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10/6/2005 Well History File Cover Page.doc
DATA SUBMITTAL COMPLIANCE REPORT
11 /23/2007
Permit to Drill 2051140 Well Name/No. KUPARUK RIV UNIT 1B-15AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22465-60-00
MD 9731 TVD 6457 Completion Date 10/14/2005 Completion Status 1-OIL Current Status 1-OIL UIC N
REQUIRED INFORMATION
Mud Log No Samples No Directional rvey Yes
DATA INFORMATION
Types Electric or Other Logs Run: MWD GR
Well Log Information:
Log/ Electr
Data Digital Dataset
Ty Med/Frmt Number Name
(data taken from Logs Portion of Master Well Data Maint
Interval ~~
Log Log Run OH /
Scale Media No Start Stop CH Received Comments
(,/ED D Asc Directional Survey
Directional Survery
C~~„B,fl~ (`~~ G ~-~S 14291 ~1Lera€~ezrtf6l'' 19~
~og 14291 Gamma Ray
(Jc~g 14291 Gamma Ray
8270 9731 Open 1 B-15A L1, 1 B-15A L2, 1 B-
15A L2 P61, 1 B-15A L2
PB2 on diskette
8270 9731 Open 1 B-15A L1
1 8347 9730 Open 12/15/2006 LIS VERI, GR ROP
w/Graphics
25 Blu 1 8342 9731 Open 12/15/2006 MD GR 27-Sep-2006
25 Blu 1 8342 9731 Open 12/15/200& TVD GR 27-Sep-2006
Well Cores/Samples Information:
Sample
Interval Set
Name Start Stop Sent Received Number Comments
ADDITIONAL INFORMATION
Well Cored? ~ Daily History Received?
Chips Received? Y~,~1~- Formation Tops ~ N
Analysis ~L!-fd~
Received?
Comments:
Compliance Reviewed By:
Date:
•
• •
Transmittal Form
BAKER. ~, :~
Nuc~ES
INTEQ
To: AOGCC
333 West 7th Ave, Suite 100
Anchorage, Alaska
99501
Attention: Helen Warman
Reference: 1B-15AL1
~: ,..,. wn~,r
' Contains the following: ,
1 LDWG Compact Disc
(Includes Graphic Image files)
1 LDWG lister summary
1 blueline - GR Measured Depth Log
1 blueline - GR TVD Log
j LAC Job#: 982397
Sent By: Deepa Jo lekar Dam' Bc
Received By: _ Date '~ ~,
~.
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING
OR FAXING YOUR COPY
FAX: (907) 267-6623
~-~-"~ ~ Baker Hughes INTEQ
7260 Homer Drive
Anchorage, Alaska.
9918
Direct: (907) 267-6612
~~ _j/L~ ~ l~l ~' ~ FAX: (907) 267-6623
~...,
STATE OF ALASKA
ALASKA IL AND GAS CONSERVATION COMNt7~lON
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG
20AAC 25.105 2oAAC 2s.~~o
^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class:
®Development ^ Exploratory
^ Stratigraphic ^ Service
2. Operator Name:
Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband.
10/14/2005 12. Permit to Drill Number
205-114
3. Address:
do P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded
9/25/2005 13. API Number
50-029-22465-60-00
4a. Location of Well (Governmental Section):
Surface:
'
' 7. Date T.D. Reached
9/27/2005 14. Well Name and Number:
KUP 1 B-15AL1
500
FNL, 484
FEL, SEC. 09, T11 N, R10E, UM
Top of Productive Horizon:
2898' FNL, 3406' FEL, SEC. 09, T11N, R10E, UM g, KB Elevation (ft):
g5' 15. Field /Pool(s):
Kuparuk River Unit
Total Depth:
2482' FNL, 4579' FEL, SEC. 09, T11N, R10E, UM 9. Plug Back Depth (MD+TVD)
9731 + 6457 Ft
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 549955
y- 5969647 Zone- ASP4 10. Total Depth (MD+TVD) ~
< 9731 + 6457 Ft 16. Property Designation:
ADL 025648
_
TPI: x- 547055 y- 5967230 Zone- ASP4
Total Depth: x- 545878 l Y- 5967639 'Zone- ASP4 11 • Depth where SSSV set
1833' MD 17. Land Use Permit:
-~-~-----~------- ----------__--- ~----~---------~ '
18. Directional Survey ®Yes ^ No 19. Water depth, if offshore
N/A MSL kness of Permafrost
20. T
8' (Approx.)
21. Logs Run: r/~e1 ~..~~u-ac., ~~~~.~c~' ~~n~] ~ ~ S 2~ ~~~
MWD GR ~ ;r a2 ~_ 3
2. ASING, LINER AND EMENTING RECORD
CASING ETi7NQ EPTM MD ETTINe EPTH TVD `f'fOIE
~ AMOUNT"
SIZE WT, PER FT. GRADE OP TTOM OP TTOM $IZE CEMENT
~ Fi PULLED'
16" 62.5# H-40 Surface 121' Surface 121' 24" 00 sx Arcticset I q
9-5/8" 40# L-80 Surface 4190' Surface 4138' 12-1/4" 00 sx AS III, 400 sx Cla
7" 26# L-80 Surface 4405' Surface 4324' 8-1/2" 350 sx Class 'G'
5-1/2" 15.5# L-80 4234' 8340' 4176' 6353' 6-1/8" 83 sx Class 'G'
3-1/2" 9.2# L-80 8121' 8340' 6170' 8353' 6-1/8" 55 sx Class 'G'
2-3/8" 4.6# L-80 8334' 9700' 6348' 6457' 3" Uncemented Slotted Liner
23. Perforations open to Produc tion (MD + TV D of Top and
"
" 24, TuBlyda RECOSo
Bottom Interval, Size and Number; if none, state
none
): SIZE DEPTH SET (MD) PACKER SET (MD)
23/8" Slotted Section 3-1/2", 9.3#, L-80 8121'
MD TVD MD TVD
8462' - 9667 6439' -6457 25. ACID, FRACTURE,. CEMENT. SpUEEZE, ETC.
DEPTH INTERVAL MD AMOUNT Ec KIND OF MATERIAL USED
8340' Set Flow-Thru Whipstock
2000' Freeze Protect w/ Diesel
26. PRODUCTION TEST
Date First Production:
October 23, 2005 Method of Operation (Flowing, Gas Lift, etc.):
Gas Lift
Date of Test
10/29/2005 Hours Tested
18 PRODUCTION FOR
TEST PERIOD OIL-BBL
698 GAS-MCF
1490 WATER-BBL
300 CHOKE SIZE
176 GAS-OIL RATIO
2136
Flow Tubing
Press. 17 Casing Pressure
1224 CALCULATED
24-HOUR RATE OIL-BBL
930 GAS-MCF
1986 WATER-BBL
400 OIL GRAVITY-API (CORK)
24
27. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary).
Submit core chips; if none, state "none". -- - -
,,1
None ' ~~L N~~ ~ ~ ~~)~ /c' ~ i _~~
_. _~_1_a___-
Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE /~
~1
28. GEOLOGIC MARKERS 29' ORMATION TESTS
Include and briefly summarize test results. List intervals tested,
NAME MD TVD and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
Kuparuk B2 8360' 6369' None
Kuparuk 61 8386' 6390'
Kuparuk A6 8405' 6403'
Kuparuk A5 8413' 6409'
Kuparuk A4 8438 6425'
Miluveach 9700' 6457"
30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys
31. I hereby certify that the foregoing is true and correct to the best of my knowledge.
/ ,,
Signed Terrie Hubble Title Technical Assistant Date ~, l ~ 1 ~ j
KUP 1 B-15AL1 205-114 Prepareal By Name/Number: Terrie Hubble, 564-4628
Well Number Permit No. / A royal No. Dril-ing Engineer: Aras WorthJngton, 265-6802
INSTRUCTIONS
GeNeRn>_: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in
Alaska.
FrEM ta: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water
Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with
production from each pool completely segregated. Each segregated pool is a completion.
Ireea 4b: TPI (Top of Producing Interval).
Frets 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other
spaces on this form and in any attachments.
ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00).
Frets 20: True vertical thickness.
IreM 22: Attached supplemental records for this welt should show the details of any multiple stage cementing and the location of the
cementing tool.
Frees 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in
item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval).
ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or
Other (explain).
Frets 27: If no cores taken, indicate "None".
ITEM 29: List all test information. If none, state "None".
Form 10-407 Revised 12/2003 Submit Original Only
LJ
BP EXPLORATION
Operations Summary Report
Page 1 of 18
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALIS TA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To .Hours Task II Code NPT Phase '~ Description of Operations
9/22/2005 10:00 - 18:00 8.00 MOB P PRE Move rig off 1 D-34. Move down Spine Road to 1 B Pad. Move
rig over well and set down
18:00 - 21:00 3.00 RIGU P PRE Accept rig for operations at 1800 hrs 9/22/05
ND tree cap. NU BOPE. Install 10' lub
21:00 - 23:15 2.25 BOPSU P PRE Initial BOPE test 4000/250. Witness waived by AOGCC
23:15 - 23:45 0.50 BOPSU P PRE
23:45 - 00:00 0.25 BOPSU P PRE
9/23/2005 00:00 - 03:45 3.75 BOPSU P PRE
03:45 - 05:15 1.50 RIGU P PRE
05:15 - 06:30 1.25 RIGU P PRE
06:30 - 07:15 0.75 RIGU P PRE
07:15 - 11:00
11:00 - 13:00
3.75 RIGU P
2.00 STWHIP P
PRE
WEXIT
13:00 - 13:30
13:30 - 15:00
15:00 - 15:30
15:30 - 18:00
18:00 - 20:00
20:00 - 22:00
22:00 - 23:15
0.50 STWHIP P
1.50 STWHIP P
0.50 STWHIP P
2.50 STWHIP P
2.00 STWHIP P
2.00 STWHIP P
1.25 STWHIP P
23:15 - 23:30 I 0.251 STWHIPI P
23:30 - 00:00 0.50 STWHIP P
9/24/2005 00:00 - 01:00 1.00 STWHIP P
01:00 - 02:20 1.33 STWHIP P
02:20 - 04:00 1.67 STWHIP P
04:00 - 05:10 1.17 STWHIP P
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
WEXIT
Load new 2" CT reel into reelhouse. Set TL shack and camp.
Set other misc buildings and cuttings box
Prespud mtg given by Aras Worthington
Resume BOPE test
Finish BOPE test. Prep reel. APC build berm and set tiger
tank
PT grapple connector. Pull CT to floor and stab. Replace
packoff. Stab onto lub
Fill CT w/ FW
Hold pre spud meeting with day crew and A. Worthington.
Review well plan and general KRU CTD performance issues.
Hold HSE discussion regarding brown bear do's and don'ts.
Good group participation.
Install Kendall coil connector. Pressure and pull test same.
MU e-coil head. Test same.
Review SSSV panel with DSO. Open sssv and monitor whp.
22 psi. Bleed same. Slowly bled off to zero. Monitor well.
Complete upright tank berm.
MU clean out BHA (2.74" D331 mill on straight mtr). Stab coil.
Get on well. Test mwd.
Run in hole to 230'.: Open EDC. Forward circulate to pump
e-line slack forward. Continue to run in hole. Circ at min rate.
IA/OA/PVT: 1/0/275 bbls.
Open sssv. No increase in whp. Continue in hole displacing
coil & well to 8.6 ppg used flo pro mud.
Circulate btms up. Take rtns to tiger tank.
Pull out of hole. Continue to circulate following whp schedule.
Close TRSSSV
LD cleanout assy. Test MWD tools and found short. MU MWD
assy to WS PVT 321
RIH w/ BHA #2 at 80'/min. Open EDC. Circ 0.35/1260 holding
400 psi bp. Open TRSSSV
Log GR tie-in down from 8200' to 8360' CTD. PUH 19.5k to
8300' and park while compare logs, corr -11' to PDC GR at
8192'. Close EDC
RIH from 8289' to 8365'. PUH to set depth 22.2k and park at
40R. Start pump at 0.5 bpm and tool stroked before 2920 psi
(losing str wt). Stack 3.5k. PUH pumping at 0.5 bpm 3300 psi
19.5k. Left WS at 40R w/ top at 8336', bottom at 8345' (for
now). RA pip at 8341.7'. Open EDC
POOH following pressure schedule
Fin POOH w/ WS setting assy. Close TRSSSV PVT 307
LD WS setting assy and load out. LD MWD tools and
reconfigure. MU milling assy
RIH w/ BHA #3. Open EDC and circ 0.3/1300 following
pressure schedule. Open TRSSSV. Close EDC at 8200'.
PVT 323 RIH at 0.53/1700 and first MW at 8343.8'
PUH 23.5k, start motor 1.64/1.41/3400 w/ 11.25 ECD. RIH to
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION
Operations Summary Report
Page 2 of 18
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date- From - To Hours Task Code NPT
Phase Description of Operations
9/24/2005 ~ 04:00 - 05:10 ~ 1.17 ~ STW HI P P ~ ~ W EXIT first MW at 8343.4' and flag. Corr to 8336'. Got 0.15' too quick
05:10-08:00 2.83 STWHIP P WEXIT
08:00-09:30 1.50 STWHIP N DFAL WEXIT
09:30 - 11:00 1.50 STWHIP N DFAL WEXIT
11:00 - 11:45 0.75 STWHIP N DFAL WEXIT
11:45 - 13:00 1.25 STWHIP N DFAL WEXIT
13:00-13:45 0.75 STWHIP N DFAL WEXIT
13:45 - 15:30 1.75 STWHIP N DFAL WEXIT
15:30-18:45 3.25 STWHIP P WEXIT
18:45-20:10 I 1.421 STWHIPIP I (WEXIT
20:10-22:00 I 1.831 STWHIPIP I (WEXIT
22:00-23:30 I 1.501 STWHIPIP I (WEXIT
23:30-00:00 I 0.501 STWHIPIP I (WEXIT
9/25/2005 00:00 - 01:00 1.00 DRILL P PROD1
01:00 - 02:40 1.67 DRILL P PROD1
02:40 - 03:15 ~ 0.58 ~ DRILL ~ P ~ ~ PROD1
03:15 - 04:05 0.83 DRILL N DFAL PROD1
04:05 - 05:20 1.25 DRILL P PROD1
05:20 - 06:15 I 0.921 DRILL I P I I PROD1
06:15 - 12:00 I 5.751 DRILL I P I I PROD1
and stalled. Start over and mill to 8337
Mill window from 8337' 1.65/1.50/3400 w/ 11.21 ECD w/ 100
psi dill 2.5k wob
Mill window from 8339'. Taking a lot of DHWOB to mill:
4k-5k#. Not much motor work.
Pullout of hole maintaining whp. Close sssv. Pull to surface.
Flow check well. LD BHA #2 (window milling assy). Mill &
reamer recovered, but something failed inside Weatherford
motor. Mill indicates centerline of 3-1/2" crossed. Mill still in
good condition.
Unable to determine what failed in Weatherford motor.
Discuss and decide to go with Baker mtr until Weatherford
problem is addressed.
Call for Baker 2-3/8" extreme motor.
MU BHA #4 (Baker mtr w/ 2.74" DSM window mill). Stab coil.
Test mwd. Get on well.
RIH. Pressure well. Open sssv. Continue to run in hole.
Mill ahead from 8340'. 3650 psi fs @ 1.5 in. 50-100 dpsi.
DHWOB: 1.5k# to 3.Ok#. WHP/BHP/ECD: 25/3650/11.29 ppg.
Appear to break out into formation at 8342.6' with loss of string
wt, dill and increase in return loss rate
Drill rathole from 8342.6' 1.51/1.15/3600 w/ 200 psi dift 1.5-3.5k
wob ECD 11.52 to 8352'
Backream and ream window until clean 1.5/1.21/3400. Dry
drift, clean PVT 318
POOH for build assy circ 1.5/3200 thru mill. Close TRSSSV
PVT 288
LD and load out milling assy. WM was 2.73" no-go and had
outside wear
Fire drill
MU build assy
RIH w/ BHA #5 (2.2 deg motor, bi bit). Circ thru open EDC
0.5/1320 w/ 200 psi bp. Open TRSSSV
Log tie-in down from 8190', Corr -12'. Close EDC, RIH and tag
at min rate at 8356'. PUH and start pump 1.6/1.3/3500, bleed
off 200 psi whp PVT 306 Work with orientor stops
Attempt to drill from 8356' 1.54/1.30/3350/408 w/ 100 psi dill,
0.5-1.5k wob at 11.5 ECD (3715 psi dhp). Work with orientor
stops, then couldn't get orientor to move. PUH thru window,
clean. Determine that when the orientor is in contact w/ the
WS the internal magnetometers go hay-wire. This isa BHl
'lessons learned' that catches all the new DD's since it is not
documented, but only passed on verbally. It will be
documented now .. .
Drill from 8356' 1.58/1.40/3500/458 w/ 200-500 psi dill, 2.5-5k
wob at 11.6 ECD
Drill from 8382' 1.58/1.40/3500/458 w/ 300-600 psi dill, 3-6k
wob at 11.5 ECD
Drill ahead from 8400'. 3550 psi fs @ 1.157 in/1.27 out. DPSI:
100-200. DHWOB: 3-6k#. WHP/BHP/EDC? 22/3730/11.48
ppg. IA/OA/PVT: 411/10/272 bbls.
ROP varying from 10 to 30 fph.
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION Page 3 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To 'I Hours Task Code ~I NPT Phase I Description of Operations
9/25/2005 12:00 - 13:45 1.751 DRILL P PROD1 Drill ahead from 8503'. INC/AZMlfF: 58.1/274.2/158. PVT
13:45 - 15:30 I 1.751 DRILL I P
15:30 - 16:30 I 1.001 DRILL I P
16:30 - 18:15 1.75 DRILL P
18:15 - 18:50 0.58 DRILL P
18:50 - 19:20 I 0.501 DRILL I P
19:20 - 22:40 3.33 DRILL P
22:40 - 23:05 0.42 DRILL P
23:05 - 00:00 0.92 DRILL P
9/26/2005 00:00 - 02:25 2.42 DRILL P
02:25 - 03:00 0.58 DRILL P
03:00 - 05:45 2.75 DRILL P
05:45 - 09:30 I 3.751 DRILL I P
09:30 - 10:10 0.67 DRILL P
10:10 - 13:45 3.58 DRILL P
13:45 - 14:30 0.75 DRILL P
14:30 - 19:20 4.83 DRILL P
19:20 - 20:20 1.00 DRILL P
20:20 - 00:00 3.67 DRILL P
9/27/2005 00:00 - 01:30 1.50 DRILL P
01:30 - 02:10 0.67 DRILL P
02:10 - 02:20 0.17 DRILL P
02:20 - 03:00 0.67 DRILL P
PROD1
PROD1
I
~ PROD1
i
PROD1
PROD1
PROD1
PROD1
PROD1
PRODi
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
229 bbls.
Complete /land build section at 8560'.
Pull out of hole following whp/bhp schedule to maintain a
minimum of 11.2 ppg on B2 and B2 shales. Shut in sssv with
750 psi whp. Continue to surface.
At surface. Get off well. Unstab coil.
LD BHA # 5. MU BHA # 6 (0.8 deg mtr w/ Hyc bicenter).
Stab coil. Test mwd. Get on well.
RIH w/ BHA #6 circ thru EDC 0.3/1200 following pressure
schedule. Open SSSV
Log tie-in down from 8210', corr -9'. Close EDC. RIH 0.3/1900
w/ 400 psi whp thru window, clean. Log tie-in down from 8354'
to tie-in RA tag to 'mother'. See RA pip at 8346'. Therefore
TOWS/TOW is 8340', BOW is 8347'. Wiper to TD 1.5/3400
Set down at 8414' several times. Ream thru at
1.35/1.32/3250/DTF w/ 11.85 ECD and precautionary ream to
TD w/ MW and wt loss at 8541'. Tag TD at 8560'
Drill from 8560' 1.5/1.3/3500/908 w/ 200-500 psi dill, 2-4k wob
w/ 11.85 ECD at 93 deg
Wiper to window, clean both ways
Drill from 8700' 1.55/1.47/3600/908 w/ 300-500 psi dill, 2-5k
wob w/ 11.94 ECD at 93 deg
Continue drilling from 8754' 1'.55/1.49/3560/908 w/ 400-600 psi
dill 2-5k wob at 12.0 ECD. Swap to left side at 8800'
Wiper to window, clean both ways PVT 442
Drill from 8850' 1.53/1.44/3580/90L w/ 200-500 psi, 2-4k wob
w/ 12.0 ECD at 94 deg. Start getting into ankerite at 8890' and
slower drilling
Drill ahead from 8920'. 3650 psi fs @ 1.60 in/1.50 out. DPSI:
250-350 DHW06:3.0-5.Ok# WHP/BHP/EDC: 44/3942/11.98
ppg IA/OA/PVT: 668/192/418 bbls INC/AZM/TF:
93.8/299.0/90L.
Continued slow drilling in ankerite streak in A sand: 10-15 fph.
Get out of ankerite at 8950'. ROP: 30-50 fph.
Wiper trip to window. Log gr across RA tag. Add 4' correction.
Continue wiper trip in hole. Hole smooth.
Drill ahead from 9012'. 3600 psi fs @ 1.61 in/1.54 out. PVT:
401 bbls.
W iper trip to window. Hole smooth both in and out.
Drill ahead from 9162'. 3750 psi fs @ 1.63 in/1.54 out. PVT:
368 bbls. ROP: 35-50 fph. DHWOB: 2.0 - 3.Ok#.
WHP/BHP/ECD: 29/4010/12.23 ppg. Back in ankerite at 9270'.
Drill to 9300' and swap to right side
Wiper to window, clean both ways PVT 362
Drill from 9300' in and out of ankerite 1.56/1.5/3700/1058 w/
200-600 psi dill, 2.5-4.Ok wob w/ 11.93 ECD at 87 deg 6337'
TVD
Drill from 9410' 1.6/1.54/3780/1358 w/ 100-400 psi dill, 1-4k
wob w/ 12.2 ECD at 89 deg at 6350' TVD
Wiper to window, clean
Log tie-in down from 8360', corr +4'
Wiper back to TD, clean PVT 368
Printed: 10/17/2005 7:36:41 AM
C.
BP EXPLORATION
Operations Summary Report
Legal Well Name:
Common Well Name
Event Name:
Contractor Name:
Rig Name:
1 B-15A
1 B-15A
DRILL+COMPLETE
NORDIC CALISTA
NORDIC 2
Date 'From - To Hours Task Code ' NPT
,_- - - '-
9/27/2005 103:00 - 05:15 ~ 2.25 ~ DRILL ~ P
05:15 - 06:45 1.50 DRILL P
06:45 - 10:45 4.00 DRILL P
10:45 - 11:45 I 1.001 DRILL I P
11:45 - 12:20 I 0.581 DRILL I P
12:20 - 14:30 I 2.171 DRILL I P
14:30 - 15:30 I 1.001 DRILL I P
15:30 - 15:45 0.25 CASE P
15:45 - 19:00 3.25 CASE P
19:00 - 20:50 I 1.831 CASE I P
20:50 - 21:10 0.33 CASE P
21:10 - 21:25 0.25 CASE P
21:25 - 22:45 1.33 CASE P
22:45 - 23:00 0.25 CASE P
23:00 - 00:00 1.00 DRILL P
9/28/2005 00:00 - 00:20 0.33 STWHIP P
00:20 - 02:15 1.92 STWHIP P
02:15 - 02:35 0.33 STWHIP P
02:35 - 02:55 0.33 STWHIP P
02:55 - 04:25 1.50 STWHIP P
04:25 - 04:35 O.i7 STWHIP P
04:35 - 06:00 1.42 STWHIP P
06:00 - 07:35 I 1.581 STWHIPI P
07:35 - 11:00 I 3.421 STWHIPI P
Page 4 of 18
Spud Date: 9/5/2005
Start: 9/22/2005 End: 10/15/2005
Rig Release:
Rig Number:
Phase Description of Operations
PROD1 Drill from 9450' 1.6/1.55/3780/1058 w/ 100-300 psi dill,
1.5-3.5k wob w/ 12.25 ECD at 85 deg at 6351' TVD PVT 361
PRODi Wiper to window. Hole smooth in and out.
PROD1 Drill ahead from 9600'. 3800 psi fs @ 1.61 in/1.53 out. DPSI:
100-200 DHWOB: 1.5 - 2.5k# WHP/BHP/ECD:
44/4060/12.30 ppg IA/OA/PVT: 258/212/354 bbls
INC/AZM/TF: 88.68/291.3/55L. ROP: 35-55 fph.
Drill into a high gr formation (160 api +) at 9698'. Call TD at
9725'.
PROD1 Wiper trip to window. Log gr tie in across RA. Add 6'
correction. TD corrected to 9731'.
PROD1 Run in hole. Start 80 bbl 8.9 ppg new flopro pill with max tubes
and 3 ppb coarse Alpine beads down coil.
PROD1 Wiper trip from 9700'. Pull out of hole laying in bead pill. 2600
psi @ 1.06 in. Pull at 33 fpm. Slow rate to 0.3 bpm through
window. Continue to POOH and lay in bead pill at 1.12 bpm
and 35 fpm coil speed. Bead pill top at +/-6700'.
Paint EOP flags at 8200' and 6700'. Continue circulating out of
hole.
Close sssv with 750 psi on well. Circulate to surface.
PROD1 At surface. Monitor well during PJSM to review handling BHA.
Get off well. Unstab coil. LD lateral drilling assy.
RUNPRD Safety mfg re: liner
RUNPRD MU 38 slotted and 5 solid jts 2-3/8" 4.6# L-80 STL R2 liner w/
Unique Indexing Guide Shoe and O-ring sub. MU BBT GS
assy
MU BHI MWD assy
RUNPRD Pressure well to 700 psi. Open SSSV bled down to 300psi. RIH
with 2-3/8" liner. Weight check at window 19.5k up 9.2 dwn
RUNPRD Log GR tie in from 8173' -12' correction
RUNPRD RIH to 9700'. Bring pump up to 1.2bpm. Pick-up and dropped
off liner placing top at 8334'. Up wt 15.5k Open EDC
RUNPRD TOH to surface. Trap 300psi on well and shut SSSV.
RUNPRD PJSM reveiw BHA changes.
PROD1 Bleed off WHP and insure SSSV is closed. Setback injector.
LD BTT and BHI tools.
PU BHI orienter and Weatherford LSX Whipstock and Fury
setting tool. Align toolfaces. 3 PIP tags have been installed
5.69' from top of WS
WEXIT PU and stab injector.
WEXIT RIH to 8220'
WEXIT Log tie-in -13' correction.
WEXIT RIH to 8297' putting top of WS at 8288'. With EDC closed bring
on pump build pressure to 3750psi shearing setting tool same
time setdown 3-4k. PU clean to 8265' open EDC.
WEXIT TOH stop at 200' close EDC close SSSV. Tag up.
WEXIT PJSM. Review BHA changes.
WEXIT LD Weatherford tools and BHI orienter. PU BTT motor and
2.74" window and string mill assembly.
WEXIT RIH w/ BHA #9 0.3/1300 following pressure schedule after
open TRSSV. Tag WS at 8299' at min rate PVT 391
WEXIT Start motor 1.5/1.5/3840 and RIH to first MW at 8299.7'. Corr
to 8288' and flag. Mill window from 8288' 1.52/1.52/3750 w/
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION
Operations Summary Report
Page 5 of 18
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date
From - To 'Task Code
Hours
NPT
~ Phase i Description of Operations
-
_
9/28/2005
07:35 - 11:00
3.42 -
STWHIP
P _
WEXIT __ _ _ - _.
100-200 psi diff 1-3k wob w/ 11.9 ECD PVT 390
11:00 - 14:30 3.50 STWHIP P WEXIT Mill from 8292' 1.52/1.52/3600 w/ 100-200 psi diff, 1-3k wob w/
11.9 ECD. Stall at 8295.6' and assume bottom of window
14:30 - 15:30 1.00 STWHIP P WEXIT Mill/dress BOW then drill OH from 8295.6' 1.5/1.5/3520 to
8303'
15:30 - 16:10 0.67 STWHIP P WEXIT Backream and ream window clean, dry tag PVT 390
16:10 - 17:30 1.33 STWHIP P WEXIT POH following pressure schedule. Close TRSSSV w/ 650 psi
PVT 360
17:30 - 18:00 0.50 STWHIP P WEXIT LD and load out milling assy. Window mills gauged 2.74" go
2.73" no-go
18:00 - 22:30 4.50 DRILL P PROD2 Cut-off CTC. Perform slack management. Cut-off 90 coil.
Behead Kendal connector pul{ test to 38k. Behead with BH1
upper quick connect. PT to 4000psi.
22:30 - 23:20 0.83 DRILL P PROD2 PU BHA #10
23:20 -00:00 0.67 DRILL P PROD2 RIH following pressure schedule
9/29/2005 00:00 - 01:25 1.42 DRILL P PROD2 TIH w/ BHA #10
01:25 - 01:40 0.25 DRILL P PROD2 Log tie-in -13' correction.
01:40 - 01:50 0.17 DRILL P PROD2 RIH through window. No problems
01:50 - 06:00 4.17 DRILL P PROD2 Directionally drill ahead f/ 8303' with L2 build section.
1.54/1.54 FS= 3550psi Ann= 3836 ECD= 11.94 2-300psi
motorwork 15-20'/hr PVT 391
06:00 - 11:00 5.00 DRILL P PROD2 Continue drilling with slow penetration in B Shales at 60-09L to
8430'
11:00 - 12:00 1.00 DRILL P PROD2 Increase in penetration rate from 8430', but also more stalls.
Drill to 8453'
12:00 - 12:15 0.25 DRILL P PROD2 Wiper to window
12:15 - 16:15 4.00 DRILL P PROD2 Drill from 8453' 1.55/1.55/3600/ 75L w/ 200-400 psi diff, 2-5.5k
wob w/ 11.95 ECD at 62 deg
16:15 - 17:00 0.75 DRILL P PROD2 Drill from 8500' 1.55/1.55/3640/158 w/ 200-400 psi diff,
1.5-4.Ok wob w/ 12.0 ECD at 66 deg and finally get in sand
(and higher penetration rate) at 8510' and land build at 8535'
17:00 - 17:15 0.25 DRILL P PROD2 Wiper to window, clean
17:15 - 18:30 1.25 DRILL P PROD2 POOH for lateral assy following pressure schedule
18:30 - 20:00 1.50 DRILL P PROD2 Check torque on BHI tools coming out. LD 2.6deg motor PU
.8deg motor and new bicenter bit. Sevice lower quick connect.
20:00 - 22:00 2.00 DRILL P PROD2 Pressure well to 700psi and open TRSSSV. RIH to 8192'. No
problem seen at 8085'.
22:00 - 22:15 0.25 DRILL P PROD2 Log tie-in -13' continue logging past PIP tags installed in
whipstock. Confirm window depths as follows: TOW 8289' (Pip
tag 8295') BOW 8296'
22:15 - 22:30 0.25 DRILL P PROD2 RIH to bottom.
22:30 - 00:00 1.50 DRILL P PROD2 Directionally drill ahead f/ 8535' to 8625'. 1.52/1.52bpm
freespin 3500psi 3-400psi motonvork. On bottom annular
pressure 3919psi ECD 11.9 2-3k wob 50-60'/hr
9/30/2005 00:00 - 00:55 0.92 DRILL P PROD2 Directionally drill ahead f/ 8625' to 8685'. 1.52 / 1.52 fs=3500
mw= 3-400 wob= 2k 50'/hr ann= 3900
00:55 - 01:20 0.42 DRILL P PROD2 Wiper trip to window. No problems.
01:20 - 02:00 0.67 DRILL P PROD2 Drilling ahead f/ 8685' to 8700' and hit Ankorite striner.
02:00 - 03:05 1.08 DRILL P PROD2 Drilling on Ankorite. 1:521 1.52 fs=3500 mw=80 wob= 4k
10'/hr
03:05 - 04:00 0.92 DRILL P PROD2 Drilling ahead f/ 8715' 1.52/1.52 fs=3500 mw=2-300 wob=1-2k
60'/hr ann=3923 ecd=11.93
04:00 - 06:00 2.00 DRILL P PROD2 Drilling on Ankorite 8775' @ 0600hrs
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION
Operations Summary Report
Legal Weli Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date From - To
9/30/2005 06:00 - 09:00
1 B-15A
1 B-15A
DRILL+COMPLETE
NORDIC CALISTA
NORDIC 2
Hours Task ~ Code NPT
1 _ ~ -
3.001 DRILL P
09:00 - 09:35 I 0.58 DRILL P
09:35 - 10:40 1.08 DRILL P
10:40 - 13:30 ~ 2.831 DRILL P
13:30 - 15:50 ! 2.331 DRILL I P
15:50 - 17:30
17:30 - 23:30
23:30 - 00:00
10/1/2005 00:00 - 06:00
06:00 - 07:00
07:00 - 07:50
1.671 DRILL I P
Start: 9/22/2005
Rig Release:
Rig Number:
Phase
PROD2
PROD2
PROD2
PROD2
PROD2
PROD2
6.001 DRILL I N I DPRB I PROD2
0.501 DRILL I P I I PROD2
6.001 DRILL I P I I PROD2
1.001 DRILL 1 P f 1 PROD2
0.831 DRILL I P I I PROD2
07:50 - 10:00
10:00 - 11:15
11:15 - 13:30
2.171 DRILL I P I I PROD2
1.251 DRILL I P I I PROD2
2.251 STKOH P PROD2
Page 6 of 18
Spud Date: 9/5/2005
End: 10/15/2005
Description of Operations
Drill from 8775' 1.5(1.5/3520/110L w/ 100-400 psi diff, 1.5-3.5k
wob w/ 11.9 ECD at 80 deg in shale at 15'/hr
Start new mud and drill from 8828' 1.5/1.5/3520/165L w/
100-400 psi diff, 1.5-3.5k wob w/ 11.9 ECD at 76 deg
Wiper to window w/ fresh mud at bit. Minor overpull and MW at
8440'. On RIH had set down and stall at 8415' w/ HS TF.
Orient to DTF (SOL) and set down at 8440'. Backream to
8390'. Ream w/ DTF to 8480' at 1.0 bpm. Continue wiper and
had set down and MW at 8760', 8790', 8766' and 8815'
Drill from tag at 8839' 1.53/1.53/3800/110L w/ 100-300 psi diff,
2-4k wob at 11.80 ECD at 75 deg at i 5'/hr and still in shale
Drill from 8900' 1.45/1.45/3740/50L w/ 100-350 psi diff, 2-4k
wob at 11.84 ECD at 70 deg at 6390' TVD at 25'/hr
At 8945' perform a BHA length wiper due to slower penetration
rate. GR showed Miluveach top later at 8926'. Continue
drilling 1.43/1.43/3550/30L w/ 100-250 psi diff, 3-5k wob at 11.7
ECD at 70 deg at 6405' TVD at 15'/hr in the Miluveach
At 8970' perform a 100' wiper, but could not go back down past
8935'. Wiper to window. Problems washing down through build
section. Maintaining constant BHP ECD 11.8ppg. RIH slow
<20'/min following as drilled TF's okay to 8770 seeing MW to
8780' pick-up 22.7k work back okay RIH slow to 8880' stacking
wt. work area back to 8730' RIH 1.50bpm 35'/min tag 8812'
stalled motor. PU 6k over. RIH to 8814 stacking, PU 14k over.
W/R slowly 12'/hr wo MW (alerted town group of problems and
possible sidetrack considerations) Increase WHP from 0 to
300 psi. ECD 12.6ppg work down to 8850', increase WHP to
400psi. Work down to to 8880' and cleared up. W/R to 8935
(Miluveach Sh) and tagged. Work down maintaining 400psi
WHP to 8967'. 3' difference from previous TD.
Directionally drill ahead f/ 8967' 1.44 / 1.44 fs= 3900psi
mw=50psi ann=4344 ecd=13.07ppg holding 400psi at surface.
2-3k wob <10'/hr
Directionally drilling ahead in Miluveach Sh f/ 8973' 1.45 / 1.45
fs=3925 mw=100psi ann=4367 ecd=12.93 (holding 400psi at
surface) wob= 3-4k rop= 10-15'/hr
Drill from 9040' 1.45/1.45/3800/350/60L w/ 100-200 psi diff, 4k
wob w/ 12.8 ECD at 15'/hr in the Miluveach PVT 327
Perform 100' wiper w/ 400 psi bp. Choke and out MM started
plugging off w/ shale. Choke cycling between i00 and 1400
psi. Overpulls to 5k and high MW to 8780'. Continue wiper to
window while using manual choke and cleaning return lines.
Shaker had a steady stream of shale peices as large as 3/8"
Pull thru window, clean at min rate. Continue to plug off choke.
Bypass 'out' MM. POOH circ thru bit at 1.5 bpm w/ 500 psi by
and plug off occasionally while POOH (at reduced speed of
50'/min). Pull to surface, do in/out jog to 500' w/ no additional
solids other than those from the possum belly, POOH, close
TRSSSV
LD drilling BHA. MU sidetrack BHA
Function test BOP rams
RIH w/ BHA #12 (R60ST bit on 1.7 deg motor) circ thru EDC
0.3/1300 following pressure schedule. Open TRSSSV
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION Page 7 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common W ell Name: 1 B-15A Spud Date: 9/5/2005
Event Nam e: DRILL+C OMPLE TE Start : 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALIST A Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To ~ Hours ' Task Code NPT Phase ', Description of Operations
10/1/2005 13:30 - 13:45
0.25
STKOH
P
PROD2
Log tie-in down from 8310'/ corr -10'
13:45 - 14:00 0.25 STKOH P PROD2 Wiper to TD 1.0 bpm @ 15'/min w/ 200 psi by with one
setdown at 8410' and see brass cap get shucked PVT 313
14:00 - 15:45 1.75 STKOH P PROD2 Trough 8510-8525' 1.53/1.53/3540/140L w/ 11.78 ECD
15:45 - 16:15 0.50 STKOH P PROD2 Begin kickoff at 0.1'/min from 8525' at 135E
16:15 - 21:30 5.25 STKOH P PROD2 At 8533' see NB incl at 8517' show 2 deg loss so move TF to
90L and start drilling at 25'/hr while gradually bring TF to HS.
Drilled to 8620'md 6365'tvd. (Projected dev at bit 96deg. Plan
to level off to 90deg at 8800' )
21:30 - 22:00 0.50 STKOH P PROD2 Backream sidetrack.
22:00 - 00:00 2.00 STKOH P PROD2 TOH following pressure schedule.
10/2/2005 00:00 - 00:30 0.50 STKOH P PROD2 Close TRSSSV trapping 500psi on well. Pull to surface then
RIH to 300' and circulate trapped cuttings around BHA.
00:30 - Of :00 0.50 STKOH P PROD2 L/D sidetrack BHA.
01:00 - 02:00 1.00 STKOH P PROD2 Flush all surface and BOP stack lines of trapped shale.
02:00 - 02:15 0.25 DRILL P PROD2 PJSM review procedures for cutting coil.
02:15 - 03:30 1.25 DRILL P PROD2 Cut off BHI UOC. Pump slack management. Cut 650' of coil
due to fatigue.
03:30 - 06:00 2.50 DRILL P PROD2 Dress end of coil and install new Kendal CTC. Pull test to 35k
and PT to 4000psi. Start reheading BHI UOC.
06:00 - 08:30 2.50 DRILL N SFAL PROD2 Test a-line continuity and found short somewhere. Track it to
BHI Jupitor connector-solder had failed. Resolder and test
08`.30 - 09:00. 0.50 DRILL P PROD2 Pump slack forward
09:00 - 09:15 0.25 DRILL P PROD2 MU lateral assy
09:15 - 10:50 1.58 DRILL P PROD2 RIH w/ BHA #13 (used Hyc bi bit, 0.8 deg motor) circ thru bit
0.3/1700 following pressure schedule. Open TRSSSV
10:50 - 11:05 0.25 DRILL P PROD2 Log tie-in down from 8310', corr -12'
11:05 - 11:20 0.25 DRILL P PROD2 RIH 15'/min 1.0/2300 w/ 200 psi by w/ one set down at 8410'.
RIH thru sidetrack area at 135E clean to 8550'. PUH
11:20 - 12:00 0.67 DRILL P PROD2 Log tie-in down 0.6/1300 w/ 400 psi by from 8510' to 8590' and
stacking wt
12:00 - 15:00 3.00 DRILL P PROD2 Ream/redrill tite hole from 8590'-TD 1.5/1.5/3520/DTF w/ 11.8
ECD. Get to sidetrack TD of 8620' and stacking wt. Attempt to
PUH and were BHA stuck. Work pipe several times and came
free at 51 k (30k over). Wiper back up hole to 8550'.
Ream/redrill from stall at 8560' 1'/min. Several stalls at 8578',
then notice ECD is 14.0 ppg w/ open choke, but full returns and
no loss. Ream in hole at 5'/min from 8560' to 8617' w/ no
problem except stacking near the end. Wiper back up hole and
10k overpulls and MW to 8560'. Assume problem w/ BHA
(motor)
15:00 - 15:15 0.25 DRILL P PROD2 Wiper thru sidetrack point and window was clean
15:15 - 16:50 1.58 DRILL P PROD2 Open EDC. POOH following pressure schedule
16:50 - 17:40 0.83 DRILL P PROD2 LD lateral assy. PT CTC, okay. FW PT MWD assy. Motor
was tite and bit okay, but change both anyway
17:40 - 18:45 1.08 DRILL P PROD2 MU BHA #14
18:45 - 20:20 1.58 DRILL P PROD2 TIH open TRSSSV with 500psi assist TIH 8345' following
pressure schedule.
20:20 - 20:30 0.17 DRILL P PROD2 Log tie-in -13' correction.
20:30 - 20:50 0.33 DRILL P PROD2 TIH past OHST wo problems at reduced pump rate. Inc rate
1.55/1.55 fs= 3320psi ecd= 11.8 ann= 3882. Stall at 8560'.
20:50 - 22:45 1.92 DRILL P PROD2 Backream to 8530' ream to 8569' stalled. Reduce pump rate to
1.Obpm RIH to 8580' backream to 8560'. Work this area.
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION Page 8 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPL ETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date ~ From - To Hours ~'I Task Code' NPT Phase ', Description of Operations
10/2/2005 20:50 - 22:45 1.92 DRILL P PROD2 Continue ream/backreaming .5'/min to 8620'. Backreamed to
8540 then reamed back to TD.
22:45 - 00:00 1.25 DRILL P PROD2 Directionally drill ahead. 1.50/1.50 fs= 3300 ann= 3880 ecd=
11.75 2-3k wob 10'/hr
10/3/2005 00:00 -04:25 4.42 DRILL P PROD2 Continue drilling ahead f/ 8640'. 1.5 / 1.5 fs/3300 mw/2-300
04:25 - 05:00 I 0.581 DRILL I P I I PROD2
05:00 - 06:30 1.50 DRILL N SFAL PROD2
06:30 - 10:00 3.50 DRILL N SFAL ' PROD2
10:00 - 10:30 0.50 DRILL N SFAL PROD2
10:30 - 12:00 1.50 DRILL N SFAL PROD2
12:00 - 12:20 0.33 DRILL N SFAL PROD2
12:20 - 13:00 0.67 DRILL N SFAL PROD2
13:00 - 14:00 1.00 DRILL P PROD2
14:00 - 14:30 0.50 DRILL P PROD2
14:30 - 15:25 0.92 DRILL P PROD2
15:25 - 15:45 0.33 DRILL P PROD2
15:45 - 16:25 0.67 DRILL P PROD2
16:25 - 17:15 0.83 DRILL P PROD2
17:15 - 19:00 1.75 DRILL P PROD2
19:00 - 19:45 I 0.75 I DRILL I P I I PROD2
19:45 - 20:30 0.75 DRILL P PROD2
20:30 - 21:00 0.50 DRILL P PROD2
21:00 - 00:00 3.00 DRILL P PROD2
10/4/2005 00:00 - 02:00 2.00 DRILL P PROD2
02:00 - 02:30 0.50 DRILL P PROD2
ann/3910 ecd/11.87 wob/2-3k 20-30'/hr. Problem with
communication to BHI tools.
Wiper trip. up wt 18.5k pulled tight at 8658'. Work down.
Backream to OHST wo problem. Attempting to re-start BHi
tools.Motorwork at 8450' in 'B' shale (8420'-8500') BHi problem
appears to be downhole with Power/Comms sub. Wiper /
backream to window.
TOH for dead BHi tools following pressure schedule.
LD lateral BHA and test tools. Tools tested okay. Found short
in same Jupitor connector (BHI end). Install new connector,
test okay. Then, find fault in SWS end of connector
MU lateral assy PVT 271
RIH w/ BHA #15 (new bi bit, 0.8 deg motor)
Log tie-in down from 8320', Corr 10' PVT 301
Precautionary ream from 8550' to TD 1.54/1.54/3400/DTF w/
11.88 ECD w/ high MW and PU's at 8574', 8582', 8597', 8610',
8643'. Rest of hole was clean
Drill from tag at 8757' 1.54/1.54/3440/80-100L w/ 150-400 psi
diff, 0.5-2.5k wob w/ 12.0 ECD at 25-45'/hr to 8800' PVT 302
Wiper to 8550' to check for solids in belly and ream belly some
more. Wiper was clean of overpulls, but had MW from
8590-8610'. RBIH and had set downs and MW at 8560' and
8592', but much better than first time thru. Rest of hole was
clean
Drill from 8800' 1.53/1.53/3500/100-170L w/ 200-400 psi diff,
2-4k wob w/ 12.08 ECD at 50-70'/hr to 8850'
Wiper to 8550' to check for solids and ream tite hole again.
Had MW at 8570-90' while PUH, was clean RIH!
Drill from 8850' 1.53/1.53/3520/100L w/ 200-400 psi, 2-3.5k
wob w/ 12.14 ECD at 60-80'/hr to 8900' PVT 302
Wiper to window w/ MW at 8590'. RIH had set down at 8600',
rest of hole was clean
Drill from 8900' 1.53/1.53/3520/80L w/ 200-400 psi, 2-3.5k wob
w/ 12.12 ECD at 80-100'/hr. Drilled across fault at 8970-80
area. Drilled to 9014'.
Wiper trip. Overpulls at 8590-8570'. Pull into tbg. Called town
to figure out plan forward. Intially wanted to drop 40'tvd within
100' md. Not possible. Recalled town. Waiting on call back
WOO. Plan is to drill ahead drop 5' tvd looking for sand and
then leveling off. If no sand re-evaluate situation.
Wiper back in. Clean..
Directionall drill ahead f/ 9014' (6342'tvd) 1.52/1.53 fs= 3500
mw= 2-300 ann= 3985 ecd= 12.12 wob= 2-3k 50-70'/hr
dropping angle .Drilled to 9105' (6345'tvd)
Continue directionally drill f/ 9105' 1.5/1.5 fs=3450 mw= 2-300
ecd= 12.1 wob=2k 30'/hr Drill to 9165'.
Wiper trip back to 8310'. Clean pu of bottom, 5k overpulls
8620'-8570'.
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION Page 9 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date i~ From - To Hours I' Task I Code NPT ! Phase I~ Description of Operations
10/4/2005 02:30 - 03:00 0.50 DRILL P PROD2 Log tie-in +11' (missed on 1st try)
03:00 - 03:45 0.75 DRILL P PROD2 Wiper in hole. Setdown at 8430', 9088' then good to bottom.
03:45 - 06:00 2.25 DRILL P PROD2 Directionally drill ahead 1.50 / 1.50 fs= 3520 mw= 2-300 ecd=
12.3 wob= 2-3k. (Town group agrees we've crossed the major
fault at+/- 8970' and are now in the 'B' shale. Plan forward is to
drop angle to 75-78deg. Will revise as 'B' sh markers are
seen.)
06:00 - 08:50 2.83 DRILL P PROD2 See a marker at 9195' and slow down drop rate and move TF
to 908 at 9240'. Drill 1.54/1.54/3580/908 w! 200-400 psi dill,
2-4k wob at 12.3 ECD 78 deg at 6360' TVD Drill to 9300' PVT
302
08:50 - 09:35 0.75 DRILL P PROD2 Wiper to window. 5k overpulls and MW thru B Sha{e area and
at 8990' (fault). Pulled fife and packed off at 8590'. Couldn't
go down. Backream at reduced rate and cleaned up. Fin wiper
to window, clean
09:35 - 10:45 1.17 DRILL P PROD2 Wiper in hole was clean thru build and OH sidetrack point
1.2/2800 w/ 200 psi by to hold 12.0 ECD. Set down at 8665' w/
TF 90 deg out. Orient around to repostion stops and to get
DTF. RIH, clean until set down at 8990' w/ TF 100 deg out.
8950' is where TF changed from 90L to 908. Work thru this
spot at DTF, then get to 9074' set down. Get to 9100' letdown
and PUH sticky. Wiper back to 8960', clean. Wiper in hole
clean to 9074' set down. Red rate to 0.9 bpm w/ 200 psi by
and make a high speed run to 9150'
10:45 - 11:05 0.33 DRILL P PROD2 Sticky back to 9100'. PUH to 9050'. Make a high speed run to
9210', then PUH sticky to 9160'. RIH to 9180' and can't get by
and getting real sticky
11:05 - 11:50 0.75 DRILL P PROD2 Wiper 1.513580 w/ 12.1 ECD back to OH sidetrack point w/ MW
and overpulls at 9100', 9088', 9050'. Packed off at 8580' again.
Wipe clean then PUH to 8540'. Wiper back in hole at
0.95/2550/DTF w/ 200 psi by was clean to set down at 9060' w/
TF 90 deg off
11:50 - 12:25 0.58 DRILL P PROD2 RIH thru 9060' clean, then get to 9198', then to 9280'. Wiper
back to 9210' was clean. Wiper back to TD PVT 289
12:25 - 15:40 3.25 DRILL P PROD2 Resume drilling from 9300' 1.52/1.52/3590/1708-160L w/
100-400 psi diff, 2-5k wob w/ 12.3 ECD at 78 deg. Good A6
marker seen at 9358'. Plan to land in A4 pay at +/- 9600'md
6329'tvd. Drilled to 9400'.
15:40 - 16:55 1.25 DRILL P PROD2 Wiper trip to window and tie-in point. PU off btm 18.2k 1.59
bpm 12.1 ecd Overpulls and MW at 9300', 9253', 9126'-9110',
9044' 'mfr stall, then clean through A4 area pulling at 26'/min
1.6/3680 up to 8615 then slowed to 6'/min mw at 8600' pulling
22-26k 2-400psi mw 8600'-8570' pulling fairly clean 2k over but
high mw (belly of well) 1.55/0.80 12.Oecd full returns back at
8544' clean to 8440'. Pull through B sh again with 2-4k over
and 300 mw. Clean to window. PVT 278
16:55 - 17:05 0.17 DRILL P PROD2 Log tie-in +10'
17:05 - 18:50 1.75 DRILL P PROD2 Wiper trip at reduced pump rate .9 holding 280psi on well. Had
to ream back to bottom the last 100'. Pickups slightly heavy at
full pump rate. Able to get back to bottom finally at 0.6 bpm
and 300 psi WHP.
18:50 - 19:00 0.17 DRILL P PROD2 Tag bottom and resume drilling.
19:00 - 19:50 0.83 DRILL P PROD2 Took 2 bbl kick. Held back pressure at surface to circulate kick
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A
Event Name: DRILL+COMPLETE Start: 9/22/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours ~ Task Code
10/4/2005 19:00 - 19:50 0.83 DRILL P
19:50 - 20:40 0.83 DRILL P
20:40 - 00:00
10!5!2005 100:00 - 02:30
02:30 - 03:30
03:30 - 04:20
04:20 - 05:15
05:15 - 07:35
07:35 - 09:35
3.33 DRILL P
2.50 DRILL P
1.00 DRILL P
0.83 DRILL P
0.92 DRILL P
2.33 DRILL P
2.00 DRILL P
09:35 - 11:45
11:45 - 17:15
17:15 - 18:00
18:00 - 21:00
21:00 - 00:00
10/6/2005 00:00 - 01:05
01:05 - 02:05
02:05 - 02:40
2.171 DRILL I P
5.50 DRILL P
0.75 DRILL P
3.00 DRILL P
3.00 DRILL P
1.08 DRILL P
1.00 DRILL P
0.58 DRILL P
NPT I Phase
Page 10 of 18
Spud Date: 9/5/2005
End: 10/15/2005
Description of Operations
PROD2 OOH. Had crude and gas cut mud. Picked up slowly. Density
fell off to 6.6 ppg. Held 550 psi to keep returns 1 for 1.
Circulated until we got out denisty equal to in density.
PROD2 Resume drilling. 1.44/1.45/4200 psi. PVT=275 bbls. Pickup
weight is 17 klbs. Free spin is 4070 psi at 1.44 bpm.
WHP=550 psi. BHP=4720 psi. ECD=14.5 ppg. IAP=390 psi,
OAP=348 psi.
PROD2 Continue drilling ahead with slow ROP. Begin swap to new
mud. Pumping 8.9 ppg mud with 14 Ib Klagard.
PROD2 Continue drilling ahead with very slow ROP. Geo reports we
are in Anchorite, and have another 2' TVD to nibble our way
thru at 77 degs INC. Now holding 750 Ibs on the surface choke
to keep 1 for 1 returns. Any less WHP than that and the well
wants to flow. Drilling at 1.5/1.5/3940 psi, with new mud all the
way around. WHP = 750 psi. BHP=4590 psi, ECD=13.82 ppg.
A noticable decrease in BHP since we swapped to new mud.
PROD2 Broke thru the Anchorite. ROP now 80 fph.
PROD2 Wiper trip to the window. Clean PU off bottom at 18 klbs. One
overpull at 9180'. Ratty from 9090' to 9040' with motor work
and heavy overpulls. Ratty from 8990'-8950. Overpulls
8580'-8530'.
PROD2 Continue back in the hole on the wiper trip. Maintaining 4530
psi BHP. Pumping at a reduced pump rate of 0.9 bpm. No
problems running back to bottom!
PROD2 Resume drilling lateral section. 1.50 / 1.50 8.9/8.9 3765
2-300mw 765whp 4630ann 13.91 ecd 2-3kwob 40-60'/hr
PROD2 Wiper trip. PU off btm 19k. Essentially seen the same areas of
overpulls and mw as prior wiper trip coming out. RIH with
reduced pump rates and higher choke pressures and also
maintaining TF's as drilled. Lost 10bbls mud during wiper trip.
PVT 370
PROD2 Directionally drill ahead f/9690'. 1.50/1.65 8.89/8.73
3780fs(pressure balance shows 8.9) holding 824psi WHP
4590ann 13.78ecd. These annular pressures are lower than
before the wiper trip suggesting cuttings build-up in the belly
area of well. Will limit future wiper trips intervals to 100'-130'
range.
2-3k wob 50-60'/hr 2-300psi mw ROP slowed at 9725' coming
up into predicted shale then into Ankorite.
PROD2 Drilling Ankorite 1.5/1.6 3750fs 100mw 2-3kwob 4'/hr 4572ann
13.72ecd 820whp
PROD2 Still drilling Ankorite at 9793'
PROD2 Still drilling Anchorite with slow ROP of about 4 fph.
1.5/1.48/3950 psi. 800 psi WHP. PVT=340 bbls. IAP=498
psi, OAP=438 psi. Pumping 1, 10 bbl sweep of 100 klsrv high
vis mud per hour to assist in hole cleaning.
PROD2 ROP now up to 14 fph. PVT=333 bbls.
PROD2 Continue drilling Anchorite with slow ROP.
PROD2 W iper trip to window. Clean PU off bottom. Pumped a high vis
sweep to exit bit as we went thru belly of well. slight overpulls
with motor work in the same places as previous runs, but much
better than yesterday. No significant motor work or overpulls.
PROD2 Log tie in pass over RA tag. Make +17' correction.
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION Page 11 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 16-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To ;Hours Task Code- f ~ - -
T NPT ' Phase Description of Operations
10/6/2005 .02:40 - 03:25 0.75 ~ DRILL ~ P ~ ~ PROD2 ~ Continue back in the hole on a wiper trip. Using reduced pump
03:25 - 06:00 I 2.581 DRILL I P I I PROD2
06:00 - 08:30 I 2.501 DRILL I P I I PROD2
08:30 - 11:15 ( 2.751 DRILL P ~ ~ PROD2
11:15 - 16:30 5.25 BOPSU P PROD2
16:30 - 17:00 0.50 DRILL P PROD2
17:00 - 18:00 1.00 DRILL P PROD2
18:00 - 19:50 1.83 DRILL P PROD2
19:50 - 20:10 0.33 DRILL P PROD2
20:10 - 20:45 0.58 DRILL P PROD2
20:45 - 21:40 I 0.921 DRILL I N I DFAL I PROD2
21:40 - 22:00 I 0.331 DRILL I N I DFAL I PROD2
22:00 - 23:30 ~ 1.50 ~ DRILL ~ N ~ DFAL PROD2
23:30 - 00:00 I 0.501 DRILL I N I DFAL I PROD2
10/7/2005 ~ 00:00 - 00:45 ~ 0.75 ~ DRILL ~ N ~ DFAL ~ PROD2
00:45 - 02:20 1.58 DRILL N DFAL PROD2
02:20 - 02:40 0.33 DRILL N DFAL PROD2
02:40 - 03:00 0.33 DRILL N DFAL PROD2
03:00 - 03:30 0.50 DRILL P PROD2
03:30 - 04:00 0.50 DRILL P PROD2
rate of 0.75 bpm while RIH. No problems with motor work or
set downs while running back in hole.
Free spin 4130 psi at 1.5 bpm. Tag bottom. Resume drilling
Anchorite at 10 fph.
Drilling ahead in Ankorite. 4'/hr 3-4k wob 1.5/1.5 8.9/8.9 3900fs
100mw 4664ann 14.Oecd
TOH for BOP test, BHA inspection, new bit and following
revised pressure schedule. (Notified AOGCC of pending test.
Rep John Spaulding questioned our not giving 24hr notice.
Explained situation with drilling Ankorite and well plans beyond
and, it was in our best interest to trip how rather than
scheduled test tomorrow. John waived the wittnessing of
test.)Trapped 1480psi on well prior to shut-in of TRSSSV.
(PJSM before reaching surface re: I/d of BHA and prep for BOP
test)
Checked torque on all BHi connections on catwalk.
Test BOP's 250psi low / 4000psi high (2500psi annular). Draw
down test accumulator.
Service injector.
PU BHA #16
RIH with BHA #16. Using Hughes bicenter bit with "Z" cutters.
Opened SSSV and found 1380psi beneath it. (SI w/1480psi)
Followed revised pressure schedule.
Log tie in pass over RA tag. Make -14' correction.
RIH in open hole. Pumping at 0.9 bpm. 1100 Ibs on choke.
BHP=4690 psi. ECd=14.26 ppg. PVT=256 bbls. Getting
crude and gas back in returns. Run returns thru gas buster.
Will need to do a mud swap once on bottom. Probably got
crossflow from high pressure zone at toe of well to lower
pressured zone near heel.
BHI equipment no longer working. They suspect an electrical
short in the surface wiring. PUH to the window. .Defer mud
swap until we get this sorted out.
Stop above window. Lock reel brake. Set pins in drum.
Energize warning lights. Hold pre task safety meeting. Enter
reel and troubleshoot BHI wiring.
BHI determined that the problem is not on surface, it is
downhole, possibly in the ecoil. POOH to trouble shoot
downhole problem.
Tag up at surface. Hold PJSM. Stand back injector, and
troubleshoot BHA.
Lay down BHA #16. Trouble shoot MWD. Found bad upper
quick connect. Change same. Pickup BHA #17. Same motor
and bit. Using Hughes bit with "Z" cutters.
RIH with BHA #17, following pressure schedule.
Log a tie in pass over the RA tag in the WS. Make -13'
correction.
Continue RIH to resume drilling. Pumping 0.75 bpm while RIH
and holding 1100 psi on WHP. No problems in open hole.
Continue RIH.
Bring pumps up to full rate. Free spin is 4140 psi at 1.4 bpm.
Printed: 10/17/2005 7:36:41 AM
•
BP EXPLORATION Page 12 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common W ell Name: 1 B-15A Spud Date: 9/5/2005
Event Nam e: DRILL+C OMPLE TE Start : 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALIS TA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date
From - To ~
Hours Task Codee~ NPT Phase ~ Description of Operations
10/7/2005
03:30 - 04:00
0.50
DRILL
P
PROD2 - - - _ -
Holding 800 psi on WHP. Tag bottom at 9879'. Begin drilling
at 1.44/1.46/4300 psi. ROP=20 fph. Getting crude and gas
back in returns. Run returns thru gas buster.
04:00 - 05:30 1.50 DRILL P PROD2 Begin pumping new mud for mud swap. Continue drilling in
Ankorite with slow ROP. Broke through Ankorite a t 9897'.
05:30 - 16:05 10.58 DRILL P PROD2 Drilling ahead f/ 9897'. Drilled +/- 20'md of sand then into
shale. Turned down looking for sand again. Haven't seen it yet.
3-4k wob 10'/hr avg 1.46/1.46 4015fs 170mw 4635ann
13.9ecd. Pumped 10bb1 sweeps/2hrs. Lost +/-5 bbls/hr mud to
formation.
16:05 - 18:05 2.00 DRILL P PROD2 Wiper trip clean p/u 17k. Overpulls 5-10k 9326, 9220, 9180,
9080-40, 9004-8970,
18:05 - 18:50 0.75 DRILL P PROD2 Resume drilling. Having trouble getting weight to bit now.
String wt = -8000 lbs. DHWOB = 200 lbs. Ask mud man to
add an additional 1.5% of EMI-776 to system. System
currently has 4% of lubetex, no EMI-776. Free spin 4000 psi at
1.4 bpm. Drilling at 1.37/1.35/4200 psi. PVT=323 bbls.
IAP=230 psi, OAP=212 psi. BHP=4933 psi. ECD=14.3 ppg.
Pump high vis sweeps 1 per hour.
18:50 - 19:05 0.25 DRILL P PROD2 Not getting weight to bottom. Make a BHA wiper. Heavy
pickup off bottom with motor work. PUH slow for 100'.
19:05 - 20:00 0.92 DRILL P PROD2 Back on bottom. WOB=1200 lbs. String wt = -7000 lbs. WOB
immediately drills off, then we can't make additional hole.
Make multiple pickups, and we get the same situation. We
pick up off bottom, tag bottom and get WOB and motor work,
then it quickly drills off, and we can't make additional hole.
Pickups are clean. Not differential sticking.
20:00 - 21:10 1.17 DRILL P PROD2 Call town, discuss situation. Also discuss with slope Geo.
Able to get weight to bit finally. DHWOB=1500 lbs. String wt =
-9000 lbs. Not making any ROP. Continue trying to drill while
waiting on orders.
21:10 - 20:00 22.83 DRILL P PROD2 Discuss with town. POOH to pick up sidetrack bit. Clean PU
off bottom. Slight motor work and overpulls at the usual places
in open hole.
20:00 - 23:30 3.50 DRILL P PROD2 POH in cased hole with EDC open and pumping at 1.5 bpm.
Following choke schedule while POH.
23:30 - 00:00 0.50 DRILL P PROD2 Tag up at surface. Stand back injector. Lay down BHA #17.
Bit was packed off with clay. Problem downhole could have
been swelling shale preventing us from getting good weight
transfer. Bit recovered graded 1,1.
10/8/2005 00:00 - 00:30 0.50 STKOH P PROD2 Pick up R60 sidetrack bit with brass cap and 1.7 deg motor.
00:30 - 02:00 1.50 STKOH P PROD2 RIH with BHA #18 to sidetrack hole.
02:00 - 02:10 0.17 STKOH P PROD2 Log tie in pass over RA tag in whipstock. Make -14' correction.
02:10 - 03:00 0.83 STKOH P PROD2 Shut EDC, RIH. Pumping 0.3 bpm thru the motor. A few
bounces while RIH, but no set downs or significant motor work.
03:00 - 05:00 2.00 STKOH P PROD2 RIH to 9750', Kick on pumps to full rate. Free spin = 1.38 bpm,
3900 psi. PUH to sidetrack depth. Trough 2 times from
9650'-9665'. WOB on first time down was 200 lbs. Motor work
was 100 lbs. WOB on 2nd time down was 0 lbs. Motor work
was 200 lbs.
05:00 - 06:00 1.00 STKOH P PROD2 Begin time milling from bottom of trough at 9665' to 9685'.
~ Applied more WOB drill ahead to 9705'. Doesn't appear to be
Printed: 10/17/2005 7:36:41 AM
C]
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1B-15A
Common Well Name: 1 B-15A
Event Name: DRILL+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 2
Date 'From - To
1 Hours Task '~ Code i NPT
10/8/2005 05:00 - 06:00 I
1.00
STKOH~ ~
06:00 - 07:00 1.00 STKOH P
07:00 - 08:15 1.25 STKOH P
08:15 - 12:00 3.75 STKOH P
12:00 - 18:00 6.00 STKOH P
18:00 - 18:30 0.50 STKOH P
18:30 - 18:50 0.33 STKOH P
18:50 - 19:05 0.25 STKOH P
19:05 - 20:30 1.42 STKOH P
20:30 - 22:35 2.08 STKOH P
22:35 - 23:30 0.92 STKOH P
23:30 - 00:00 0.50 STKOH P
10/9/2005 00:00 - 01:00
01:00 - 02:00
02:00 - 03:25
03:25 - 03:40
03:40 - 04:35
04:35 - 04:50
04:50 - 06:00
1.00 STKOH P
1.00 STKOH P
1.42 DRILL P
0.25 DRILL P
0.92 DRILL P
0.25 DRILL P
1.17 DRILL P
06:00 - 12:00
Page 13 of 18
Spud Date: 9/5/2005
Start: 9/22/2005 End: 10/15/2005
Rig Release:
Rig Number:
Phase Description of Operations
- L_- - --
PROD2 sidetracked.
PROD2 Start time drilling again. No motor work. Thinking brass cap is
still in place. RIH to 10033' try drilling ahead. No progress.
Could be too soft here. Pull back to 9900.
PROD2 Backream Ankorite from 9890 to 9750 with opposite drilled
TF's. If brass cap is still on this should wear it off.
PROD2 From 9650' trough 3 times to 9665'.
PROD2 Stay parked at 9665' for 30min then begin time drilling from
bottom of trough. Initially doing good for first foot then start
having weight transfer problems. (mud system is at max
lubricants). Switch tatics and PU to get weight back after 6min
and then RIH back to last depth plus 0.1' seeing slight motor
wrok.
PROD2 Continue drilling at 0.1'/6 minutes. Not seeing motor work.
PROD2 9666.0'. Saw 300 Ibs wt on bit at this tenth that drilled off.
Good sign. Begin drilling at 0.1'/1 minute. Getting WOB with
drill off on each tenth. Time drilling at 1.46/1.44/4170 psi.
Getting more WOB as we make hole. Starting to get motor
work.
PROD2 Start drilling at a constant 6 fph. Seeing 550 Ibs WOB and 100
Ibs motor work. Consistent with good sidetrack.
PROD2 Begin pushing on it a little. Drilling at 15 fph. WOB=650 Ibs.
Motor work = 50-100 Ibs.
PROD2 Confirmed sidetrack on INC. Good weight on bit and motor
work to new TD of 9721'. Begin backreaming at 90 L/R to open
up sidetrack. Make a total of 2 passes on each side.
PROD2 POH to pick up lateral assembly. Pump high vis sweep to exit
the bit as we pull thru the heel of the well. Hole was ratty in the
usual places with motor work and overpulls.
PROD2 Stop below window, open EDC, POOH pumping at full rate thru
an open EDC.
PROD2 Continue to POH with sidetrack BHA.
PROD2 Tag up at surface. Hold PJSM to discuss BHA swap. Lay
down BHA #18. Change bits and motor. Pick up same
Hughes bicenter with "Z" cutters as run on BHA #17. Adjust
motor AKO to 1.1 deg.
PROD2 R1H with BHA #19 to resume drilling L2 lateral section from
9721'. 1230 psi below SSSV when opened.
PROD2 Log tie in pass over RA tag. Make -13' correction.
PROD2 Open EDC. Run to bottom to resume drilling. RIH at reduced
pump rate of 0.75 bpm. RIH slick down to 8980', set down.
PU, and made it to 9004', PU made it to bottom ok.
PROD2 Log MAD pass for missing data in sidetrack interval.
PROD2 Resume drilling L2 lateral section as per Geo plan.
1.38/1.30/4182 psi. PVT=394 bbls. IAP=190 psi, OAP=205
psi. BHP=4835 psi. ECD=14.51 ppg. WHP=800 psi. ROP =
60-90 fph.
6.00 DRILL P PROD2 Climbing back into shale section looking for thin sand below
Ankorite. Slow drilling f/ 9754' to 9778'. Hit sand at 9778'md
(92.7deg NBI) Drilling ahead 1-2k wob 60'-80'/hr. 1.4/1.4
4065fs 4800ann 780whp 14.4ecd 100-200psi mw coil wt 4k.
Turning down to level-off. Drilled good sand to 9855'. Then
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A
Event Name: DRILL+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 2
Date I From - To ' Hours I Task
10/9/2005 ~ 06:00 - 12:00 ~ 6.00 ~ DRILL
Code I! NPT '
P
12:00 - 14:10 I 2.171 DRILL I P
14:10 - 15:50 I 1.671 DRILL I P
15:50 - 18:00 2.17 DRILL P
18:00 - 18:30 0.50 DRILL P
18:30 - 19:15 I 0.751 DRILL I P
19:15 - 21:20 I 2.081 DRILL I P
21:20 - 00:00 I 2.671 DRILL I P
10/10/2005 100:00 - 01:05 I 1.081 DRILL I P
01:05 - 02:05 I 1.001 DRILL I P
02:05 - 02:25 I 0.331 DRILL I P
02:25 - 03:30 I 1.081 DRILL I P
03:30 - 06:00 ~ 2.50 ~ DRILL ~ P
06:00 - 17:00 I 11.001 DRILL I P
Page 14 of 18
Spud Date: 9/5/2005
Start: 9/22/2005 End: 10/15/2005
Rig Release:
Rig Number:
Phase ~ Description of Operations
PROD2 back into slow drilling Ankorite/Shale? Continue drilling ahead
with low TF. Broke out into sand at 9864'.
PROD2 Wiper trip to window. Clean p/u 15.5k tight coming through
9040-80' minor overpulls as in prior wiper trips.
PROD2 Continue drilling ahead f/ 9870' to 9908' 6427'tvd. Same
parameters. Inlout of shales/sand.
PROD2 Contine drilling dive down to target TVD of 6433' in A4 sand
PROD2 Now drilling back up again at Geo's direction with slow ROP.
Drilling at 1.37/1.32/4120 psi. ROP=10 fph. IAP=480 psi,
OAP=405 psi. BHP=4820 psi. ECD=14.46 ppg. Ask Geo to
catch a sample to confirm we are not in Ankorite. He indicates
we are drilling shale.
PROD2 Now drilling back down as per Geo's direction. ROP 5-10 fph.
Make pickup to check free spin. FS = 3990 psi at 1.35 bpm.
Tag bottom, continue chewing away at it.
PROD2 Geo needs time to sort out situation. Make wiper trip while he
discusses with town. Clean PU off bottom. Had motor work
and overpulls at a half dozen spots in the shales as we pulled
up hole. No worse, but no better than we have seen so far on
this lateral. Need to get this hole TD'd pretty quick and get
liner run lest they get worse. Run back to bottom. Had to work
it past 9050'. Got to TD finally.
PROD2 Tag bottom and resume drilling. The current plan is to drill up
to get into a better sand. Geo reports we are currently drilling
shale. ROP is certainly very slow and more reminisant of the
ROP we had in Ankorite. Ask Geo to catch another sample.
He confirms it is shale and not Ankorite. Continue drilling with
very slow ROP. Trying to build up out of it as per Geo's
directions.
PROD2 Continue drilling. 1.37/1.39/4300 psi. WOP=3200 lbs.
BHP=4800 psi. ECD=14.4 ppg. IAP=500 psi, OAP=430 psi.
PVT=340 bbls. ROP is very slow. About the same as the last
time we drilled Ankorite. If it quacks like a duck...
PROD2 Geo needs to sort out a plan forward. Make a wiper trip to the
window to give him time to discuss with town. Clean PU off
bottom. Ratty with motor work and overpulls in half a dozen
places. Not getting any better. Probably generatiing some
shale cuttings and washing out shales each time we make a
wiper.
PROD2 Log tie in pass over RA tag in whipstock. Make +19'
correction.
PROD2 Continue wiper trip back in the hole. Pumping at a reduced
rate of 0.75 bpm. Discuss plan forward with Geo. Latest
interpretation of data is that we are in the Ankorite, and need to
drill down to get out of it. Yikes!
PROD2 Tag TD. Resume drilling. Tool Face oriented lowside. Drilling
down at Geo's instructions. Drilling at 1.3911.39!4400 psi.
PVT=326 bbls. IAP=342 psi, OAP=322 psi. BHP=4872 psi.
ECD=14.6 ppg. WHP=800 psi.
PROD2 Continue drilling ahead f/ 10008' 1.33/1.33 4050fs 200mw
780whp 14.6ecd 3k wob 5-6'/hr with 2'-3' spurts of faster
drilling. Drilling Ankorite .Maintaining 87-85 deg inc all day
Making BHA wipers every 1/2hr. Thinning mud down with 10bb1
Printed: 70/17/2005 7:36:41 AM
•
BP EXPLORATION Page 15 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common W ell Name: 1 B-15A Spud Dater 9/5/2005
Event Nam e: DRILL+C OMPLE TE Start : 9/22/2005 End: 10/15/2005
Contractor Name: NORDIC CALIS TA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To i Hours Task 'Code
~ NPT I Phase Description of Operations
'
10/10/2005
06:00 - 17:00
11.00
DRILL __
P -
PROD2 - -
additons of 8.9 brine mixed throughly in system. Drilled to
10095'
17:00 - 18:00 1.00 DRILL P PROD2 Drill ahead f/ 10095' Geo's saying we hsould break into A4
soon. 1.44/1.44 4100fs 100-150mw 760whp 14.37ecd 3-3.5k
wob 4-8'/hr
18:00 - 18:45 0.75 DRILL P PROD2 Continuing to drill ahead in Ankorite. Drilling at 1.42/1.47/4140
psi. ROP=10 fph. IAP=580 psi, OAP=490 psi. BHP=4800 psi,
ECD=14.4 ppg. WHP=780 psi.
18:45 - 19:40 0.92 DRILL P PROD2 ROP is down to 3 fph. Probably due to the Ankorite, but we
were able to drill at closer to 10 fph when we first entered this
zone. We have 24 hours on this bit in Ankorite. POOH to
change bits. Currently in the hole with a Hughes bicenter with
"Z" cutters. Clean PU off bottom. Pump sweep to exit bit as
we pull thru the heel of the well. Hole condition in good shape
only a few overpulls in the usual areas. Had one spot of motor
work at 8530', which is new.
19:40 - 20:55 1.25 DRILL P PROD2 Open the EDC. Pull thru the window. POH, pumping at full
rate and following the pressure schedule.
20:55 - 21:10 0.25 DRILL P PROD2 PJSM to discuss BHA swap while POH.
21:10 - 22:00 0.83 DRILL P PROD2 Tag up at surface. Close SSSV. Flow check ok. Stand back
injector. Break out bit. Graded 2,3 with 1 broken cutter on the
center of the pilot and 1 additional broken cutter on the wing
section. The overall sharpness of the remaining cutters was
excellent. They were not dulled in any obvious way, and did
much better than expected from the hard Ankorite that we have
drilled for the past 24 hours. The bit was very balled up with
clay.
22:00 - 22:35 0.58 DRILL P PROD2 Pick up BHA #20. We are running a Hycalog DS100 with Trex
cutters. The rest of the BHA is identical to the .last run.
22:35 - 00:00 1.42 DRILL P PROD2 RIH with BHA #20.
10/11/2005 00:00 - 00:20 0.33 DRILL P PROD2 Log tie in pass over RA tag in whipstock. Make -14' correction.
00:20 - 01:25 1.08 DRILL P PROD2 RIH in open hole. Pumping minimum rate while RIH. Set
down at 9050', worked thru. Continue to bottom.
01:25 - 06:00 4.58 DRILL P PROD2 Kick on pumps. Free spin is 4050 psi at 1.36 bpm. Tag
bottom, and start drilling. 1.43/1.45/4250 psi. WHP=800 psi.
IAP=236 psi, OAP=248 psi. PVT=392 bbls. ECD=14.51 ppg.
BHP=4840 psi. ROP=5-10 fph. About the same as before.
06:00 - 08:45 2.75 DRILL P PROD2 Continue drilling Ankorite f/ 10103' to 10145' increased rete to
1.53 in this section. No help. Did have a drilling break at
10145'.
08:45 - 11:00 2.25 DRILL P PROD2 Drilling ahead f/ 10145'. Drlg small amount of shale then
dropped into sand. 1.52/1.52 4150fs 2-300 mw 750whp
4800ann 2-3k wob 40-50'/hr +1500-2000# coil wt. while
drilling pit vol at 0845 401 bbls. Still drilling good at 10210'
11:00 - 13:30 2.50 DRILL P PROD2 Wiper trip to window. PU off btm 16.7k No problems on wiper
trip in or out.
13:30 - 14:00 0.50 DRILL P PROD2 Contintue drilling ahead f/ 10260' 1.52/1.52 4100fs 2-300mw
765whp 4846ann 2-3k wob 40'/hr good wt transfer 2-3k coil wt.
Pit vol after wiper trip 394bb1s
14:00 - 19:00 5.00 DRILL P PROD2 Continue drilling ahead. 1.5/1.52/4400 psi. PVT=386 bbls.
IAP=540 psi, OAP=440 psi. WHP=765 psi. BHP=4870 psi.
ECD=14.56 ppg. INC=88 deg. ROP=40 fph.
19:00 - 21:30 2.50 DRILL P PROD2 Wiper trip to window. Hole mostly smooth. PVT: 370 bbls.
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION Page 16 of 18
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A Spud Date: 9/5/2005
Event Name: DRILL+COMPLETE Start: 9/22/2005. End: 10/15/2005
Contractor Name: NORDIC CALISTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To Hours Task I Code' NPT ' Phase j Description of Operations
10/11/2005 21:30 - 00:00 2.50 DRILL P PROD2 Drill ahead from 10,405'.. 4000 psi fs C~ 1.32 in/1.36 out
100-200 DSPI. DHWOB: 1.5 - 2.5k#. WHP/BHP/ECD:
820/4890/14.65 ppg. IA/OA/PVT: 475/405i36i bbls.
I N C/AZM/TF: 87.2/134.9/1108.
10/12/2005 00:00 - 01:30 1.50 DRILL P PROD2 Drill ahead from 10493'. Pump high vis sweeps every 100 bbls
pumped to help hole cleaning. ROP: 20-40 fph. PVT: 355
bbls.
01:30 - 04:15 2.75 DRILL P PROD2 Wiper trip to window. Hole mostly smooth. Motor work in a
few spots. PVT: 340 bbls.
04:15 - 06:00 1.75 DRILL P PROD2 Drill ahead from 10553'. 4300 psi fs @ 1.44 in/1.38 out.
DHWOB: 1.5-2.4k#. PVT: 336 bbls
06:00 - 09:20 3.33 DRILL P PROD2 Slow drilling. 1.35/1.4/4200 psi. DHWOB=600 lbs. String wt =
-8000 lbs. Having to snub to get any WOB. Need new mud.
Call for mud swap. IAP=520 psi, OAP=430 psi. BHP=4920
psi. WHP=750 psi. PVT=330 bbls. Finally able to get it to
drill by making a BHA wiper, then picking up and ramming
bottom with pumps down, then bringing up pumps. Definately
need to do a mud swap.
Continuing to pump 1 10 bbl sweep of high vis mud per hour,
and on wiper trips.
09:20 - 10:15 0.92 DRILL P PROD2 Begin pumping new mud downhole. Note, that this mud has
4% lubetex, but no EMI-776. Once we get mud back to
surface, we will add the EMI-776 to bring it up to 1.5%.
10:15 - 12:45 2.50 DRILL P PROD2 Wiper trip to the window. Clean PU off bottom. Free spin 500
psi lower with new mud. Wiper trip to window. A few hickups
on the trip up, nothing significant. Better than it was a few days
ago.
12:45 - 13:30 0.75 DRILL P PROD2 Resume drilling. Free spin 3860 psi at 1.4 bpm. Drilling at 46
fph. Drilling at 1.42/1.48/3940 psi. PVT=415 bbls of new mud.
IAP=270 psi, OAP=230 psi. BHP=4650 psi. WHP=750 psi.
Much better ability to slide with new mud in the hole. String wt
_ -800 Ibs, DHWOB=2000 lbs.
13:30 - 14:40 1.17 DRILL P PROD2 BHI orienter getting a bit weak. Having to pick up off bottom to
orient now.
14:40 - 17:30 2.83 DRILL C PROD2 We have achieved the program TD. The asset would like to
extend the well and get additional footage. MOC for the
additional footage has been completed. Continue drilling as
per the Geo.
17:30 - 20:30 3:00 DRILL C PROD2 Wiper trip to the window. Clean PU off bottom. Small amount
of motor work in a few areas. Overall hole condition is very
good.
20:30 - 00:00 3.50 DRILL C PROD2 Drill ahead from 10,860'. 3910 psi fs @ 1.41 in/1.42 out.
DPS1:100-200. DHW0B:1.4-2.1k#. WHP/BHP/ECD:
780/4710/14.25 ppg. IA/OA/PVT: 349/286/402 bbls.
ROP: 40-60 fph. Weight transfer is good.
10/13/2005 00:00 - 02:15 2.25 DRILL C PROD2 Hit hard spot. Perform wiper trip to get a btms up sample and
to discuss with twon. Appear to have crosed a small fault and
entered a zone containing ankorite.
Log gr tie in at window. Add 16' correction. Run in hole.
Smooth.
02:15 - 06:00 3.75 DRILL C PROD2 Drill ahead from 10,957'. 3950 psi fs @ 1.45 in/1.44 out.
DHWOB: 2.3k#. TF straight down to try and drill out of hard
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A
Event Name: DRILL+COMPLETE Start: 9/22/2005
Contractor Name: NORDIC CALiSTA Rig Release:
Rig Name: NORDIC 2 Rig Number:
Date From - To .Hours ' Task Code I NPT ~i Phase
Page 17 of 18
Spud Date: 9/5/2005
End: 10/15/2005
Description of Operations
10/13/2005 02:15 - 06:00 3.75 DRILL C PROD2 streak. PVT: 388 bbls.
06:00 - 08:10 2.17 DRILL C PROD2 Continued slow drilling in Ankorite. 1.46/1.4614100 psi.
WOB=2100 lbs. String wt = -5000 lbs. IAP=520 psi, OAP=430
psi. PVT=384 bbls. BHP=4730 psi. ECD=14.16 ppg.
08:10 - 09:50 1.67 DRILL C PROD2 Discuss with town slow drilliing in Ankorite. The decision has
been made to call this TD. Make wiper trip for final tie in.
Clean PU off bottom at 18500 lbs. Call for vac truck to shuttle
80 bbls of new mud from uprights to pits for liner running pill.
The trip up was very smooth. Minor overpulls, but no motor
work at 10553', 9350'. Hole is in much better shape than a few
days ago.
09:50 - 10:05 0.25 DRILL C PROD2 Log tie in pass down over RA tag. Make +6' correction.
10:05 - 12:00 1.92 DRILL C PROD2 RIH pumping at minimum rate to get final TD tag. Smooth
back to bottom. Pump 80 bbls of new mud with 4% Lubetex,
1.5% EMI-776 and 3#/bbl of course Alpine glass beads.
12:00 - 15:00 3.00 DRILL C PROD2 Tag bottom at 10992'. Pull off bottom laying in liner pill. Clean
PU off bottom at 19 klbs. Clean in open hole. Paint EOP flags
at 9500', 7000'. POH in tubing with EDC open and pumping at
1.7 bpm.
15:00 - 15:15 0.25 DRILL C PROD2 PJSM Re: Flow check, Laying down drilling BHA, BOP function
test, and BHI BHA for next run.
15:15 - 15:50 0.58 DRILL C PROD2 Flow check well. No flow observed. Stand back injector. Lay
down BHA #20, last drilling BHA. Bit recovered and graded
1,1.
15:50 - 16:45 0.92 BOPSU C PROD2 Weekly function test of BOP rams. All passed ok.
16:45 - 17:05 0.33 CASE P RUNPRD PJSM Re: Running Liner. Discuss overhead loads, pinch
points, MU torque, hazards and mitigations to hazards.
17:05 - 19:45 2.67 CASE P RUNPRD Liner will be run in 2 sections due to depth of SSSV. Make up
section #1. BHA consists of;
BTT Deployment Slv
38 Jts of 2-3/8", 4.6#, L-80, Slotted STL tubing
BTT O-Ring Sub.
1 Jt of 2-3/8", 4.6#, L-80, Solid STL tubing
Unique Bias Edge Guide Shoe.
Overall liner length is 1240.56'
Stab coil. Test mwd. Get on well. Pressure up WHP to 1450
psi. Open SSSV.
19:45 - 21:45 2.00 CASE P RUNPRD Run in hole with liner assembly. Offset at 7000' EOP flag
(-23'). Made no correction. 16.5k# up wt, 8.3k# do wt.
Through window ok. Continue to RIH at 50 fpm. Bounced
through a spot at 9330'.
21:45 - 22:30 0.75 CASE P RUNPRD Log gr tie in from 9530'. Subtract 13' correction. Continue to
RIH. Bounced through another spot at 9675'. Stop with liner
shoe at 10895'. 6.2k# coil down wt at setting depth. 20.4k#
pick up. Circ at 1.2 bpm @ 4200 psi to release from GS. Coil
up wt 17.5k#. Keep 1000 psi WHP.
Bottom of liner section #1 =10895.56
Top of liner section #1 = 9655'.
22:30 - 00:00 1.50 CASE P RUNPRD Pull out of hole with liner running BHA. Circulate out of hole
with 1000 psi on well head.
10/14/2005 00:00 - 00:45 0.75 CASE P RUNPRD Continue to pull out of hole with liner setting BHA. Close sssv
Printed: 10/17/2005 7:36:41 AM
BP EXPLORATION
Operations Summary Report
Legal Well Name: 1 B-15A
Common Well Name: 1 B-15A
Event Name: DRILL+COMPLETE
Contractor Name: NORDIC CALISTA
Rig Name: NORDIC 2
Date From - To Hours I' Task Code NPT
10/14/2005 00:00 - 00:45 ~ 0.75 ~ CASE ~ P
00:45 - 01:00 I 0.251 CASE I P
01:00 - 01:45 I 0.751 CASE I P
01:45 - 04:00 I 2.251 CASE I P
04:00 - 04:15 I 0.251 CASE I P
04:15 - 06:00 I 1.751 CASE I P
06:00 - 06:10 I 0.171 CASE I P
06:10 - 06:20 0.17 CASE P
06:20 - 06:40 0.33 CASE P
06:40 - 09:00 I 2.331 CASE I P
09:00 - 10:00 I 1.001 CASE I P
10:00 - 13:00 3.001 DEMOB P
Page 18 of 18
Spud Date: 9/5/2005
Start: 9/22/2005 End: 10/15/2005
Rig Release:
Rig Number:
Phase j Description of Operations
RUNPRD with 1600 psi tubing pressure. Pull to surface. Flow check
well.
RUNPRD Hold PJSM to discuss getting off well. Continue to flow check.
Well stable.
RUNPRD Get off well. Unstab coil. Blow down tools. Remove and
inspect GS spear. Test mwd tools.
RUNPRD Make up section #2, 44 jts of 2-3/8", 4.6#, L80, STL total.
'Deployment sleeve, 6 solid, 16 slotted, 13 solid, 8 slotted,
o-ring sub, 1 solid, indexing guide shoe. Total length: 1396.36'.
MU mwd BHA tools with Baker GS spear. Stab coil. Get on
well.
RUNPRD Pressure test lubricator and well to 1500 psi. Open sssv. 1450
psitbg pressure.
RUNPRD Run in hole with liner assy #2. Maintain whp as per schedule.
Wt check at window = 17 klbs. RIH thru the window slick. No
!problems in open hole.
RUNPRD Wt check at 9630'=22 klbs. RIH at 6 klbs. Tag up on top of
liner #1 at 9655', right on depth. Pick up, and retag to confirm.
Tagged up at 9656' on second tag. Confirmed at top of Liner
section #1.
RUNPRD Shut EDC. Line up to pump down coil. Bring on pumps to
1.35 bpm at 4300 psi. PU off liner. PU wt = 17 klbs. Released
from liner. PU to tie in depth above window.
RUNPRD Log tie in pass down. Make 0 correction. We are on depth.
Retag top of liner. found liner on depth.
Liner Section #2
Bottom at 9655'
Top at 8258'
RUNPRD Circulate 2% KCL to the end of coil. POH swapping well to
water. FP top 2000' of well with diesel.
RUNPRD Tag up at surface. Close SSSV. Flow check. No flow
observed. Stand back injector, rig down Baker tools and BHI
BHA.
POST ND stack, NU tree cap. PT with diesel to 500 and 3500 psi.
Clean pits. Prepare to move to move rig.
Rig released at 13:00
Telex entries carried on 10-04 morning report.
Printed: 10/17/2005 7:36:41 AM
.~:onoc~hillips
E
~aker Hughes INTEQ ~ ~~~
Baker Hughes INTEQ Survey Report ~Nr~t~
Company: ' ConocoPhillips Alaska, Inc Date: 10/25/2005 Time: 09`i48:I2 Page: 2
Field: Kuparuk.River Unit Co-ordinate(NE) Reference: .Well: 15, True North
Site: Pad 1 B' Vertical (TVD) Reference: Wetlhead(95') 95.0.
Wellr 15 Section (VS) Reference: 'Well (O.OON,O.OOE,285.OOAzi)
Wellpath: 18-15AL1 Survey CalculationMethod: Minimum Curvature, Db: Oracle
Field: Kuparuk River Unit
North Slope, Alaska
USA
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model : bggm2004
Site: Pad 1 B
Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N
From: Map Easting: 550434.96 ft Longitude: 149 35 27.418 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 0.39 deg
Well: 15 Slot Name:
Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N
+E/-W -479.82 ft Easting : 549958.57 ft Longitude: 149 35 41.425 W
Position Uncertainty: 0.00 ft
Wellpath: 16-15AL 1 Drilled From: 1 B-15A
Tie-on Depth: 8270.12 ft
Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level
Magnetic Data: 7/22/2005 Declination: 24.24 deg
Field Strength: 57606 nT Mag Dip Angle: 80.77 deg
Vertical Section: Depth From (TVD) +N/-S +E/-W Direction
ft ft ft deg
0.00 0.00 0.00 285.00
Survey Program for Definitive Wellpath
Date: 7/22!2005 Validated: No Version: 0
Planned From To Survey Toolcode Tool Name
ft ft
463.34 4405.00 MWD<0 - 7450'> (470.34-7450.00) (0) MWD MWD -Standard
4430.86 8270.12 MWD (4430.86-8621.00) (1) MWD+IFR+MS MWD +IFR + Multi Station
8270.12 9975.00 No definitive Plan MWD MWD -Standard
Annotation
MD TVD
fF ft
8270.12 6293.06 TIP
8339.00 6351.76 KOP
9731.00 6457.05 TD
Survey: MWD Start Date: 9/26/2005
Company: Baker Hughes INTEQ Engineer:
Tool: MWD;MWD -Standard Tied-to: From: Definitive Path
~,~~ , l t~
,ConocoPhillips ~aker Hughes INTEQ ~ ~
Baker Hughes INTEQ Survey Report zwT~~
Coropauy: ConocoPhillips Alaska, Inc Date: 10/25/2005 Time: 09:48:12 Page:. 2
Field: Kuparuk River Unit Co-ordinate(NE) Reference: We{I: 15; True North
Site:. Pad 16 Vertical (1'VD) Reference: Wellhead(95'} 95.0
Well: 15 Section (VS) Reference: Well (O.OON,O. OOE,285 .OOAzi)
Wellpath: 16-15AL1 Survey Calculation Method: Minimum Curvature Db: Oracle
Survey
MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS 'Tool
ft deg deg, ft` ft ft ft ft ft ft degl100ft
8270.12 31.71 231.73 6293.06 6198.06 -2356.97 -2825.58 5967268. 33 547149.02 2119. 27 0 .00 MWD
8339.00 31.38 232.58 6351.76 6256.76 -2379.08 -2854.03 5967246. 04 547120.72 2141. 03 0. 80 MWD
8346.00 33.31 236.10 6357.68 6262.68 -2381.26 -2857.08 5967243. 84 547117.69 2143. 41 38 .51 MWD
8370.23 37.55 246.50 6377.44 6282.44 -2387.93 -2869.39 5967237. 09 547105.43 2153. 57 30 .37 MWD
8400.28 45.05 255.00 6400.01 6305.01 -2394.34 -2888.10 5967230. 55 547086.76 2169. 99 31. 12 MWD
8430.49 50.12 264.34 6420.41 6325.41 -2398.26 -2910.00 5967226. 49 547064.89 2190. 13 28 .30 MWD
8464.07 58.17 274.60 6440.09 6345.09 -2398.39 -2937.13 5967226. 18 547037.76 2216. 30 34. 42 MWD
8499.03 71.20 269.79 6455.02 6360.02 -2397.25 -2968.63 5967227. 10 547006.25 2247. 02 39. 28 MWD
8530.40 84.67 269.39 6461.56 6366.56 -2397.47 -2999.24 5967226. 68 546975.65 2276. 53 42 .96 MWD
8560.36 96.17 274.97 6461.34 6366.34 -2396.34 -3029.11 5967227. 62 546945.77 2305. 68 42. 65 MWD
8591.74 94.45 280.15 6458.43 6363.43 -2392.23 -3060.08 5967231. 52 546914.79 2336. 65 17. 33 MWD
8621.53 92.13 284.34 6456.72 6361.72 -2385.92 -3089.13 5967237. 63 546885.69 2366. 35 16. 06 MWD
8656.14 93.43 290.22 6455.04 6360.04 -2375.66 -3122.12 5967247. 68 546852.64 2400. 88 17. 38 MWD
8688.64 95.21 295.63 6452.59 6357.59 -2363.04 -3151.96 5967260. 09 546822.72 2432. 96 17. 48 MWD
8724.24 95.00 301.71 6449.42 6354.42 -2346.04 -3183.06 5967276. 89 546791.51 2467. 40 17. 02 MWD
8755.48 94.63 307.45 6446.80 6351.80 -2328.37 -3208.68 5967294. 38 546765.78 2496. 72 18. 35 MWD
8786.21 94.38 313.49 6444.38 6349.38 -2308.50 -3231.97 5967314. 09 546742.36 2524. 36 19. 61 MWD
8817.53 94.35 311.08 6442.00 6347.00 -2287.49 -3255.07 5967334. 95 546719.12 2552. 11 7. 67 MWD
8849.90 94.29 304.87 6439.56 6344.56 -2267.64 -3280.50 5967354. 63 546693.56 2581. 82 19. 13 MWD
8878.16 94.42 299.00 6437.41 6342.41 -2252.74 -3304.41 5967369. 36 546669.56 2608. 76 20. 72 MWD
8910.25 93.73 293.15 6435.13 6340.13 -2238.68 -3333.15 5967383. 23 546640.73 2640. 16 18. 31 MWD
8944.57 95.80 287.85 6432.28 6337.28 -2226.70 -3365.17 5967394. 99 546608.63 2674. 19 16. 53 MWD
8975.38 92.29 283.42 6430.10 6335.10 -2218.43 -3394.75 5967403. 07 546578.99 2704. 91 18. 31 MWD
9005.45 91.92 279.28 6429.00 6334.00 -2212.51 -3424.21 5967408. 79 546549.50 2734. 89 13 .81 MWD
9037.88 89.62 282.21 6428.56 6333.56 -2206.47 -3456.06 5967414. 62 546517.61 2767. 22 11. 48 MWD
9071.16 90.14 288.04 6428.63 6333.63 -2197.79 -3488.17 5967423. 08 546485.45 2800. 49 17. 59 MWD
9100.10 87.84 291.73 6429.14 6334.14 -2187.95 -3515.38 5967432. 74 546458.18 2829. 31 15 .02 MWD
9130.50 87.65 287.70 6430.34 6335.34 -2177.70 -3543.97 5967442. 80 546429.53 2859. 58 13. 26 MWD
9160.83 87.07 282.05 6431.74 6336.74 -2169.93 -3573.24 5967450. 37 546400.21 2889. 86 18. 71 MWD
9192.02 87.96 277.64 6433.09 6338.09 -2164.60 -3603.93 5967455. 50 546369.48 2920. 89 14. 41 MWD
9220.38 88.63 272.49 6433.93 6338.93 -2162.10 -3632.16 5967457. 81 546341.24 2948. 80 18. 30 MWD
9250.08 87.80 269.95 6434.86 6339.86 -2161.47 -3661.83 5967458. 24 546311.56 2977. 63 8. 99 MWD
9282.69 84.42 267.05 6437.07 6342.07 -2162.32 -3694.35 5967457. 18 546279.06 3008. 82 13 .64 MWD
9328.69 85.68 272.94 6441.04 6346.04 -2162.32 -3740.16 5967456. 87 546233.26 3053. 06 13. 05 MWD
9358.98 88.54 276.35 6442.57 6347.57 -2159.87 -3770.30 5967459. 12 546203.10 3082. 82 14. 68 MWD
9393.01 89.68 282.81 6443.10 6348.10 -2154.21 -3803.83 5967464. 56 546169.53 3116. 67 19 .27 MWD
9430.20 87.56 287.60 6444.00 6349.00 -2144.46 -3839.70 5967474. 06 546133.61 3153. 84 14 .08 MWD
9464.45 85.07 291.30 6446.20 6351.20 -2133.09 -3871.92 5967485. 22. 546101.31 3187. 90 13. 00 MWD
9501.43 85.47 298.27 6449.25 6354.25 -2117.65 -3905.36 5967500. 44 546067.78 3224. 20 18 .81 MWD
9536.81 84.94 304.97 6452.21 6357.21 -2099.17 -3935.36 5967518. 71 546037.65 3257. 96 18 .93 MWD
9576.67 86.17 312.40 6455.31 6360.31 -2074.35 -3966.36 5967543. 32 546006.49 3294. 33 18. 84 MWD
9605.92 88.66 312.05 6456.62 6361.62 -2054.72 -3988.00 5967562. 81 545984.73 3320. 31 8 .60 MWD
9636.40 90.35 309.81 6456.89 6361.89 -2034.75 -4011.02 5967582. 62 545961.57 3347. 72 9 .21 MWD
9665.37 90.78 304.96 6456.60 6361.60 -2017.17 -4034.03 5967600. 05 545938.45 3374. 50 16 .81 MWD
9696.29 89.25 300.95 6456.59 6361.59 -2000.35 -4059.97 5967616. 69 545912.40 3403. 90 13 .88 MWD
9731.00 89.25 300.95 6457.05 6362.05 -1982.50 -4089.74 5967634. 34 545882.52 3437. 27 0 .00 MWD
• •
ConocoPhillips Alaska, Inc. KRU 1 B-15AL1
• •
ConocoPhillips Alaska, Inc. KRU 1 B-15AL2
•
•
KRU 1 B-15A
ConocoPhillips Alaska, Inc.
1 B-15A
API:
SSSV T
Annular Fluid: 500292246501
TRDP Well T
Ori Com letion:
Last W/O: PROD
2/16/2005
9/2/2005 An le TS:
An le TD:
Rev Reason: 34 d 8206
24 d 8621
Workover/ Sidetracks
Reference L : 30.33' RKB Ref L Date: Last U ate: 11/14/2005
Last Ta : 8341 TD: 8621 ftKB
- Last Ta Date: 9/4/2005 Max Hole An le: 71 d 5294
Casin Strin -ALL STRI NGS
_ Descri lion Size To Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 121 121 62.50 H~0
SURFACE 9.625 0 4190 4138 40.00 LSO
PRODUCTION 7.000 0 4405 4324 26.00 LSO BTC-M
Producttion liner 5.500 4234 8350 6361 15.50 L50 H dril 511
ProduMion Liner 3.500 8121 8621 8621 9.20 LSO H drll 511
L2 LINER TOP 2.375 8258 8300 6319 4.60 LSO STL
L7 LINER TOP 2.375 8334 8400 6405 4.60 LSO STL
Tubin Strin -TUBING
Size To Bottom TVD Wt Grade Thread
3.500 0 3922 3898 9.30 LSO EUESrd
3.500 3922 7876 5977 9.30 LSO IBT
3.500 7876 8077 6134 9.30 LSO EUE8rd
Perforations Summa
Interval TVD Zone Status Ft SPF Date T e Comment
8208 - 8218 6241 - 6250 C~ 10 6 9/512005 SOZ
PERF 2.5" HMX PJ 2506 10.SG for cement
SOZ on back side
8291 - 8296 6311 - 6315 UNIT B 5 6 9/5/2005 SOZ
PERF 2.5" HMX PJ 2506 10.5G for cement
SOZ on back side
8305 -8307 6323 -6325 UNIT B 2 4 3/2/2005 SOZ
PERF 1 9/16" Gun, Smail charges for
cements ueeze on back side
8408 -6417 6412 -6420 A-5 9 6 7/25/2005 (PERF 2.5" HMX PJ 60 d hase
8432 -8452 6434 -6452 A~ 20 6 3/28/2005 PERF Alternatin PJ 8 PF char es
8506 - 8510 6501 - 6505 A-3 4 6 3/2/2005 SOZ
PERF 2.5" HSD Powerflow 60 deg phase
for cements ueeze on back side
Stimulations & Treatments
TUBING Interval Date T e Comment
(7876$077, 8432 -8452 5/14/2005 FRAC FRAC w/180 000# 16/20
OD:3.500,
ID:z.ssz)
Gas Lift Mandrelsr'Valves
St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv
Cmnt
1 2631 2630 CAMCO KBUG-M GLV 1.0 BK 0.125 1225 10/17/2005
2 3903 3881 CAMCO KBUG-M GLV 1.0 BK 0.156 1265 10/17/2005
3 5093 4791 CAMCO KBG-2-9 GLV 1.0 INT 0.188 1295 10/17/2005
4 6978 5494 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1290 10/16/2005
5 7822 5940 CAMCO KBG-2-9 OV 1.0 BTM 0.188 0 10/16/2005
Other lu s e ui .etc. - W/O & SIDETRACK COMPLET ION
De th TVD T e Descri lion ID
30 30 HANGER FMC GEN IV TBG HANGER 3.500
1482 1481 SSSV CAMCO TRM-5E SSSV 2.920
7875 5977 PBR BAKER PBR 3.000
7889 5987 PACKER BAKER SABL3 PACKER 2.800
8032 6098 NIP HES 2.75'X' NIPPLE 2.750
8077 6134 Overshot POOR BOY OVERSHOT SWALLOWED 5' OF TUBING STUB FROM ORIGINAL COMPLETION 3.870
8259 6284 De to SLV L2 BTT SEAL BORE DEPLOYMENT SLEEVE w/3' GS PROFILE 1.920
8288 6308 WINDOW L2 OPEN HOLE 0.000
8292 6312 Whi stock L2 3.5" LSX FLOW-THRU WHIPSTOCKTO L2 1.992
8334 6348 De to SLV L1 BTT SEAL BORE DEPLOYMENT SLEEVE w/3" GS PROFILE 1.920
8340 6353 WINDOW L1 OPEN HOLE 0.000
8343 6355 Whi stock L1 3.5" LXS FLOW-THRU WHIPSTOCK TO L1 1.992
Other lu s e ui .etc. -ORIGINAL COMPLETION
De th TVD T e Descri lion ID
I 8081 6137 TBG STUB TUBING STUB FROM ORIGINAL COMPLETION 2/1312005 2.992
1
~ 8118 6167 LOCATOR BAKER NO GO LOCATOR 2/13/2005 2.970
I 8119 6168 SEAL BAKER BULLET SEAL ASSEMBLY 2/13/2005 2.990
Other lu s e ui .etc. - 3.5" PRODUCTION LINER
I I De th TVD T e Descri lion ID
8121 6170 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 4.130
t r 8140 6185 PACKER BAKER 'ZXP' LINER TOP PACKER 3.410
8148 6192 PBR POLISHED BORE NIPPLE SL-HT 3.230
I 8152 6195 HANGER 3.5" x 5.5" BAKER'HMC' LINER HANGER 2.920
8498 6494 RETAINER HES 3.5" EZ DRILL RETAINER 0.000
8556 6547 COLLAR BAKER 3.5" LANDING COLLAR 2.993
Other lu s e ui .etc. - 5.5" PRODUCTION LINER
De th TVD T e Descri lion ID
4235 4177 TIE BACK SLV BAKER LINER TIE BACK SLEEVE 5.500
4241 4182 PACKER BAKER 'CPH' LINER TOP PACKER 4.870
4245 4186 HANGER BAKER 'HMC' LINER HANGER 4.920
I 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
t ~ 8224 6255 COLLAR 5.5" JOINT w/INSERT LANDING COLLAR 4.950
I 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
Pen - - General Notes
(ea°a-ea17) - Date Note
FRAC 2/1 312 00 5 TREE: GMC /GEN IV/ 3-118" SM
TREE CAP CONECTION: 5.75 OTIS QUICK CONNECT
(84325452) 10/14/2 005 SIDETRACKED 18-15A -MULTI-LATERALS L1 8 L2 -ALL 3 LEGS PRODUCING
Perf
(85065510)
11 /09/04 STATE O F ALASKA
OIL AND GAS CONSERVATION COMMISSION
BO PE Test Report
Submit to: ~3L~FTt~3.SY~~~_,~
~
~
?C:~4~;
,€iE`3..-~E't,~'
s
.5
b S,
t
~
c~~:+~x~~`.~'....f::' ~.~C.3 C~~~., i~C~vi~~t+".~Ct ~~~e~~.:~1,i~i~.c~h.f.e to
~~~I:~...~~~~y~~r~s~~r~~W~~r~i~3_s~~~f_,~~c,
Contractor: Nordic Rig No.: 2 DATE: 9/23/05
Rig Rep.: Mckeirnan / Dowell Rig Phone: 659-4398 Rig Fax: 659-4356
Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356
Rep.: Goodrich / Sevcik E-Mail ~~~~c~ysr~rl~rE7~ic~'~~c~~:l~~us~f~E';~.~~?:~:{e3
Well Name: 1 B-15AL1 PTD # 2tFS-1114
Operation: Drlg: XXX Workover: Explor.:
Test: Initial: XXX Weekly: Bi-Weekly
Test Pressure: Rams: 250-4000 Annular: 250-2500 Valves: 250-4000
MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES:
Test Result Test Result Quantity Test Result
Location Gen.: P Well Sign P Upper Kelly NT
Housekeeping: P Drl. Rig P Lower Kelly NT
PTD On Location P Hazard Sec. P Ball Type 2 P
Standing Order Posted P Inside BOP NT
BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm
Stripper 1 2" P Trip Tank P P
Annular Preventer 1 7 1/16" P Pit Level Indicators P P
#1 Rams 1 Blind /Shear P Flow Indicator P P
#2 Rams 1 2" Combi P Meth Gas Detector P P
#3 Rams 1 2 3/8" Combi P H2S Gas Detector P P
#4 Rams 1 2" Combi P
#5 Rams N/A NA Quantity Te st Result
Choke Ln. Valves 1 3 1/8" P Inside Reel valves NA
HCR Valves 2 3 1/8" P
Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM:
Check Valve N/A NA Time/Pressure Te st Result
System Pressure 3000 P
CHOKE MANIFOLD: Pressure After Closure 2150 P
Quantity Test Result 200 psi Attained 17 sec P
No. Valves 14 P Full Pressure Attained 83 sec P
Manual Chokes 1 P Blind Switch Covers: All stations Y
Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2000
Test Results
Number of Failures: 0 Test Time: 5.5 Hours Components tested 29
Repair or replacement of equipment will be made within 0 days. Notify the North Slope
Inspector 659-3607, follow with written confirmation to Superviser at: ,~iE~3.-1'f`g~ ~~~r~i~3.~4~tt.~>t_~s
Remarks:
Distribution: 24 HOUR NOTICE GIVEN
orig-Well File YES )OOC NO
c - Oper./Rig Waived By Chuck Scheve
c-Database Date 9/21/05 Time 07:00
c -Trip Rpt File Witness Tyler Mconnell
c -Inspector Test start 21;30 Finish 03;00
Coil Tubing BFL 11/09/04 Nordic 2 BOP 9-23-05.x1s
.~ ~
~~
~?~ ~ a ~~~ ~ ~~, ~"?, ~ FRANK H. MURKOWSK/, GOVERNOR
~~ ~
~~ OI~ ~ ~ 333 W. 7TM AVENUE, SUITE 100
COI~TSERQA'1`IO1~T CODII-'IISSIOI~T ANCHORAGE, ALASKA 99501-3539
. PHONE (907) 279-1433
FAX (907) 276-7542
Aras Worthington
CT Drilling Engineer
ConocoPhillips Alaska Inc.
P.O. Box 196612
Anchorage, Alaska 99519-6612
Re: Kuparuk 1 B-15AL 1
ConocoPhillips Alaska Inc.
Permit No: 205-114
Surface Location: 500' FNL, 484' FEL, SEC. 09, T11N, R10E, UM
Bottomhole Location: 2421' FNL, 4795' FEL, SEC. 09, T11N, R10E, UM
Dear Mr. Worthington:
Enclosed is the approved application for permit to redrill the above
development well.
The permit is for a new wellbore segment of existing well KRU 1 B-15A, Permit No. 204-256,
API No. 50-029-22465-01. Production should continue to be reported as a function of the
original API number stated above.
This permit to redrill does not exempt you from obtaining additional permits or
approvals required by law from other governmental agencies, and does not
authorize conducting drilling operations until all other required permits and
approvals have been issued. In addition, the Commission reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20,
Chapter 25 of the Alaska Administrative Code unless the Commission
specifically authorizes a variance. Failure to comply with an applicable
provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit. Please provide at least twenty-
four (24) hours notice for a representative of the Commission to witness any
required test. Contact the Commission's petroleum field inspector at (907) 659-
3607 (pager).
DATED this( day of July, 2005
cc: Department of Fish 8s Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
1, ~._ ~ L.,~ •
Subject. ~E: 1$-15A ~„~~„ '~~ ~ 1
From: CONOCO$ ~ '~. ~ Q ~ - t ~ ~®
<IMCEAEX-_O=CONOCO OU=NORTH+20AMERICA-SW_CN=RECIPIENTS_CN=AJWORTH@conocophillips.com>
Date: Fri, 29 Ju12005 13:21:41 -0800
To: Thomas Maunder <tom maunder@admin.state.ak.us>
No problem; here it is...
Tom,
Apologies for lack of detail; basically the 3 1/2" x 5 1/2" liner lap
was remedially (and successfully) squeezed once before (post rotary rig
sidetrack) but the squeeze didn't bring cement up above the point where
we will set the upper A-sand whipstock. Since there is some concern
about movement of the 3 1/2" liner inside the 5 1/2" (might cause
mechanical problems with the window milling) as well as some isolation
concerns for a possible C-sand CTD lateral that may be drilled at a
future date, we have decided to do a second "remedial" job on the 3 1/2"
x 5 1/2" liner lap to cover both issues.
Steps are as follows:
1) Pump CaC03 pill over existing A-sand frac'ed perfs, covering
them entirely
2) Tag top of CaC03 to confirm coverage
3) Dump-bail latex slurry sand cap on CaC03 to prevent cement
filtration into CaC03
4) E-line perforate the 3 1/2" x 5 1/2" liner at both the planned
uppper A-sand whipstock set depth and the assumed future C-sand
whipstock depth
5) Lay in cement with Coiled Tubing and squeeze 2-3 barrels away
6) Mill out cement with CTU & Clean-out CaC03 plug
7) Run whipstock Dummy drift w/ Slickline
S) MIRU Nordic 2 (whipstock will be set on rig)
Please let me know if you need further details.
Aras Worthington
CPAI CTD Engineer
265-6802
-----Original Message-----
From: Thomas Maunder [mai..tc:tcm maundsr~adm.i.n..state.ak.us]
Sent: Friday, July 29, 2005 8:15 AM
To: Worthington, Aras J
Subject: iB-15A
Aras,
I am looking at the proposed CT laterals from 1B-15A. I am curious
regarding the operation for step 3 of your procedure where it says "Pre
CTD CT cement squeeze of 3-1/2" x 5-1/2"." Could you please provide
further information. Thanks in advance.
Tom Maunder, PE
AOGCC
-----Original Message-----
From: Thomas Maunder [mailtc:tcm maunderaadmin.state.ak.us]
Sent: Friday, July 29, 2005 11:32 AM
To: Worthington, Aras J
Subject: Re: 1B-15A
Aras,
Hate to bother you, but could you resend your original response to my
question on the procedure for 1B-15AL1??
I did a print, trashed and deleted the emails and there was a sizing
error on the printing. I would like to put a copy of the message in the
well files.
Thanks for the help.
Tom
Thomas Maunder wrote:
', Aras,
1 of 2 7/29/2005 1:29 PM
• •
I am looking at the proposed CT laterals from 1B-15A. I am curious
regarding the operation for step 3 of your procedure where it says
"Pre CTD CT cement squeeze of 3-1/2" x 5-1/2"." Could you please
provide further information. Thanks in advance.
Tom Maunder, PE
AOGCC
2 of 2 7/29/2005 1:29 PM
STATE OF ALAS ~~t
At_ SKA OIL AND GAS CONSERVATI COMMISSION
PERMIT TO DRILL ~~-~- ~i~~~ '~~~~
^ Drill ®Redrill
1 a. Type of work
^ Re-Entry 1b. Current Well Class ^ Explorato ®Develo ment O' ^Multi le Zone
'~' p p
^ Stratigraphic Test ^ Service ^ Development ~~~@~~~le Zone
2. Operator Name:
Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well
Bond No. 59-52-180 ~ 11. Well Name and Number:
KUP 1 B-15AL1
3. Address:
c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ,
MD 9975 ~ TVD 6368ss 12. Field /Pool(s):
Kuparuk River Unit
4a. Location of Well (Governmental Section):
Surface:
500' FNL
484' FEL
SEC
09
T11 N
R10E
UM ~ 7. Property Designation:
ADL 025648 °
,
,
.
,
,
,
Top of Productive Horizon:
2905' FNL, 3376' FEL, SEC. 09, T11 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date:
August 10, 2005
Total Depth:
2421' FNL, 4795' FEL, SEC. 09, T11N, R10E, UM 9. Acres in Property:
2560 ~ 14. Distance to Nearest Property:
23,900' `
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 549955 '• Y- 5969647 Zone- ASP4 10. KB Elevation
(Height above GL): 34' RKB feet 15. Distance to Nearest We11 within Pool
1 B-20 is offset by 430'
16. Deviated Wells: Kickoff Depth: 8334 ~ feet
Maximum Hole Angle: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Downhofe: 4370 '' Surface: 3740 '
1 Casing Program:
..Size
.Specifications Setting Depth
To Bottom Quantity of ement
c.f. or sacks
Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data
3" 2-3/8" 4.6# L-80 STL 1651' 8324' 6244' 9975' 8368' Uncemented Slotted Liner
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations)
Total Depth MD (ft):
8621 Total Depth TVD (ft):
6607 Plugs (measured):
None Effective Depth MD (ft):
8588 Effective Depth TVD (ft):
6576 Junk (measured):
None
Casing Length Size Cement Volume MD TVD
tr
nduct r 121' 16" 200 sx Arcticset I 121' 121'
4190' 9-5/8" 900 sx AS III, 400 sx Class 'G' 4190' 4138'
Int r ' t 4405' 7" 350 sx Class 'G' 4405' 4324'
Produ i n
Lin 4116' S-1/2" 383 sx Class 'G' 4234' - 8350' 4176' - 6361'
Liner 500' 3-1/2" 55 sx Class'G' 8121' - 8621' 6170' - 6607'
Perforation Depth MD (ft): 8305' - 8510'
--~... ~ l o S~ Perforation Depth TVD (ft): 6323' - 6505'
20. Attachments ;filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis
LI Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 265-6802
Printed Name Aras Worthington Title CT Drilling Engineer
Prepared By Name/Number:
Si nature Phone 265-6802 Date ,s Terrie Hubble, 564-4628
Commission Use Only
Permit To Drill ~~
Number. ~%.~ ~/~ API Number:
50- 029-22465-60-00 Permit Approval /
Date: 7 2~~1 ~S See cover letter for
other requirements
Conditions of Approval: Sampl Req fired ^ Yes No Mud Log Required ^ Yes No
Hyd gen Su fide Measures 'Yes ^ No Directional Survey Required Yes ^ No
Other: l.{ '~ ~ o,S ,~h~~ ,
~~ APPROVED BY
A roved B ~,. ~ ~ THE COMMISSION Date
Form 10-401 Rued (004 ~ ~ `~ ' ° ~ `-- $ubmi~ Irf Duplicate
KRU 1 B-15AL1 and 1 B-15AL2 Sidetra• -Coiled Tubin Drillin
9 9
Summary of Operations:
Coiled tubing drilling will dri1121aterals in producer KRU 1B-15A using Dynamically Overbalanced pressure '"
drilling technique (DOBCTD, see description below). This horizontal laterals will target Kuparuk A sand `
reserves for production. The Frac'ed Kuparuk A Sand perforations in the existing well, 1B-15A, will be r
retained.
CTD Drill and Complete 1B-15AL1 & 1B-15AL2 program: Planned for Aug 10, 2005
1. Pre CTD MIT-IA, MITT
2. Pre CTD test MV & SV
3. Pre CTD CT cement squeeze of 3 ''/2" X 5 ''/z"
4. Pre CTD CT Mill out cement.
5. Pre CTD drift tubing/liner with dumm whipstock
6. MIRU Nor is 7-1116" BOPE, test
7. Set 3 'h" whipstock at 8334' and - ~ ~~-~ ~ A ~~ aQS- ~
8. Mi112.74" window at 8334' and and 10' of openhole _
9. Dri113" bicenter hole horizontal lateral from window to ~9975'~md targeting Kuparuk A sands
10. Complete with 2 3/8" slotted liner from TD 9975', up into the 3 1/2" liner to 8324'
. Set 3 /2" whipstock 8286' and
12. Mi112.74" window at 8286' and and 10' of openhole.
13. Dri113" bicenter hole horizontal lateral from window to 10750' and targeting Kuparuk A sands
14. Complete with 2 3/8" slotted liner from 10750', up into the 3 '/2" liner to ~ 8276'
15. ND BOPE. RDMO Nordic 2.
16. Post CTD rig -Run GLVs. BOL.
Mud Program:
• Step 8: 8.9 ppg Chloride based biozan mud
• Step 9-14: Chloride based Flo-Pro (8.9 - 10 ppg)
Disposal:
• No annular injection on this well
• Class II liquids to KRU 1R Pad Class II disposal well
• Class II drill solids to Grind & Inject at PBU Drillsite 4
• Class I wastes will go to Pad 3 for disposal
Casing Program:
• 1B-15AL1: 2 3/8", 4.6#, L-80, STL slotted liner from 8324' and to 9975' and '
• 1B-15AL2: 2 3/8", 4.6#, L-80, STL slotted liner from 8276' and to 10750' and
Well Control:
• Two wellbore volumes 0220 bbls) of KWF will be location during drilling operations. •~
• BOP diagram is attached.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi.
• The annular preventer will be tested to 400 psi and 2500 psi. ~`
Directional
• See attached directional plans for 1B-15AL1 & 1B-15AL2.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• The nearest well to 1B-15AL1 is 1B-20, which is offset by 430'. KRU boundary is 23,900' away.
• The nearest well to 1B-15AL2 is 1A-04, which is offset by 660'. KRU boundary is 22,700' away.
Logging
• MWD Gamma Ray will be run. "
KRU 1 B-15AL1 and 1 B-15AL2 Sidetracks -Coiled Tubin Drillin
9 9
Hazards
• High pressure (4370 psi) is expected after crossing a mapped fault in 1B-15AL2.
• 1B is an H2S pad, the highest H2S measurement on the pad is 183 ppm. All H2S monitoring equipment
will be operational.
Reservoir Pressure
• The drilling plan includes crossing a fault (1B-15AL2) where the expected pressure is 4370 psi at 6307' '
TVD, 13.3 ppg EMW. Max. surface pressure with gas (0.1 psi/ft) to surface is 3740 psi.
DOBCTD Pressure Drilling
Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant
bottom hole pressure by using 8.9-10 ppg drilling fluid in combination with annular friction losses and
applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole
stabili Applying annular friction and choke pressure also allow use of less expensive drilling fluid and
minimizes fluid losses and/or fracturing at the end of the long wellbores. A hydraulic choke for regulating
surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be
independent of the BOPE choke.
Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure
deployment of the BHA will be accomplished utilizing either the TRSSSV or the BOP pipe/slips (2-3/8"
rams, see attached BOP configuration). The annular preventer will act as a secondary containment during
deployment and not as a stripper.
Estimated max reservoir pressure: 4370 psi at 6307' TVD, 13.3 ppg EMW. ~
Expected annular friction losses while circulating: 750 psi.
Planned mud density: 10 ppg equates to 3280 psi hydrostatic bottom hole pressure.
While circulating 10 ppg fluid, plus 340 psi surface pressure applied via the choke, bottom hole circulating
pressure is estimated to be 4370 psi or 13.3 ppg ECD.
When circulation is stopped, a minimum of 1090 psi surface pressure will be applied to maintain constant
BHP.
Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure
measurements while drilling and shale behavior. The production liner will be deployed by closing the SSSV
as a barrier. '-~
~~
•
;. ~r~~r..~ CanacaPhlillips Alaska, Inc.
KRU 1 B-15A
1B-15A
API: 500292246501 Well T e: PROD An le TS: 34 de 8206
TUBING
(0121,
00:3.500 SSSV Type: TRDP Orig
Com letion: 2/16/2005 Angle @ TD: 24 deg @ 8621
,
i0:2.ssz) Annular Fluid: Last W/O: Rev Reason: Post FCO Ta
Reference L 34' RKB Ref Lo Date: Last U ate: 7/10/2005
Last Ta : 8488 TD: 8621 ftK6
Last Ta Date: 6/29/2005 Max Hole An le: 71 de 5294
Casin Strin -ALL STRINGS
Descri lion Size To Bottom TVD Wt Grade Thread
CONDUCTOR 16.000 0 121 121 62.50 H-40
r'r SURFACE 9.625 0 4190 4138 40.00 L-80
~" PRODUCTION 7.000 0 4405 4324 26.00 L-80 BTC-M
Protection Liner 5.500 4234 8350 6361 15.50 L-80 H dril 511
Preductlon Liner 3.500 8121 8621 8621 9.20 L-80 H dril 511
Tubin Strin -TUBING w1~owC° ~
Size To Bottom TVD Wt Grade Thread
3.500 0 8121 6170 9.30 L-80 EUE8rd
~ Perforations Summar
Interval TVD Zone Status Ft SPF Date T e Comment
8305 - 8307
w i 6323 - 6325
CJ~~ e ~ UNIT B
-~~ 2 4 3/2/2005
F'+~RF 1 9/16" Gun, Small charges
for cement squeeze on back
side
8432 - 8452 6434 - 6452 A-4 20 6 3/28/2005 PERF Alternatin PJ & PF char es
*~: 8506 - 8510 6501 - 6505 A-3 4 6 3/2/2005 : 8QZ
PERF 2.5" HSD Powerflow 60 deg
phase for cement squeeze
on back side
Stimulations & Treatments
Interval Date T e Comment
8432 - 8452 5/14/2005 FRAC FRAC w/180,000# 16/20
1 Gas Lift Mandrels/Valves
-~;:
'`- St MD TVD Man
Mfr Man Type V Mfr V Type V OD Latch Port TRO Date
Run Vlv
Cmnt
1 2573 2572 CAMCO KBUG-M GLV 1.0 BK 0.188 1300 5/17/2005
2 3939 3914 CAMCO KBUG-M GLV 1.0 BK 0.200 1270 5/17/2005
3 5364 4888 CAMCO KBG-2-9 GLV 1.0 BTM 0.188 1245 5/17/2005
4 7263 5615 CAMCO KBG-2-9 DMY 1.0 INT 0.000 0 4/23/2005
LOCATOR 5 8037 6102 CAMCO KBG-2-9 OV 1.0 INT 0.188 0 5/16/2005
(e116-611s, Other lu s, a ui ., etc. -JEWELRY
o0:a.zso) De th TVD T e Descri lion ID
30 30 HANGER FMC GEN IV TBG HANGER 3.500
1833 1832 SSSV CAMCO TRM-4E SAFETY VALVE 2.812
8080 6136 NIP CAMCO'D' LANDING NIPPLE 2.750
8118 6167 LOCATOR BAKER NO GO LOCATOR 2.970
8119 6168 SEAL BAKER BULLET SEAL ASSEMBLY 2.990
PACKER Other lu s, a ui etc. -Protection Liner Jewelr
(a1ao~1a1, De th TVD T e Descri lion ID
o0:a.s~o) 4235 4177 TIE BACK
SLV BAKER LINER TIE BACK SLEEVE 5.500
pgR 4241 4182 PACKER BAKER 'CPH' LINER TOP PACKER 4.870
(61aa~1as, 4245 4186 HANGER BAKER'HMC' LINER HANGER 4.920
OD:4.350) 8177 6215 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
8221 6252 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
n ' + ; /, 8224 6255 COLLAR 5.5" JOINT w/INSERT LANDING COLLAR 4.950
I ' ~' 8264 6288 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
, 8309 6326 Centralizer WEATHERFORD IN-LINE CENTRALIZER 4.850
'
i ! ~ ~` Other lu s, a ui ., etc. -Production Liner Jewler
De th TVD T e Descri lion ID
8121 6170 TIE BACK
SLV BAKER LINER TIE BACK SLEEVE 4.130
Pert' 8140 6185 PACKER BAKER 'ZXP' LINER TOP PACKER 3.410
(s3osB3o~) 8148 6192 PBR POLISHED BORE NIPPLE SL-HT 3.230
8152 6195 HANGER 3.5" x 5.5" BAKER 'HMC' LINER HANGER 2.920
8498 6494 RETAINER HES 3.5" EZ DRILL RETAINER 0.000
FRAC ~ 8556 6547 COLLAR BAKER 3.5" l1~NDING COLLAR 2.993
(8432A452) ~ General Notes
Pert
(8432-8452) ~
~ Date Note
~ ~ 2/13/2005 TREE: GMC /GEN IV/ 3-1/8" 5M
TREE CAP CONECTION: 5.75 OTIS QUICK CONNECT
2/13/2005 WELL SIDETRACKED
Perf
(8506-8510)
KRU 1B-15A Dual A-sand Producer
Proposed Completion
3-1/2" Camco TRM-4# SSSV, 2.875" min ID at 1833' MD
3-1/2" 9.3# L-80 EUE 8rd Mod Tubing
3-%2' Camco KBUG-M GLM @ 2573', 3939' MD
•
9-5/8" 40#
L-80
4190'
7" 26# L-80
4405' MD
3-%" Camco KBG-2-9 GLM @ 5364', 7263', 8~ 8037' MD
3-%2' Camco DS nipple, 2.75" min ID @ 8080' MD
Baker CPH Packer w/SBE @ 9927' MD
1 B-15A L2 Lateral (A-sand west),
TD ~ 10750' and
L2 KOP 8286' MD
1 KOP 8334' MD
8350' and
A sand perfs _
ner
WS
3" openhole
~ono~oPhillips
Alaska, Inc.
1 B-15A L1 lateral (A-sand east);
TD @ 9975' and
2.3/8" slotted liner
owtnru> 3" openhole Thy S ~~~~ ~,~~' ~, ~ ~
~~_
7/18/05
`J, •
Conc~€vP'hillips
•
Baker Hughes INTEQ
Baker Hughes INTEQ Planning Report
~~^
Company: ConocoPhillips Alaska, Inc ____
Datc: 7/26/2005 "Pimr.
11:01:4$ _--
Pagc 1
Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 15, True North
Site: Pad 16 Vertical (TVDj Reference: Wellhead(95') 95.0
Well: 15
~ Section (VS) Reference: Well (0.OON,O.OOE,285 .OOAzi)
i Wcllpath: PIan3, 1B-15L1 Survey Calculation Method: Mi nimum Curvature llb: Oracle
Field: ~~Kuparuk River Unit
North Slope, Alaska
USA
Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4
Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre
Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004
Site: Pad 1 B
Site Position: Northing: 5970149.71 ft Latitude: 70 19 45.173 N
From: Map Fasting: 550434.96 ft Longitude: 149 35 27.418 W
Position Uncertainty: 0.00 ft North Reference: True
Ground Level: 0.00 ft Grid Convergence: 0.39 deg
We11: 15 Slot Name:
Well Position: +N/-S -502.71 ft Northing: 5969643.84 ft Latitude: 70 19 40.229 N
+E/-W -479.82 ft Fasting : 549958.57 ft Longitude: 149 35 41.425 W
Position Uncertainty: 0.00 ft
Wellpath: PIan3, 1 B-15L1 Drilled From: 1 B-15A
Tie-on Depth: 8270.12 ft
Current Datum: Wellhead(95') Height 95.00 ft Above System Datum: Mean Sea Level
Magnetic Data: 7/22/2005 DectinaNon: 24.24 deg
Field Strength: 57606 nT Mag Dip Angle: 80.77 deg
Vertical Section: Depth From (TVD) +N!-S +E/-W Direction
ft ft ft deg
0.00 0.00 0.00 285.00
Plan: Plan #3 Date Composed: 7/22/2005
Copy Lamar's Plan#3 Version: 1
Principal: Yes Tied-to: From: Definitive Path
Targets
-
--
--
Map - Map <--- Latitude ---> <--- Longitude --->
Name Description TVll +N/-S +E/-R' Northing Fasting Deg Min Sec Deg Min Sec
Uip. Dir. ft ft ft ft ft
16-15L1 Polygon
95.00
-2062.41
-3555.73 5967558.00 546417.00 -
70 19 19.937 N _
149 37 25.198 W
-Polygon 1 95.00 -2062.41 -3555.73 5967558.00 546417.00 70 19 19.937 N 149 37 25.198 W
-Polygon 2 95.00 -2320.98 -2874.37 5967304.00 547100.00 70 19 17.397 N 149 37 5.310 W
-Polygon 3 95.00 -2551.15 -2851.90 5967074.00 547124.00 70 19 15.133 N 149 37 4.651 W
-Polygon 4 95.00 -2549.30 -3129.92 5967074.00 546846.00 70 19 15.150 N 149 37 12.765 W
-Polygon 5 95.00 -2347.32 -3573.62 5967273.00 546401.00 70 19 17.135 N 149 37 25.716 W
-Polygon 6 95.00 -2314.52 -3843.44 5967304.00 546131.00 70 19 17.456 N 149 37 33.591 W
-Polygon 7 95.00 -2111.91 -4382.15 5967503.00 545591.00 70 19 19.446 N 149 37 49.316 W
-Polygon 8 95.00 -1739.52 -4284.66 5967876.00 545686.00 70 19 23.109 N 149 37 46.477 W
-Polygon 9 95.00 -2003.97 -3921.38 5967614.00 546051.00 70 19 20.510 N 149 37 35.870 W
16-15L1 Faultl 95.00 -1192.64 -4857.09 5968419.00 545110.00 70 19 28.484 N 149 38 3.194 W
-Polygon 1 95.00 -1192.64 -4857.09 5968419.00 545110.00 70 19 28.484 N 149 38 3.194 W
-Polygon 2 95.00 -1155.49 -4278.77 5968460.00 545688.00 70 19 28.853 N 149 37 46.315 W
-Polygon 3 95.00 -1317.51 -3827.80 5968301.00 546140.00 70 19 27.262 N 149 37 33.149 W
-Polygon 4 95.00 -1603.98 -3611.68 5968016.00 546358.00 70 19 24.445 N 149 37 26.837 W
-Polygon 5 95.00 -1647.93 -3168.92 5967975.00 546801.00 70 19 24.015 N 149 37 13.914 W
-Polygon 6 95.00 -1884.57 -2927.47 5967740.00 547044.00 70 19 21.689 N 149 37 6.864 W
-Polygon 7 95.00 -1903.36 -2659.56 5967723.00 547312.00 70 19 21.505 N 149 36 59.045 W
-Polygon 8 95.00 -2064.49 -2342.59 5967564.00 547630.00 70 19 19.921 N 149 36 49.793 W
-Polygon 9 95.00 -2090.89 -2132.75 5967539.00 547840.00 70 19 19.662 N 149 36 43.668 W
-Polygon 10 95.00 -2490.88 -1239.30 5967145.00 548736.00 70 19 15.730 N 149 36 17.592 W
-Polygon 11 95.00 -2827.91 -940.51 5966810.00 549037.00 70 19 12.416 N 149 36 8.871 W
-Polygon 12 95.00 -3402.58 -249.25 5966240.00 549732.00 70 19 6.765 N 149 35 48.698 W
1 B-15L1 Fault 2 95.00 -1029.71 -3941.90 5968588.00 546024.00 70 19 30.091 N 149 37 36.484 W
-Polygon 1 95.00 -1029.71 -3941.90 5968588.00 546024.00 70 19 30.091 N 149 37 36.484 W
-Polygon 2 95.00 -1351.54 -3974.04 5968266.00 545994.00 70 19 26.926 N 149 37 37.417 W
y,, • •
Convcol~hi{lips Baker Hughes INTEQ
Baker Hughes INTEQ Planning Report
~~~
I~
iNT'tJt~
Company: ConocoPhillips Alaska, Inc Dace:
' 7/26/2005 Time: 11:01.48 Page: 2
Rield: Kuparuk Ri
Site: Pad 1B ver Unit Co-ordinate(NF) Reference: Well: 15, True North
Vertical (TVD) 12efercnce: Wellhead(95') 95.0
Well: 15 Secti on (VS) Reference: W ell (O.OON,O.OOE,285. OOAzi)
Weltpath: PIan3, 1B-15L1 _ Survey Calculation Method: M inimum Curvature llb: Oracle
Targets
Map Map <_-_ Latitude ---> <-- L,ongitudc --->
Vamc Description TVD +~/-S +E!-W 1\orthing Fasting Deg Min Sec Deg Min Sec
llip. Dir, ft ft ft ft ft
-Polygon 3 95.00 -1843.84 -3937.32 5967774.00 546034.00 70 19 22.085 N 149 37 36.337 W
-Polygon 4 95.00 -2130.06 -4060.24 5967487.00 545913.00 70 19 19.269 N 149 37 39.920 W
-Polygon 5 95.00 -2415.27 -4183.15 5967201.00 545792.00 70 19 16.463 N 149 37 43.503 W
-Polygon 6 95.00 -2907.81 -4261.44 5966708.00 545717.00 70 19 11.619 N 149 37 45.779 W
-Polygon 7 95.00 -3399.35 -4339.72 5966216.00 545642.00 70 19 6.784 N 149 37 48.056 W
1 B-15L1 Target 2 6426.00 -2154.30 -3573.34 5967466.00 546400.00 70 19 19.033 N 149 37 25.710 W
1 B-15L1 Target 3 6439.00 -2059.45 -3999.76 5967558.00 545973.00 70 19 19.964 N 149 37 38.157 W
18-15L1 Target 4 6456.00 -1915.34 -4314.84 5967700.00 545657.00 70 19 21.379 N 149 37 47.354 W
16-15L1 Target 1 6463.00 -2408.90 -3036.97 5967215.00 546938.00 70 19 16.531 N 149 37 10.054 W
Annotation
_.
~1D TVD
ft ft
8270.12 6293.06 TIP
8334.00 6347.60 KOP
8354.00 6364.62 End 9°/ 100' DLS
8583.09 6469.17 End 30°/100' DLS
8839.09 6451.40 5
8894.09 6447.60 6
9044.09 6437.46 7
9194.09 6432.67 8
9294.09 6434.05 9
9669.09 6447.52 10
9975.00 6463.00 TD
Plan Section Information
MD Incl Azim TVll rVl-S +Fl-W DLS Build Turn TFO Target
ft deg deg ft ft ft deg/100ft deg/t00ft deg/100ft deg
8270.12 31.71 231.73 6293.06 -2356.97 -2825.58 0.00 0.00 0.00 0.00
8334.00 31.03 232.02 6347.60 -2377.50 -2851.74 1.09 -1.06 0.45 167.61
8354.00 32.43 234.18 6364.62 -2383.81 -2860.15 9.00 6.99 10.79 40.00
8589.09 94.00 277.01 6469.17 -2409.76 -3052.57 30.00 26.19 18.22 46.00
8839.09 93.97 307.08 6451.40 -2317.22 -3281.06 12.00 -0.01 12.03 89.00
8894.09 93.94 313.70 6447.60 -2281.68 -3322.82 12.00 -0.05 12.03 90.00
9044.09 93.75 295.66 6437.46 -2196.88 -3445.39 12.00 -0.13 -12.03 270.00
9194.09 89.89 278.07 6432.67 -2153.60 -3588.28 12.00 -2.57 -11.73 258.00
9294.09 88.54 266.14 6434.05 -2149.93 -3688.02 12.00 -1.35 -11.93 263.50
9669.09 87.55 311.16 6447.52 -2033.19 -4034.05 12.00 -0.26 12.00 92.00
9975.00 86.84 274.41 6463.00 -1916.87 -4310.91 12.00 -0.23 -12.01 268.00
`~ •
Ccxw~aPhillps Baker Hughes INTEQ
Baker Hughes INTEQ Planning Report
~~
i.~a7 ~c~
i Company: ConocoPhillips Alaska, Inc Date: 7/26/2005 Time: 11:01: 48 Page: 3
~~ Fieid: Kuparuk Riv er Unit Co- ordiuate(NE) R eference: Well: 15, True North
Site: Pad 16 Vertical (TVD) Reference: Wellhead(95') 95.0
Weil: 15 Sec tion (VS) Reference: Well (O.OON,O.OOE,2H5. OOAzi)
Wcllpath: PIa n3, 1B-15L1 Survey Calculation Method: Minimum Curvature 1)b: O racle
Survey
MD iucl Azim SS TVD r!S E:/W 'lfapN ~tapE DLS VS TFO Tool
ft deg deg ft ft ft ft ft deg/100ft ft deg
8270.12 31.71 231.73 6198.06 -2356.97 -2825.58 5967268.33 547149.02 0.00 2119.27 0.00 MWD
8275.00 31.66 231.75 6202.22 -2358.56 -2827.59 5967266.73 547147.02 1.09 2120.80 167.61 MWD
8300.00 31.39 231.86 6223.53 -2366.64 -2837.86 5967258.58 547136.80 1.09 2128.63 167.59 MWD
8325.00 31.13 231.98 6244.90 -2374.64 -2848.08 5967250.51 547126.65 1.09 2136.43 167.49 MWD
8334.00 31.03 232.02 6252.60 -2377.50 -2851.74 5967247.63 547123.00 1.09 2139.22 167.39 MWD
8350.00 32.15 233.76 6266.23 -2382.56 -2858.42 5967242.53 547116.35 9.00 2144.37 40.00 MWD
8354.00 32.43 234.18 6269.62 -2383.81 -2860.15 5967241.26 547114.64 9.00 2145.71 38.52 MWD
8375.00 37.05 241.71 6286.88 -2390.11 -2870.29 5967234.90 547104.53 30.00 2153.88 46.00 MWD
8400.00 43.04 248.74 6306.02 -2396.79 -2884.90 5967228.13 547089.97 30.00 2166.26 39.81 MWD
8425.00 49.38 254.32 6323.31 -2402.45 -2902.01 5967222.35 547072.91 30.00 2181.32 34.41 MWD
8437.20 52.55 256.66 6331.00 -2404.83 -2911.18 5967219.91 547063.75 30.00 2189.57 30.55 1 B-15L1
8450.00 55.93 258.91 6338.48 -2407.02 -2921.33 5967217.65 547053.62 30.00 2198.81 29.07 MWD
8460.22 58.60 260.54 6344.00 -2408.55 -2929.79 5967216.07 547045.16 29.35 2206.58 27.75 16-15L1
8475.00 62.63 262.83 6351.25 -2410.40 -2942.54 5967214.13 547032.43 30.45 2218.41 26.87 MWD
8498.87 69.12 266.16 6361.00 -2412.47 -2964.21 5967211.92 547010.78 30.00 2238.81 25.74 16-15L1
8500.00 69.43 266.31 6361.40 -2412.54 -2965.26 5967211.84 547009.73 30.00 2239.81 24.38 MWD
8521.87 75.43 269.09 6368.00 -2413.37 -2986.08 5967210.87 546988.91 30.00 2259.71 24.33 16-15L1
8525.00 76.29 269.48 6368.76 -2413.41 -2989.12 5967210.81 546985.88 30.00 2262.63 23.49 MWD
8550.00 83.19 272.47 6373.22 -2412.98 -3013.69 5967211.08 546961.30 30.00 2286.48 23.39 MWD
8575.00 90.10 275.38 6374.68 -2411.27 -3038.58 5967212.62 546936.41 30.00 2310.95 22.86 MWD
8589.09 94.00 277.01 6374.17 -2409.76 -3052.57 5967214.04 546922.41 30.00 2324.87 22.69 MWD
8600.00 94.02 278.32 6373.41 -2408.30 -3063.36 5967215.42 546911.61 12.00 2335.66 89.00 MWD
8625.00 94.07 281.33 6371.65 -2404.05 -3087.93 5967219.51 546887.02 12.00 2360.49 89.09 MWD
8650.00 94.10 284.34 6369.87 -2398.51 -3112.24 5967224.89 546862.67 12.00 2385.41 89.30 MWD
8675.00 94.12 287.34 6368.08 -2391.70 -3136.22 5967231.54 546838.65 12.00 2410.34 89.52 MWD
8700.00 94.13 290.35 6366.28 -2383.65 -3159.82 5967239.43 546815.00 12.00 2435.22 89.73 MWD
8725.00 94.12 293.36 6364.48 -2374.37 -3182.96 5967248.56 546791.80 12.00 2459.97 89.95 MWD
8750.00 94.11 296.37 6362.69 -2363.89 -3205.58 5967258.89 546769.11 12.00 2484.53 90.17 MWD
8775.00 94.08 299.38 6360.90 -2352.23 -3227.62 5967270.40 546747.00 12.00 2508.84 90.38 MWD
8800.00 94.05 302.38 6359.13 -2339.43 -3249.02 5967283.05 546725.51 12.00 2532.82 90.60 MWD
8825.00 94.00 305.39 6357.37 -2325.53 -3269.72 5967296.81 546704.72 12.00 2556.42 90.81 MWD
8839.09 93.97 307.08 6356.40 -2317.22 -3281.06 5967305.05 546693.33 12.00 2569.52 91.02 MWD
8850.00 93.96 308.40 6355.64 -2310.56 -3289.66 5967311.65 546684.68 12.00 2579.56 90.00 MWD
8875.00 93.95 311.40 6353.91 -2294.56 -3308.80 5967327.52 546665.45 12.00 2602.17 90.09 MWD
8894.09 93.94 313.70 6352.60 -2281.68 -3322.82 5967340.30 546651.33 12.00 2619.06 90.30 MWD
8900.00 93.94 312.99 6352.19 -2277.64 -3327.11 5967344.32 546647.02 12.00 2624.25 270.00 MWD
8925.00 93.93 309.98 6350.48 -2261.12 -3345.79 5967360.71 546628.23 12.00 2646.57 269.95 MWD
8950.00 93.91 306.97 6348.77 -2245.60 -3365.32 5967376.10 546608.61 12.00 2669.44 269.74 MWD
8975.00 93.88 303.97 6347.07 -2231.13 -3385.63 5967390.43 546588.20 12.00 2692.81 269.54 MWD
9000.00 93.84 300.96 6345.38 -2217.74 -3406.67 5967403.68 546567.07 12.00 2716.60 269.33 MWD
9025.00 93.79 297.96 6343.72 -2205.47 -3428.39 5967415.80 546545.28 12.00 2740.75 269.13 MWD
9044.09 93.75 295.66 6342.46 -2196.88 -3445.39 5967424.27 546528.22 12.00 2759.39 268.93 MWD
9050.00 93.60 294.96 6342.08 -2194.36 -3450.72 5967426.76 546522.87 12.00 2765.20 258.00 MWD
9075.00 92.97 292.03 6340.65 -2184.41 -3473.61 5967436.56 546499.92 12.00 2789.88 257.96 MWD
9100.00 92.33 289.09 6339.50 -2175.64 -3496.99 5967445.17 546476.49 12.00 2814.73 257.79 MWD
9125.00 91.69 286.16 6338.62 -2168.08 -3520.79 5967452.57 546452.63 12.00 2839.69 257.65 MWD
9150.00 91.04 283.23 6338.03 -2161.74 -3544.97 5967458.75 546428.42 12.00 2864.68 257.55 MWD
9175.00 90.39 280.30 6337.72 -2156.64 -3569.44 5967463.68 546403.92 12.00 2889.63 257.48 MWD
9194.09 89.89 278.07 6337.67 -2153.60 -3588.28 5967466.61 546385.06 12.00 2908.62 257.44 MWD
9200.00 89.81 277.36 6337.69 -2152.80 -3594.14 5967467.36 546379.19 12.00 2914.48 263.50 MWD
9225.00 89.47 274.38 6337.84 -2150.25 -3619.00 5967469.75 546354.32 12.00 2939.16 263.50 MWD
9250.00 89.13 271.40 6338.15 -2148.99 -3643.97 5967470.85 546329.35 12.00 2963.60 263.52 MWD
9275.00 88.79 268.42 6338.60 -2149.03 -3668.96 5967470.64 546304.36 12.00 2987.73 263.56 MWD
Con~~r~hilhps Baker Hughes INTEQ ~ '~~
Baker Hughes INTEQ Planning Report ,~;:z-~~----
Company: ConocoPhillips Alaska, Inc Date: 7/26/2005 Time: 11:01:48 Page: 4
Field: Kuparuk River Unit Co-ordinate(VE) Re ference. Well: 15, Tr ue North
Site: Pa d 1B Verti cal (TW) Refe rence: Wellhead(9 5') 95.0
Well: 15 Sectio n (VS) Referen ce: Well (O.OON ,O.OOE,285. OOAzi)
Wcllpath: PIa n3, 1B-1 5L1 Surve y Calculation Method: M inimum C urvature Db: Oracle
Survcv -_ - - u
ND lncl Azim SS "TVD n/S E/V4' MapN MapE llLS VS TFO Tool
ft deg deg ft ft ft ft ft deg/100ft ft deg
9294.09 88.54 266.14 6339.05 -2149.93 -3688.02 5967469.61 546285.30 12.00 3005.91 263.61 MWD
9300.00 88.52 266.85 6339.20 -2150.29 -3693.92 5967469.21 546279.41 12.00 3011.52 92.00 MWD
9325.00 88.41 269.85 6339.87 -2151.01 -3718.90 5967468.32 546254.44 12.00 3035.46 91.98 MWD
9350.00 88.32 272.85 6340.58 -2150.42 -3743.88 5967468.74 546229.46 12.00 3059.74 91.90 MWD
9375.00 88.22 275.85 6341.34 -2148.53 -3768.79 5967470.47 546204.53 12.00 3084.29 91.82 MWD
9400.00 88.14 278.85 6342.13 -2145.33 -3793.57 5967473.50 546179.74 12.00 3109.05 91.73 MWD
9425.00 88.05 281.85 6342.96 -2140.85 -3818.15 5967477.82 546155.13 12.00 3133.96 91.63 MWD
9450.00 87.98 284.85 6343.83 -2135.08 -3842.45 5967483.43 546130.79 12.00 3158.93 91.53 MWD
9475.00 87.90 287.85 6344.73 -2128.04 -3866.42 5967490.30 546106.78 12.00 3183.90 91.43 MWD
9500.00 87.84 290.85 6345.65 -2119.77 -3889.99 5967498.42 546083.15 12.00 3208.81 91.32 MWD
9525.00 87.78 293.85 6346.61 -2110.27 -3913.09 5967507.77 546059.99 12.00 3233.58 91.21 MWD
9550.00 87.72 296.86 6347.59 -2099.57 -3935.67 5967518.31 546037.35 12.00 3258.15 91.09 MWD
9575.00 87.68 299.86 6348.60 -2087.71 -3957.65 5967530.03 546015.30 12.00 3282.45 90.97 MWD
9600.00 87.63 302.86 6349.62 -2074.71 -3978.97 5967542.88 545993.88 12.00 3306.42 90.85 MWD
9625.00 87.60 305.86 6350.66 -2060.61 -3999.59 5967556.84 545973.18 12.00 3329.98 90.73 MWD
9650.00 87.57 308.87 6351.71 -2045.46 -4019.44 5967571.86 545953.23 12.00 3353.08 90.61 MWD
9669.09 87.55 311.16 6352.52 -2033.19 -4034.05 5967584.02 545938.54 12.00 3370.36 90.48 MWD
9675.00 87.53 310.45 6352.78 -2029.34 -4038.52 5967587.85 545934.05 12.00 3375.68 268.00 MWD
9700.00 87.43 307.45 6353.88 -2013.64 -4057.94 5967603.42 545914.52 12.00 3398.50 268.03 MWD
9725.00 87.34 304.45 6355.02 -1998.98 -4078.16 5967617.94 545894.21 12.00 3421.82 268.16 MWD
9750.00 87.25 301.44 6356.20 -1985.40 -4099.11 5967631.38 545873.17 12.00 3445.58 268.30 MWD
9775.00 87.17 298.44 6357.41 -1972.94 -4120.74 5967643.70 545851.45 12.00 3469.70 268.44 MWD
9800.00 87.10 295.44 6358.66 -1961.63 -4143.00 5967654.86 545829.12 12.00 3494.13 268.59 MWD
9825.00 87.04 292.43 6359.94 -1951.50 -4165.82 5967664.83 545806.24 12.00 3518.79 268.74 MWD
9850.00 86.99 289.43 6361.24 -1942.58 -4189.13 5967673.60 545782.87 12.00 3543.62 268.89 MWD
9875.00 86.94 286.43 6362.56 -1934.90 -4212.88 5967681.12 545759.07 12.00 3568.55 269.05 MWD
9900.00 86.90 283.42 6363.91 -1928.47 -4237.00 5967687.39 545734.91 12.00 3593.51 269.21 MWD
9925.00 86.88 280.42 6365.26 -1923.31 -4261.43 5967692.38 545710.46 12.00 3618.43 269.37 MWD
9950.00 86.86 277.41 6366.63 -1919.44 -4286.08 5967696.09 545685.78 12.00 3643.25 269.53 MWD
~" 9975.00 86.84 274.41 6368.00 ~ -1916.87 -4310.91 5967698.49 545660.94 12.00 3667.90 269.69 MWD
BP Amoco
weuv.TN Dn.aa
n.•a, ~r~s~i
TM °n MDR
n.r. D•wm~ wa•naapa~l ».oa~
v a..e~. oMp° onyn s°.nmD._
LEGEND
~~ _ T
Azimuths to True North
° Plan: Plan p3 (15/PIan3. 1B-15L1)
~ - 15 ~iB-15A) M MagnetlC North: 24.24 Createtl By: BIII Mkhaelson Date: 7/28/2005
111 15 (PIan3, iB-t SL2)
~~~~ ~
''
'iiVii"'fff111 (''ti zo 11 B-aul
- PIan3, t8-15Lt Magnetic Fleld
Slfen
the 57606nT
Cor,;aC!Informa;for
f - Plan M3 g
Dip Angle: 80.77° BIII Michaelson
Duea- (907) 267.6624
(~
•~Y Date: 7/22/2005 CeIP (907)301-7 3 570
i Model: bggm2004 E-maiP bill.michaelson~inteq.com
•
•
PM
Vertical Section at 285.00° [50ft/in]
•
Kuparuk DOBCTD BOP configuration
2" CT
Well 1 B-15A Rig Floor
0
0 ~
Tree Size
2
KB
Flow Tee I I d" '~j
1 --
SSV
Master Valve
Base Flan e
Page 1
•
•
TRANSMITAL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME ~~~~ l~ ~ S'~/ L` /
PTD# ~~-~~ ' ~~
CHECK WHAT ADD-ONS "CLUE"
APPLIES (OPTIONS)
MULTI The permit is for a new wellbore segment of
`
`
~
D ~ ~~ ~'
/
LATERAL tom ° 1~
/
~
~
existing well ~~%~l-[
Permit No, ZU~-~s ~ API No.~C~ ~-Z2'
(If API number Production should continue to be reported as
last two (2) digits a function of the original API number stated
are between 60-69) above.
PILOT HOLE In accordance with 20 AAC 25.005(f), all
(PIT) records, data and logs acquired for the pilot
hole must be clearly differentiated in both
name (name on permit plus ~ PH)
and API number (50 -
70/80) from records, data and logs acquired
for well (name on permit).
SPACING The permit is approved subject to full
EXCEPTION compliance with 20 AAC 25.055. Approval to
perforate and produce/infect is contingent
upon issuance of a conservation order
approving a spacing exception.
(Company Name) assumes
the liability of any protest to the spacing
exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the
SAMPLE Commission must be in no greater than 30'
sample intervals from below the permafrost
or from where samples are first caught and
10' sample intervals through target zones.
.~-
mss`-
Rev: 04/01/05
C\jody\transmittal_checklist
WEL PERMIT CHECKLIST Field 8 Pool KUPARUK RIVER, KUPARUK RVOIL -490100 Well Name: KUPARUK RIV UNIT 1B-15AL1 Program DEV Well bare seg ^~
PTD#:2051140 Company CONOCOPHILLIPS ALASKA INC Initial Classffype DEV I PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^
Administration 1 Pe[mit_feeattached-------------------------------------- ------NA_-___- -_Multilateral_wellbor_e; feewaiyed_pet20-AAC25.004(e)______________________
2 Lease number appropriate- - - - - - - - - Yes - - - - - - - - -
3 Uniquewell_nameandnumber------------ --- -------------- -- -Yes----- - -- ---------- - --- ----------- -- ---------- --- -- --- -- -- ---
4 Well located ina_defined_pool____________________---_--_-___ ______-Yes_--__ -_Kupa[ukRiverOil_Pool, governed byConseryationOrderNo.432C__-___--________________
5 Well located proper distance-from drilling unit_boundary_ - - - _ .... - . - Yes _ .. - - - .Conservation Order No. 4320 contains no spacing restrictions with respect to drilling unit boundaries. - -
6 Well located proper distance_ f[o_m other wells_ - - _ - - _ _ - - _ - - - Yes Conservation Order No. 4320 has_no interwell_spaeing-restrictions, - _ - - _ - _
-- - - --
7 Sufficient acreage ayailabl~ in-drilling unit_ _ _ - - - Yes _ _ _ _ _ _ -Conservation Order No. 4320 has no interwell spacingrestr_ictions, Wellbore_will be_more than 500' from - -
8 If deviated, is-wellbore plat_included _ - _ - _ - _ - _ - - - .. - - - Yes an_ external property line where ownership or_lan_downersh~ changes. . . . . . . .. . . . . . .. . . . . . .. .
9 Ope[ator Only affected party - - - - - - - Yes - - - - - - - - - -
10 Ope[atorhas-appropriate.bondinforre-------------------------- -- -~--Yes ---- ------ --------- ----- --------- ------ ----- ------------------- --
11 Permit can be issued without conservation order Yes
Appr Date 12 Permit_eanbeissuedwithoutadministrative_approval__________________ _______Yes___-_ ______--..--.-..--___-___--__-
SFD 7!2812005 13 Can permit be approved before 15-day wait Yes
14 Well located within area and strataauthonzedbylnjectionOrde[#(putl9#in_comm ents)-(For_ NA------ -------_--____---_--__-__-.-_..---..------_._-_-__--_-____--_--.
15 Allwells_within114_milearea_ofreyiewidentified(Forservicewellonly)________ _______NA______ .____.________,-__--________..-.-_.
16 Pre-produced injector; duration_of preproduction less than 3 months-(For_service well only) - - NA_ - _ _ _ - - _ _ -
----------------------------------------------------
17 ACMP-Finding of Consistency-has been issued_for_this project- - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ _ Multilate[alwell branch of existing well. _ _ _ _ - _ _ - - _ - - - - - , _ - _ _ _ - . - - - , _ - _ - - - _ _ - - - _ _ - - - -
Engineering 18 Conductor string_p_rovided_______________________________-_ _______ NA---__ __Conduetorset_inoriginal_well,l_B-15_(194-051).-__.-_------_--__-,__________________--
19 Surface casing_proteetsallknown-USDWs________ ______________ _______ NA-_--_- -_Allaquifersexempted,40CFR_147.102(b)(3).--_-------.-.-.----.-_- _--___-__--__._-
20 CMT.vol-adequ_ate_tocirculate_onconductor_&su__rf_csg__________________ ______ NA______ __Surfacecasingsetin_1_B-t5,______-_-..-..-._-.---...--.--_-____-_...
21 CMT vol_adequate-to tie-in long string to surf csg_ - _ _ - - - - - - _ - NA_ - - _ _ - . _ 7" csg not cemented_into 9-518" csg_ 5.112" liner fully cemented in 16-15A (204-256)_
22 CMT will coverall known-productive horizons_ - ... - - . . - No_ Slotted liner completion planned, _ - . _
- - ---
23 Casing designs adequate for C, T, B &-permaf[ost_ NA_ Only slotked liner will be run_inrhis-lateral, True casingstrings comply with regulations .. . . . . . .. . . . ..... .
24 Adequate tankage-or reserve pit - - -- - - - - - - - - - Yes .. - - . . -Rig is-equipped with st_eel_pits. No reserve_pitplanned, All waste to approved disposatwells._
25 If a-re-drill, has_a_ t0-403 for abandonment been approved NA_
26 Adequate wellbore separationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ _ Proximity analysis performed: Close approaches identified._ All segments in reservoir. No collision issues._ _ - - -
27 Ifdiverterrequired,doesitmeetregulations------------------------ ------- NA_---_- -_BOPStack_willalready_beinplace,_____---_--._-._--__-------_____________
Appr Date 28 Drilling fluid-program schematic & equip listadequate_ _ - . _ - .. _ _ - Yes - . - - - ..Maximum expected formation pressure 13.3 EMW.- Plan to use dynamic overbalance and_10,0_ppg mud._ -
TE 7!2912005 29 BOPEs, do they meet_ regulation - - _ - _ _ - - - Yes 2 hole volumes ofkill-weight fluid_will be available on location for contingencies_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
/~
~ 30 BOPS-press rating appropriate; test to-(put prig in comments)_ - Yes _ - _ _ - - - MA$P calculated up to 3740 psi.- 4000psi BOP-test planned,
~r 31 _C_hoke.manifold complieswlAPI-RP-53 (M_ay $4) - - - - - - Yes - - - - - -
32 Work willoccurwithoutoperationshutdown_________________________ ___ __Yes_--__ ---_____________-___-__--____---_----_______________
-----------------
33 Is presence. of H2S gas probable - - - - - - -- - - - - - - - - - - - - - Yes _ - - _ _ - H2S is reported_al 1 B pad. Mud should preclude H2S on rig. Rig has_sensors_and alarms.
34 Mechanical condition of wells withinAORyerified(For_servicewellonly)________ ______NA______ ___--__--__--______-_-_______________-__-__--__---_-.--_-__-__---_-.-
Geology 35 Permit_ean be issued wlo hydrogen_s_ulfide measures - - .. - - .. - - . - No_ _ - - _ _ - - KRU 1 B-15 measured 120 ppm H2$ on_ $!3012004-- - - - - - - - - - - -
36 Data_presented on_ potential overpressure zones _ _ - . ... - -Yes - Expected reservoirpressure is 13.3 ppg EMW; will be drilled with coiled-tubing-and 10 ppgmud_ - - _ _ - - - - _ - -
Appr Date 37 Seismic analysis ofshallow gas_zones- - - - - - - -- - - - - - - - NA_ _ _ _ _ - -using overbalanced pressu[e,drillingtechniques, $FD - - - -
------------------------
SFD 7128/2005 38 Seabed condition survey_(if off-shore) - - NA_
39 _ Contact namelphone_for weekly progress_reports [exploratory only]- _ NA_ _ _ _
Geologic
Commissioner: Engineering P '
Date: Commissione : Date Co issio
Date
~~"~ ~~/ Z~ 7-29-05
/U ~~ ~~
•
Well History File
APPENDIX
Information of detailed nature that is not
particularly germane to the Welf Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simpiify finding information, infiormation of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
r~
**** REEL HEADER ****
MWD
06/11/22
BHI
01
LIS Customer Format Tape
•
RECEivEa
**** TAPE HEADER ****
MWD
05/Q9/27
982397
01
2.375" CTK
*** LIS COMMENT RECORD ***
DEC ~ ~ 2406
AIBS~ OI) & G8S CODS. COD1D11$S~Ol1
~~
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
!!!!!!!!!!!!!!!!!!! Extract File: ldwg.las
Version Information
VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20
WRAP. NO: One line per frame
Well Information Block
#MNEM.UNIT Data Type Information
STRT.FT 8347.0000: Starting Depth
STOP.FT 9731.0000: Ending Depth
STEP.FT 0.5000: Level Spacing
NULL. -999.2500: Absent Value
COMP. COMPANY: ConocoPhillips Alaska, Inc.
WELL. WELL: 1B-15AL1
FLD FIELD: Kuparuk River Unit
LOC LOCATION: 70 deg 19' 40.229"N 149 deg 35' 41.425"W
CNTY. COUNTY: North Slope Borough
STAT. STATE: Alaska
SRVC. SERVICE COMPANY: Baker Hughes INTEQ
TOOL. TOOL NAME & TYPE: 2.375" CTK
DATE. LOG DATE: 27-Sep-05
API API NYUMBER: 500292246560
Parameter Information Block
#MNEM.UNIT Value Description
------------------ -------------
SECT. 09 Section
TOWN.N 11N Township
RANG. l0E Range
PDAT. MSL Permanent Datum
EPD .F 0 Elevation Of Perm. Datum
LMF RKB Log Measured from
FAPD.F 95 Feet Above Perm. Datum
DMF KB Drilling Measured From
EKB .F 95 Elevation of Kelly Bushing
EDF .F N/A Elevation of Derrick Floor
EGL .F 0 Elevation of Ground Level
CASE.F N/A Casing Depth
OS1 DIRECTIONAL Other Services Line 1
Remarks
~Ou -~I4~ ~ J~(~1
•
(1) All depths. are Measured Depths (MD) unless otherwise noted.
(2) All depths are Bit Depths unless otherwise noted.
(3) All Gamma Ray data (GRAX) presented is realtime data.
(4) Baker Hughes INTEQ utilized CoilTrak downhole tools and the
advantage surface system to log this well.
(5) Tools ran in the string included Casing Collar Locator, an
Electrical Disconnect and Circulating Sub, a Drilling Performance
Sub (Inner and Outer Downhole Pressure and Downhole Weight on
Bit),
a Directional and Gamma Sub, Ultra Slim Resistivity Sub and a
Hydraulic
Orienting Sub with a Near Bit Inclination Sensor.
(6) Data presented here is final and has not been depth adjusted to a
PDC (Primary
Depth Control)log. The INTEQ MWD Gamma Ray is the PDC for this
wellbore.
(7) The sidetrack was drilled from 1B-15A through a milled window in
3 1/2" liner.
Top of Window 8340 ft.MD (6257.7 ft.SSTVD)
Bottom of Window 8347 ft.MD (6263.6 ft.SSTVD)
(8) The interval from 9707 ft.to 9731 ft.MD (6361.7 ft.to 6362.0
ft.S5TVD) was not
logged due to sensor bit offset at TD.
(9) Tied to 1B-15A at 8208 ft.MD (6145.9 ft.SSTVD)
MNEMONICS:
GRAX -> Gamma Ray MWD-AAPI [MWD] (MWD-API units)
ROPS -> Rate of Penetration, feet/hour
TVD -> Subsea True Vertical Depth, feet
Tape Subfile: 1
Minimum record length:
Maximum record length:
**** FILE HEADER ****
MWD .001
1024
63 records...
14 bytes
132 bytes
*** INFORMATION TABLE: CONS
MNEM VALU
----------------------------------
WDFN 1B-15AL1 5.xtf
LCC 150
CN ConocoPhillips Alaska Inc.
WN 1B-15AL1,
FN Kuparuk River Unit
COUN North Slope
STAT Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
The data presented here is final and has not been depth shifted
*** INFORMATION TABLE: LIFO
MNEM CHAN DIMT CNAM ODEP
• •
----------------------------------------------------
GR GR GRAX 0.0
ROP ROP ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.500000
Frame spacing units: [F ]
Number of frames per record is: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.500 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Lenqth
1 GR MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 FjHR 4 4
8
Total Data Records: 33
Tape File Start Depth = 834'7.000000
Tape File End Depth = 9730.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 2 42 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** FILE HEADER ****
MWD .002
1024
*** INFORMATION TABLE: CONS
MNEM VALU
--------------------------------
WDFN 1B-15AL1.xtf
LCC 150
CN ConocoPhillips Alaska In
WN 1B-15AL1,
FN Kuparuk River Unit
• •
COUN North Slope
STAT Alaska
*** LIS COMMENT RECORD ***
!!!!!!!!!!!!!!!!!!! Remark File Version 1.000
This file contains the raw-unedited field data.
*** INFORMATION TABLE: CIFO
MNEM CHAN DIMT CNAM ODEP
----------------------------------------------------
GRAX GRAX GRAX 0.0
ROP ROP ROPA 0.0
* FORMAT RECORD (TYPE# 64)
Data record type is: 0
Datum Frame Size is: 12 bytes
Logging direction is down (value= 255)
Optical Log Depth Scale Units: Feet
Frame spacing: 0.250000
Frame spacing units: [F
Number of frames per record is: 84
One depth per frame (value= 0)
Datum Specification Block Sub-type is: 1
FRAME SPACE = 0.250 * F
ONE DEPTH PER FRAME
Tape depth ID: F
2 Curves:
Name Tool Code Samples Units Size Length
1 GRAX MWD 68 1 AAPI 4 4
2 ROP MWD 68 1 F/HR 4 4
8
Total Data Records: 67
Tape File Start Depth = 8329.000000
Tape File End Depth = 9730.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
**** FILE TRAILER ****
Tape Subfile: 3 76 records...
Minimum record length: 54 bytes
Maximum record length: 4124 bytes
**** TAPE TRAILER ****
MG7D
05/09/27
982397
01
• •
**** REEL TRAILER ****
MWD
06/11/22
BHI
01
Tape Subfile: 4 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
• •
Tape Subfile 1 is type: LIS
• •
Tape Subfile 2 is type: LIS
DEPTH GR ROP
8347.0000 95.6000 -999.2500
8347.5000 94.0600 -999.2500
8400.0000 162.7400 27.0300
8500.0000 121.9900 31.1300
8600.0000 72.5400 64.7000
8700.0000 65.6200 57.1800
8800.0000 123.0200 23.4300
8900.0000 33.5900 12.3100
9000.0000 84.5800 42.1600
9100.0000 126.8600 45.8600
9200.0000 48.9600 37.9500
9300.0000 33.5900 50.0000
9400.0000 118.4100 24.6800
9500.0000 68.9500 67.1600
9600.0000 90.9900 71.8100
9700.0000 164.5300 46.6200
9730.0000 -999.2500 -999.2500
Tape File Start Depth = 8347.000000
Tape File End Depth = 9730.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = feet
• •
Tape Subfile 3 is type: LIS
DEPTH GRAX ROP
8329.0000 55.1100 -999.2500
8329.2500 55.1100 -999.2500
8400.0000 162.7400 27.0300
8500.0000 121.9900 31.1300
8600.0000 72.5400 64.7000
8700.0000 65.6200 57.1800
8800.0000 123.0200 23.4300
8900.0000 33.5900 12.3100
9000.0000 84.5800 42.1600
9100.0000 126.8600 45.8600
9200.0000 48.9600 37.9500
9300.0000 33.5900 50.0000
9400.0000 118.4100 24.6800
9500.0000 68.9500 67.1600
9600.0000 90.9900 71.8100
9700.0000 164.5300 46.6200
9730.0000 -999.2500 -999.2500
Tape File Start Depth = 8329.000000
Tape File End Depth = 9730.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = feet
• •
Tape Subfile 4 is type: LIS
