for
drilling and is submitted as an attachment to Form 10-403. A schematic diagram
of this proposed completion is attached.
Nabors 4ES plans to pull the existing ESP pump completion and set a cast iron
bridge plug to abandon the perforations as preparation for the CTD sidetrack.
1. MIRU Nabors 4ES.
2. Pull existing 2 318' ESP completion.
3. Perform scraper run to 6760'.
4. Set 5 ~" cast iron bridge plug at 6750' (8' above the top perforations) shutting
off sand/proppant production from the existing Schrader OA and OB
perforation intervals.
5. Test 5 ~" casing and plug to 2000 psi.
6. ND BOPs and swap tubing spool to 11"x 7". Set BPV.
7. RDMO Nabors 4ES.
CTD Sidetrack Operations
8. MIRU service coil. Pull BPV.
9. RIH with whipstock and set above the CIBP at 6750'- service coil.
10. Mill window off whipstock and --,5' of formation - service coil.
11. RDMO service coil.
12. MIRU Coiled Tubing Drilling and drill 2 horizontal laterals (E-30a & E-30a L1)
targeting the Schrader OA sand. Run 2 7~8" slotted liner in both. (Please
see drilling permit application for details).
The Nabors 4ES operations are expected to commence February 7, 2001. Drilling
coil is expected to beg/i~he sidetrack drilling on February 15, 2001.
Mark O. Johnson/"//
CT Drilling Engine(~r
564-5666 office
240-8034 cell
johnsomo@BP.com
RECEIVED
dJ~N _1 ~ 2001
Alaska 0il & Gas Cc~s. Commission,
Anchorage
Tree: 29/16"-5M MpI~F-Rn Orig. DFElev.= 57.0' (N 27E)
r Wellhead: 7" 5M Varco ADRS-7 Weld
I r--'-'--I--'- ' Orig. GL Bev. = 23.2'
on style I -- / DF to 7" csg. hng.= 33.6' (N 27E)
Tbg. Hng: 2 7/8" x 11" FMC w/2 7/8"
I
/
/
NSCT T&B and 2.5" CIW H BPV ! /I-- - 7" 26 ppf L-80 Btrc.
13 3/8" 72 ppi, L-80
KOP @ 500' ~ ii Camco 2 3/8'x 1"
Max. hole angle = 69 to 73 deg. sidepocket KBMM GLM I 120' I
from 3950' to 5850'
Hole angle thru' perfs = 73 deg.
i I ~' 5.5"PortCollarCementer ' 1336'md I
I 3,500'1 Centrilift heat trace
2 3/8" 4.70" ppf, J-55, 8 rd EUE tbg..
( drift ID =1.995" cap. = 0.00387 bpf )
5.5" 15.5 ppf, J-55, Btrc. prod. casing
( drift ID = 4.950", cap. = 0.0238 bpf )
I [. Camco 2 3/8"x 1"
i L KUDU 110TP/1800PCP,I 6536'
il Centrilift flex shaft intake tvdl 4,354' I
Stimulation Summary ~ Centrilift seal section
I
6~570'
OA / OB Sands - Limited entry frac w/119.6 M# fst3dblresh6aflashsn
of PropLoked 16/30 Badger prop. behind pipe. ~. Centrilift FMH series,
54 hp motor, 1020 v. / 35
amps. [ 9:01 Gear Box ]
Perforation Summary Centrilift PHD
Ref lo.q:
Two 5.5" x 20' short jts. f/6320' to 6359' md
Size SPF Interval (TVD) ~
3 3/8" 0.6 6758' - 6778' (4475' - 4484')
'OB' Sand ~
3 3/8" 2 6845'-6865' 4523'-4560') 'JTM , J
Fish* * fish - three 1" x 4" slip dies
..-fish - 90 ea. 7/8" dia., 1.3 s.g. ball sealers
,~~ k. 5.5" float collar (PBTD)
5.5" float shoe
DATE REV. BY ! COMMENTS MILNE POINT UNIT
08/05/98 JBF Drilled and Cased by Nabors 27E WELL E-30
10/20/98 MDO Completion w/heat trace 4 ES APl NO: 50-029-22903
BP EXPLORATION (AK)
R CEiVED
A~ho
MPE-30a & L1
Proposal
ESP completion installed by
Nabors 4ES after CTD is ~
completed
2 7/8" Slotted Liner 6665'-9775'
Whipstock
at 6655'
5 1/2" 15.5# long string casing
MPE-30a L1
TD 9775'
3.75" Openhole
Whipstock
at 6745'
Existing Perfs
6758-6778'
6845-6865'
ClBP
at 6750'
2 7~8" Slotted Liner 6740'-10361'
MPE-30a
3.75" Openhole
TD 10361'
MOJ
1/11/01
5 1/2" Float Shoe 7169'
RECEIVED
JAN 1 B 2001
Alaska Oil & Gas Cons, Commission
Anchorage
'~' Rig: NABORS.4ES
13-5/8 BOP STACK
All equipment is rated to 5000 psi rated minumum
DRIP PAN I
',Line Line
ANNULAR
ii
BLIND SHEARS
#
PIPE RAMS
RIG FLOOR
I.
17.oa I
~-11.90 1
#
3' Choke Une
20.94
21.95
t
TBG
SPOOL
CSG
SPOOL
RECEIVED
JAN -]- 2 2001
Alaska Oil & Gas Cons, Commission
Updated: 06/18/96 (tlh)
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of~~¢ll
[~ Oil i--] Gas i--I Suspended I--] Abandoned [--] Service --. vu ~.~$ ~.,,~....
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 98-139
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22903
4. Location of well at surface 9. Unit or Lease Name
3853' NSL, 1923' WEL, SEC. 25 T13N, R10E, UM' 'i:i;:.~,':",f.:'i'.i: :~ Milne Point Unit
.... . .~ ~ ..
At top of productive interval !' r ; i.';",i i ~ 10. Well Number
1643' NSL, 693' EWE, SEC. 19, T13N, RllE, UM'/¢/20/¢/.~.~ ~
-'I ",'~.~;~?~ ~ MPE-30
At total depth : /.....r. :~:!:.... i ~ ':~...-~. ' ~ 11 Field and Pool
1910' NSL, 942' EWL, SEC. 19, T13N, R11E, UM: )~_~" ! '; :~" - ~-~-:-; '
e Milne Point Unit / Schrader Bluff
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease'Designa1~i0n and S ri
KBE = 57.05' I ADL 047438
12. Date Spudded I 13. Date I.D. Reached I 14. Date Comp., Susp., or Aband. I15. Water depth, if offshore 116. No. of Completions
7/25/98 7/29/98 10/20/98 N/A MSLI One
17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost
7200' 4744 FTI 7169' 4725 FTI [] Yes I--I No] N/A MD I 1800' (Approx.)
22. Type Electric or Other Logs Run
MWD/LWD, GR/CCL/CBL
23. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH HOLE
SIZE WT. PER FT. GRADE TOP BO-FrOM SIZE CEMENTING RECORD AMOUNT PULLED
13-3/8" 72# L-80 36' 120' 16" 250 sx Arcticset I (Approx.)
5-1/2" 15.5# J-55 34' 7169' 6-3/4" 747 sx Coldset II1, 158sx Foamed, 70sx 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD)
3-3/8" Gun Diameter, 2 spf 3-3/8" Gun Diameter, 6 shots 2-3/8", 4.7#, J-55 6596' None
MD TVD MD TVD
6855' - 6865' 4534' - 4540' 6768' - 6778' 4480' - 4487' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
6845' - 6855' 4528' - 4534' 6758' - 6768' 4474' - 4480'
Freeze protect with 13 bbls Diesel
123820# 16/30 Badger proppant, 119620#
behind pipe, 4200# left in casing
27. PRODUCTION TEST ~ ~ ! /'~
Date First Production [Method of Operation (Flowing, gas lift, etc.)U I1 ! LU i111/&L
November 3, 1998 Electric Submersible Pump
Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAs-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED OIL-DEL iGAs-MCF WATER-DEL OIL GRAVFY-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.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name
Depth Depth recovered and gravity, GOR, and time of each phase.
' Schrader Bluff 'D3' 6739' 4463'
Schrader Bluff 'C' 6790' 4494'
Schrader Bluff 'B' 6835' 4522'
31. List of Attachments
Summary of Daily Drilling Reports, Surveys
32. I hereby certjCv that the f~regoi~ and cCr~to the b~s~of ~¢y k, nowledge /Z///;~(-:-~/¢¢ c~
Signed ~~.~ ~... //~.1~% ~ ~/-: 'Z)//
Ch ~ Title' Drilling Superintendent Date
[~j~, MPE-30 98-139 '-' Prepared By Name/Number: Carol Withey, 564-4114
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'.
Form 10-407 Rev. 07-01-80
Facility
Date/Time
22 Jul 98
23 Jul 98
24 Jul 98
25 Jul 98
26 Jul 98
27 Jul 98
28 Jul 98
29 Jul 98
M Pt E Pad
Progress Report
Well MPE-30
Rig Nabors~ ~7~
Page
Date
Duration
Activity
12:00-14:00
14:00-14:30
14:30-06:00
06:00-06:30
06:30-15:00
15:00-21:00
21:00-02:00
02:00-06:00
06:00-06:30
06:30-09:00
09:00-12:00
12:00-12:30
12:30-18:00
18:00-18:30
18:30-00:00
00:00-02:00
02:00-06:00
06:00-06:30
06:30-10:00
10:00-10:30
10:30-12:00
12:00-12:30
12:30-18:00
18:00-18:30
18:30-06:00
06:00-06:30
06:30-10:30
10:30-11:30
11:30-12:00
12:00-13:00
13:00-18:00
18:00-18:30
18:30-19:00
19:00-22:30
22:30-23:30
23:30-02:30
02:30-04:30
04:30-06:00
06:00-06:30
06:30-15:30
15:30-17:00
17:00-19:00
19:00-23:00
23:00-05:00
06:00-06:30
06:30-08:30
08:30-09:00
09:00-10:00
2 hr
1/2 hr
15-1/2 hr
1/2 hr
8-1/2 hr
6 hr
5 hr
4 hr
1/2 hr
2-1/2 hr
3 hr
1/2 hr
5-1/2 hr
1/2 hr
5-1/2 hr
2 hr
4 hr
1/2 hr
3~1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
5-1/2 hr
1/2 hr
11-1/2 hr
1/2 hr
4 hr
lhr
1/2 hr
1 hr
5 hr
1/2 hr
1/2 hr
3-1/2 hr
1 hr
3 hr
2 hr
1-1/2 hr
1/2 hr
9 hr
1-1/2 hr
2 hr
4hr
6 hr
1/2 hr
2 hr
1/2 hr
1 hr
Rigged down Lines / Cables
Held safety meeting
Rig moved 50.00 %
Held safety meeting
Rig moved 80.00 %
Held safety meeting
Rig moved 100.00 %
Rigged up Divertor
Held safety meeting
Rigged up Divertor
Racked back Drillpipe
Tested Divertor
Racked back Drillpipe
Held safety meeting
Racked back Drillpipe
Rigged up Handling equipment
Racked back Tubing
Held safety meeting
Racked back Tubing
Held safety meeting
Made up BHA no. 1
Tested Fluid system
Drilled to 632.0 ft
Held safety meeting
Drilled to 1961.0 ft
Held safety meeting
Drilled to 2534.0 ft
Circulated at 2534.0 ft
Pulled out of hole to 1579.0 ft
R.I.H. to 2534.0 ft
Drilled to 3013.0 ft
Held safety meeting
Circulated at 3013.0 ft
Pulled out of hole to 200.0 ft
Pulled BHA
Made up BHA no. 2
R.I.H. to 3013.0 ft
Drilled to 3203.0 ft
Held safety meeting
Drilled to 4062.0 ft
Circulated at 4062.0 ft
Pulled out of hole to 1765.0 fl
R.I.H. to 4062.0 ft
Drilled to 4827.0 ft
Held safety meeting
Drilled to 5018.0 ft
Circulated at 5018.0 fl
Pumped out of hole to 3310.0 ft
10:00-10:30
10:30-18:00
18:00-18:30
18:30-01:30
01:30-02:30
02:30-03:30
1/2 hr
7-1/2 hr
1/2 hr
7 hr
1 hr
1 hr
R.I.H. to 5018.0 ft
Drilled to 5688.0 fl
Held safety meeting
Drilled to 6166.0 ft
Circulated at 6166.0 ft
Pumped out of hole to 4750.0 ft
1
29 December 98
Progress Report
Facility M Pt E Pad
Well MPE-30 .~ c'
Page 2
Date 29 December 98
Date/Time
03:30-05:00
05:00-06:00
06:00-06:30
06:30-03:00
30 Jul 98 03:00-04:00
04:00-06:00
06:00-06:30
06:30-09:00
09:00-11:30
11:30-13:00
13:00-17:00
17:00-19:00
19:00-23:00
23:00-00:00
31 Jul 98 00:00-02:00
02:00-04:00
04:00-06:00
06:00-06:30
06:30-08:00
08:00-09:00
09:00-12:00
12:00-13:00
13:00-23:00
23:00-00:30
01 Aug 98 00:30-06:00
06:00-08:30
08:30-10:30
10:30-12:00
12:00-12:30
12:30-15:30
15:30-18:00
18:00-19:30
19:30-21:30
21:30-04:00
02 Aug 98 04:00-06:00
06:00-06:30
06:30-08:30
08:30-10:30
10:30-12:30
12:30-13:00
13:00-17:00
17:00-19:00
19:00-21:00
21:00-01:00
03 Aug 98 01:00-02:00
02:00-03:00
03:00-06:00
06:00-06:30
06:30-07:30
07:30-08:00
08:00-09:00
09:00-10:00
10:00-11:00
11:00-12:00
Duration
1-1/2 hr
1 hr
1/2 hr
20-1/2 hr
1 hr
2hr
1/2 hr
2-1/2 hr
2-1/2 hr
1-1/2 hr
4 hr
2 hr
4 hr
1 hr
2 hr
2hr
2 hr
1/2 hr
1-1/2 hr
1 hr
3hr
1 hr
10hr
1-1/2 hr
5-1/2 hr
2-1/2 hr
2hr
1-1/2 hr
1/2 hr
3 hr
2-1/2 hr
1-1/2 hr
2 hr
6-1/2 hr
2hr
1/2 hr
2 hr
2 hr
2 hr
1/2 hr
4 hr
2 hr
2 hr
4 hr
1 hr
1 hr
3 hr
1/2 hr
1 hr
1/2 hr
lhr
1 hr
1 hr
1 hr
Activity
R.I.H. to 6166.0 ft
Drilled to 6261.0 ft
Held safety meeting
Drilled to 7200.0 ft
Circulated at 7200.0 ft
Pumped out of hole to 5800.0 ft
Held safety meeting
Pulled out of hole to 1460.0 ft
R.I.H. to 7200.0 ft
Circulated at 7200.0 ft
Pulled out of hole to 200.0 ft
Pulled BHA
Conducted electric cable operations
Made up BHA no. 3
R.I.H. to 7200.0 ft
Circulated at 7200.0 ft
Pulled out of hole to 5800.0 ft
Held safety meeting
Pulled out of hole to 200.0 ft
Pulled BHA
Conducted electric cable operations
Held safety meeting
Ran Casing to 7168.0 ft (5-1/2in OD)
Circulated at 7169.0 ft
Ran Tubing in stands to 7088.0 ft
Repaired Draw works
Space out tubulars
Circulated at 7~169.0 ft
Held safety meeting
Mixed and pumped slurry - 224.000 bbl
Circulated at 1336.0 ft
Mixed and pumped slurry - 105.000 bbl
Retrieved downhole equipment - DV collar
Pulled Tubing in stands to 0.0 ft
Rigged down Handling equipment
Held safety meeting
Pulled Tubing in stands to 0.0 ft
Ran Drillpipe to 0.0 ft (2-7/8in OD)
Ran Drillpipe to 1400.0 ft (2-7/8in OD)
Circulated at 1400.0 ft
Ran Drillpipe to 4826.0 ft (2-7/8in OD)
Repaired Handling equipment
Ran Drillpipe to 7086.0 ft (2-7/8in OD)
Circulated at 7086.0 ft
Pulled Drillpipe in stands to 5250.0 ft
Serviced Top drive
Tested Casing
Held safety meeting
Ran Drillpipe to 1438.0 ft (2-7/8in OD)
Tested Casing
Pulled Drillpipe in stands to 1300.0 ft
Tested Casing
Pulled Drillpipe in stands to 0.0 ft
Rig waited · Materials
Facility
Date/Time
04 Aug 98
05 Aug 98
M Pt E Pad
Progress Report
Well MPE-30
Rig Nabors/4~
Page
Date
Duration
Activity
12:00-13:30
13:30-14:00
14:00-14:30
14:30-15:00
15:00-15:45
15:45-16:30
16:30-17:00
17:00-03:00
03:00-04:00
04:00-05:00
05:00-06:00
06:00-06:30
06:30-07:00
07:00-08:00
08:00-10:00
10:00-11:00
11:00-12:00
12:00-14:30
14:30-21:30
21:30-01:30
01:30-02:30
02:30-06:00
06:00-06:30
06:30-08:00
1-1/2 hr
1/2 hr
1/2 hr
1/2 hr
3/4 hr
3/4 hr
1/2 hr
10hr
1 hr
1 hr
1 hr
1/2 hr
1/2 hr
1 hr
2hr
1 hr
1 hr
2-1/2 hr
7 hr
4 hr
1 hr
3-1/2 hr
1/2 hr
1-1/2 hr
Ran Drillpipe to 1336.0 ft (2-7/8in OD)
Pulled Drillpipe in stands to 972.0 ft
Ran Drillpipe to 270.0 ft (2-7/8in OD)
Tested Casing
Pulled Drillpipe in stands to 0.0 ft
Ran Drillpipe to 200.0 ft (2~7/8in OD)
Tested Casing
Laid down 5000.0 ft of 2-7/8in OD drill pipe
Serviced Block line
Serviced Top drive
Ran Drill collar to 630.0 ft (3-1/8in OD)
Held safety meeting
Ran Drill collar to 630.0 ft (3-1/8in OD)
Tested Casing
Laid down 630.0 ft of Drill collar
Ran Drillpipe in stands to 2200.0 fl
Freeze protect well - 50.000 bbl of Diesel
Laid down 2200.0 ft of 2-7/8in OD drill pipe
Laid down 5200.0 ft of Tubing
Rigged down Divertor
Serviced Drillfloor / Derrick
· Rig waited: Assessed situation
Held safety meeting
Set Retrievable packer at 55.0 ft with 2500.0 psi
3
29 December 98
Facility
Date/Time
13 Sep 98
14 Sep 98
15 Sep 98
16 Sep 98
17 Sep 98
M Pt E Pad
Progress Report
Well MPE-30
Rig Nabors 4ES
Page
Date
Duration
Activity
06:01-19:00
19:00-19:30
19:30-22:00
22:00-01:00
01:00-04:30
04:30-05:30
05:30-06:00
06:00-06:15
06:15-06:30
06:30-07:00
07:00-08:00
08:00-08:15
08:15-10:00
10:00-10:30
10:30-11:00
11:00-14:00
14:00-16:00
16:00-17:00
17:00-18:00
18:00-18:15
18:15-20:00
20:00-20:30
20:30-21:30
21:30-23:00
23:00-04:00
04:00-06:00
06:00-06:15
06:15-07:00
07:00-09:30
09:30-14:00
14:00-14:30
14:30-15:00
15:00-15:30
15:30-16:00
16:00-17:00
17:00-18:00
18:00-18:15
18:15-20:30
20:30-23:00
23:00-23:15
23:15-03:00
03:00-04:00
04:00-06:00
06:00-06:15
06:15-14:00
14:00-17:30
17:30-18:00
18:00-18:15
18:15-19:00
19:00-22:00
22:00-22:30
22:30-00:30
00:30-01:00
01:00-02:30
12-3/4 hr
1/2 hr
2-1/2 hr
3 hr
3-1/2 hr
1 hr
1/2 hr
1/4 hr
1/4 hr
1/2 hr
1 hr
1/4 hr
1-3/4 hr
1/2 hr
1/2 hr
3 hr
2hr
lhr
1 hr
1/4 hr
1-3/4 hr
1/2 hr
lhr
1-1/2 hr
5 hr
2 hr
1/4 hr
3/4 hr
2-1/2 hr
4-1/2 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
1 hr
1 hr
1/4 hr
2-1/4 hr
2-1/2 hr
1/4 hr
3-3/4 hr
1 hr
2 hr
1/4 hr
7-3/4 hr
3-1/2 hr
1/2 hr
1/4 hr
3/4 hr
3 hr
1/2 hr
2hr
1/2 hr
1-1/2 hr
Rig moved 100.00 %
Removed Xmas tree
Installed BOP stack
Tested BOP stack
Ran Tubing to 3103.0 fl (2-3/8in OD)
Circulated at 3103.0 fl
Ran Tubing to 3500.0 ft (2-3/8in OD)
Held safety meeting
Serviced Drillfloor / Derrick
Ran Tubing to 3797.0 ft (2-3/8in OD)
Pulled Tubing in stands to 0.0 ft
Installed BOP test plug assembly
Serviced Variable ram
Tested Variable ram
Made up BHA no. 1
Singled in drill pipe to 3797.0 fi
Reamed to 3961.0 ft
Circulated at 3961.0 fl
Reamed to 4115.0 ft
Held safety meeting
Reamed to 4330.0 ft
Singled in drill pipe to 4680.0 fi
Circulated at 4680.0 ft
Singled in drill pipe to 6576.0 ft
Reamed to 7079.0 ft
Circulated at 7079.0 ft
Held safety meeting
Circulated at 7069.0
Circulated at 7069.0
Laid down 7061.0 ft
Pulled BHA
Serviced Block line
Installed BOP stack
Tested Pipe ram
fl
fl
of 2-7/8in OD drill pipe
Rigged up Completion string handling equipment
Rig waited · Equipment
Held safety meeting
Rigged up sub-surface equipment - ESP
Installed Electrical submersible pumps
Held safety meeting
Ran Tubing to 2937.0 ft (2-3/8in OD)
Rigged up sub-surface equipment - Electric cable
Ran Tubing in stands to 3583.0 ft
Held safety meeting
Ran Tubing in stands to 4850.0 ft
Pulled Tubing in stands to 2937.0 fi
Rigged down sub-surface equipment - Electric cable
Held safety meeting
Rigged down sub-surface equipment - Electric cable
Ran Tubing in stands to 6627.0 ft
Rigged up Tubing hanger
Installed Electric cable
Ran Tubing on landing string to 6627.0 ft
Removed BOP stack
1
29 December 98
Facility
Date/Time
M Pt E Pad
Progress Report
Well MPE-30
Rig Nabors 4ES
Duration
Activity
02:30-03:00
03:00-04:00
04:00-04:15
04:15-04:30
04:30-05:00
05:00-06:00
1/2 hr
1 hr
1/4 hr
1/4 hr
1/2 hr
1 hr
Installed Xmas tree
Tested Xmas tree
Retrieved Hanger plug
Installed Hanger plug
Freeze protect well - 50.000 bbl of Diesel
Removed High pressure lines
Page
Date
2
29 December 98
Facility
Date/Time
18 Oct 98
19 Oct 98
20 Oct 98
M Pt E Pad
12:00-13:00
13:00-14:00
14:00-20:00
20:00-21:00
21:00-22:00
22:00-22:30
22:30-00:30
00:30-01:00
01:00-02:00
02:00-02:30
02:30-03:00
03:00-03:15
03:15-04:00
04:00-05:30
05:30-06:00
06:00-06:15
06:15-09:00
09:00-09:30
09:30-10:30
10:30-11:00
11:00-11:30
11:30-13:00
13:00-14:00
14:00-16:00
16:00-18:00
18:00-18:15
18:15-19:00
19:00-20:00
20:00-21:00
21:00-06:00
06:00-06:15
06:15-10:00
10:00-10:30
10:30-13:00
13:00-15:30
15:30-16:00
16:00-16:15
16:15-18:00
18:00-18:15
18:15-19:00
19:00-19:30
19:30-20:00
20:00-20:30
20:30-21:00
21:00-21:30
21:30-22:00
Duration
1 hr
1 hr
6 hr
1 hr
1 hr
1/2 hr
2hr
1/2 hr
1 hr
1/2 hr
1/2 hr
1/4 hr
3/4 hr
1-1/2 hr
1/2 hr
1/4 hr
2-3/4 hr
1/2 hr
1 hr
1/2 hr
1/2 hr
1-1/2 hr
1 hr
2 hr
2 hr
1/4 hr
3/4 hr
1 hr
1 hr
9 hr
1/4 hr
3-3/4 hr
1/2 hr
2-1/2 hr
2-1/2 hr
1/2 hr
1/4 hr
1-3/4 hr
1/4 hr
3/4 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
1/2 hr
Progress Report
Well MPE-30 Page
Rig Nabors 4ES Date
Activity
Rigged down Drillfloor / Derrick
Rigged down Service lines
Rig moved 100.00 %
Rigged up Drillfloor / Derrick
Installed High pressure lines
Retrieved Hanger plug
Fill pits with Brine
Tested High pressure lines
Circulated closed in well at 6540.0 ft
Circulated at 6540.0 ft
Flow check
Installed Hanger plug
Removed Xmas tree
Installed BOP stack
Serviced Pipe ram
Held safety meeting
Tested All functions
Retrieved Hanger plug
Installed Tubing retrieval string
Retrieved Tubing hanger
Tested Hanger penetrator
Pulled Tubing in stands to 1498.0 ft
Serviced Electric cable
Pulled Tubing in stands to 3500.0 ft
Rigged up sub-surface equipment ~ Electric cable
Held safety meeting
Rigged up sub-surface equipment - Electric cable
Ran Tubing in stands to 3783.0 ft
Serviced Electric cable
Ran Tubing in stands to 5925.0 ft
Held safety meeting
Ran Tubing in stands to 6560.0 ft
Rigged up Tubing hanger
Serviced Electric cable
Serviced Electric cable
Ran Tubing on landing string to 6597.0 ft
Installed Hanger plug
Removed BOP stack
Held safety meeting
Installed Xmas tree
Tested Xmas tree
Tested High pressure lines
Retrieved Hanger plug
Freeze protect well - 13.000 bbl of Diesel
Cleared Chicksan lines
Held safety meeting
1
29 December 98
Well Compliance Report
File on Left side of folder
198-139-0 MILNE POINT UNIT SB
Roll/41: Start: Stop Roll/42:
MD 07200 TVD 04744 Completion Date:
E-30 50- 029-22903-00
Start Stop
10/20/98 Completed Status: 1-OIL
BP EXPLORATION
(ALASKA) INC
Current:
Name Inferval
D 8733 2 ~/SPERRY MPT/GR/EWR4 OH
L 4 ARM CALIPER FINAL 154-3938.5 CH 5
L CBL FINAL 70-4775 CH 5
L CBL FINAL 70-4775 CH 2
L DGR/EWR4-MD 2 3013-7200 OH
L DGR/EWR4-TVD 2 2839-4744 OH
L PERF FINAL 0-4775 CH 5
R SRVY RPT /SPERRY 0-7200. OH
?,
Daily
Well
Ops
-- Are Dry Ditch Samples Required? yes (~
Was the well cored? yes (~) Analysis Description Received? yes ~
Comments:
Sent Received T/C/D
11/18/98 11/18/98
10/22/98 10/22/98
12/4/98 12/10/98
12/4/98 12/10/98
11/18/98 11/18/98
11/18/98 11/18/98
9/25/98 10/22/98
12/30/98 1/6/99
And Received? yes no
Sample Set #
Wednesday, November 08, 2000 Page 1 of 1
Milne Point Unit, Alaska
TO:
FROM:
Well Name:
Main Category:
Sub Category:
Operation Date:
Bill Hill Date: 19-8-98
Herb Thackeray
MP E-30
DRLG
PERF
9-7-98
Background: During primary cementing of the casing, the port collar did not work properly on
the second stage and the well was found with green cement and sand in the hole requiring coil
clean out. There is also a small drip coming from the bradenhead that is being monitored.
A previous perf attempt resulted in stuck tools and having to pull out of the rope socket. Slickline
was able to fish the tools and bail additional sand 'that accumulated at 4377' where the dogleg is
severest. The drilling rig had also lost 3 slip dies in the hole which are now believed to be pushed
to bottom.
Objective: Run E-line GR/CCL/CBL for correlation Icg and access cement for possible clues to
bradenhead leak situation. Perforate the Schrader Bluff "OB" and "CA" sands using 10 foot guns
to reduce risk of getting stuck again.
Sequence of Events: MIRU SWS. MU Cement Bond Tool w/centralizers & GR/CCL with set
of rollers (total length a scary 51 ') with packoff on frac tree. RIH and made it through dogleg at
4377' ok but stopped rolling at 4775'. Didn't feel it was worth risking getting stuck or the time to
experiment with other roller systems. Logged from 4775' to surface. The bond actually looks
pretty good considering the Iow compressive strength of the lead cement, up to ,--1770' (there was
probably a few hundred feet of fallback from the port collar at 1336'). The second stage was again
Iow compressive strength, the bond is not great but there is cement to ,--150' (fallback likely
again). The 13 3/8" shoe is at 115' so the drip could possibly originate below the surface shoe or
be channeling from further down?
MU 10' 3 3/8" perf gun and GR/CCL tool on rollers. Pick up lubricator and PFF to 2500 psi. RIH to
7000' with no problems getting down hole. Log up to 6250' and correlate to MWD Icg 7/30/98.
Depth correct and drop back down to 7020'. Pull up to position Gun #1. Perforate "OB" from 6855
- 6865' (10') with 2 spf (20 holes) 'Big Hole' charges at 0-180 phasing. POOH - all shots fired.
MU and RIH with Gun #2. Position in "OB" and perforate 6845 - 6855' (10') with 2 spf (20 holes)
'Big Hole' charges at 0-180 phasing. POOH - all shots fired.
MU and RIH with Gun #3. Position in "CA" and perforate 6768 - 6778' (10') with total of 6 shots
'Big Hole' charges at 0-180 phasing. POOH - all shots fired.
MU and RIH with Gun #4. Position in "CA" and perforate 6758 - 6768' (10') with total of 6 shots
'Big Hole' charges at 0-180 phasing. POOH - all shots fired.
RD MO SWS.
Results: Ran GR/CCL/CBL from 4775' to surface. Inconclusive as to source of bradenhead drip.
Ran GR/CCL from 7020 to 6250' (above marker joints). Perforated Schrader Bluff "OB" from
6845-6865' (20') with 2 spf and "OA" from 6758-6778' (20' - 12 holes total).
BP EXPLORATION (ALASKA)INC.
Milne Point Unit
TO: John Hendrix
FROM: Jim Fox
DATE:
RE:
Sept. 08, 1998
E-30 'OA / OB' DATAFRAC AND PROPLOK FRAC
SERVICE CO'S.: Dowell, Halliburton, Peak
JOB SUMMARY
This is the third radically descoped well to be fracced and utilized a limited entry frac design.
Both the 'OA' and 'OB' were fracced at one time rather than individually as in non-RDS wells.
The design of this frac was similar to the first two. The design plus excess was put away without
problem however there did not appear to be any net pressure increase indicative of tip
screenout.
The final design called for 115.1 M# of proppant. 123,800 lbs. of 16-30 Badger proppant was
pumped, 119,600 made it behind pipe of which everything after the 0.5 ppg stage (122,800 lbs.)
was coated with Halliburton PropLok resin at a concentration of 3/8 gal. / 100 lbs proppant.
Crosslinked borate gel was used for the pad through 0.5 ppg stage, then switched to 75# HEC
linear gel for the remainder of the slurry when the PropLok resin was pumped (due to
incompatibility with the guar gel). The pad and 0.5 ppg stages were pumped at 20 bpm and
then ramped up to 40 bpm for the duration. The slurry was displaced with 30 bbl. of HEC gel
followed by 9.8 ppg brine (for freeze protection) to within 20 bbl. of the top perforation..
Prior to the frac a ball out, injectivity test, and a water data frac were performed. The ball out
was performed with 90 ea. 7/8" dia., 1.3 s.g. ball sealers pumped at intervals of one ball every
two seconds in 45 bbl. of 2% KCI water, displaced to the perfs at a rate of 15 bpm, and over
displaced by 45 bbls. (last ball 14 bbls. past the bottom perforation) at a rate of 15 bpm. There
was very good pressure response (740 to 1200 psi build ) starting shortly after the ball sealers
reached the perfs in two distinct events. Immediately following, the wellbore was surged three
times to dislodge the ball sealers from the casing wall. Each surge consisted of rapidly bleeding
the pressure back to the open top tank until the pressures fell from approx. 1000 psi to approx.
100 psi and stabilized (a period of approx. 20 sec. each). The pressure falloff was monitored for
3,~ hour before going to the injectivity test to allow time for the ball sealers to fall into the rathole.
The injectivity test consisted of 120 bbl. of 2% KCI water injected at 20 bpm. and monitor
pressure falloff for 1/2 hr. This was then followed by the 200 bbl. KCI data frac at 40 bpm w/1
hr. pressure falloff surveys.
Page 2 ' . ,_ --
BALL OUT
Design Rate, Bbls Ball Number of Ball Final STP, psi Fluid Type
BPM Pumped Type Balls Action?
15 209 7/8" 1.3 SG 90 very 2880 2% KCI
good
INJECTIVITY TEST
Design Rate, Bbls Max Rate, Final treat. ISIP, NWB friction, Treat grad,
BPM Pumped bpm psi PSI psi psi/ft
20 120 20.2 1525 1050 na 0.67
DataFRAC (2% KCI)
Design Rate, Bbls Max Rate, Final Treating ISIP, NWB friction, Treat grad,
BPM Pumped bpm psi PSI psi psi/ft
40 200 40.2 2216 1075 na 0.68
FRAC
Sand Prop Prop Proppant Coated Tresaver
pumped, # behind pipe, left in csg, size/type Prop, # rubber left in
Job was # # hole?
Flushed 123,820 119,620 4200 16/30 Badger 122,800 No
I
TIME I OPERATIONS SUMMARY
09/08/98
1520 Safety meeting
1550 Set Treesaver - Pressure test treating lines to 5000 psig.
1603 Start ball out.
1702 Start injectivity test.
1739 Start 200 bbl. KCI datafrac
2043 Start frac.
2108 S/D pumps, monitor pressure for 15 min. and start rig down.
Page 3 ...... ~__-J
II PUMPING SUMMARY
TIME RATE ANNP WHP STAGE CUM COMMENTS
BPM PSIG PSIG BBL BBL
BALL OUT DISPLACEMENT = 160.8 BBLS
1557 Open well. Set tree saver.
1603 0 / 15 440 0 0 Start ball out procedure.
1603.5 15 1653 4 4 At rate. Start releasing 90 7/8" 1.3 s.g. ball
sealers at 2 sec. interval.
1605 15.1 1602 31 31
1605.5 15.2 1584 34 34 All balls released.
1607.5 15.2 1488 66 66
1609 15.2 1456 88 88
1611 14.9 1500 120 120
1612 15.0 1465 100 100
1614 15.0 1447 165 165 First ball sealer reaching perfs.
1614.7 14.6 1808 175 175
1615.5 14.9 2225 186 186
1616.2 15.5 2989 197 197
1617 15 / 0 2880 209.5 209.5 S/D pumps. ISIP = 1090 psig.
1617.5 surge 1000 Back surge wellbore to tank for approx. 20 sec.
approx. 1000 psi to 100 psi.
1618.0 surge 1000 Back surge wellbore to tank for approx. 20 sec.
approx. 1000 psi to 100 psi.
1618.5 surge 980 Back surge wellbore to tank for approx. 20 sec.
approx. 1000 psi to 100 psi.
1620 0 907 Allow time for ball sealers to fall into the rathole.
Monitor pressure falloff.
1630 0 797
1639 0 701 Stop monitoring pressures in order to shut in well
and remove ball launcher from treating line.
INJECTIVITY TEST
1702 0 / 20 421 209.5 Start pumping KCl for Injectivity test.
1702.8 20 1648 10 219 @ rate
1705 20.2 1547 54 263
1706 20.0 1529 66 285
1707 20.1 1525 306
1708.3 20 / 0 1523 329.5 S/D pumps. ISIP = 1050. Monitor PFO.
1710 0 1007
172O 0 9O7
1730 0 801
Page 4 .~ _J
DATA FRAC
1739 0 / 40 737 0 329.5 Start pumping 200 bbl. KCI datafrac
1740.7 40 2298 38 367
1741.5 40.1 2298 75 405
1743 40.2 2220 132 462
1744 40.2 2211 170 500
:1744.7 40 / 0 2216 200.3 529.8 S/D pumps. ISIP = 1075. Monitor PFC).
1750 0 971
1800 0 893
1810 0 829
1820 0 788
1830 0 746
1840 0 714
1850 0 687
1900 0 655
1915 0 623
1930 0 595
1945 0 568
2000 0 540
2015 0 522
2030 0 504
2040 0 495
FRAC
2043 0 / 20 485 0 529.8 Start pumping 12 bbI.XL borate gel pad at 20
bpm
2044.5 20 1666 8 538 @ displacement rate.
2046.5 20.4 1570 50 579
2046.8 20 / 40 2180 55 584 increase rate from 20 to 40 bpm.
2047.5 40 2097 79 608 @ design rate
2050 39.6 1923 179 708
2051.5 40.0 2088 779 1 ppg just starting on perfs.
2054 40.2 2289 880
2051.5 :.~05540.2 2275 910 3 ppg just starting on perfs.
2056.7 40.0 2243 983 4 ppg just starting on perfs.
2058.4 40.1 2248 1046 5 ppg just starting on perfs.
2100.3 40.1 2211 1124 6 ppg just starting on perfs.
2103.8 40.1 2220 1276 7 ppg just starting on perfs.
2104.4 40.0 2230 1286 8 ppg just starting on perfs.
2106.1 40.3 2271 1356 Flush called at 1305 cum. vol.
2107 40.3 2200 1400
2108 40 / 0 2097 1446.2 Shut down pumps w/20 bbl. underdisplacement.
Page 5 ..... . i
FLUIDS PUMPED DOWNHOLE
Bailout 210 BBL
Injectivity 120 BBL
Datafrac 200 BBL
Frac 916 BBL
Total 1446 BBL
HEC QUALITY CONTROL CHECK
HEC HEC KCI HEC PIPE XL XL
pH TEMP TEMP VISCOSITY TIME TIME pH
DF/FRAC 6.3 100 104 150 @ 100 deg 4.0 N/A N/A
GEL QUALITY CONTROL CHECK
WF30 WF30 XL TIME Activator PIPE
pH TEMP Concentration TIME
DF/FRAC 8.7 94 2:06 5.0 #/1000
FLUID ADDITIVES
F-56 (surfactant) - 2 gal/lO00 gal on the data frac fluid
Halliburton surfactant was used for the entire frac job (.i.e. pad and slurry)
J-218 (breaker) - 5 ppt gal on crosslinked fluids
J-466 (breaker) - 2 ppt gal on crosslinked fluids
J-475 (breaker) - 5 ppt gal on HEC stages
J-898 (activator) - 5 gpt on crosslinked fluids
L10 (crosslinker) - 2.2ppt gal on crosslinked fluids
Milne Point Unit
Alaska State Plane Zone 4
Milne Point E Pad
MPE-30
RECEIVED
AUG 1 9 1998
BPXA PDC
ORIGINAL
S UR VEY REPORT
.,'
10 August, 1998
Your Ref: AP1-500292290300
Last Survey Date 30-July-98
Job# AKMM80303
KBE- 57.05'
DRILLING SERVICES
A DIV~IION OF O~E:~Sr~. INDU~T~[~.~
Survey Ref: svy2177
Milne Point Unit
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
·
.,
0.00 0.000 0.000 -57.05 0.00
288.39 0.840 190.350 231.33 288.38
378.87 1.550 134.600 321.79 378.84
471.47 0.920 65.300 414.37 471.42
562.79 2.270 31.330 505.66 562.71
654.87 2.610 16.700 597.66 654.71
745.21 2.780 50.180 687.90 744.95
837.01 2.880 16.750 779.60 836.65
932.33 3.580 346.130 874.77 931.82
1029.95 3.680 337.030 972.20 1029.25
1125.50 6.290 358.320 1067.38 1124.43
1221.33 7.550 11.910 1162.52 1219.57
..
1317.06 7.680 28.850 1257.42 1314.47
1412.80 8.810 46.820 1352.18 1409.23
1508.23 10.950 51.540 1446.19 1503.24
1603.84 13.540 47.190 1539.62 1596.67
1699.55 16.540 43.110 1632.05 1689.10
1794.49 19.220 37.590 1722.40 1779.45
1889.37 20.410 35.980 1811.66 1868.71
1985.31 20.190 35.130 1901.64 1958.69
2082.83 21.650 36.820 1992.73 2049.78
2177.10 23.820 38.490 2079.67 2136.72
2273.91 24.380 40.690 2168.04 2225.09
2368.27 26.220 41.510 2253.35 2310.40
2463.83 28.120' 41.830 2338.36 2395.41
2560.79 30.360 43.180 2422.96 2480.01
2655.04 32.790 43.070 2503.25 2560.30
2750.52 35.970 42.590 2582.04 2639.09
2846.19 39.040 41.930 2657.93 2714.98
2941.96 41.390 43.310 2731.06 2788.11
Sperry-Sun Drilling Services
Survey Report for MPE-30
Your Ref: API-500292290300
Local Coordinates Global Coordinates Dogleg Vertical
Northing.~ Eastings Northings Eastings Rate Section
(ft) ~ (ft) (ft) (ft) (°ll00ft) (ft)
0.00 N 0.00 E 6016390.55 N 569220.32 E 0.00
2.08 S 0.38 W 6016388.47 N 569219.96 E 0.291 -1.83
3.59 S 0.37 E 6016386.96 N 569220.73 E 1.416 -2.48
4.16 S 1.94 E 6016386.41 N 569222.30 E 1.616 -1.89
2.31 S 3.55 E 6016388.27 N 569223.89 E 1.744 0.56
1.26 N 5.10 E 6016391.85 N 569225.40 E 0.768 4.27
4.63 N 7.37 E 6016395.25 N 569227.65 E 1.727 8.31
8.26 N 9.75 E 6016398.90 N 569229.99 E 1.776 12.62
13.45 N 9.72 E 6016404.09 N 569229.92 E 1.924 16.54
19.29 N 7.77 E 6016409.91 N 569227.91 E 0.598 19.70
27.35 N 6.42 E 6016417.96 N 569226.48 E 3.304 24.93
38.76 N 7.56 E 6016429.38 N 569227.52 E 2.147 34.33
50.51 N 11.95 E 6016441.17 N 569231.80 E 2.340 46.11
61.14 N 20.38 E 6016451.87 N 569240.13 E 2.923 59.66
71.78 N 32.81 E 6016462.63 N 569252.46 E 2.396 75.83
85.03 N 48.14 E 6016476.03 N 569267.66 E 2.874 95.87
102.60 N 65.67 E 6016493.75 N 569285.03 E 3.322 120.62
124.85 N 84.44 E 6016516.18 N 569303.60 E 3.337 149.73
150.62 N 103.69 E 6016542.12 N 569322.61 E 1.380 181.82
177.69 N 123.05 E 6016569.38 N 569341.71 E 0.383 214.97
205.86 N 143.51 E 6016597.73 N 569361.91 E 1.620 249.67
234.68 N 165.78 E 6016626.76 N 569383.92 E 2.401 286.05
265.14 N 190.98 E 6016657.45 N 569408.83 E 1.093 325.57
295.52 N 217.49 E 6016688.07 N 569435.06 E 1.985 365.89
328.11 N 246.51 E 6016720.93 N 569463.77 E 1.994 409.52
363.01 N 278.52 E 6016756.13 N 569495.45 E 2.408 456.85
399.02 N 312.25 E 6016792.46 N 569528.85 E 2.579 506.15
438.56 N 348.89 E 6016832.34 N 569565.12 E 3.343 560.02
481.67 N 388.05 E 6016875.81 N 569603.87 E 3.236 618.24
527.16 N 429.92 E 6016921.68 N 569645.33 E 2.624 680.03
Comment
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
10 August, 1998 - 14:40 - 2 - DrillQuest
Milne Point Unit
Measured
Depth
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
3041.21 44.310 42.490 2803.82 2860.87
3136.25 46.190 40.750 2870.73 2927.78
3231.61 47.970 40.460 2935.66 2992.71
3325.97 50.680 40.780 2997.16 3054.21
3420.00 52.880 39.440 3055.33 3112.38
3515.84 55.300 39.680 3111.54 3168.59
3611.35 58.650 40.090 3163.58 3220.63
3707.52 62.100 38.950 3211.12 3268.17
3802.43 64.090 39.230 3254.06 3311.11
3897.84 66.980 38.400 3293.57 3350.62
3994.27 69.980 36.460 3328.94 3385.99
4089.60 68.540 36.360 3362.70 3419.75
4185.01 69.870 34.970 3396.57 3453.62
4280.44 72.340 35.750 3427.48 3484.53
4376.49 73.460 41.040 3455.74 3512.79
4473.57 73.090 40.860 3483.67 3540.72
4569.41 71.560 40.150 3512.77 3569.82
4664.17 69.140 40.360 3544.63 3601.68
4759.60 71.630 39.430 3576.67 3633.72
4855.24 70.190 40.590 3607.95 3665.00
4952.92 70.880 42.310 3640.50 3697.55
5048.22 69.770 41.550 3672.59 3729.64
5144.37 72.020 42.060 3704.05 3761.10
5239.23 70.740 42.410 3734.34 3791.39
5335.09 70.490 42.120 3766.16 3823.21
5430.67 69.630 42.100 3798.75 3855.80
5526.58 71.140 42.770 3830.95 3888.00
5622.48 71.200 42.570 3861.90 3918.95
5716.72 71.130 41.570 3892.33 3949.38
5812.70 71.080 41.060 3923.41 3980.46
Sperry-Sun Drilling Services
Survey Report for MPE-30
Your Ref: API-500292290300
Local Coordinates Global Coordinates Dogleg Vertical
Northing.s Eastings Northings Eastings Rate Section
(ft) ~ (ft) (ft) (ft) (°/100ft) (ft)
576.61 N 475.86 E 6016971.55 N 569690.80 E 2.995 747.46
627.07 N 520.67 E 6017022.43 N 569735.14 E 2.367 814.94
680.09 N 566.11 E 6017075.87 N 569780.09 E 1.880 884.77
734.40 N 612.70 E 6017130.61 N 569826.17 E 2.883 956.33
790.90 N 660.28 E 6017187.55 N 569873.23 E 2.594 1030.19
850.74 N 709.72 E 6017247.85 N 569922.10 E 2.533 1107.80
912.18 N 761.07 E 6017309.76 N 569972.88 E 3.526 1187.86
976.66 N 814.24 E 6017374.73 N 570025.45 E 3.732 1271.42
1042.35 N 867.61 E 6017440.91 N 570078.21 E 2.113 1356.03
1110.01 N 922.03 E 6017509.08 N 570132.00 E 3.131 1442.81
1181.24 N 976.53 E 6017580.82 N 570185.84 E 3.630 1532.36
1252.99 N 1029.45 E 6017653.05 N 570238.08 E 1.514 1621.27
1325.46 N 1081.45 E 6017726.00 N 570289.41 E 1.949 1710.12
1399.08 N 1133.70 E 6017800.10 N 570340.97 E 2.701 1800.02
1470.99 N 1190.70 E 6017872.54 N 570397.30 E 5.391 1891.71
1541.21N 1251.63 E 6017943.32 N 570457.58 E 0.420 1984.68
1610.64N 1310.95 E 6018013.30 N 570516.24 E 1.745 2076.00
1678.74 N 1368.61 E 6018081.94 N 570573.27 E 2.562 2165.23
1747.71 N 1426.25 E 6018151.43 N 570630.27 E 2.766 2255.10
1816.93 N 1484.35 E 6018221.19 N 570687.73 E 1.892 2345.47
1885.96 N 1545.32 E 6018290.78 N 570748.05 E 1.804 2437.56
1952.71 N 1605.28 E 6018358.09 N 570807.39 E 1.386 2527.27
2020.43 N 1665.84E 6018426.37 N 570867.32 E 2.393 2618.10
2086.99 N 1726.27 E 6018493.49 N 570927.12 E 1.394 2707.96
2153.91N 1787.08 E 6018560.97 N 570987.31E 0.387 2798.35
2220.56 N 1847.33 E 6018628.18 N 571046.94 E 0.900 2888.17
2287.24 N 1908.29 E 6018695.42 N 571107.28 E 1.706 2978.46
2353.97 N 1969.81E 6018762.72 N 571168.18 E 0.207 3069.17
2420.18 N 2029.57 E 6018829.49 N 571227.32 E 1.007 3158.34
2488.39 N 2089.52 E 6018898.24 N 571286.64 E 0.505 3249.14
Comment
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
1.0 August, 1998- 14:40 -3- DrillQuest
Sperry-Sun Drilling Services
Survey Report for MPE-30
Your Ref: AP1-500292290300
Milne Point Unit
Measured Sub-Sea Vertical
Depth Incl. Azim. Depth Depth
(ft) (ft) (ft)
5908.52 67.870 41.050 3957.00 4014.05
6003.81 65.010 41.690 3995.09 4052.14
6099.65 61.920 42.670 4037.90 4094.95
6194.94 58.750 42.530 4085.05 4142.10
6290.33 56.250 43.170 4136.30 4193.35
6385.71 53.940 42.550 4190.88 4247.93
6481.23 52.090 42.130 4248.34 4305.39
6577.31 52.630 42.260 4307.02 4364.07
6672.61 52.280 41.820 4365.09 4422.14
6768.01 52.330 42.670 4423.43 4480.48
6863.95 52.090 42.930 4482.21 4539.26
6959.27 52.320 43.720 4540.63 4597.68
7054.24 52.630 43.010 4598.48 4655.53
7133.74 52.580 42.870 4646.76 4703.81
7200.00 52.580 42.870 4687.02 4744.07
Local Coordinates Global Coordinates Dogleg Vertical
Northing..s Eastings Northings Eastings Rate Section
(ft) ~' (ft) (ft) (ft) (°/100ft) (ft)
2556.05 N 2148.45 E 6018966.45 N 571344.93 E 3.350 3338.86
2621.59 N 2206.17 E 6019032.53 N 571402.04 E 3.064 3426.19
2685,13 N 2263.73 E 6019096.60 N 571459.01 E 3.351 3511.90
2746.07 N 2319.77 E 6019158.06 N 571514.48 E 3.329 3594.64
2805.05 N 2374.48 E 6019217.54 N 571568.63 E 2.681 3675.02
2862.38 N 2427.68 E 6019275.36 N 571621.30 E 2.480 3753,18
2918.78 N 2479.07 E 6019332.23 N 571672.17 E 1.968 3829.44
2975.14 N 2530.18 E 6019389.07 N 571722.74 E 0.572 3905.50
3031.26 N 2580.78 E 6019445.66 N 571772.82 E 0.519 3981.04
3087.14 N 2631.52 E 6019502.01 N 571823.05 E 0.707 4056.49
3142.77 N 2683.04 E 6019558.11 N 571874.04 E 0.329 4132.26
3197.56 N 2734.72 E 6019613.38 N 571925.21 E 0.698 4207.50
3252.32 N 2786.44 E 6019668.62 N 571976.42 E 0.677 4282.73
3298.56 N 2829.46 E 6019715.25 N 572019.01 E 0.153 4345.84
3337.13 N 2865.26 E 6019754.15 N 572054.46 E 0.000 4398.43
All data is in feet unless otherwise stated. Directions and coordinates are relative to
?ertical depths are relative to Well. Northings and Eastings are relative to Well.
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 40.649° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 7200.00ft.-,
The Bottom Hole Displacement is 4398.43ft., in the Direction of 40.649° (True).
True North.
Comment
Projected Survey
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
10 August, 1998- 14:40 .4- DrillQuest
Milne Point Unit
Sperry-Sun Drilling Services
Survey Report for MPE-30
Your Ref: AP1-500292290300
Alaska State Plane Zone 4
Milne Point E Pad
Comments
Measured
Depth
(ft)
0.00
7200.00
Station Coordinates
TVD Northings Eastings
(ft) (ft) (ft)
0.00 0.00 N 0.00 E
4744.07 3337.13 N 2865.26 E
Comment
Tie-on Survey
Projected Survey
10 August, 1998 - 14:40 - 5- DrillQuest
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
ATTN: Sherfle
NO. 12127
Company Alaska OII & Gas Cons Camm
Attn: Lorl Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Milne Point (Cased Hole)
12/4/98
Well Job # Log Description Date BL Sepia LIS Tape
MPG-09 - REPLACEMENT)I98562. IUS~T (PDC) --JW.. ~*~g 980220 I
I(*CORRUPTED DLIS FILE WAS USED WHICH CONTAINED ERRONEOUS DATA.)
MPB-20 DIGITAL FLUID IMAGER 98091 i 3 1
MPB-20 PRODUCTION PROFILE 980911 3 1
MPB-20 GAS LIFT SURVEY 980911 3 1
MPC- 17 RST/WFL 981106 3 1
MPE-30 CBT/GR/CCL 980907 3 i
MPK-21 INJECTION PROFILE 980913 3 I
MPK-21 WFL W/RST ...... 980913 3 i
MPU L-42 INJECTION-PROFILE. 981105 3 1
,
. .
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska)Inc.
Petrotectnical Data Center MB33
900 E. Benson Blvd. "'
RECEIVED
Anchorage, Alaska 99519-6612 ,
.o
Date Delivered:
Schlumberger GeoQuest
3940 Arctic Blvd
Anchorage, AK 9~.~'~--~-~ '
D I::! I L..I-- I ~J (:S S E I~IL/I r' ~ S
WELL LOG TRANSM/TrAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Atm.: Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
MWD Formation Evaluation Logs - MPE-30,
AK-MM-80303
November 18, 1998
2"x 5"MD Resistivity and Gamma Ray Logs:
50-029-22903-00
2" x 5" TVD Resistivity and Gamma Ray Logs:
50-029-22903-00
1 Blueline
1 Folded Sepia
1 Blueline
1 Folded Sepia
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHlt~D COPIES
OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:
Sperry-Sun Drilling Services
Atto: 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
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535
A Halliburton Company
n I=1 I I_1_1 ~ G S E I::lk/I I:: E S
WELL LOG TRANSMITTAL
To:
State of Alaska
Alaska Oil and Gas Conservation Comm.
Attn.' Loft Taylor
3001 Porcupine Dr.
Anchorage, Alaska 99501
November 18, 1998
RE: MWD Formation Evaluation Logs MPE-30, AK-MM-80303
1 LDWG formatted Disc with verification listing.
API#: 50-029-22903-00
PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING THE ATTACHED COPIES
OF THE TRANSMITrAL LETrER TO TltE ATTENTION OF:
Sperry-Sun Drilling Services
Attn: 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
5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535
A, Halliburton Company
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
AI'I'N: Sherrie
NO. 11592
Company Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Field: Milne Point (Cased Hole)
10/22/98
Well Job # Log Description Date BL Sepia LIS Tape
MPB-03 PRODUCTION PROFILE 980823 1 1
MPB-03 GAS LIFT SURVEY 980823 1 1
MPB-03 DIGITAL FLUID IMAGER 980823 1 1
MPB-04 PRODUCTION PROFILE 980823 1 !
MPB-04 GAS LIFT SURVEY 980823 1 i
MPB-04 DIGITAL FLUID IMAGER 980823 1 !
MPB-10 PRODUCTION PROFILE 980823 1 !
MPB-10 GAS LIFT SURVEY 980823 1 i
MP8-10 DIGITAL FLUID IMAGER 980823 1 1
MP8-15 PRODUCTION PROFILE 980825 1 1
MPB-15 GAS LIFT SURVEY 980825 1 1
MPB-15 DIGITAL FLUID IMAGER 980825 1 1
MPE-21 FOUR ARM CALIPER 980829 1 1
MPE-30 FOUR ARM CALIPER 980731 1 1
MPE-33 FOUR ARM CALIPER 980811 1 1
MPG-01 WATER FLOW LOG 980717 1 1
MPH- 10 GAM MA RAY/COLLAR LOG 980825 1 1
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center M83-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
Date Delivered:
Schlumberger GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
A1ZN: Sherrie /'"'" ',
Received ~¥'.~~//~'
GeoQuest
3940 Arctic Blvd
Anchorage, AK 99503
ATTN: Sherrie
NO. 11515
Company:
Field:
Alaska Oil & Gas Cons Comm
Attn: Lori Taylor
3001 Porcupine Drive
Anchorage, AK 99501
Milne Point (Cased Hole)
9/25/98
~2. · o7,,
8,5.o,"1'
'~5.
R~'"'
~ .'-),
Well Job # Log Description Date BL RF Sepia LIS Tape
MPB-03 JEWELRY LOG 9 8 0 8 2 3 1 1
MPB-04 JEWELRY LOG 9 8 0 8 2 3 I 1
MPB-10 JEWELRY LOG 9 8 0 8 2 3 1 1
MPB-15 JEWELRY LOG 9 8 0 8 2 5 1 1
MPB-20 JEWELRY LOG 9 8 0 91 1 1 1
MPC-22A TUBING PUNCHER RECORD 9 8 0 8 0 2 1 1
MPE-21 PERFORATING RECORD 9 8 0 9 0 3 I 1
MPE-30 PERFORATING RECORD 9 8 0 9 0 7 1 1
MPH-10 PERFORATING RECORD 9 8 0 8 2 7 1 1
M P H- 10 PERFORATING RECORD 9 8 0 8 2 9 I 1
M P H- 10 PERFORATING RECORD 9 8 0 8 31 I 1
MPH-11 PERFORATION RECORD 9 8 0 8 0 8 I 1
M P H- 14 PERFORATING RECORD 9 8 0 7 2 8 I 1
M P H- 14 PERFORATING RECORD 9 8 0 7 3 0 I 1
MPH-14 PACKER SE'ri'lNG RECORD 9 8 0 8 01 1 1
MPJ-22 PERFORATION RECORD 9 8 0 7 3 0 1 1
M PJ-22 BRIDGE PLUG SET RECORD 9 8 0 813 1 1
MPJ-22 PERFORATION RECORD 9 8 0 81 7 1 1
MPK-21 /-4 i(-- JEWELRY LOG 98091 3 I 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:
Schlumberger GeoQuest
3940 Arctic Blvd
MEMORANDUM State of Alaska
TO:
David Johj:~n,
Chairman"-
Alaska Oil and Gas Conservation Commission
DATE: July 24; 1998
THRU' Blair Wondzell, ~_ FILE NO:
P. I. Supervisor -"
;,
FROM' Lou G rimaid i,.~..~_ SUBJECT:
Petroleum InSpector
EWQJGWFE.DOC
Diverter inspection
Nabors rig #27E
BPX well flMPE 30
PTD 98-139
Thursday, July 24, 1998: I witnessed the Diverter function test on Nabors rig
#27E which was preparing to drill surface hole on BPX well #MPE-30.
The Diverter assembly was assembled when I arrived. I made a cursory
inspection of the rig, which appeared to be in good shape.
The 10-inch knife valve used on the vent line operated adequately and was open
before the annular completely closed. The 13 5/8" annular preventer had a
closure time of 18 seconds. The accumulator had a recharge time of 1 minute 8
seconds and appeared to be in good shape. The gas detection system was
calibrated and tested after I left location as verified by a telephone conversation
with the rig electrician.
I walked the vent line and found a good solid construction with the exception of
two loose bolts on one of the flange of the stacks knife valve, these were
tightened in my presence. The line terminated 150 feet from the sub-base of the
rig, which was past the opposite row of wells. This is where the Bifurcation of the
vent line occurred. The vent line was secured with pallets of mud but had no
support under the line and a 2-foot gap between the top of the vent line and the
pallet placed above it. I suggested some solid wood dunnage be placed under the
vent line, a chain be draped over the vent line and the pallets of mud placed on
the chain.
SUMMARY: I witnessed the Diverter function test on Nabors rig #27E. Some bolt
tightening and better support for the vent line was required.
Attachments: EWQJGWFE.XLS
cc; Steve Walls/John Raul (Shared Services Drilling)
NON-CONFIDENTIAL
Drlg Contractor:
Operator:
Well Name:
Location: Sec.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
Diverter Systems Inspection Report
Operation: Development X
Nabors Alaska Rig No. PTD # 98-139
BPX Oper. Rep.' Jimmy Pyron
MPE-30 Rig Rep.: Leonard Schiller
25 T. 13N R. 10E M erdian Umiat
Date:
Exploratory:
Rig Ph. #
7/24~98
659-4373
TEST DATA
!MISC. INSPECTIONS:
Location Gen.: P
Housekeeping: P
Reserve Pit: N/A
Well Sign: P
(Gen.) Drlg. Rig: P
Flare Pit: N/A
DIVERTER SYSTEM INSPECTION:
Diverter Size: 13 5/8
Divert Valve(s) Full Opening: P
IValve(s) Auto & Simultaneous: P
Vent Line(s) Size: 10" ~'
Vent Line(s) Length: 158 '" ft.
Line(s) Bifurcated: P
Line(s) Down Wind: P
Line(s) Anchored: F
Turns Targeted / Long Radius: N/A
in.
in,
ACCUMULATOR SYSTEM:
Systems Pressure:
Pressure After Closure:
200 psi Attained After Closure: min.
Systems Pressure Attained: i min.
Nitrogen Bottles: Eight Bottles
2100 Average
28OO
2000
18
MUD SYSTEM INSPECTION: Light Alarm
Trip Tank: P P
Mud Pits: P P
Flow Monitor: P P
GAS DETECTORS: Light Alarm
Methane P P
Hydrogen Sulfide: P P
psig
psig
sec.
sec.
psig
DIVERTER SCHEMATIC
Nodh
Wind
Non Compliance Items I Repair Within N/A Day (s) And contact the Inspector @ 659-3607
Remarks: Rig looked good. Few bolts loose and needed better support under line, throw chain over vent
line and secure before drilling out.
Distribution
orig. - Well File
c - Oper/Rep
c - Database
c - Trip Rpt File
c -inspector
AOGCC REP.: Louis R. Grimaldi
OPERATOR REP.: Jimmy Pyron
DVTRINSP.XLT (REV. 1/28/97) L.G. Ewqjgwfe.xls Report prepared 7/29/98
TONY KNOWLE$, GOVERNOI~
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
Julv 22, 1998
Chuck R. Mallary
Senior Drilling Engineer
BP Exploration (Alaska) Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re~
Milne Point Unit MPE-30
BP Exploration (Alaska) Inc.
Permit No. 98-139
Sur. Loc. 38_~SL, 1923'WEL. Sec. 25, T13N, R10E. UM
Btmnhole Loc. 1957'NSL, 4270'WEL, Sec. 19, T13N, R11E, UM
Dear Mr. Mallary:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required bv 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 max,' witness the
test. Notice ma,,,' be given bx' contacting the Commission petroleum field inspector on the North
BY ORDER OF THE COMMISSION
dltVenclosures
cc: Department of Fish & Game. Habitat Section w/o encl.
Department o1' En~'ironmental Conservation w,'o encl.
. STATE OF ALASKA
ALASKA ',~--,'L AND GAS CONSERVATION COIV,,-..~ISSION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] DeepenI [] 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 = 57' Milne Point Unit / Schrader Bluff
3. Address 6. Property Designation
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047438
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
3853' NSL, 1923' WEL, SEC. 25, T13N, R10E, UM Milne Point Unit
At top of productive interval ,,~//'~' 8. Well Number Number 2S100302630-277
1584' NSL, 4584' WEL, SEC. 19, T13N, 1~l.-t4~, UM MPE-30
At total depth 9. Approximate spud date Amount $200,000.00
1957' NSL, 4270' WEL, SEC. 19, T13N, R11E, UM 08/10/98
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 047437, 956'I MPE-05, 23.18' at 1000' MD 2544 7396' MD / 4747' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)}
Kick Off Depth 400' MD Maximum Hole Angle 72.634° Maximum surface 1511 psig, At total depth (TVD) 4352' / 1946 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
16" 13-3/8" 72# L-80 BTC-Mod 120' 31' 31' 151' 151' 250 sx Arcticset I (Approx.)
6-3/4" 5-1/2" 15.5# J-55 BTC-Mod 7366' 30' 30' 7396' 4747' _~30 sx CS III, 106 sx Foamed, 410 sx 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented MD TVD
Structural
Conductor
Surface
Intermediate
LPirn°edructiOn
0
Perforation depth: measured Jl~,$~r~O"&6asc°ns'C0'[TI[~0ft 0 RIG iN A L
true vertical Aflch0ra[~
20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
ContactEngineerName/Number: R. George Scott, 564-5862 [-~l ~'Q "~1~,~. PreparedByName/Number: KathyCampoamor, 564-5122
. -
21. I hereby certi~y)tha~the fore_q.oil;~l is true and correct to the best of my knowledge
Chuck Uallary I~l,~'v'..4/~ Title Senior Drilling Engineer Date
, .... ~,.~. Commission Use Only
Perm t Number APl Number _ Approval Date _ See cover letter
,/,~-/O,~,~ 50- O ,~. 9- .~- ~- ~:::::~ ,~ '~,.-~-.. ¢~ for other requirements
Conditions of Approval: Samples Required []Yes [~ No Mud Log Required []Yes ,J~ No
Hydrogen Sulfide Measures ,~Yes1~ No Directional Survey Required ,J~Yes I-] No
Required Working Pressure for DOPE []2M; [~;3M; []5M; []10M; []15M
Other:
by order of
Approved By Original Signer, _. Commissioner the commission Date ""~""~"
Form 10-401 Rev. 12-01-85
Submit In Triplicate
'-. r
Shared Services Drilling Contact:
R. George Scoff
I Well Name: IMP E-30
Well Plan Summary
IType of Well (producer or injector):
ISchrader Bluff
Producer
564-5862
Surface Location: 3853' FSL, 1,923' FEL, S25 T13N R10E UM
Target Location: 1584' FSL, 4,584',FEL S19 T13N R11E UM
Bottom Hole Location: 1957' FSL, 4270' FEL, S19 T13N R11E UM
I AFE Number: 1337136 I
Estimated Start Date: I 10 August 98 I
I Rig: I Nabors 27E
Operating days to complete:
IMD: 17396' I I TVD: 14747' I
J7.0
I KBE: 157 ft
J Well Design:
Schrader Bluff Producer
Formation Markers:
Formation Tops MD TVDSS
KOP 400 400
Base of Permafrost 1803' 1752'
Top of Ugnu 5855' 3831'
Top M Sand 6340' 4046'
Top NA (Target) 6759' 4294' Top of the N-A (EMW 8.6 ppg)
Base Of Schrader 7096' 4410'
TD 7396' 4703' TD at 300' MD past base of Schrader Bluff
RECEIVED
laska 0il & Gas Cons. CommJ~
Anchorage
Casing/Tubing Program:
Hole ,~ize "Csg~ Wt/Ft Grade Conn. Length Top Bottom
Tbg O.D. MD/TVD MD/TVD (bkb)
16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151'
6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 7366' 30'/30' 7396'/4747'
Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/ft) to the
reservoir at ±4352' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1946
psi (8.6 ppg EMW), is 1511 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). **
** Note:The top joint in the 5-1/2" surface casing consists of 1 joint of 7" 26# BTC-MOD L-80, this is
required to accommodate the penetrater offset. This will require a X-over to the 5-1/2" 15.5# J-55 BTC-
MOD Casing. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151", Collapse-
5410psi, Burst-7240psi, Yield-604M lbs. Two 20' marker joints of 5-1/2"15.5# casing will be set arounf
100' above the top of the NA.
MP E-30 Well Plan PAGE 3 26 Jun 98
Logging Program:
Open Hole Logs:
MWD directional only from surface to 2200' MD.
4-Arm Caliper Log From T.D. to 151' M.D. (Base of 13-3/8" Conductor.)*
MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a
controlled drilling speed of no more than 200 ft/hr.
Cased Hole Logs: A CCL/GR Log will be run for correlation purposes.
Mud loggers are NOT required for this well. *A conditioning trip will be made if required to assure running of
the caliper.
Mud Program:
ISpecial design considerations
An inhibitive polymer mud is planned from surface to TD. Solids
control is critical to the success of the system.
Surface Mud Properties: I
Density Marsh Yield LSRV 10 min pH Fluid
(PPG) Viscosity Point gel Loss
8.6 150 40 50,000 8.5 NC
to
9.0
Production Mud Properties: I ~
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
9.0 50 30 14 16 8.5 <6
to to to to
9.5 60 35 9.0
LSVR- 40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17
Well Control:
Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Div'erter
with 10" Diverter Line.
A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer
will be used for the completion and is capable of handling maximum potential surface pressures.
Diverter, BOPE, and drilling fluid system schematics are attached.
Directional:
I KOP: 1400' MD I
Maximum Hole Angle:
Close Approach Well:
72.634° @ 3666'md
Close Approach To E-05 Well The E-05 Well is an
injector and will need to be SI and secured. Closs
approach is 23.18' at 1000' MD
Waste Management:
Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility.
Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection.
Annular Injection: Not Planned for this well.
MP E-30 Well Plan PAGE 4 26 Jun 98
MP E-30
Proposed Summary of Operations
.
2.
3.
4.
5.
6.
7.
.
.
Drill and Set 13-3/8" Conductor. Weld a starting head on conductor.
Prepare location for rig move.
MIRU Nabors 27E rig.
NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program.
Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to +/- 2200'MD.
POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP.
Drill 6-3/4" hole to TD as per directional plan. Stand back drill string and run 4-Armed Caliper from the
base of T.D. to the bottom of the 13-3/8" conductor. Following this, the casing will be cemented. A 2-
7/8" work string will be picked up and stood back prior to running the casing to reduce the time the
casing is on bottom prior to cementing.)
Run and Cement 5-1/2"", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement
Program and Back-up Port Collar operating Procedure. Following cementing displace casing to sea
water. POOH freeze protect from 2000'MD to Surface.
Following the cementing of the well and the landing of the 7" landing joint the casing will be tested to
3500 psi.(74% of internal yield). The Diverter system will be rigged down and the frac head provided
by the Well Services group installed, and tested.
POST DRILL AND CASE:
Nabors Rig 4ES will run the completion on this well following rigless
completion work.
1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out.
Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly.
The well will be completed with 2-3/8" tubing.
2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift Heat
Trace to a depth of 5100" MD. Install Surface Lines and Wellhouse and turn well over to production.
MP E-30 Well Plan PAGE 5 26 Jun 98
DRILLING HAZARDS AND RISKS:
See the latest Milne Point E-Pad Data Sheet for offset information on E pad. Specific potential hazards
for this well are outlined below.
The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion
program.
1. Hydrates:
HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the
interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If
encountered mud will be treated with 1-1.$ ppb Lechithin (See Attached Mud Program).
2. Close Approach:
There is a close approach problem with the E-05 Well. This will need to be shut-in and secured while
drilling.
3. Lost Circulation:
There have not been any significant lost circulation incidents reported on any of the E Pad wells.
HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96
no stuck pipe problems have occurred but tight hole problems have been experienced.
4. Stuck Pipe Potential:
There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells
experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially
aware of the need to maintain good hole cleaning properties and practices through the upper hole and
the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE
STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as
determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions
using Hi/Low sweep combinations.
If heavy gravel's are encountered while drilling the surface hole section, operations should be
immediately stopped and the mud funnel viscosity is increased to help clean hole.
5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of
0.4476 psi/ft (8.6 ppg EMW) and a pressure of 2029 psi in the middle of the Schrader Bluff at 4352' TVDSS.
6. Directional Drillinq Concerns
MP E-30 will be an ultra slim 6-3/4" hole drilled to a T.D. of 7396' md. KOP is 400' md and a variable
build rate from that point will yield a sail angle of 72.634 o at 3666' md. At 5628' md the well will begin' to
drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E-
30 will have a horizontal displacement of 4444'.
7. Cement '
The surface hole will be cemented to surface in a single stage with three slurriesl Cold Set Ill Cement, a
foamed 10# intermediate slurry followed by Class G.
The Class G top will be 1000' TVD above the top of the Schrader Bluff Sands. A back up port collar will be run
approximately 200' below the permafrost the exact position determined from the caliper log. This is a full
gauge tool and will be placed using the caliper in a slightly over gauge hole section.
MP E-30 Well Plan PAGE 6 26 Jun 98
MP E-30
5-1/2"" SURFACE CASING
CEMENT PROGRAM - B.J. Alaska
CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695' TVDSS.
Spacer 250bbls. Water 8.43 pp~l.
STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Intermediate)
WEIGHT: Cold Set III 12.2ppg
WEIGHT: Foamed 10.0ppg
YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk.
YIELD:1.74 ft3/sx MIX WATER: 6.06. gal/sk
APPROX #SACKS: 230 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F
106 Foamed Greater than 4:30 hrs."
ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT
2200' MD +30% EXCESS. (Confirm From Caliper)
STAGE1 TAIL CEMENT TYPE:
ADDITIVES:
APPROX #SACKS:
FLUID LOSS:
PREMIUM 'G'
FI-33-.4%, CD-32- .3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8'ppg
YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk
410 THICKENING TIME: Greater than 5 hrs at 50° F.
100-150 cc FREE WATER: 0
TAIL CEMENT FROM TD TO 1000 FEET TVD ABOVE SCHRADER
BLUFF + 30% EXCESS + 80'md 5-1/2"", 15.5# capacity for float
joints. EST TOC 4100' md (Confirm from Caliper)
STAGE2 Contingency:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
Cold Set III PERMAFROST (If Single Stage Unsuccessful)
Retarder
12.0ppg
272 SACKS
YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
THICKENING TIME: Greater than 4 hrs at 50° F.
ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO
SURFACE+ 200% EXCESS. (Confirmed by Caliper)
Note Excess is estimate only caliper will be used for final determination.
DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT
TOP JOB CEMENT TYPE: Permafrost Cold Set Set III
NOTE:
ADDITIVES: Retarder
TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO
SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE
PUMPS ARE SHUT DOWN.
WEIGHT: 12.2 ppg
YIELD:1.92 ft3/sx
MIX WATER: 10.53 gal/sk
APPROX NO SACKS: 100
RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL
MP E-30 Well Plan PAGE 7 26 Jun 98
CENTRALIZER PLACEMENT:
1. Spiral Glide 5-1/2" X 6-3/4" centralizers are planned for the 5-1/2" casing The number to be
determined by the Caliper log, and also on the joint of casing above and below port collar.
See attached Weatherford centralizer program in cementing section.
2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer
program will be issued following receipt of the results of the 4-Arm Caliper Log.
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 as per
attached cement program. Mix slurry on the fly -- batch mixing is not necessary.
Before Landing Casing following returns to surface the section of the diverter and wellhead system
below the diverter line to the starting head may need to be will be displaced with inhibitive wash to
prevent it from setting and thus easing the clean out of that section. .
MP E-30 Well Plan PAGE 8 26 Jun 98
E-PAD
~., !800.00 +
3 8
· ·
· 33
1om
· ~-
22m · 1
13m m5
+ 3o
11 · m?
18 · · 16
20 · · 2,3
24m · 19
14. · + 21
15 · · 17
NOTES
1. ALASKA STATE PLANE COORDINATES
ARE ZONE 4-, NAD 27.
2. OEODETIC COORDINATES ARE NAD 27.
,3. MEAN PAD SCALE FACTOR 0.9999054-34-.
4-. HORIZONTAL AND VERTICAL CONTROL IS
BASED ON MONUMENTS CFP-,3 ond E-1.
5. DATE OF SURVEY: JUNE ,30, 1998.
6. REFERENCE FIELD BOOK:
MP98-06 (Pgs. 05-07).
7. ELEVATIONS ARE BASED ON BPX
MILNE POINT DATUM (M.S.L.).
8. (*) DENOTES PREVIOUSLY INSTALLED 20" DIA.
CONDUCTOR WITH NEW 1,3 .3/8" DIA. CONDUCTOR
INSIDE OF OLD 20" DIA. CONDUCTOR.
2600.00
3N ~. N.
VICINITY MAP
N.T.S.
LEGEND
AS-BUILT WELL CONDUCTOR
· EXISTING WELL CONDUCTOR
JANET T. HALL
7606
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN
THE STATE OF ALASKA AND THAT
THIS PLAT REPRESENTS A SURVEY
MADE BY ME OR UNDER MY DIRECT
SUPERVISION AND THAT ALL
DIMENSIONS AND OTHER DETAILS ARE
CORRECT AS OF JUNE 30, 1998.
LOCATED WITHIN PROTRACTED SEC. 25, T. 1,3 N., R. 10 E., UMIAT MERIDIAN, ALASKA
WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION
NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS
21' y= 6,016,227.28 N. 1,950.56 70'27'16.877" 70.4546879' 23.4' $,688' FSL
X= 569,550.97 E. 1,450.11 149'26'02.626" 149.4340629' 1,794' FEL
50 y= 6,016,590.55 N. 2,159.67 70'27'18.494" 70.455157.5' 23.2' 5,855' FSL
X= 569,220..52 E. 1,450.40 149'26'06.4-20" 149.4.551166' 1,925' FEL
FOR INFORMATION
R£V~SK)N
,RAg~N:
dACO~S
:HECKED: O'HANLEY
DATE:
7/'1/98
,RA~4NG: MPE- AB
JOB NO:
;CALE:
BP EXP,_u.,FRA
MILNE POINT UNIT- E PAD
AS-BUILT WELL CONDUCTOR
WELLS 21 & 30
ts~'££]'i of 1
~'~Ell-~ ~a~-~--I.Jl-I Sharod Services Orillin~ D rill Q u es t-
~'"~'272'"d2c~s WeE' MPE-30 (98~) WP2
S~le: linch = 7~ Eastings
0 7~ 14~ 21 ~ 28~
I I I I
35~ - 51~' ~ - 35~
7395.45 MD
Proposal Data for MPE-30 (gM) Wp2 4747.~ ~D 47~.~
V~ ~: We~
M~t U~: ~ ,
N~h R~: T~ ~dh
~ ~: D~ ~r 1~ I
Ve~ ~ ~1~: 40.~
Ve~l ~ D~:We~ 4~ ~
Ved~l ~ ~: 0.~ N,O.~ E I
M~s~ I~L ~m. Ve~al No~lng= ~ Venal ~leg 28~- 41~.~ -- 28~
o.~ 0.= o.~= 0.~ 0.~. o.~ 0.~
~.~ o.~ o.s32 ~.~ o.~ N o.~ ~ o.~ o.~
~1~ 4.413 59.~ ~.~ 8.63 N 14.63 E 16.05 1
1753.14 4,413 59.~ 1750.~ ~7 N 75.~ E 8236 0.~ 3~'
1953.73 4.413 59.~ 1950.ffi 52.11 N 88.36 E ~,~ 0.~
3~.~ 72.6M 39.~ 3213.32 8~.30 N 745.10 E 1~8,45
~27~ 72.6~ 39.~ 3~8.77 2~2.67 N 19~.11 E 2970.32 0.~
6759.41 ~.~ 39.938 4338.~ 3011.70 N ~.~ E 3956.77 2.~ ~.
7~5.45 ~.~ 39.938 4554.~ 32~.07 N 2731Ji E 4214.18 0.~
7395.45 ~.~ 39.938 4747.M 3385.28 N ~.~ E ~3.~ 0.~ I
21~ -~ -- 2100
P~OPOSAL TARGET SUMMARY
o
MPE~ {~8~) T~ a~o4.~ ao~.~ ~ ~.70 ~.~ ~ ~o~ ~.~ ~, s7~7~8.~ E 1 4~ -- / -- ~ 4~
24.~ fl Well (CBE)
44.~ ~ RKB - AMS ~ By: 2~.
-27~.0~
SURFACE LOCATION PLOT DATE: 2/12/98 700 -- - 700
Horizontal Coordinates: 6016390.59 N.569219.83 E Created By:
CooRtinate System: NAD27 Alaska State Planes,
Zone 4, US Foot
0 0 ·
I I I I
0 700 1400 2100 2800
Scale: linch = 700ft Eastings Reference is True North
51/2' Casing
7395.45 MD
TM
Shared Services Drifting DrillQ uest"
Well: MPE-30 (98~) WP2
Proposal Da~ for MPE~0 (9~) Wp2
v~ ~: w~
H~I ~: W~
M~t U~: fl
N~h R~e: T~ ~h
~ Sev~: D~ ~ 1~
, Ve~l ~n ~i~h: ~.~
0 -- ' Ve~ ~ D~:W~
~ Ve~l ~n ~: 0.~ N,0.~ E
I ~ ~.~ 0.~ 0.532 ~.~ 0.~ N 0.~ E 0.~ 0.~
~ ~1.30 4.413 59.~ ~.~ 8.63 N 14.63 E 16.~ 1.~
I ~.~ 1753.14 4.413 59.~ 1750.ffi ~.27 N 75.~E 82~ 0.~
i '
[ 1953.73 4.413 59.~ 1950.ffi 52.11 N 8836E ~.~ 0.~
: 3~6.~ 72.6~ 39~ 3213.32 808.30 N 745.10 E i~8.45 4.~
5627.56 72.6~ 39.~ 3798.77 2~2.67 N 1936.11 E 2970.32 0.~
~ ~00.~ ~ 6759.41 50.~ 39.938 4338.50 3011.70 N 25~.26 E 3956.~ 2.~
-- 7(~)5.45 50.~ 39.938 4554.50 32~.07 N 2731.51 E 4214.18 0.~
900 1000.~ 7395.45 50.~) 39.938 4747.34 3385.28 N 2879.~ E ~3.~ 0.~
~2~.~ PROPOSAL TARGEI SUMMARY
14~.~ Target Name: WDSS WDRKB: Wellhead Offsets: Global Ccmr~nates:
MPE-30 (984) T1 4294.~ 4338.50 3011.70 N,2~.26 E 6019426.~ N, 571758.~ E
1800 - ' ..... ~a~ .......................................................................................................................
~.~ SURFACE LOCAII~N PLOT DATE: ~1~98
~ _ _ Horizontal Coord~atos: 60163~.59 N,569219.83 E Created By ·
~'~ RKB Elevation: ~.~ fl Rig (ES~ '
~a~ 24.~ fl Well (CAE) ,
2700-
i ~ ..... Coordinate System: NAD27 ~ska State Pl~es, -
; ~.uu Zone 4, US F~t
~8~.~
~4~.~
3600 ~~.~
5 1/2' Casing
7395.45 MD
4747.~ ~D
I I I I I I
0 9~ 18~ 27~ 36~ 45~
Scale: linch = ~ Ve~ical Section Section ~imuth: 40.380° ~rue No~h)
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
Depth-
(ft)
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
0.o0 0.000 0.000 -44.50 0.00
100.00 0.000 0.000 55.50 100.00
200.00 0.000 0.000 155.50 200.00
300.00 0.000 0.000 255.50 300.00
400.00 0.000 0.000 355.50 400.00
50o.o0 1.000 59.468 455.49 499.99
600.00 2.000 59.468 555.46 599.96
700.o0 3.000 59.468 655.36 699.86
800.o0 4.000 59.468 755.18 799.68
841.30 4.413 59.468 796.36 840.86
900.00 4.413 59.468 854.89 899.39
1000.o0 4.413 59.468 954.59 999.09
1100.o0 4.413 59.468 1054.30 1098.80
1200.o0 4.413 59.468 1154.00 1198.50
1300.o0 4.413 59.468 1253.70 1298.20
1400.o0 4.413 59.468 1353.41 1397.91
1500.o0 4.413 59.468 1453.11 1497.61
1600.00 4.413 59.468 1552.81 1597.31
1700.o0 4.413 59.468 1652.52 1697.02
1753.14 4.413 59.468 1705.50 1750.00
1800.00 4.413 59.468 1752.22 1796.72
1803.29 4.413 59.468 1755.50 1800.00
1900.o0 4.413 59.468 1851.93 1896.43
1953.73 4.413 59.468 1905.50 1950.00
2000.00 6.180 53.439 1951.57 1996,07
2100.00 10.103 47.727 2050.54 2095.04
2200.00 14.069 45.200 2148.31' 2192.81
2300.00 18.049 43.770 2244.38 2288.88
2400.00 22.037 42.844 2338.31 2382.81
2500.00 26.028 42.190 2429.62 2474.12
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/lOOft) (ft)
0.00 N 0.00 E 6016390.59 N 569219.83 E 0.00
0.00 N ~ 0.00 E 6016390,59 N 569219.83 E 0.000 0.00
0.00 N 0.00 E 6016390.59 N 569219.83 E 0.000 0.00
0.00 N 0.00 E 6016390.59 N 569219.83 E 0.000 0.00
0.00 N 0.00 E 6016390.59 N 569219.83 E 0.000 0.00
0.44 N 0.75 E 6016391.04 N 569220.58 E 1.000 0.82
1.77 N 3.01 E 6016392.39 N 569222.82 E 1.000 3.30
3.99 N 6.76 E 6016394.64 N 569226.56 E 1.000 7.42
7.09 N 12.02 E 6016397.79 N 569231.79 E 1.000 13.19
8.63 N 14.63 E 6016399.35 N 569234,38 E 1.000 16.05
10.92 N 18.52 E 6016401.69 N 569238.25 E 0.000 20.32
14.83 N 25.15 E 6016405.66 N 569244.84 E 0.000 27.59
18.74 N 31.78 E 6016409.63 N 569251.43 E 0.000 34.86
22.65 N 38.40 E 6016413.60 N 569258.02 E 0.000 42.14
26.56 N 45.03 E 6016417.57 N 569264.61 E 0.000 49.41
30.47 N 51.66 E 6016421.54 N 569271.20 E 0.000 56.68
34.38 N 58.29 E 6016425.51N 569277.80 E 0.000 63.95
38.29 N 64.92 E 6016429.48 N 569284.39 E 0.000 71.22
42.20 N 71.54 E 6016433.45 N 569290.98 E 0.000 78.49
44.27 N 75.06 E 6016435.56 N 569294.48 E 0.000 82.36
46.10 N 78.17 E 6016437.42 N 569297.57 E 0.000 85.76
46.23 N 78.39 E 6016437.55 N 569297.79 E 0.000 86.00
50.01 N 84.80 E 6016441.39 N 569304.16 E 0.000 93.04
52.11 N 88.36 E 6016443.52 N 569307.70 E 0.000 96.94
54.50 N 91.89 E 6016445.94 N 569311.21 E 4.000 101.05
63.61 N 102.71 E 6016455.15 N 569321.95 E 4.000 115.00
78.08 N 117.83 E 6016469.76 N 569336.93 E 4.000 135.82
97.84 N 137.18 E 6016489.70 N 569356.10 E 4.000 163.40
122.79 N 160.66 E 6016514.87 N 569379.35 E 4.000 197.63
152.82 N 188.17 E 6016545.15 N 569406.57 E 4.000 238.31
Comment
Base Permafrost
Alaska State Plane Zone 4
Milne Point E Pad
Con#nued...
13 February, 1998- 10:41 - 1 - DrillQuest
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
Depth'
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
2600.00 30.021 41.699 2517.88 2562.38
2700.00 34.016 41.315 2602.65 2647.15
2800.00 38.012 41.002 2683.52 2728.02
2900.00 42.008 40.741 2760.10 2804.60
3000.00 46.005 40.517 2832.01 2876.51
3100.00 50.003 40.322 2898.90 2943.40
3200.00 54.000 40.148 2960.46 3004.96
3300.00 57.998 39.991 3016.37 3060.87
3400.00 61.996 39.847 3066.36 3110.86
3500.00 65.994 39.713 3110.19 3154.69
3600.00 69.993 39.588 3147.66 3192.16
3666.06 72.634 39.509 3168.82 3213.32
3700.00 72.634 39.509 3178.95 3223.45
3800.00 72.634 39.509 3208.80 3253.30
3900.00 72.634 39.509 3238.65 3283.15
4000.00 72.634 39.509 3268.49 3312.99
4100.00 72.634 39.509 3298.34 3342.64
4200.00 72.634 39.509 3328.19 3372.69
4300.00 72.634 39.509 3358.04 3402.54
4400.00 72.634 39.509 3387.88 3432.38
4500.00 72.634 39.509 3417.73 3462.23
4600.00 72.634 39.509 3447.58 3492.08
4700.00 72.634 39.509 3477.42 3521.92
4800.00 72.634 39.509 3507.27 3551.77
4900.00 72.634 39.509 3537.12 3581.62
5000.00 72.634 39.509 3566.97 3611.47
5100.00 72.6,.c~ 39.509 3596.81 3641.31
5200.00 72.634 39.509 3626.66 3671.16
5300.00 72.634 39.509 3656.51 3701.01
5400.00 72.634 39.509 3686.36 3730.86
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/lOOft) (ft)
187.76 N 219.55 E 6016580.39 N 569437.63 E 4,000 285.27
227.47 N 254.68 E 6016620.41 N 569472.38 E 4.000 338.27
271.73 N 293.36 E 6016665.04 N 569510.65 E 4.000 397.05
320.34 N 335.42 E 6016714.04 N 569552.26 E 4.000 461.33
373.06 N 380.64 E 6016767.17 N 569596.99 E 4.000 530,79
429,64 N 428.82 E 6016824.19 N 569644.64 E 4.000 605.09
489.78 N 479.70 E 6016884,81 N 569694.96 E 4.000 683.88
553.22 N 533.06 E 6016948.73 N 569747.72 E 4.000 766,76
619,62 N 588.62 E 6017015.65 N 569802.66 E 4.000 853.34
688.68 N 646.11 E 6017085.24 N 569859.51 E 4.000 943.20
760.05 N 705.26 E 6017157.16 N 569918.00 E 4.000 1035.88
808.30 N 745.10 E 6017205.78 N 569957.39 E 4.000 1098.45
833.29 N 765.71 E 6017230.96 N 569977.76 E 0.000 1130.84
906.93 N 826,43 E 6017305.16 N 570037.80 E 0.000 1226.27
980.56 N 887.15 E 6017379.35 N 570097.83 E 0.000 1321.70
1054.20 N 947.87 E 6017453.55 N 570157.86 E 0.000 1417.13
1127.84 N 1008.59 E 6017527.75 N 570217.89 E 0.000 1512.56
1201.47 N 1069.31 E 6017601.94 N 570277.93 E 0.000 1607.99
1275.11 N 1130.02 E 6017676.14 N 570337.96 E 0.000 1703.42
1348.74 N 1190.74 E 6017750.34 N 570397.99 E 0.000 1798.85
1422.38 N 1251.46 E 6017824.54N 570458.02 E 0.000 1894.28
1496.02 N 1312.18 E 6017898.73 N 570518.06 E 0.000 1989.71
1569.65 N 1372.90 E 6017972.93 N 570578.09 E 0.000 2085.15
1643.29 N 1433.62 E 6018047.13 N 570638.12 E 0.000 2180.58
1716.92 N 1494.34 E 6018121.32 N 570698.16 E 0.000 2276.01
1790.56 N 1555.06 E 6018195.52 N 570758.19 E 0.000 2371.44
1864.20 N 1615.78 E 6018269.72 N 570818.22 E 0.000 2466.87
1937.83 N 1676.50 E 6018343.91 N 570878.25 E 0.000 2562.30
2011.47N 1737.22 E 6018418.11 N 570938.29 E 0.000 2657.73
2085.10 N 1797.94 E 6018492.31N 570998.32 E 0.000 2753.16
Comment
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
13 February, 1998-10:41 - 2- DrillQuest
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
DePth-
(fi)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
5500.00 72.634 39.509 3716.20 3760.70
5600.00 72.634 39.509 3746.05 3790.55
5627.56 72.634 39.509 3754.27 3798.77
5700.00 71.185 39.531 3776.77 3821.27
5800.00 69.186 39.564 3810.67 3855.17
5900.00 67.186 39.597 3847.82 3892.32
6000.00 65.186 39.631 3888.20 3932.70
6100.00 63.186 39.666 3931.74 3976.24
6200.00 61.187 39.702 3978.40 4022.90
6300.00 59.187 39.740 4028.11 4072.61
6400.00 57.187 39.779 4080.83 4125.33
6500.00 55.187 39.820 4136.47 4180.97
6600.00 53.188 39.864 4194.98 4239.48
6700.00 51.188 39.909 4256,29 4300.79
6759.41 50.000 39.938 4294.00 4338.50
6800.00 50.000 39.938 4320.09 4364.59
6900.00 50.000 39.938 4384.37 4428.87
7000.00 50.000 39.938 4448.65 4493.15
7095.45 50.000 39.938 4510.00 4554.50
7100.00 50.000 39.938 4512.93 4557.43
7200.00 50.000 39.938 4577.20 4621.70
7300.00 50.000 39.938 4641.43 4685.98
7395.45 50.000 39.938 4702.84 4747.34
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
2158.74 N 1858.66 E 6018566.51 N , 571058.35 E 0.000 2848.59
2232.38 N 1919.38 E 6018640.70 N 571118.39 E 0.000 2944.02
2252.67 N 1936.11 E 6018661.15 N 571134.93 E 0.000 2970.32
2305.79 N 1979.93 E 6018714.67 N 571178.25 E 2.000 3039.17
2378.33 N 2039.83 E 6018787.77 N 571237.47 E 2.000 3133.24
2449.88 N 2098.98 E 6018859.86 N 571295.96 E 2.000 3226.06
2520.35 N 2157.31 E 6018930.88 N 571353.63 E 2.000 3317.54
2589.66 N 2214.75 E 6019000.72 N 571410.42 E 2.000 3407.55
2657.73 N 2271.22 E 6019069.30 N 571466.26 E 2.000 3495.98
2724.46 N 2326.66 E 6019136.55 N 571521.08 E 2.000 3582.74
2789.78 N 2381.01 E 6019202.37 N 571574.82 E 2.000 3667.70
2853.61N 2434.19 E 6019266.70 N 571627.40 E 2.000 3750.78
2915.88 N 2486.14 E 6019329.44 N 571678.77 E 2.000 3831.87
2976.49 N 2536.80 E 6019390.52 N 571728.87 E 2.000 3910.86
3011.70 N 2566.26 E 6019426.00 N 571758.00 E 2.000 3956.77,
3035.54 N 2586.22 E 6019450.02 N 571777.74 E 0.000 3987.86
3094.27 N 2635.40 E 6019509.21 N 571826.37 E 0.000 4064.46
3153.01 N 2684.57 E 6019568.40 N 571874.99 E 0.000 4141.06
3209.07 N 2731.51 E 6019624.90 N 571921.41 E 0.000 4214.18
3211.75 N 2733.75 E 6019627.60 N 571923.62 E 0.000 4217.67
3270.48 N 2782.93 E 6019686.79 N 571972.25 E 0.000 4294.27
3329.22 N 2832.10 E 6019745.98 N 572020.88 E 0.000 4370.87
3385.28 N 2879.04 E 6019802.47 N 572067.30 E 0.000 ddd3.99
Comment
MPE-30 (98-4) T1
Top NA
Base SB
5 1/2' Casing
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
13 February, 1998 o 10:41 - 3 - DrillQuest
Milne Point Unit
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Alaska State Plane Zone 4
Milne Point E Pad
All data is in'feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
ii" Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 40.380° (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 7395.45ft.,
The Bottom Hole Displacement is 4443.99ft., in the Direction of 40.380° (True).
13 February, 1998 - 10:41 - 4 - DrillQuest
Shared Services Drilling Contact:
I Well Name:
IType of Well (producer or injector):
R. George Scott
IMP E-30 I
Well Plan Summary
ISchrader Bluff
Producer
564-5862
Surface Location: 3853' FSL, 1,923' FEL, S25 T13N R10E UM
Target Location: 1584' FSL, 4,584',FEL S19 T13N R11E UM
Bottom Hole Location: 1957' FSL, 4270' FEL, S19 T13N R11E UM
I AFE Number: 1337136 I
I Ri~l: I Nabors27E
Estimated Start Date: I 10August 98 I I Operatin~ days to complete: 17.0
MD: 17396' I ITvD: t4747' I IKBE:
I Well Design:
Formation Markers:
157ft
Schrader Bluff Producer
Formation Tops MD TVDSS
KOP 400 400
Base of Permafrost 1803' 1752'
Top of Ugnu 5855' 3831'
Top M Sand 6340' 4046'
Top NA (Target) 6759' 4294' Top of the N-A (EMW 8.6 ppg)
Base Of Schrader 7096' 4410'
TD 7396' 4703' TD at 300' MD past base of Schrader Bluff
RECEIVED
JUL 'j 0 1998
~ska 0il & Gas Cons. ~
Anchorage
Casin~lrrul: ing Program:
Hole ~ize Csg~ Wt/Ft Grade Conn. Length Top 'Bott~)m
Tbg O.D. MD/I'VD MDrrVD (bkb)
16" 13-3/8" 72# L-80 BTC-MOD 120' 31'/31' 151'/151'
6-3/4" 5-1/2"** 15.5# J-55 BTC-MOD 7366' 30'/30' 7396'/4747'
· .
Internal yield pressure of the 5-1/2 .... 15.5# casing is 4,810 psi. With a full column of gas (0.10 psi/ft) to the
reservoir at ±4352' TVDSS the maximum anticipated surface pressure assuming a reservoir pressure of 1946
psi (8.6 ppg EMW), is 1511 psi, well below the internal yield pressure rating of the 5-1/2" casing (4810psi). **
** Note:The top joint in the 5-1/2" surface casing consists of I joint of 7" 26# BTC-MOD L-80, this is
required to accommodate the penetrater offset. This will require a X-over to the 5-1/2" 15.5# J-55 BTC-
MOD Casing. Properties of this top joint are Coupling O.D.-7.656", I.D. 6.276", Drift-6.151", Collapse-
5410psi, Burst-7240psi, Yield-604M lbs. Two 20' marker joints of 5-1/2"15.5# casing will be set arounf
100' above the top of the NA.
MP E-30 Well Plan PAGE 3 26 Jun 98
Logging Program:
Open Hole Logs'
Cased Hole Logs:
MWD directional only from surface to 2200' MD.
4-Arm Caliper Log From T.D. to 151' M.D. (Base of 13-3/8" Conductor.)*
MWD directional and LWD (GR/Resistivity/ROP) from top of Ugnu to TD with a
controlled drilling speed of no more than 200 ft/hr.
A CCL/GR Log will be run for correlation purposes.
Mud loggers are NOT required for this well. *A conditioning trip will be made if required to assure running of
the caliper.
Mud Program:
ISpecial design considerations
lAn inhibitive polymer mud is planned from surface to TD. Solids
control is critical to the success of the system.
Surface Mud Properties-
Density Marsh Yield LSRV 10 min pH Fluid
(PPG) Viscosity Point gel Loss
8.6 150 40 50,000 8.5 NC
to
.:
9.0
Production Mud Properties: I
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
9.0 50 30 14 16 8.5 <6
to to to to
9.5 60 35 9.0
LSVR-40,000+, Fann-600/50-55, 300/40-45, 200/33-37, 6/18-20, 3/14-17
Well Control:
Well control equipment consists of: Rig (Nabors 27E) ,13-5/8" 5000 psi W.P.Annular and 3000 psi Div'erter
with 10" Diverter Line.
A Completion/Workover Rig with 5000 psi W.P. variable pipe rams, blind/shear rams, and annular preventer
will be used for the completion and is capable of handling maximum potential surface pressures.
Diverter, BOPE, and drilling fluid system schematics are attached.
Directional:
J KOP: 1400' MD J
Maximum Hole Angle: 72.634° @ 3666'md
Close Approach Well:
Close Approach To E-05 Well The E-05 Well is an
injector and will need to be SI and secured. Closs
approach is 23.18' at 1000' MD
Waste Management:
Cuttings Handling: All cuttings will be hauled to the CC-2A or Drill Site #4 facility.
Fluids Handling: All drilling and completion fluids will be hauled to Drill Site #4 or CC-2A for injection.
Annular Injection: Not Planned for this well.
MP E-30 Well Plan PAGE 4 26 Jun 98
MP E-30
Proposed Summary of Operations
.
2.
3.
4.
5.
6.
7.
o
,
Drill and Set 13-3/8" Conductor. Weld a starting head on conductor.
Prepare location for rig move.
MIRU Nabors 27E rig.
NU and function test 13-3/8 .... diverter. Spud Mud Will Have been Built as per Mud Program.
Drill a 6-3/4" surface hole as per directional plan. Run Directional MWD from surface to +/- 2200'MD.
POOH. MU a PDC bit on a motor, with Directional MWD and LWD GR/RES/ROP.
Drill 6-3/4" hole to TD as per directional plan. Stand back drill string and run 4-Armed Caliper from the
base of T.D. to the bottom of the 13-3/8" conductor. Following this, the casing will be cemented. A 2-
7/8" work string will be picked up and stood back prior to running the casing to reduce the time the
casing is on bottom prior to cementing.)
Run and Cement 5-1/2"", 15.5#, J-55, Buttress-Modified casing. Refer to attached Detailed Cement
Program and Back-up Port Collar operating Procedure. Following cementing displace casing to sea
water. POOH freeze protect from 2000'MD to Surface.
Following the cementing of the well and the landing of the 7" landing joint the casing will be tested to
3500 psi.(74% of internal yield). The Diverter system will be rigged down and the frac head provided
by the Well Services group installed, and tested,
POST DRILL AND CASE:
Nabors Rig 4ES will run the completion on this well following rigless
completion work.
1. The first part of the completion is planned to be done rigless. This includes perforating, frac'ing clean out.
Rig 4ES is planned to be used for setting the screen and for the final running of the completion assembly.
The well will be completed with 2-3/8" tubing.
2. A completion program will be issued for this. It is planned to run an ESPC completion with Centrilift Heat
Trace to a depth of 5100" MD. Install Surface Lines and Wellhouse and turn well over to production.
MP E-30 Well Plan PAGE 5 26 Jun 98
DRILLING HAZARDS AND RISKS:
See the latest Milne Point E-Pad Data Sheet for offset information on E pad. Specific potential hazards
for this well are outlined below.
The MPU PE group will be perforating, hydraulic fracturing and cleaning out this as per the completion
program.
1. Hydrates:
HYDRATES HAVE BEEN ENCOUNTERED ON WELLS DRILLED AT MILNE POINT 'E' PAD, in the
interval of 2100-2400'MD just below the permafrost as summarized on the Pad data sheet. If
encountered mud will be treated with 1-1.5 ppb Lechithin (See Attached Mud Program).
2. Close Approach:
There is a close approach problem with the E-05 Well. This will need to be shut-in and secured while
drilling.
3. Lost Circulation:
There have not been any significant lost circulation incidents reported on any of the E Pad wells.
HOWEVER, STUCK PIPE INCIDENTS OCCURED WHILE Drilling. Recently over the period of 1994-96
no stuck pipe problems have occurred but tight hole problems have been experienced.
4. Stuck Pipe Potential:
There have been several STUCK PIPE incidents on Milne Point 'E' Pad. The E-22 and E-3 wells
experienced stuck pipe incidents. These wells were drilled in 1994 and 1990 respectively. Be especially
aware of the need to maintain good hole cleaning properties and practices through the upper hole and
the heavy clay sections REFER TO THE PAD DATA SHEETS FOR MORE INFORMATION ON THE
STUCK PIPE INCIDENTS. The frequency of wiper trips should be a minimum of once every 1000' as
determined by hole conditions. Viscous sweeps should also be made as determined by hole conditions
using Hi/Low sweep combinations.
If heavy gravel's are encountered while drilling the surface hole section, operations should be
immediately stopped and the mud funnel viscosity is increased to help clean hole.
5. Formation Pressure: The Schrader Bluff zone is anticipated to be normally pressured with a gradient of
0.4476 psi/ft (8.6 ppg EMW) and a pressure of 2029 psi in the middle of the Schrader Bluff at 4352' TVDSS.
6. Directional Drillinq Concerns
MP E-30 will be an ultra slim 6-3/4" hole drilled to a T.D. of 7396' md. KOP is 400' md and a variable
build rate from that point will yield a sail angle of 72.634 o at 3666' md. At 5628' md the well will begin' to
drop until a final angle of 50° is reached. The 50° angle will be held through the reservoir to TD. MP E-
30 will have a horizontal displacement of 4444'.
7. Cement
The surface hole will be cemented to surface in a single stage with three slurriesl Cold Set III Cement, a
foamed 10# intermediate slurry followed by Class G.
The Class G top will be 1000' TVD above the top of the Schrader Bluff Sands. A back up port collar will be run
approximately 200' below the permafrost the exact position determined from the caliper log. This is a full
gauge tool and will be placed using the caliper in a slightly over gauge hole section.
MP E-30 Well Plan PAGE 6 26 Jun 98
MP E-30
5-1/2 .... SURFACE CASING
CEMENT PROGRAM - B.J. Alaska
CASING SIZE: 5-1/2 .... CIRC. TEMP 80 deg F at 4695'TVDSS.
Spacer 250bbls. Water 8.43 ppg.
STAGE1 LEAD: TYPE Cold Set III PERMAFROST, Foamed (10# Inte.rmediate)
WEIGHT: Cold Set III 12.2ppg YIELD: 1.92FT3/Sk. MIX WATER:10.53 GAL/sk.
WEIGHT: Foamed 10.0ppg YIELD:1.74 ft3/sx MIX WATER: 6.06 gal/$k
APPROX #SACKS: 230 Cold Set III THICKENING TIME: Greater than 6 hrs at 50° F
106 Foamed Greater than 4:30 hrs."
ANNULAR VOLUME TOP OF TAIL CEMENT TO Port Collar AT
2200' MD +30% EXCESS. (Confirm From Caliper)
STAGE1 TAIL CEMENT TYPE: PREMIUM 'G'
ADDITIVES:
APPROX #SACKS:
FLUID LOSS:
FI-33-.4%, CD-32-.3%, R-1-.1% FP-6L lghs. WEIGHT: 15.8'ppg
YIELD: 1.34 ft3/sx MIX WATER 6.06 gal/sk
410 THICKENING TIME: Greater than 5 hrs at 50° F.
100-150 cc FREE WATER: 0
TAIL CEMENT FROM TD TO 1000 FEET TVD ABOVE SCHRADER
BLUFF + 30% EXCESS + 80'md 5-1/2 .... ,15.5# capacity for float
joints. EST TOC 4100' md (Confirm from Caliper)
STAGE2 Contingency:
ADDITIVES:
WEIGHT:
APPROX #SACKS:
Cold Set !11 PERMAFROST (If Single Stage Unsuccessful)
Retarder
12.0ppg
YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
272 SACKS THICKENING TIME: Greater than 4 hrs at 50° F.
ANNULAR VOLUME FROM STAGE COLLAR AT 2200' MD TO
SURFACE+ 200% EXCESS. (Confirmed by Caliper)
Note Excess is estimate only caliper will be used for final determination.
DO NOT PUMP TOP JOB WITHOUT APPROVAL OF AOGCC AND DRILLING SUPERINTENDENT
TOP JOB CEMENT TYPE: Permafrost Cold Set Set III
NOTE:
ADDITIVES: Retarder
TOP JOB WILL BE PUMPED IF THERE ARE NO CEMENT RETURNS TO
SURFACE OR THE CEMENT TOP FALLS BELOW SURFACE AFTER THE
PUMPS ARE SHUT DOWN.
:;
WEIGHT: 12.2 ppg
YI ELD: 1.92 ft3/sx
MIX WATER: 10.53 gal/sk
APPROX NO SACKS: 100
RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL
MP E-30 Well Plan PAGE 7 26 Jun 98
CENTRALIZER PLACEMENT:
1. Spiral Glide 5-1/2" X 6-3/4" centralizers are planned for the 5-1/2" casing The number to be
determined by the Caliper log, and also on the joint of casing above and below port collar.
See attached Weatherford centralizer program in cementing section.
2. Place all centralizers in middle of joints using stop collars. Note: A revised centralizer
program will be issued following receipt of the results of the 4-Arm Caliper Log.
OTHER CONSIDERATIONS:
Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping
job. Ensure thickening times are adequate relative to pumping job requirement. Displace as per
attached cement program. Mix slurry on the fly -- batch mixing is not necessary.
Before Landing Casing following returns to surface the section of the diverter and wellhead system
below the diverter line to the starting head may need to be will be displaced with inhibitive wash to
prevent it from setting and thus easing the clean out of that section.
MP E-30 Well Plan PAGE 8 26 Jun 98
E-PAD
3 8
· ·
'. !800.00
1om
· ~
· 1
13m ms
+ 3O
9 · m6
11 · m7
18m · 16
20 · · 2,3
24m · 19
14 · + 21
1.5 · · 17
NOTES
1. ALASKA STATE PLANE COORDINATES
ARE ZONE 4, NAD 27.
2. CEODETIC COORDINATES ARE NAD 27.
5. MEAN PAD SCALE FACTOR 0.999905454.
4. HORIZONTAL AND VERTICAL CONTROL IS
BASED ON MONUMENTS CFP-5 and E-I.
5. DATE OF SURVEY: JUNE 50, 1998.
6. REFERENCE FIELD BOOK:
MP98-06 (Pgs. 05-07).
7. ELEVATIONS ARE BASED ON BPX
MILNE POINT DATUM (M.S.L.).
(*) DENOTES PREVIOUSLY INSTALLED 20" DIA.
CONDUCTOR WITH NEW 15 5/8" DIA. CONDUCTOR
INSIDE OF OLD 20" DIA. CONDUCTOR.
+ N 2600.00
SURVEY AREA ~,j ! "'i
1.1,SN I T. 13N.
VICINITY MAP
N.T.S.
LEGEND
+AS-BUiLT WELL CONDUCTOR
· EXISTING WELL CONDUCTOR
SURVEYOR'S CERTIFICATE
I HEREBY CERTIFY THAT I AM
PROPERLY REGISTERED AND LICENSED
TO PRACTICE LAND SURVEYING IN
THE STATE OF ALASKA AND THAT
THIS PLAT REPRESENTS A SURVEY
MADE BY ME OR UNDER MY DIRECT
SUPERVISION AND THAT ALL
DIMENSIONS AND OTHER DETAILS ARE
CORRECT AS OF JUNE 30, 1998.
LOCATED WITHIN PROTRACTED SEC. 25, T. 15 N., R. 10 E., UMIAT MERIDIAN, ALASKA
WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION
NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS
21' y= 6,016,227.28 N. 1,950.56 70'27'16.877" 70.454-6879' 25.4-' 5,688' FSL
X= 569,350.97 E. 1,450.11 149"26'02.626" 149.4340629' 1,794-' FEL
y= 6,016,590.55 N. 2,159.67 70'2T18.494" 70.4-551575' 25.2' 3,853' FSL
30 X= 569,220.32 E. 1,450.40 14-9'26'06.4-20" 14-9.4-351166' 1,925' FEL
ISSUED FOR INFO~M^RON
REVISIOf, I
F. Rober~_~t,
DRAWN:
JACOBS
CHECKED: O'HANLEY
DATE:
7/1/'98
ORAWINC:
MPE- AB
SCALE:
ffiBP EXPLORATIC>'"'
MILNE POINT UNIT- E PAD
AS-BUILT WELL CONDUCTOR
WELLS 21 & 30
lo¢1
~I~--I-q~[-~-I-!~ Shared Services Drillin~ DrillQ
. uest
S~le: linch = 7~ Eastings
0 7~ 14~ 21 ~ 28~
35~ - 5
73~.45 MD
Proposal Data for MPE-30 (9~) Wp2 J 4747.~ ~D 47~.~
,
v~ ~: we~
M~t ~:
~h R~: T~ ~h
VeA~ ~ ~: 40.~
Ve~ ~ D~:We~
VeStal ~ ~: 0,~ N,O.~ E 4
M~ I~L ~ Ve~l NoSings ~ Venal ~ 2~ ~ 41~.~ ~ 28~
0.~ 0.~ 0.532 0.~ 0.~ N 0.~ E 0.~ 4~.
~.~ 0.~ 0.532 ~.~ 0.~ N 0.~ E 0.~ 0.~
~1~ 4.413 59.~ ~.~ 8.63 N ]4.~3 E 16.05 I.~
~753.14 4.4]3 59,~ 1750.~ ~27N 75.~E 8236 0.~ 3~.
7~.6~ 3~]332 S~ N 745.]0 E t~8.45 4,~ ~
7395.45 ~.~ 39.~38 4~47.~ 33S5~8 N ~.~ E ~3.~ 0.~ ~3/
21~ -- ' -- 21~
PROPOSAL TARGET SUMMARY ~
O
T~et ~e: ~DSS ~DRKB: We~ ~s~: G~I C~rd~les: Z I Z
MPE~ (984) T1 42~.~ 4~.~ ~11.70 N~.~ E 601~.~ N. 5717S8.~ E 14~ -- -- 14~
, ~.
$H~FA~E [OCAIIO~ P~OI DAIE.~: ~98 7~ - -
RKB E~vat~: ~ ~.~fl Rig (ES~ ~
24.~ ~ Wall (CBE) '---'-~
~le Syst~: NAD27 A~a State Pl~es, - ~,I
Z~e 4, US F~t ~ 27~
2~.
0' 0
I I I
0 700 14~ 2100 28~
Scale: linch = 70Oft Eastings Reference is True No~h
I I I I
-- 5 1/2' Casing
7395.45 MD
4747.34 'I'VD
,..
2700.20~ -"
Well' MPE-30 (98-4) WP2 r
Proposal Data for MPE-30 (98-4) Wp2
Ve~lJcaJ Origin: Well
Horizontal Odgin: Well
Me~.~,rement Units: ft
North Re~e~ence: True No~th
0 -- Ven~.~ Set,on Descdpl~on:Wea
V~I Section Origin: 0.00 N.0.O0 E
i
~30.00 Measured IncL ~ Vertical Norl~lngs F. aJ~ng~ Ve~:~l
,~00.00 i 0.00 0.000 0.532 0.00 0.00 S 0.00 E
400.00 0.000 0.532 400.00 0.00 N 0.00 l~ 0.00 0.000
I ~.41.30 4.4t3 59.,1~IJ ~IO.S6 8.63 N 14.63 E 16.0~ t.0CO
1753.14 4.413 59.468 1750.00 44~7 N 75.06 £ 82.36 0.000
~ ~X).OO i 1953.73 4.413 .59.468 1950.00 52.11 N 8836E 96.94 0.000
i
3666.06 72.6.%4 39.509 3213.32 808.30 N 745.10£ 1098.45
56"7.56 72,634 39,509 3798.77 2'Z52.67 N 1936.11 F, 297032
)00.00 i 6759.41 50,000 39.938 4338.50 ."~) ! 1.70 N 2566.26 E 39.56.77 2,000
7095.-15 50.0('~ 39.938 455a.50 3209.07 N 2731.51 £ 4214.1g 0,000
900 -- I000.OO 7305.45 50,000 39.93g 4747.34 3385.2g N 2879.04 I:: 4443.99 0,0~O
PROPOSAL TARGET SUMMARY
~ 1200.00
Target Name: TVDSS TVDRKB: Wellhead Offsets: Global Co~rd~r~les:
MPE-30 (98-n) T1 4294.00 n33S.$O 3m~.70 N.Z.~.2~ E 60~.00 N. S7~7SS.O0
1800 -- ' ...... i~a°°'°a ....................................................................................................................... '~'~'~'"~
/
~ oooo SURFACE LOCATION PLOT DATE: 2/12/98
~ ' ,
~ Nori:,ontat ~oord~ate~ 6016~00.59 Iq r:~9219.8:t E Created By ·
'~600.00 RKB £1evation: 20.00 fi ~i~ {ESI) '
2700
~'-' I Coordinate System: NAD27 Alaska State Planes. --
: "~00.00 I Zone 4, US Foot
---....~8oo.oo
"~_.4ooo.oo
-'~44oo.oo
g600 .
~$00.00
o~ .00 3011,70 N. 25~.26 E
~o 4soo ........
.'{~0' .... ~, s~
~; 5 1/2" Casing
-- 7395.45 MD
~ 4747.34 ]-VD
I I I I I I
0 900 1800 2700 3600 4500
Scale: linch = 900ft Vertical Section Section Azimuth: 40.380° {True North)
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
Depth-
(ft)
Incl.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
0.00 0.000 0.000 -44.50 0.00
100.00 0.000 0.000 55.50 100.00
200.00 0.000 0.000 155.50 200.00
300.00 0.000 0.000 255.50 300.00
400.00 0.000 0.000 355.50 400.00
500.00 1.000 59.468 455.49 499.99
600.00 2.000 ,,59.468 555.46 ~;99.96
700.00 3.000 59.468 655.36 699.86
800.00 4.000 59.468 755.18 799.68
841.30 4.413 59.468 796.36 840.86
900.00 4.413 59.468 854.89 899.39
1000.00 4.413 59.468 954.59 999.09
1100.00 4.413 59.468 1054.30 1098.80
1200.00 4.413 59.468 1154.00 1198.50
1300.00 4.413 59.468 1253.70 1298.20
1400.00 4.413 59.468 1353.41 1397.91
1500.00 4.413 59.468 1453.11 1497.61
1600.00 4.413 59.468 1552.81 1597.31
1700.00 4.413 59.468 1652.52 1697.02
1753.14 4.413 59.468 1705.50 1750.00
1800.00 4.413 59.468 1752.22 1796.72
1803.29 4.413 59.468 1755.50 1800.00
1900.00 4.413 59.468 1851.93 1896.43
1953.73 4.413 '59.468 1905.50 1950.00
2000.00 6.180 53.439 1951.57 1996.07
2100.00 10.103 47.727 2050.54 2095.04
2200.00 14.069 45.200 2148.31' 2192.81
2300.00 18.049 43.770 2244.38 2288.88
2400.00 22.037 42.844 2338.31 2382.81
2500.00 26.028 42.190 2429.62 2474.12
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
0.00 N 0.00 E
0.00 N 0.00 E
0.00 N 0.00 E
0.00 N 0.00 E
0.00 N 0.00 E
0.44 N 0.75 E
1.77 N 3.01 E
3.99 N 6.76 E
7.09 N 12.02 E
8.63 N 14.63 E
10.92 N 18.52 E
14.83 N 25.15 E
18.74 N 31.78 E
22.65 N 38.40 E
'26.56 N 45.03 E
30.47 N 51.66 E
34.38 N 58.29 E
38.29 N 64.92 E
42.20 N 71.54 E
44.27 N 75.06 E
46.10 N 78.17 E
46.23 N 78.39 E
50.01 N 84.80 E
52.11 N 88.36 E
54.50 N 91.89 E
63.61N 102.71E
78.08 N 117.83 E
97.84 N 137.18 E
122.79 N 160.66 E
152.82 N 188.17 E
6016390.59 N 569219.83 E
6016390.59 N 569219.83 E 0.000
6016390.59 N 569219.83 E 0.000
6016390.59 N 569219.83 E 0.000
6016390.59 N 569219.83 E 0.000
6016391.04 N 569220.58 E 1.000
6016392.39 N 569222.82 E 1.000
6016394.64 N 569226.56 E 1.000
6016397.79 N 569231.79 E 1.000
6016399.35 N 569234.38 E 1.000
6016401.69 N 569238.25 E 0.000
6016405.66 N 569244.84 E 0.000
6016409.63 N 569251.43 E 0.000
6016413.60 N 569258.02 E 0.000
6016417.57 N 569264.61 E 0.000
6016421.54 N 569271.20 E 0.000
6016425.51N 569277.80 E 0.000
6016429.48 N 569284.39 E 0.000
6016433.45 N 569290.98 E 0.000
6016435.56 N 569294.48 E 0.000
6016437.42 N 569297.57 E 0.000
6016437.55 N 569297.79 E 0.000
6016441.39 N 569304.16 E 0.000
6016443.52 N 569307.70 E 0.000
6016445.94 N 569311.21 E 4.000
6016455.15 N 569321.95 E 4.000
6016469.76 N 569336.93 E 4.000
6016489.70 N 569356.10 E 4.000
6016514.87 N 569379.35 E 4.000
6016545.15 N 569406.57 E 4.000
Comment
0.00
0.00
0.00
0.00
0.00
0.82
3.30
7.42
13.19
16.05
20.32
27.59
34.86
42.14
49.41
56.68
63.95
71.22
78.49
82.36
85.76
86.00 : Base Permafrost
93.04
96.94
101.05
115.00
135.82
163.40
197.63
238.31
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
13 February, 1998 - 10:41
-1-
DriliQuest
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
Depth'
(ft)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
2600.00 30.021 41.699 2517.88 2562.38
2700.00 34.016 41.315 2602.65 2647.15
2800.00 38.012 41.002 2683.52 2728.02
2900.00 42.008 40.741 2760.10 2804.60
3000.00 46.005 40.517 2832.01 2876.51
3100.00 50.003 40.322 2898.90 2943.40
3200.00 54.000 40.148 2960.46 3004.96
3300.00 57.998 39.991 3016.37 3060.87
3400.00 61.996 39.847 3066.36 3110.86
3500.00 65.994 39.713 3110.19 3154.69
3600.00 69.993 39.588 3147.66 3192.16
3666.06 72.634 39.509 3168.82 3213.32
3700.00 72.634 39.509 3178.95 3223.45
3800.00 72.634 39.509 3208.80 3253.30
3900.00 72.634 39.509 3238.65 3283.15
4000.00 72.634 39.509 3268.49 3312.99
4100.00 72.634 39.509 3298.34 3342.~4
4200.00 72.634 39.509 3328.19 3372.69
4300.00 72.634 39.509 3358.04 3402.54
4400.00 72.634 39.509 3387.88 3432.38
4500.00 72.634 39.509 3417.73 3462.23
4600.00 72.634 39.509 3447.58 3492.08
4700.00 72.634 :39.509 3477.42 3521.92
4800.00 72.634' 39.509 3507.27 3551.77
4900.00 72.634 39.509 3537.12 3581.62
5000.00 72.634 39.509 3566.97 3611.47
5100.00 72.634 39.509 3596.81 3641.31
5200.00 72.634 39.509 3626.66 3671.16
5300.00 72.634 39.509 3656.51 3701.01
5400.00 72.634 39.509 3686.36 3730.86
Local Coordinates Global Coordinates Dogleg Vertical
Northings · Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
187.76 N 219.55 E 6016580.39 N 569437.63 E 4.000 285.27
227.47 N 254.68 E 6016620.41 N 569472.38 E 4.000 338.27
271.73 N 293.36 E 6016665.04 N 569510.65 E 4.000 397.05
320.34 N 335.42 E 6016714.04 N 569552.26 E 4.000 461.33
373.06 N 380.64 E 6016767.17 N 569596.99 E 4.000 530.79
429.64 1'4 428.82 E 6016824.19 N 569644.64 E 4.000 605.09
489.78 N 479.70 E 6016884.81 N 569694.96 E 4.000 683.88
553.22 N 533.06 E 6016948.73 N 569747.72 E 4.000 766.76
619.62 N 588.62 E 6017015.65 N 569802.66 E 4.000 853.34
688.68 N 646.11 E 6017085.24 N 569859.51 E 4.000 943.20
760.05 N 705.26 E 6017157.16 N 569918.00 E 4.000 1035.88
808.30 N 745.10 E 6017205.78 N 569957.39 E 4.000 1098.45
833.29 N 765.71 E 6017230.96 N 569977.76 E "0.000 1130.84
906.93 N 826.43 E 6017305.16 N 570037.80 E 0.000 1226.27
980.56 N 887.15 E 6017379.35 N 570097.83 E 0.000 1321.70
1054.20 N 947.87 E 6017453.55 N 570157.86 E 0.000 1417.13
1127.84 N 1008.59 E 6017527.75 N 570217.89 E 0.000 1512.56
1201.47 N 1069.31 E 6017601.94 N 570277.93 E 0.000 1607.99
1275.11 N 1130.02 E 6017676.14 N 570337.96 E 0.000 1703.42
1348.74 N 1190.74 E 6017750.34 N 570397.99 E 0.000 1798.85
1422.38 N 1251.46 E 6017824.54 N 570458.02 E 0.000 1894.28
1496.02 N 1312.18 E 6017898.73 N 570518.06 E 0.000 1989.71
1569.65 N 1372.90 E 6017972.93 N 570578.09 E 0.000 2085.15
1643.29 N 1433.62 E 6018047.13 N 570638.12 E 0.000 2180.58
1716.92 N 1494.34 E 6018121.32 N 570698.16 E 0.000 2276.01
1790.56 N 1555.06 E 6018195.52 N 570758.19 E 0.000 2371.44
1864.20 N 1615.78 E 6018269.72 N 570818.22 E 0.000 2466.87
1937.83 N 1676.50 E 6018343.91 N 570878.25 E 0.000 2562.30
2011.47 N 1737.22 E 6018418.11 N 570938.29 E 0.000 2657.73
2085.10 N 1797.94 E 6018492.31 N 570998.32 E 0.000 2753.16
Comment
Alaska State Plane Zone 4
Milne Point E Pad
Continued...
13 February, 1998 - 10:41
-2-
DrillQuest
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Milne Point Unit
Measured
Depth.
(fi)
Incl.
Azim.
Sub-Sea
Depth
(ft)
Vertical
Depth
(ft)
5500.00 72.634 39.509 3716.20 3760.70
5600.C0 72.634 39.509 3746.05 3790.55
5627.56 72.634 39.509 3754.27 3798.77
5700.00 71.185 39.531 3776.77 3821.27
5800.00 69.186 39.564 3810.67 3855.17
5900.00 67.186 39.597 3847.82 3892.32
6000.00 65.186 39.631 3888.20 3932.70
6100.00 63.186 39.666 3931.74 3976.24
6200.00 61.187 39.702 3978.40 4022.90
6300.00 59.187 39.740 4028.11 4072.61
6400.00 57.187 39.779 4080.83 4125.33
6500.00 55.187 39.820 4136.47 4180.97
6600.00 53.188 39.864 4194.98 4239.48
6700.00 51.188 39.909 4256.29 4300.79
6759.41 50.000 39.938 4294.00 4338.50
6800.00 50.000 39.938 4320.09 4364.59
6900.00 50.000 39.938 4384.37 4428.87
7000.00 50.000 39.938 4448.65 4493.15
7095.45 50.000 39.938 4510.00 4554.50
7100.00 50.000 39.938 4512.93 4557.43
7200.00 50.000 39.938 4577.20 4621.70
7300.00 50.000 39.938 4641.48 4685.98
7395.45 50.000 '39.938 4702.84 4747.34
Local Coordinates Global Coordinates Dogleg Vertical
Northings Eastings Northings Eastings Rate Section
(ft) (ft) (ft) (ft) (°/100ft) (ft)
2158.74 N 1858.66 E 6018566.51 N
2232.38 N 1919.38 E 6018640.70 N
2252.67 N 1936.11 E 6018661.15 N
2305.79 N 1979.93 E 6018714.67 N
2378.33 N 2039.83 E 6018787.77 N
2449.88 N 2098.98 E 6018859.86 N
2520.35 N 2157.31 E 6018930.88 N
2589.66 N 2214.75 E 6019000.72 N
2657.73 N 2271.22 E 6019069.30 N
2724.46 N 2326.66 E 6019136.55 N
2789.78 N 2381.01 E 6019202.37 N
2853.61 N 2434.19 E 6019266.70 N
2915.88 N 2486.14 E 6019329.44 N
2976.49 N 2536.80 E 6019390.52 N
3011.70 N 2566.26 E 6019426.00 N
3035.54 N 2586.22 E 6019450.02 N
3094.27 N 2635.40 E 6019509.21N
3153.01N 2684.57 E 6019568.40 N
3209.07 N 2731.51 E 6019624.90 N
3211.75 N 2733.75 E 6019627.60 N
3270.48 N 2782.93 E 6019686.79 N
3329.22 N 2832.10 E 6019745.98 N
3385.28 N 2879.04 E 6019802.47 N
571058.35 E 0.000 2848.59
571118.39 E 0.000 2944.02
571134.93 E 0.000 2970.32
571178.25 E 2.000 3039.17
571237.47 E 2.000 3133.24
571295.96 E 2.000 3226.06
571353.63 E 2.000 3317.54
571410.42 E 2.000 3407.55
571466.26 E 2.000 3495.98
571521.08 E 2.000 3582.74
571574.82 E 2.000 3667.70
571627.40 E 2.000 3750.78
571678.77 E 2.000 3831.87
571728.87 E 2.000 3910.86
571758.00 E 2.000 3956.77
571777.74 E 0.000 3987.86
571826.37 E 0.000 4064.46
571874.99 E 0.000 4141.06
571921.41E 0.000 4214.18
571923.62 E 0.000 4217.67
571972.25 E 0.000 4294.27
572020.88 E 0.000 4370.87
572067.30 E 0.000 4443.99
Comment
MPE-30 (98-4) T1
Top NA
Base SB
5 1/2" Casing
Alaska State Plane Zone 4
Milne Point E Pad
Conb'nued...
13 February, 1998 - 10:41 - 3 -
DrillQuest
Milne Point Unit
Sperry-Sun Drilling Services
Proposal Report for MPE-30 (98-4) - MPE-30 (98-4) Wp2
Alaska State Plane Zone 4
Milne Point E Pad
All data is in'feet unless otherwise stated. Directions and coordinates are relative to True North.
Vertical depths are relative to Well. Northings and Eastings are relative to Well.
The Dogleg Severity is in Degrees per 100ft.
Vertical Section is from Well and calculated along an Azimuth of 40.380" (True).
Based upon Minimum Curvature type calculations, at a Measured Depth of 7395.45ft.,
The Bottom Hole Displacement is 4443.99ft., in the Direction of 40.380° (True).
13 February, 1998 - 10:41 - 4 - DrillQuest
H 13 7 17 3 °4/24'/~sl °°i-371731
VENDOR AL ASA,S T 14 O0
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET
· _
042~_98~-,""t~ O~-~'-,oou...,..,=.e_~,~,~ 100. oo !00. O0
HANDLINO i'NST: S/H g. ATHY CAPtPOA,"tOR X 5122
' ....... ~ .... ] 1 oo_ oo__:J
· WELL PERMIT CHECKLIST
FIELD & POOL ,.~~,,/'~/~__,)
COMPANY ? WELL NAME ~. ,,~ -,~::~ PROGRAM: exp [] dev/~redrll [] serv [] wellbore seg[I ann. disposal para reqtl
INIT CLASS Z~--~-' ,/~o;/~ GEOL AREA ~;'~'<::3 UNIT# ///' ~.~_. ~ ON/OFF SHORE ~ ¢,d
ADMINISTRATION
ENGINEERING
A_P~R. DATE
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
14. Conductor string provided ...................
15. Surface casing protects all known USDWs ...........
16. CMT vol adequate to circulate on conductor & surf csg .....
17. CMT vol adequate to tie-in long string to surf csg ........
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved...
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. 13OPEs, do they meet regulation ................
26. BOPE press rating appropriate; test to ~O~ psig.
27. Choke manifold complies w/APl RP-53 (May 84) ........
yy~~N
Y N
N
N
N
N
Y N
N
N
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable .................
GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~'"_
31. Data presented on potential overpressure zones .......
32. Seismic analysis of shallow gas zones ............. ~Y N,/c--',
33. Seabed condition survey (if off-shore) ............. J Y N' --
,,,~I~R ~//~~ 34. Con. tact.nam, elphon.e.forweekl, progress reports ...... lexplora~ory onlyj .........
,/A--~-~0-L~L 35. With prol~er cementing records, this plan
I/
(A) will co'¢rt-a~ waste in a suitable receiving zone; ....... Y N
I/APPR DATE (B) will not co~~te freshwater; or cause drilling waste . . . Y N
to surface; '~ Pi-~'~'
(C) will not impair mechanic~,~grity of the well used for disposal; Y N
(D) willpool;nOtanddamage producing form-"a~~r, ecovery~ from a Y N
(E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N
G _E_.O__L~: ENGINEERING: UIC/Annular COMMISSION:
JDH /~ RNC
-' '" CO C,.~ '~/7. t-
Comments/Instructions:
M:chel~list rev 05/29/98
dlf:C:\msoffice\wordian\diana\checklist
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.
Sperry-Sun Drill~-] Services
LIS Scan L ity
Fri Nov 13 13:17:53 1998
Reel Header
Service name ............. LISTPE
Date ..................... 98/11/13
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 ..................... 98/11/13
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
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)
KELLY BUSHING:
DERRICK FLOOR:
GROIZxrD LEVEL:
WELL CASING RECORD
MWD RUN 2
AK-MM-80303
S. LATZ
J. PYRON
1ST STRING
MPE-30
500292290300
BP EXPLORATION (ALASKA), INC.
SPERRY-SUN DRILLING SERVICES
13-NOV-98
25
13N
10E
3853
1923
.00
57.10
23.20
OPEN HOLE CASING DRILLERS
BIT SIZE (IN) SIZE (IN) DEPTH (FT)
2ND.STRING
3RD STRING
PRODUCTION STRING
REMARKS:
13.375 120.0
6.750 7200.0
1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE
NOTED.
2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS
PER THE E-MAIL MESSAGE
FROM D. DOUGLAS FOR KATIE NITZBERG AND MARK VANDERGON OF
BP EXPLORATION
(ALASKA), INC. ON 10/29/98.
3. RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED.
4. RUN 2 IS DIRECTIONAL, DUAL GAFflvLA R3kY (DGR) UTILIZING
GEIGER-MUELLER TUBE
DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4
(EWR4) .
5. WELL MPE-33 REACHED A TOTAL DEPTH OF 7200'MD,
4744'TVD.
SROP = SMOOTHED RATE OF PENETRATION.
SGRC = SMOOTHED GAMMA RAY COMBINED.
SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTR3k
SHALLOW SPACING).
SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(SHALLOW SPACING).
SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY
(MEDIUM SPACING).
SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP
SPACING).
SFXE = SMOOTHED FORMATION EXPOSURE TIME RESISTIVITY
SENSOR.
SLIDE = MUD MOTOR DRILLING (NO ROTATION).
$
File Header
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/11/13
Maximum Physical Record..65535
File Type ................ LO
Previous File Name ....... STSLIB.000
Comment Record
FILE HEADER
FILE NUMBER: 1
EDITED MERGED MWD
Depth shifted and clipped curves; all bit runs merged.
DEPTH INCREMENT: .5000
FILE SUMMARY
PBU TOOL CODE START DEPTH STOP DEPTH
GR 2961 5 7148 5
FET 2969 0 7155 5
RPD 2969 0 7155 5
RPM 2969 0 7155 5
RPS 2969 0 7155 5
RPX 2969 0 7155 5
ROP 3013 5 7200 0
$
BASELINE CURVE FOR SHIFTS:
CURVE SHIFT DATA (MEASURED DEPTH)
BASELINE DEPTH
$
MERGED DATA SOURCE
PBU TOOL CODE
MWD
$
REMARKS:
~QUIVALENT UNSHIFTED DEPTH
BIT RUN NO MERGE TOP MERGE BASE
2 3013.0 7200.0
MERGED MAIN PASS.
$
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
GR MWD API 4 1
RPX MWD OHMM 4 1
RPS MWD OHMM 4 1
RPM MWD OHMM 4 1
RPD MWD OHMM 4 1
ROP MWD FT/H 4 1
FET MWD HOUR 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
Name Min Max Mean
DEPT 2961.5 7200 5080.75
GR 3.559 129.475 69.7493
RPX 1.1191 57.9982 7.07203
RPS 1.0919 52.7732 7.61267
RPM 1.08 75.8552 7.4332
RPD 1.0836 63.8519 7.66815
ROP 1.98 630.049 168.972
FET 0.1082 11.4831 0.859696
First Last
Nsam Reading Reading
8478 2961.5 7200
8375 2961.5 7148.5
8374 2969 7155.5
8374 2969 7155.5
8374 2969 7155.5
8374 2969 7155.5
8374 3013.5 7200
8374 2969 7155.5
First Reading For Entire File .......... 2961.5
Last Reading For Entire File ........... 7200
File Trailer
Service name ............. STSLIB.001
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/11/13
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 ....... 98/11/13
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.
BlT RUN NUMBER: 2
DEPTH INCREMENT: .5000
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR
FET
RPD
RPM
RPS
RPX
ROP
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE
2961 5
2969 0
2969 0
2969 0
2969 0
2969 0
3013 5
SURFACE SOFTWARE VERSION:
DOWNHOLE SOFTWARE VERSION:
DATA TYPE (MEMORY OR REAL-TIME):
TD DRILLER (FT) :
TOP LOG INTERVAL (FT) :
BOTTOM LOG INTERVAL (FT) :
BIT ROTATING SPEED (RPM) :
HOLE INCLINATION (DEG
MINIMUM ANGLE:
MAXIMUM ANGLE:
STOP DEPTH
7148.5
7155.5
7155.5
7155.5
7155.5
7155.5
7200.0
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) :
30-JUL-98
ISC 5.07
DEPII(2.22A), SP4 (5.04)
MEMORY
7200.0
3013.0
7200.0
44.3
72.0
TOOL NUMBER
P1043GR4
P1043GR4
6.750
6.8
POLYMER/KLAGARD
9.40
57.0
9.1
6500
8.5
PESISTIVITY (OHMM) AT TF"~ERATURE (DEGF) MUD AT MEASURED TEMPL 2URE (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
.700
.493
.600
1.200
.5
Name Service Order
Units Size Nsam
DEPT FT 4 1
FET MWD 2 HOUR 4 1
ROP MWD 2 FT/H 4 1
GR MWD 2 API 4 1
RPX MWD 2 OHMM 4 1
RPS MWD 2 OHMM 4 1
RPM MWD 2 OHMM 4 1
RPD MWD 2 OHMM 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
42.2
Name Min Max Mean
DEPT 2961.5 7200 5080.75
FET 0.1082 11.4831 0.859696
ROP 1.98 630.049 168.972
GR 3.559 129.475 69.7493
RPX 1.1191 57.9982 7.07203
RPS 1.0919 52.7732 7.61267
RPM 1.08 75.8552 7.4332
RPD 1.0836 63.8519 7.66815
First Last
Nsam Reading Reading
8478 2961.5 7200
8374 2969 7155.5
8374 3013.5 7200
8375 2961.5 7148.5
8374 2969 7155.5
8374 2969 7155.5
8374 2969 7155.5
8374 2969 7155.5
First Reading For Entire File .......... 2961.5
Last Reading For Entire File ........... 7200
File Trailer
Service name ............. STSLIB.002
Service Sub Level Name...
Version Number ........... 1.0.0
Date of Generation ....... 98/11/13
Maximum Physical Record..6~
File Type ................
Next File Name ........... STSLIB.003
Physical EOF
Tape Trailer
Service name ............. LISTPE
Date ..................... 98/11/13
Origin ................... STS
Tape Name ................ UNKNOWN
Continuation Number ...... 01
Next Tape Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Reel Trailer
Service name ............. LISTPE
Date ..................... 98/11/13
Origin ................... STS
Reel Name ................ UNKNOWN
Continuation Number ...... 01
Next Reel Name ........... UNKNOWN
Comments ................. STS LIS Writing Library.
Scientific
Scientific
Technical
Technical
Services
Services
Physical EOF
Physical EOF
End Of LIS File
