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Alaska Oil and Gas Conservation Commission
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. STATE OF ALASKA I
ALAS~IL AND GAS CONSERVATION COM SSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
.
1a. Well Status: 0 Oil 0 Gas 0 Plugged ~ Abandoned 0 Suspended 0 WAG
20MC25.105 20MC25.110
o GINJ 0 WINJ 0 WDSPL No. of Completions
2. Operator Name:
BP Exploration (Alaska) Inc.
3. Address:
P.O. Box 196612, Anchorage, Alaska 99519-6612
4a. Location of Well (Governmental Section):
Surface:
1383' FSL, 900' FEL, SEC. 36, T12N, R15E, UM
Top of Productive Horizon:
1938' FSL, 4441' FEL, SEC. 25, T12N, R15E, UM
Total Depth:
2094' FSL, 4552' FEL, SEC. 25, T12N, R15E, UM
4b. Location of Well (State Base Plane Coordinates):
Surface: x- 721661 y- 5979921 Zone- ASP4
TPI: x- 717948 y- 5985650 Zone- ASP4
Total Depth: x- 717833 y- 5985803 Zone- ASP4
18. Directional Survey 0 Yes ~ No
Zero Other
5. Date Comp., Susp., or Aband.
3/23/2006
6. Date Spudded
06/27/1998
7. Date ToO. Reached
07/10/1998
8. KB Elevation (ft):
59.4'
9. Plug Back Depth (MD+ TVD)
12251 + 9576
10. Total Depth (MD+TVD)
12365 + 9684
11. Depth where SSSV set
NIA MD
19. Water depth, if offshore
NIA MSL
22.
,
, ',SIZE' '
20"
9-5/8"
7"
21. Logs Run:
US IT I Gyro, LID MWD, LDC, CDL-CNL-GR, GR I JB I GR I CCL
l ASING, LINER AND CEMENTING KECORD
__ _ _ _ I' _ <:>1: I vETTING UEPTH TVD HOLE,
, .. "''' r I . T OF ItsOTTOM I OP tsoTTOM , SIZE
42' 115' 42' 115' 30"
40' 6196' 40' 5102' 12-1/4"
38' 12351' 38' 9671' 8-1/2"
94#
47#
29#
H-40
L-80
L-80
23. Perforations oRen to Production (MD + TVD of Top and
Bottom Interval, Size and Number; if none, state "none"):
None
MD
TVD
MD
~C~i\NNED
1 b. Well Class:
~ Development 0 Exploratory
o Stratigraphic 0 Service
12. Permit to Drill Number
198-114 306-081
13. API Number
50- 029-22893-00-00
14. Well Name and Number:
PBU NK-61
15. Field I Pool(s):
Prudhoe Bay Field I Niakuk Pool
Ft
Ft
16. Property Designation:
ADL 034630
17. Land Use Permit:
PRODUCTION TEST
Method of Operation (Flowing, Gas Lift, etc.):
NIA
OIL-BBL GAs-McF WATER-BBL
OIL-BBL
None
20. Thickness of Permafrost
1800' (Approx.)
. ~' , "
,
260 sx Arctic Sett~pprox.)
2410 sx PF 'E', 410 sx Class 'G'
275 sx Class 'G'
124". ' ','"T
SIZE
3-1/2", 9.3#, L-80
TVD
I
, '..
DEPTH SET (MD) PACKER SET (MD)
11621' 11574'
"
125.' - ,
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
11605' P&A & Kick Off Plug wI 29 Bbls of Cement
GAs-McF
W A TER-BBL
26.
Date First Production:
Not on Production
Date of Test Hours Tested PRODUCTION FOR
TEST PERIOD ..
Flow Tubing Casing Pressure CALCULATED ..
Press. 24-HoUR RATE
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".
CHOKE SIZE
GAS-OIL RATIO
OIL GRAVITy-API (CORR)
R8DMS 8Ft MAY .3 I) 7U06
Form 10-407 Revised 12/2003 0 RIG I f\fJ't't~ED ON REVERSE SIDE
&
2&.
GEOLOGIC MARKE
29.
FORMATION TESTS
NAME
MD
TVD
Include and briefly summarize test results. List intervals tested,
and attach detailed supporting data as necessary. If no tests
were conducted, state "None".
HRZ
11522'
8898'
None
Kuparuk
11803'
9156'
Kingak
12064'
9400'
30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports
31. I ~erebY certify that the f0r;90i:9 is true and correct to the best of my knowledge.
Signed Terrie Hubble 1"1/7 II Title Technical Assistant
PBU NK-61
Well Number
198-114 306-081
Permit No. I Approval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in
Alaska.
Prepared By Name/Number:
Drilling Engineer:
Terrie Hubble, 564-4628
Sean McLaughlin, 564-4387
ITEM 1a: 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.
ITEM 4b: TPI (Top of Producing Interval).
ITEM 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).
ITEM 20: True vertical thickness.
ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the
cementing tool.
ITEM 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).
ITEM 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
e
e
NK-61A
Prudhoe Bay Unit
50-029-22893-01
206-035
Accept:
Spud:
Release:
Ri:
PRE-RIG WORK
02125/06
RIH W/2.25" CENT I DUAL PETREDAT GAUGES. TAG TD AT 11,900' SLM, 11' OF FILL.
03/06/06
DRIFT WI 2.70 CENT AND S-BAILER TO 11,944' (CORRECTED DEPTH), 11 FEET OF RATHOLE. NO
SAMPLE RECOVERED. CALIPER TUBING FROM 11,910' SLM TO SURFACE, GOOD DATA EXCEPT FOR 271'
SECTION FROM 8549' - 8820' SLM.
03/07/06
PULLED LGLV'S AND SET DGLV'S AT STA # 1 - 11,502', STA # 3 - 10,100', STA # 4 - 7974', AND STA # 5-
3854' SLM. PULLED EMPTY CS FROM 11, 571' SLM.
03/23/06
BHA FOR CEMENT JOB. RIH WI 2.3" BDN TO TD OF 11,932' CTMD, CORRECT TO TD. FLAG 10' OFF BTM.
CONFIRM IA IS FLUID PACKED. KILL WELL WITH 260 BBLS OF 1% KCL, 50 BBLS DIESEL. PUMP KCL
ACROSS PERFS. PUMP 29 BBLS 17# CEMENT FROM 11934'. PARK AT 11750', GET BUMP. LAY IN
REMAINING CEMENT. BUMP PLUG TO +500 PSI AT SAFETY. HOLD 30 MIN'S. BUMP TO +850 PSI, HOLD 5
MIN'S, GOOD. CONTAMINATE/CLEANOUTTO 11605'. MAKE REPEAT JETTING PASS UP.
03/24/06
JET OUT CONTAMINATED CEMENT UP TO 9600', REPEAT JET TO TARGET DEPTH OF 11605'. CHASE OUT
W/ XS KCL, MAKING SLOW REPEATS ACROSS ALL JEWELRY/GLM'S. FREEZE PROTECT FROM 2500' WI
WATERlMETH. RE-PT PLUG TO 2000 PSI (+1000) AT SURFACE FOR 30 MIN'S. RDMO.
,
BP EXPLORATION Page 1 .-
Operations Summary Report
Legal Well Name: NK-61
Common Well Name: NK-61 Spud Date: 6/28/1998
Event Name: REENTER+COMPLETE Start: 3/28/2006 End: 4/14/2006
Contractor Name: NORDIC CALISTA Rig Release: 4/14/2006
Rig Name: NORDIC 1 Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
3/28/2006 13:00 - 13:30 0.50 MOB P PRE Held pre-rig move safety meeting with Security, Nordic and
SWS personnel. Reviewed rig move plan, hazards and
mitigation.
13:30 - 00:00 10.50 MOB P PRE Move rig to Oxbow road and to Deadhorse. No problems.
3/29/2006 00:00 - 01 :00 1.00 MOB P PRE Moved rig to SWS shop for reel swap.
01 :00 - 04:00 3.00 MOB P PRE Swap reels with crane. Install 2" reel with 14880' of coil. No
problems.
04:00 - 17:00 13.00 MOB P PRE Move rig from Deadhorse to Niakuk. Good rig move, no
problems.
17:00 - 20:30 3.50 MOB N WAIT PRE Rig at Niakuk. Wait on pad prep. Weld on 2" CT connector.
Rig up 2" reel hardline.
20:30 - 21 :00 0.50 MOB P PRE SAFETY MEETING. Held safety meeting before backing rig
over well. Reviewed procedure, hazards and mitigation for
backing rig over well. Very tight well spacing. Only 6" of
clearance on one side.
21 :00 - 21 :30 0.50 MOB P PRE Back rig over well with no problems.
21 :30 - 23:00 1.50 RIGU P PRE ACCEPT RIG AT 2130 HRS, 03/29/2006.
General rig up. Spot trailers, tanks
23:00 - 00:00 1.00 BOPSUF P PRE NIU BOPE. Change out rams for 2" coil.
3/30/2006 00:00 - 04:00 4.00 BOPSUF P PRE NIU BOPE.
CIO rams for 2" coil.
04:00 - 18:30 14.50 BOPSUF P PRE Pressure I function test BOPE. AOGCC inspecter Chuck
Scheve & BP rep Bob Laule witnessed test.
Repaired 2 choke manifold valves. Repaired blind rams
bonnet.
Filled pits with 290 bbls of 2# Biozan
18:30 - 21 :00 2.50 STWHIP P WEXIT Fill coil with Biozan. Press test inner reel valve. Pump dart.
Dart on seat at 40.1 bbls.
21:00 - 21:15 0.25 STWHIP P WEXIT SAFETY MEETING. Review procedure, hazards and
mitigation for make up of WF milling BHA.
21:15 - 22:45 1.50 STWHIP P WEXIT MIU Pilot milling BHA #1 with 2.74" diamond parabolic mill,
1.75 deg WF motor, Sperry MWD and orienter and WF MHA.
OAL = 46.40'.
Test orienter at surface, 3 of 3 clicks.
22:45 - 00:00 1.25 STWHIP P WEXIT RIH with 2.74" Pilot hole milling BHA. Take returns to cuttings
tank.
3/31/2006 00:00 - 01 :45 1.75 STWHIP P WEXIT RIH with 2.74" pilot mill on a 1.75 deg WF motor.
Tag cement at 11605'. at bottom of tailpipe. 33K up wt. 11K
down wt.
01 :45 - 04:00 2.25 STWHIP P WEXIT Mill Pilot hole in cement. 1.6 bpm, 3320 psi, 20 fph, 4K web,
160R, hard cement.
Milled to 11,645'.
04:00 - 06:00 2.00 STWHIP P WEXIT Mill Pilot hole in cement. 1.6 bpm, 3200 psi, 20 fph, 4K wob,
160R. hard cement.
Milled to 11,670'.
Tied-in with GR while milling ahead. Added 2' to CTD.
06:00 - 12:00 6.00 STWHIP P WEXIT Mill Pilot hole in cement. 1.5 bpm, 3000 psi, 20 fph, 4K wob,
170R, hard cement. Drill to 11790
12:00 - 13:00 1.00 STWHIP P WEXIT Wiper tie-in Correction +1.5'.
13:00 - 13:30 0.50 STWHIP P WEXIT Mill Pilot hole in cement. 1.6 bpm, 3280 psi, 20 fph, 4K web,
175R, hard cement. Drill to 11798
e
PrInted: 4/17/2006 11 :01 :40 AM
·
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BP EXPLORATION
Operations Summary Report
Page 2..
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
NK-61
NK-61
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
Start: 3/28/2006
Rig Release: 4/14/2006
Rig Number:
Spud Date: 6/28/1998
End: 4/14/2006
Date From - To Hours Task Code NPT Phase Description of Operations
3/31/2006 13:30 - 13:45 0.25 STWHIP P WEXIT Orient to 10L
13:45 - 14:30 0.75 STWHIP P WEXIT Mill cement ramp[. 1.7 bpm, 3300 psi, 11 fph, 4K wob, 10 L,
hard cement. Drill to 11806 End of ramp.
14:30 - 17:00 2.50 STWHIP P WEXIT POH.
17:00 - 18:00 1.00 STWHIP P WEXIT LD cement mill and PIU window mill with brass guide ring and
2.5 deg fixed bend WF motor.
18:00 - 20:50 2.83 STWHIP P WEXIT RIH with BHA #2 window milling BHA. Set down on many
collars while RIH. Went thru TRSSSV OK. Circ at 0.2 bpm to
get past collars. RIH to 11780'.
20:50 - 21 :20 0.50 STWHIP P WEXIT Orient TF to 20L. RIH and tag bottom 3 times at 11816'. Pick
up 4 ft off bottom. Start pump at 1.6 bpm. Ease down with 6R
TF. 1.5 bpm, 2800 psi, 7K down wt off bottom.
First motor work at 11814'. Correct depth to 11806'. Flagged
coil at 11806'. Pick up 1 ft as per program.
21 :20 - 00:00 2.67 STWHIP P WEXIT Time mill window as per schedule. 1.6 bpm, 3000 psi, 12R,
Mill for 3 hours to get back to 11806' as per schedule.
4/1/2006 00:00 - 02:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3070 psi, 12R, No
woe.
mill as per time schedule. Milled to 11,807'.
02:00 - 04:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3070 psi, 12R, 1.5k wob,
Mill as per time schedule. Milled to 11,808'.
Getting good metal on ditch magnets.
04:00 - 06:00 2.00 STWHIP P WEXIT Time Milling 2.74" window. 1.6 bpm, 3300 psi, 11 L, 4-5k wob,
Milled to 11,810'. Stacking more weight, but milling off OK.
06:00-11:15 5.25 STWHIP P WEXIT Milling window at 1 FPH. 1.6 bpm, 3020 psi, 6R, 3.5K WOB.
Continue milling to 11811 stacking no MW. PU found bottom
@ 11809. Mill to 11810 seen motor work. Mill open hole to
11820. Make additional pass thru window. Flag pipe EOP
11600'
11:15 -13:00 1.75 STWHIP P WEXIT POH.
13:00 - 14:15 1.25 STWHIP P WEXIT LD window mill and PU window dressing mill. Mill 2.73" Go
2.72". NOGO. Window dressing mill is 2.74" Go 2.73" NOGO.
14:15 - 16:20 2.08 STWHIP P WEXIT RIH with 1.75 degree motor and Weatherford Diamond Crayola
Mill.
16:20 - 17:00 0.67 STWHIP P WEXIT Tie - in to EOP flag at 11600. Correct +10'.Orient to 13R
17:00 - 19:40 2.67 STWHIP P WEXIT RIH wo pump set down 11802. RIH w pump 1.7bpm 3240 psi.
Ream at 16 ftIhr, Stalling in window at 11,806. Time mill at
11802-11807'. Ream down and tag bottom on depth at 11820'.
19:40 - 22:30 2.83 STWHIP P WEXIT Backream up thru window at 7R TF. Ream down at 7R TF.
Orient to 90R and backream up thru window. Stop pump and
RIH clean to bottom. Backream up again while swapping well
to New 9 PPG FloPro.
22:30 - 00:00 1.50 STWHIP P WEXIT POH with reaming BHA.
4/2/2006 00:00 - 00:45 0.75 STWHIP P WEXIT POH with window reaming BHA.
00:45 - 01:15 0.50 STWHIP P WEXIT Layout reaming BHA. Taper mill gauged at 2.74Go, 2.73
no-go.
01:15 - 01:30 0.25 DRILL P PROD1 SAFETY MEETING. Held pre-spud meeting with all personnel.
Reviewed well plan, special considerations for this well,
hazards and mitigation.
01 :30 - 02:30 1.00 DRILL P PROD1 MlU MWD Build BHA #4 with HCC 2.7 x 3.0 Bi-center bit #4
and 2.6 deg BHI Xtreme motor and Sperry MWD with BOT
Printed: 4/17/2006 11 :01:40 AM
, ..
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
Date
4/2/2006
4/3/2006
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Page 3 ,..,
BP EXPLORATION
Operations Summary Report
NK-61
NK-61
REENTER+COMPLETE
NORDIC CALISTA
NORDIC 1
From - To Hours Task Code NPT Phase
01 :30 - 02:30
02:30 - 05:30
05:30 - 06:00
06:00 - 06:30
06:30 - 07:30
18:25 - 18:50
18:50 - 20:30
20:30 - 21 :30
21 :30 - 23:15
23:15 - 23:50
23:50 - 00:00
00:00 - 02:00
02:00 - 02:25
02:25 - 02:45
02:45 - 04:00
04:00 - 06:00
06:00 - 09:00
09:00 - 11 :25
11 :25 - 12:25
18:30 - 19:50
1.00 DRILL P
3.00 DRILL P
0.50 DRILL P
0.50 DRILL P
1.00 DRILL P
2.00 DRILL N
1.00 DRILL N
2.25 DRILL N
0.25 DRILL P
1.75 DRILL
0.58 DRILL
0.17 DRILL P
2.00 DRILL P
0.42 DRILL P
0.33 DRILL P
1.25 DRILL P
2.00 DRILL
1.58 DRILL P
2.00 DRILL P
0.50 DRILL P
2.00 DRILL P
1.33 DRILL P
PROD1
PROD1
PROD1
PROD1
PROD1
DFAL PROD1
DFAL PROD1
DFAL PROD1
PROD 1
P
P
P
P
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
PROD1
Start: 3/28/2006
Rig Release: 4/14/2006
Rig Number:
Spud Date: 6/28/1998
End: 4/14/2006
Description of Operations
MHA. OAL = 59.92'.
RIH with Build BHA #4. SHT tools OK. RIH clean to 11760'.
Orient TF to highside.
RIH clean thru window. Tag bottom at 11826'. Correct depth
to 11820'.
Drilling Build section in Kuparuk sand. 1. bpm,
TF.
Sperry pulses failed, drill ahead to see if they start again.
Drilled 3' pulser working. Orient to compensate for 80 d rees
of reactive torque. PU to 11766. Pulser wor1<ing agai . RIH .25
bpm. RIH to 11820 1.8 bpm MWD failed.
POH for MWD failure.
Change out MWP probe. Bit in new conditio .
RIH Shallow hole test at 800' OK. Con tin to RIH. 11780.
Orient 24R. RIH .3 bpm @ 1300 psi. gat 11832 corrected
11823.
Drill build section thru the Kupa
3300psi, 5200#WOB.
PIU and orient TF to 70L.
Drill build section, 1.5 pm, 3000 psi, 27L, 20 fph, 65 deg
incl, Drilled to 1192 .
Drill build sectio 1.55 bpm, 3000 psi, 27L, 30 fph, 80 deg
incl, Drilled to 1940'.
POH for la al BHA. Flag Coil at 11760' EOP. POH.
Adjust tor to 0.8 deg bend. CIO Bit, Bit#5 had 2 broken
cutte and 2 plugged jets.
M HCC BC Bit #6. Check motor and CTC.
IH with MWD Lateral BHA #6 with 0.8 deg motor and Bit #6.
RIH with Lateral BHA with 0.8 deg motor. Corrected to flag at
11700' EOP. Added 15 ft.
RIH clean thru window and clean to bottom. Tag bottom at
11942' and corrected depth to 11940'.
'ent TF to 30L.
Dri . g lateral in Kuparuk sand, 1.6 bpm, 3100 psi, 35L, 35
fph, 8 deg incl, Drilled to 11980'.
Drilling la ral in Kuparuk sand, 1.6 bpm, 3100 psi, 35L, 50
fph, 89 deg' cI, Drilled to 12,070'.
Drilling lateral i uparuk sand, 1.6 bpm, 3100 psi, 75L, 50 fph,
91 deg incl, drill 12161'.
Drilling lateral in Kup k sand, 1.6 bpm, 3200 psi, 55L, 55 fph,
91 deg incl, drilled to 12 0'.
Wiper trip back to bit just b w the window 11815'. Tie in
about 20' of GR to shale cha teristics at window. Correct
+4'. Run back to bottom at 1225 '
Drilling lateral in Kuparuk sand, 1.7 m, 3300 psi, 117R, 60
fph, 93 degree incl, drilled to 12330'.
Drilling lateral in Kuparuk sand, 1.7pbm,
fph, 91 degree incl, drilled to 12401'.
Wiper trip back to window after 150' of drilling.
to resume drilling lateral.
Drilling lateral in Kuparuk sand, 1.6 bpm, 3100 psi,
91 deg Incl, Drilled to 12550'.
Wiper trip to window. Clean hole. RIH clean to bottom.
Printed: 4/1712006 11 :01:40 AM
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FRANK H. MURKOWSKI, GOVERNOR
AIµ\.SKA. OIL AND GAS
CONSERVATION COMMISSION
Sean McLaughlin
CT Drilling Engineer
BP Exploration (Alaska) Inc.
PO Box 196612
Anchorage, AK 99519-6612
333 W. 7'" AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
t~~J 1I't
Re: Prudhoe Bay Field, PBU NK-61
Sundry Number: 306-081
Dear Mr. McLaughlin:
Enclosed is the approved Application for Sundry Approval relating to the
above referenced well. Please note the conditions of approval set out in the
enclosed form.
When providing notice for a representative of the Commission to witness any
required test, contact the Commission's petroleum field inspector at (907)
659-3607 (pager).
As provided in AS 31.05.080, within 20 days after written notice of this
decision, or such further time as the Commission grants for good cause
shown, a person affected by it may file with the Commission an application
for rehearing. A request for rehearing is considered timely if it is received by
4:30 PM on the 23rd day following the date of this letter, or the next working
day if the 23rd day falls on a holiday or weekend. A person may not appeal
a Commission decision to Superior Court unless rehearing has been
requested.
Sincerely,
aß-¡jJ~~
Cathy P. Foerster
Commissioner
DATED this9~y of March, 2006
Encl.
~f0
e STATE OF ALASKA )/1/0(, __'~/'ð~1
ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 7 2006
APPLICATION FOR SUNDRY APPROV&'aoil&G C . .
20 AAC 25.280 as oos. CommIssIon
Anchorage
'vJó'r- 1t'lwoC,
RECEIVED
1. Type of Request: IBI Abandon o Suspend o Operation Shutdown o Perforate o Other -~-~~---~-------------
o Alter Casing o Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well
o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension
2. Operator Name: 4. Current Well CI~S: 5. Permit To Drill Number
BP Exploration (Alaska) Inc. a Development D Exploratory 198-114 /'
3. Address: D Stratigraphic D Service 6. API Number: /
P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22893-00-00
7. KB Elevation (ft): 59.4' 9. Well Name and Number: /
PBU NK-61
8. Property Designation: 10. Field / Pool(s):
ADL 034630 Prudhoe Bay Field / Niakuk Pool
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):
12365 9684 12251 / 9576 None None
Casing Length Size MD / TVD Burst Collapse
~tnJchm:¡
73' 20" 115' 115' 1530 520
6156' 9-5/8" 6196' 5102' 6870 4760
P 12313' 7" 12351' 9671' 8160 7020
Liner
Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: ./ Tubing Grade: I Tubing MD (ft):
11803' - 11933' / 9156' - 9277' 3-1/2", 9.3# L-80 11621 ' {'"
Packers and SSSV Type: 7-5/8" x 3-1/2" Baker 'S-3' packer Packers and SSSV MD (ft): 11574' /'
12. Attachments: 13. Well Class after proposed work:
a Description Summary of Proposal D BOP Sketch D Exploratory a Development D Service
D Detailed Operations Program
14. Estimated Date for Marc~)006 15. Well Status after proposed work: /
Commencing Operations: DOil DGas D Plugged a Abandoned
16. Verbal Approval: Dàm: DWAG DGINJ DWINJ D WDSPL
Commission Representative:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sean McLaughlin, 564-4387
Printed Namç" Sean McLswghlin Title GT Drilling Engineer
Signature .IV /VL {( ~ Date 3/7/06 Prepared By Name/Number:
Phone 564-4387 Terrie Hubble, 564-4628
Commission Use Only . I
Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~o...o ~ ,
D Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance
Other: I+r) p Y'O IJ tJ kJr ,AA- I 0 - 4-0 l ~~y\.(d ~r ý(' ~ iv(;c.-(Á'- ~ll ¡J /L - lo lit- .
Subsequent Form Required: lo- 401. RBDMs 8Ft MAR J () 2D06
Approved By: f1If!w, /4 AÁ APPROVED BY
COMMISSIONER THE COMMISSION Date -i-'i-EJ,6
Form 10-403 RelÏisea 07/2'05 '\ Submit In Duplicate
ORIGINAL~
e
e
To:
Winton Aubert
Petroleum Engineer
Alaska Oil & Gas Conservation Commission
bp
From: Sean McLaughlin
CTD Engineer
Date: March 3, 2006
Re: NK-61 Sundry Approval
Sundry approval is requested for well NK-61. NK-61 was drilled as producer in 7/98. It is completed with 3-112" tubing
within 7" production casing. The well was initially perforated (37') in the 5FS and few months later 25' of perfs were added
in the upper 4MFS zones. NK-61 has been on weekly brush and flush treatments since 1999. Reservoir pressure has
dropped to 3365 psi as of 7/04, indicating little injection support from NK-IO. Stimulation with Microbial additives was
tried in 8/00 with no apparent production benefit. In 7/04 a hydrate/paraffin plug was found and the well has been shut in
since then waiting on coil to thaw the tubing. Current status: Shut in gas-lift oil producer. NK-61 has been selected for a
through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around March 23. 2006. The sidetrack, /'
NK-61A, will exit the existing 7" production casing and kick off and land in zone 4BB. The existing perforations will be
isolated by a cement squeeze. The following describes work planned and is submitted as an attachment to Form 10-403. A
schematic diagram of the proposed sidetrack is attached for reference.
Pre-Rig Work:
1. 0 AC-LDS; AC-PPPOT -IC, T
2. C Clean out Done
3. S Set DGLV
4. S Caliper the tubing and the l~ -ì
5. 0 MIT-IA,andOA. ~ /'
6. C . Pump cement for abandonment and cement ramp exi -. 17 pg cmt- 26 bbl (11 bbl casing
volume 11620' -11,900', 10 behind pipe, 5 excess)
~7. 0 Bleed gas lift and production flowlines down to zero and blind flange
8. 0 Remove wellhouse, level pad
The pre CTD work is slated to begin on March 12,2006.
TVv: S lO - 4 0 ~ r>JJrY\?-v&\...l.
Rig Work: -or
1. MIRV and test BOPE to 250 psi low and 4000 psi high.
2. Mill 3.8" cement ramp window at 11804' and 10' of rathole. Swap the well to Flo-Pro.
3. Drill Build: 3" OH, 396' (40 deg/l00 planned)
4. Drill Lateral: 3" OH, 3025' horizontal (10 deg/l00 planned)
5. MAD pass with resistivity tools
6. Run 2 3/8" solid liner leaving TOL at 11605'
7. Pump primary cement job to TOL, 16 bbl of 15.8 ppg liner cmt planned
8. Cleanout liner and MGR/CCL log
9. Test liner lap to 2000 psi.
10. Perforate liner per asset instructions (-500')
11. Freeze protect well, RDMO
Post-Rig Work:
1. Move wellhouse, Install production flowline
2. Run GLVs
3. Flowback well to separator
Sean McLaughlin
CTD Engineer
564-4387
CC: Well File
Sondra Stewmantrerrie Hubble
TREE =
WELLHEA D =
ACTUA TOR =
KB. ELEV =
BF. ELEV =
KOP=
Max Angle =
Datum MD =
OatumTVD=
4" CNV
FMC 11" GEN 5
BAKER
59.6'
37.8'
1000'
49 @ 6850'
11914'
9200'SS
9-5/8" CSG, 47#, L-80, ID = 8.681"
Minimum ID = 2.813" @
3-1/2" HES SERIES 10 FMX
3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992"
ÆRFORA TION SUMrvlARY
REF LOG: SWS DIPOLE SHEAR SONIC 0
ANGLEATTOPÆRF: 22 @ 118
Note: Refer to Production DB for historic
SIZE SPF INTERV AL Opn/Sqz
2-1/2" 6 11803-11813 0
2-1/2" 6 11803-11840 0
2-1/2" 4 11803 - 11840 0
2-1/2" 6 11908-11933 0
I PBTD
7" CSG, 26#, L-80, 10 = 6.276"
DATE
07/16198
09/29/01
06/27/03
07/10/04
09/06/05
e
el SAFElY NOTES:
N K -61
2106' H3-1/2" TRSV, SERIES 10 FMX NIP, ID = 2.813" I
.
GAS LIFT rvlANDRELS
ST MD TVD DEV TYÆ VLV LA TCH PORT DATE
L 5 3854 3457 47 MMG DOME RK 16 09/06/05
4 7974 6297 45 MMG DOME RK 16 09/06/05
3 10100 7790 45 MMG DOME RK 16 09/06/05
I µ ~ 2 11099 8524 35 MMG OMY RK 0
6196' 1 11502 8867 25 MMG SO RK 20 09/06/05
. I 11562' H 3-1/2" HES X NIP, 10 = 2.813" I
.
tg I 11574' H 7-5/8" X 4-1/2" BAKER S-3 PKR, 10 = 3.875"
2S
2106'
TR-SSSV I I 11599' H 3-1/2" HES X NIP, 10 = 2.813" I
. I I 11609' H 3-1/2" HES X NIP, ID = 2.813" I
I 11620' I 11620' H 3-1/2" TUBING TAIL WLEG I
I 11605' H ELMO TT LOGGED 07/26/98 I
N 07111/98
03' 11722' H rvlARKER JOINT 11722-11742' (ELMO) I
al perf data
DATE
11/15/98
07/27/98
07/27/98
11/15/98 ~
I
~
I 12251'
I 12351' ~
REV BY COMMENTS
ORlG COMPLETION, (POOL 7)
RNlTP CORRECTIONS
BG/KAK MO & SS DEPTH CORRECTIONS
KSB/KAK GLV C/O
DAVITLH GLV C/O
NIAKUK UNfT
WELL: NK-61
PERMfTNo: 1981140
API No: 50-029-22893-00
SEC 36, T12N, R15E, 4549.13' FEL & 3183.43' FNL
DATE
REV BY
COMMENTS
BP Exploration (Alaska)
PERf ORA TiON SUMMARY
REF lOG: SWS DIPOLE SHEAR SONIC ON 07/11/98
22 @11803'
histQrical perf data
NOTES:
COMMENTS
NIAKUK UNIT
WElL: NK-61
PERMIT No: 1981
API No: 50-029-22893-00
SEe 36, T12N, RiSE, 4549.13' FEl 8. 3183.43' FNL
BP
PRUDHOE BAY. NIAKUK OIL
PBU_NIAKUK
BAY
100
50
NK-61
- Oil Rate (CD) (Mbblla )
Water Rate (CD) (Mbblld )
Gas Rate (CD) (MMefld )
Cum Oil Prod (MMbbl )
Gasl Oil Ratio (Meflbbl )
Weter Cut ( %
10
5
05
0.1
0.05
001
04
05
1998
99
2000
01
02
Date
I
NIAKUK OIL
BAY
1??oo A1æe
Name
Oi
5000 qí
Ii
Ie
End Rate
Final Rate
Cum. Prod
Date
1000 8JR
Fcrecæt Ended By
"0 ForecætDate
""
Q 500
.n
Ô
S
Q)
ro
a::
ð
100
ffi
50
10
1998 99 2000 01 02 03 04 05 œ 07 œ
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
Convert Injection f/H20 to MI
Operation shutdown_ Stimulate _ Plugging _
Pull tubing _ Alter casing _ Repair well _
Perforate _
Other_X Cony f/H20 to MI
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
5. Type of Well:
Development __
Exploratow__
Stratigraphic__
Service__X
4. Location of well at surface
2230' FNL, 2224' FEL, Sec. 36, T12N, R16E, UM
At top of productive interval
1143' FNL, 3352' FEL, Sec. 01, T11N, R16E, UM
At effective depth
1418' FNL, 3456' FEL, Sec. 01, T11 N, R16E, UM
At total depth
1454' FNL, 3468' FEL, Sec. 01, T11N, R16E, UM
(asp's 258973, 5982188)
(asp's 257713, 5978033)
(asp's 257674, 5977946)
(asp's 257585, 5977728)
12. Present well condition summary
6. Datum elevation (DF or KB feet)
RKB 55 feet
7. Unit or Property name
Duck Island Unit / Endicott
8. Well number
1-67/T-20
9. Permit number / approval number
189-114
10. APl number
50-029-21985-00
11. Field / Pool
Endicott Oil Pool
Total depth:
measured 12150 feet Plugs (measured) CMT Cap @ 11551'
true vertical 10614 feet 4-1/2" XXN Plug @ 11645'
Effective depth: measured 11551 feet Junk (measured) 3-3/8" 25 ft Perf Gun @ 11970'.
true vertical 10063 feet
~nchorage
Casin9 Length Size Cemented Measured Depth True Vertical Depth
Conductor 64' 30" Driven 103' 103'
Surface 2459' 13-3/8" 3577 cf Permafrost 2498' 2498'
Intermediate 10923' 9-5/8" 575 cf Class 'G' 10962' 9536'
Slotted Liner 1730' 7" 643 cf Class 'G' 10683' - 12142' 9297' - 10551'
Perforation depth: measured Open Perfs 11444'-454', 11463'-473', 11488'-496', 11500'-506', 11510'-524', 11528'-550'
Sqzd Perfs Below CMT Cap 11605'-11638', Mechanically Isolated 11702'-11736'
true vertical Open Perfs 9966'-975', 9983'-992', 10006'-013', 10017'-022', 10026'-039', 10042'-062'
Sqzd Perfs Below CMT Cap 10112'-10142', Mechanically Isolated 10201 '-10232'
Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TDS to 10664'. 4-1/2" Tubing Tail @ 10748'.
Packers & SSSV(type& measured depth) 9-5/8" x 4-1/2" TIW (HBBP) PKR @ 10664'. 7" X 4-1/2" Otis 'WD' PKR @ 11655'.
4-1/2" Otis SSSVLN @ 1551'.
13. Stimulation or cement squeeze summary
Intervals treated (measured) (see attached)
Treatment description including volumes used and final pressure
14.
Prior to well operation 06/13/2002
Subsequent to operation 06/23/2002
Oil-Bbl
Representative Daily Average Production or Injection Data
Gas-Mcr Water-Bbl
10595
13400
Casing Pressure
Tubing Pressure
1886
2765
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
16. Status of well classification as:
Oil __ Gas __ Suspended __
Service MI INJECTION
17. I hereby certify that the foregoing, is~rue and correct to the best of my knowledge.
DeWayne R. Schnorr
Form 10-404 Rev 06/15/88 ·
Date Julv 03, 2002
Prepared b}' DeWa)me R. Schnorr 564-517~,~,
$CANNEI u [,NtD p E
1-67/T-20
Description of Work Completed
NRWO OPERATIONS
06/05/2002 PULL MCX VALVE: Drift & tag TD
06/09/2002 IPROF: IN.1ECTION PROFILE
ISSSV C/O OR STROKE
06/1
5/2002
06/15/2002 FREEZE PROTECT WELL
06/23/2002 CONVERTED FROM WATER TO MI INJECTION
SUMMARY
06/05/02 PULLED MCX, TAGGED BOTTOM @ 11,498' SLM, (11,537' CORRECTED
DEPTH). MCX OOH FOR REPAIR. RDMO.
06/09/02
CHOKE WELL BACK AND RIH W/1 11/16" PFCS/PILS/PSPT. DECHOKE WELL
AND PERFORM AN INJECTION PROFILE. MAKE 40, 80, 120, 160 FPM PASSES
OVER THE PERF INTERVAL. MAKE ONE 80 FPM PASS OVER THE ENTIRE
INTERVAL FROM THE TOP OF CEMENT CAP AT 11551 TO BOTTOM OF
TUBING AT 10748' TO IDENTIFY OTHER INJECTION LOCATIONS. NONE
FOUND. CHOKE WELL BACK TO POOH. NOTIFY PAD OPERATOR OF CHOKE
FULL STATUS UPON LEAVING WELL.
06/15/O2
SET 4 1/2" BBE SCSSSV (SER # NBB-61) @ 1515' SLM, POOH. NOTE: IT TOOK
ONE HOUR TO PURGE BOTH BALANCE AND CONTROL LINES. WELL LEFT
SHUT-IN.
06/15/02 PUMP 25 BBLS DOWN TUBING FOR FREEZE PROTECT AND SPACER FOR MI
INJECTION.
06/23/02 CONVERTED WELL FROM WATER INJECTION TO MI INJECTION.
FLUIDS PUMPED
BBLS
2 DIESEL USED FOR PRESSURE TESTING (2 TESTS)
25 METHANOL
27 TOTAL
Page I
;CANNED JUL 0 2002
198-1 14-0 PRUDHOE BAY UN NIA NK-61
MD 12365 TVD.09_67_2_ Completion Date:
Microfilm Roll / - Roll 2 /
50- 029-22893-00 BP EXPLORATION (ALASKA) INC
7/27/98 Completed Status: 1-OIL Current:
- Elevation: KB 0060
Name
L ADN-MD
L ADN-TVD
L CDR-MD
L CDR-TVD
L DATA FRAC/WRM B
L DSS1
L PERF/CCL
L PEX-CN/GR
L PEX-NDT/GR
L PEX-NDT/SSTVD
L PRES BU-PRES/TEM
L PROD-SPlN/TEM/
L RFT
R SRVY RPT
Interval
FINAL 8300-12300 6/27/98 THRU
FINAL 6500-9600 6/27/98 THRU
FINAL 200-12300 6/27/98 THRU
FINAL 200-9600 6/27/98 THRU
FINAL TEM/PRES 11620-11900
FINAL 10000-12360
FINAL 11700-11987
FINAL 10000-12360
FINAL 10000-12360
FINAL 10000-12360
FINAL 11690-11986
FINAL PRES 11690-11986
FINAL 10000-12360
SCHLUM 0-12365.
5
Run Sent Received T/C/D
..
7/10/98 OH 10/15/98 10/16/98
7/10/98 OH 10/15/98 10/16/98
7/10/98 OH 10/15/98 10/16/98
7/10/98 OH 10/15/98 10/16/98
0/21/98 CH 5 12/10/98 12/10/98 093
7/11/98 OH 10/6/98 10/6/98
1/15/98 CH 5 12/10/98 12/10/98 CUL
7/11/98 OH 10/6/98 10/6/98
7/11/98 OH 10/6/98 10/6/98
7/11/98 OH 10/6/98 10/6/98
1/13/98 CH 5 12/10/98 12/10/98 093
1/13/98 CH 5 12/10/98 12/10/98 093
7/11/98 OH 10/6/98 10/6/98
OH 11/23/98 11/24/98
Thursday, September 14, 2000 Page 1 of 1
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO:
THRU:
Julie Heusser,
Commissioner
Tom Maunder,
P. I. Supervisor
DATE: April 16, 2001
FROM: Jeff Jones, SUBJECT'
Petroleum Inspector
Safety ValVe Tests
Niakuk Field
BPX
PBU / Niakuk Pad
April 16, 2001: I traveled to the Niakuk Field to witness Safety Valve System
tests on BPX's oil producing wells. Well house inspections were also
conducted.
The testing went well with Ron White as the BPX representative in charge of
testing. 12 wells were tested with two failures witnessed. The pilot on NK-12A
tripped below 50% of the separator pressure and was replaced and passed a
retest. The SSV on NK-62 failed to hold D.P. and was stroked and passed a
retest. I inspected 12 well houses and all were in order with no exceptions noted.
The AOGCC test forms are attached for reference.
SUMMARY: I witnessed SVS tests on 12 oil producing wells in BPX's Niakuk
Field.
12 wells tested, 36 components. 2 failures witnessed, 5.5% failure rate.
12 well houses inspected, no exceptions noted.
Attachments_.:. SVS PBU Niakuk4-16-01 JJ
.C.C:
NON.-CONFIDENTIAL
SVS PBU Niakuk 4-16-01 JJ
Alaska Oil and Gas Conservation Commission
Safety Valve System Test Report
Operator: BPX
Operator Rep: Ron White
AOGCC Rep: Jeff Jones
Submitted By: Jeff Jones
FieldfUnit~ad: PBU/Niakuk Field
,
Separator psi: LPS 460
Date: 4/16/01
HPS
:.f:~ _ ii i .i i _ I i . ii . i i i
Well Permit Separ Set L/P Test Test Test Date oa, WAG, GIN J,
Number Number PSI PSI Trip Code Code Code Passed G~S or CYCLE
NK-07' 1931590 ....
NK-08 'i940930'''460 35'0 '' 3~0 ''P ~ '"P ' 'OiL
NK-09 1941400~ 460 350 340 P P P ' ' 0IL
NK-12A 1940070' 460' 350.. 200 3 ....P ' P 4/16/01 "OIL
NK-13 19613401
NK-14 "i~60~60' 460 350 '' 350 P P P 0IL
NK-18 1931770
341(-19 '194123b ..........
NK-20 " '1931910 460 350 J25 P ' '' P P ....... OiL
N~-51' 1940866 460 350 325 .... P P "'P '''oIL'
NK-22 1931350
NK-57 "195~21'0 '"460 350 325 '"~' P P ........ OIL
NK-28 1960930
NK-29 196190b '4~0 350 .... 250 P 'P' P ........ OIL
NK~3~ '19808~0 ......
NK-42 1~4'1080 - ' 460 350 340 "P P ' e OIL
·
NK-61 1981140 460 350 325 P P e OIL
N~'62 1'972560 '460...... 350 325 " P 4 '"P' ' 4/16201 "OIL
L~-56' ' 1940050 ....460 ' 350. 350 P P P ...... OIL
Wells: 12 Components: 36 Failures: 2 Failure Rate: 5.50% [-! 90 Day
Remarks:
NK-12A pilot was replaced and passed retest on 4/16/01
NK-62 stroked valve and passed retest on 4/16/01
L6- 26 is on the Niakmk Pad and drilled into the Lisburne formation.
12 well house inspections, no except,ions._
RJF 1/16/01 Page 1 ofl SVS PBU Niakuk 4-16-01 JJ
BP EXPLORATION
BP Exploration (Alaska) Inc.
900 East l~enson Boulevard
RO. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
December 10th, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear AOGCC Representative,
Attached are bluelines and sepias for well Niakuk 61. Per 20.AAC 25.537(d)
BP Exploration would like these logs to be held confidential for 24 months.
The specific attached logs include:
L. og Type
Perforating Record
Pressure Build Up Pressure/Temp
Data Frac/Warm Back/Pressure/Temp
Production Profile FBS/CFS/Gradio/P/T
Company
Schlumberger
Schlumberger
Schlumberger
Schlumberger
Run Date
11/15/98
11/13/98
10/21/98
11/13/98
Please contact me at 564-5126 if you have any questions.
Sincerely,
David L. Boyer, Sr. Geo~t
CNS Greater Regional Opportunities
MS
Enclosures
Please sign below and return to Marian Sloan, BPX, Mail Stop MB9-4 for
reCe'i.~t of transmittal..
Depths
11700-11987
11690-11986
11620-119OO
11690-11986
· ~- STATE OF ALASKA --.
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
1. Status of Well Classification of Service Well
[] Oil [~ Gas [] Suspended [--] Abandoned I--] Service
2. Name of Operator 7. Permit Number
BP Exploration (Alaska)Inc. 98-114
3. Address 8. APl Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22893
z~. Location of well at surface ! ~:;:ii.!.:i~ i'~:~,::i:.~ ! ~ ~ 9. Unit or Lease Name
. Niakuk
At to,p, of productiv,e interval ~I ,=.,'~._~ 10. Well Number
1920 NSL, 4492 WEL, SEC. 25, T12N, R15E, UM~ ~.'~'.~' i ,,!~t~ NK-61
At tot,al depth , : ~,/~_~..~_- ! ....
2076 NSL, 4604 WEL, SEC. 25, T12N, R15E, UM' ' ¥_'...~~
1
1.
Field
and
Pool
Niakuk Oil Pool
5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No.
RKB = 59.60'I ADL 034630
12. Date Spudded 113. Date I.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions
6/27/98 7/10/98 7/27/98 N/A MSLI One
1~. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost
12365' 9672 FT 12267' 9579 FTI []Yes E~NoI 2105' MDI 1800' (Approx.)
22. Type Electric or Other Logs Run
USlT/Gyro, L/D MWD, LDC, CDL-CNL-GR, GR/JB/GR/CCL
23. CASING, LINER AND CEMENTING RECORD
CASING SETTING DEPTH HOLE 0~1GI~AL
SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED
20" 94# H-40 42' 115' 30" 260 sx Arctic Set (Approx.)
9-5/8" 47# L-80 40' 6196' 12-1/4" 2410 sx PF 'E', 410 sx Class 'G'
7" 29# L-80 38' 12351' 8-1/2" 275 sx Class 'G'
24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD
Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD)
See Attached 3-1/2", 9.4#, EUE 8R 11621' 11574'
MD TVD MD TVD
i26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze protect with 154 bbls diesel
Frac, 11803'-11840' 1352o# 2o/4o CL Lead & ;l'f'~. ~ ~
NOV
27. PRODUCTION TEST
Date First Production I Method of Operation (Flowing, gas lift, etc.) ~-~a ,.,~ ,~
October 28, 1998I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE
TEST PERIOD
I
Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR)
Press. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Form 10-407 Rev. 07-01-80 Submit In Duplicate
29. Geologic Markers 30. Formation Tests
Measured True Vertical Include interval tested, pressure data, all fluids
Marker Name Depth Depth recovered and gravity, GOR, and time of each phase.
Top HRZ 11522' 8886'
Top Kuparuk 11803' 9144'
Top Kingak 12064' 9388'
31. List of Attachments
Summary of Daily Drilling Reports, Survey
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed t
Lo~,e, Crane .~. Title Engineering Supervisor Date
NK-61 I..~ 98-114 -~'~'Prepared By Name/Number: Carol Withey, 564-4114
Well Number Permit No. / Approval No.
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and
leases in Alaska.
ITEM 1'- Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water
supply for injection, observation, injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces
on this form and in any attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item
16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional
interval to be separately produced, showing the data pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of
the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In,
Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
WELL NAME' NK-61
24. (10-407) Attachment- Perforations open to ProdUction
11/13/98 2-1/2" Gun Diameter, 6 spf
...................
........ 11803'...;....11813' MD (re-perf) 9144' - 91.53..'' TVD .....
11908'- 11928' MD 9208'- 9246' TVD
.............
7/27/98 2-1/2" Gun Diameter, 6 spf
......
11803' - 11840' MD 9144' - 9178' TVD
,,,
7/27/98 2-1/2" Gun Diameter, 4 spf (re-perf)
....
11803' - 11840' MD 9144' - 9178' TVD
..........
...........................
.....................
Facility
Date/Time
26 Jun 98
27 Jun 98
28 Jun 98
29 Jun 98
30 Jun 98
01 Jul 98
NK Main Pad
06:00-12:00
12:00-18:00
18:00-19:30
19:30-05:00
05:00-06:00
06:00-09:00
09:00-09:30
09:30-10:30
10:30-11:00
11:00-11:30
11:30-12:00
12:00-19:00
19:00-19:15
19:15-19:30
19:30-20:00
20:00-22:30
22:30-23:00
23:00-23:30
23:30-06:00
06:00-09:30
09:30-10:30
10:30-11:30
11:30-12:00
12:00-13:00
13:00-13:30
13:30-14:30
14:30-15:00
15:00-06:00
06:00-11:00
11:00-11:30
11:30-13:00
13:00-14:00
14:00-06:00
06:00-17:00
17:00-18:00
18:00-18:30
18:30-21:30
21:30-22:30
22:30-23:30
23:30-01:00
01:00-01:30
01:30-03:00
03:00-03:30
03:30-06:00
06:00-07:00
07:00-08:00
08:00-08:30
08:30-09:00
09:00-11:00
11:00-14:00
14:00-16:00
16:00-18:00
18:00-22:30
22:30-23:00
Duration
6 hr
6 hr
1-1/2 hr
9-1/2 hr
1 hr
3 hr
1/2 hr
1 hr
1/2 hr
1/2 hr
1/2 hr
7 hr
1/4 hr
1/4 hr
1/2 hr
2-1/2 hr
1/2 hr
1/2 hr
6-1./2 hr
3-1/2 hr
1 hr
lhr
1/2 hr
1 hr
1/2 hr
lhr
1/2 hr
15hr
5 hr
1/2 hr
1-1/2 hr
1 hr
16hr
llhr
lhr
1/2 hr
3 hr
lhr
1 hr
1-1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
2-1/2 hr
1 hr
lhr
1/2 hr
1/2 hr
2hr
3 hr
2 hr
2 hr
4-1/2 hr
1/2 hr
Progress Report
Well NK-61
Activity
Rig moved 100.00 %
Rigged up Divertor
Functioned Divertor
Racked back drill pipe
Made up BHA no. 1
Made up BHA no. 1 (cont...)
Tested Fluid system
Drilled to 177.0 ft
Made up BHA no. 1
Drilled to 244.0 ft
Took Gyro survey at 215.0 ft
Drilled to 586.0 ft
Circulated at 586.0 ft
Pulled out of hole to 183.0 ft
Pulled BHA
Made up BHA no. 2
R.I.H. to 586.0 ft
Took Gyro survey at 586.0 ft
Drilled to 895.0 ft
Drilled to 1290.0 ft (cont...)
Took Gyro survey at 1290.0 ft
Drilled to 1387.0 ft
Circulated at 1387.0 ft
Pulled out of hole to 215.0 ft
Pulled BHA
Made up BHA no. 3
R.I.H. to 1387.0 ft
Drilled to 3167.0 ft
Drilled to 4013.0 ft (cont...)
Circulated at 4013.0 ft
Pulled out of hole to 1667.0 ft
R.I.H. to 4013.0 ft
Drilled to 5423.0 ft
Drilled to 5989.0 ft (cont...)
Circulated at 5989.0 ft
Cleared Kelly/top drive hose
Pulled out of hole to 214.0 ft
Pulled BHA
Made up BHA no. 4
R.I.H. to 3178.0 ft
Reamed to 3178.0 ft
R.I.H. to 5797.0 ft
Reamed to 5989.0 ft
Drilled to 6164.0 ft
Drilled to 6205.0 ft (cont...)
Circulated at 6205.0 ft
Pulled out of hole to 5240.0 ft
R.I.H. to 6205.0 ft
Circulated at 6205.0 ft
Pulled out of hole to 214.0 ft
Pulled BHA
Page
Date
Rigged up Casing handling equipment
Ran Casing to 2000.0 ft (9-5/8in OD)
Circulated at 2000.0 ft
1
18 November 98
Facility
Date/Time
02 Jul 98
03 Jul 98
04 Jul 98
05 Jul 98
06 Jul 98
07 Jul 98
08 Jul 98
NK Main Pad
Progress Report
Well NK-61
Page
Date
Duration
Activity
23:00-01:00
01:00-02:00
02:00-03:30
03:30-04:00
04:00-05:30
05:30-06:00
06:00-07:00
07:00-08:00
08:00-09:00
09:00-10:30
10:30-11:30
11:30-12:30
12:30-14:30
14:30-15:00
15:00-16:00
16:00-18:00
18:00-18:30
18:30-02:30
02:30-06:00
06:00-08:00
08:00-09:00
09:00-10:30
10:30-11:30
11:30-12:30
12:30-16:00
16:00-17:30
17:30-22:00
22:00-22:30
22:30-23:30
23:30-01:00
01:00-05:00
05:00-05:30
05:30-06:00
06:00-06:30
06:30-20:30
20:30-22:00
22:00-00:00
00:00-01:00
01:00-01:30
01:30-02:00
02:00-05:30
05:30-06:00
06:00-01:30
01:30~02:30
02:30-06:00
06:00-07:30
07:30-11:00
11:00-12:00
12:00-14:00
14:00-18:00
18:00-18:30
18:30-06:00
06:00-02:00
02:00-04:30
2 hr
1 hr
1-1/2 hr
1/2 hr
1-1/2 hr
1/2 hr
1 hr
1 hr
1 hr
1-1/2 hr
1 hr
lhr
2hr
1/2 hr
lhr
2 hr
1/2 hr
8hr
3-1/2 hr
2hr
1 hr
1-1/2 hr
1 hr
1 hr
3-1/2 hr
1-1/2 hr
4-1/2 hr
1/2 hr
1 hr
1-1/2 hr
4 hr
1/2 hr
1/2 hr
1/2 hr
14hr
1-1/2 hr
2hr
1 hr
1/2 hr
1/2 hr
3-1/2 hr
1/2 hr
19-1/2 hr
1 hr
3-1/2 hr
1-1/2 hr
3-1/2 hr
1 hr
2 hr
4 hr
1/2 hr
11-1/2 hr
20 hr
2-1/2 hr
Ran Casing to 4008.0 ft (9-5/8in OD)
Circulated at 4008.0 ft
Ran Casing to 4816.0 ft (9-5/8in OD)
Rigged up Casing handling equipment
Ran Casing to 6165.0 ft (9-5/8in OD)
Ran Casing to 6205.0 ft (9-5/8in OD)
Circulated at 6192.0 ft
Rigged up Handling equipment
Circulated at 6192.0 ft
Mixed and pumped slurry - 300.000 bbl
Displaced slurry - 149.000 bbl
Functioned DV collar
Mixed and pumped slurry - 750.000 bbl
Displaced slurry - 159.000 bbl
Rigged down Casing handling equipment
Rigged down Divertor
Rigged up Casing head
Rigged up Well control
Tested Well control
Tested Well control (cont...)
Serviced Drillstring handling equipment
Made up BHA no. 5
Serviced Drillfloor / Derrick
Made up BHA no. 5
Singled in drill pipe to 2097.0 ft
Drilled installed equipment - DV collar
Singled in drill pipe to 6083.0 ft
Circulated at 6083.0 ft
Tested Casing
Serviced Block line
Drilled cement to 6230.0 ft
Circulated at 6230.0 ft
Performed formation integrity test
Performed formation integrity test (cont...)
Drilled to 7380.0 ft
Circulated at 7380.0 ft
Pumped out of hole to 6162.0 ft
R.I.H. to 7349.0 ft
Circulated at 7349.0 ft
Rigged up Survey wireline unit
Conducted electric cable operations
Rigged down Survey wireline unit
Drilled to 8322.0 ft
Circulated at 8322.0 ft
Pulled out of hole to 3500.0 ft
Pulled out of hole to 1105.0 ft (cont...)
Pulled BHA
Serviced Drillfloor / Derrick
Made up BHA no. 6
R.I.H. to 8234.0 ft
Reamed to 8322.0 ft
Drilled to 9037.0 ft
Drilled to 10238.0 ft (cont...)
Circulated at 10238.0 ft
2
18 November 98
Facility
Date/Time
09 Jul 98
10 Jul 98
11 Jul 98
12 Jul 98
13 Jul 98
14 Jul 98
15 Jul 98
16 Jul 98
Progress Report
NK Main Pad
Well NK-61 Page 3
Rig~ ~)E~) [ 7 Date 18 November 98
04:30-06:00
06:00-07:30
07:30-11:30
11:30-13:00
13:00-14:00
14:00-17:00
17:00-17:30
17:30-22:00
22:00-22:30
22:30-06:00
06:00-06:00
06:00-11:30
11:30-13:00
13:00-15:00
15:00-16:00
16:00-18:30
18:30-01:30
01:30-03:30
03:30-06:00
06:00-07:15
07:15-12:30
12:30-17:30
17:30-03:00
03:00-03:30
03:30-05:30
05:30-06:00
06:00-13:00
13:00-14:00
14:00-19:30
19:30-20:00
20:00-22:30
22:30-06:00
06:00-09:00
09:00-10:00
10:00-11:00
11:00-11:30
11:30-14:00
14:00-15:00
15:00-18:00
18:00-20:30
20:30-21:00
21:00-02:00
02:00-06:00
06:00-15:30
15:30-18:30
18:30-02:00
02:00-06:00
06:00-14:30
14:30-15:30
15:30-20:00
20:00-21:30
21:30-22:00
22:00-01:00
01:00-03:00
Duration
1-1/2 hr
1-1/2 hr
4 hr
1-1/2 hr
1 hr
3 hr
1/2 hr
4-1/2 hr
1/2 hr
7-1/2 hr
24 hr
5-1/2 hr
1-1/2 hr
2 hr
lhr
2-1/2 hr
7 hr
2 hr
2-1/2 hr
1-1/4 hr
5-1/4 hr
5hr
9-1/2 hr
1/2 hr
2hr
1/2 hr
7 hr
1 hr
5-1/2 hr
1/2 hr
2-1/2 hr
7-1/2 hr
3 hr
lhr
1 hr
1/2 hr
2-1/2 hr
lhr
3 hr
2-1/2 hr
1/2 hr
5 hr
4hr
9-1/2 hr
3 hr
7-1/2 hr
4hr
8-1/2 hr
1 hr
4-1/2 hr
1-1/2 hr
1/2 hr
3hr
2 hr
Activity
Pulled out of hole to 9200.0 ft
Pulled out of hole to 6107.0 ft (cont...)
Fill pits with Water based mud
R.I.H. to 10165.0 ft
Circulated at 10238.0 ft
Circulated at 10238.0 ft
Circulated at 10238.0 ft
Drilled to 10356.0 ft
Serviced Mud shakers
Drilled to 10720.0 ft
Drilled to 12100.0 ft (cont...)
Drilled to 12365.0 ft (cont...)
Circulated at 12365.0 ft
Pulled out of hole to 10123.0 ft
R.I.H. to 12275.0 ft
Circulated at 12365.0 ft
Pulled out of hole to 390.0 ft
Pulled BHA
Conducted electric cable operations
Conducted electric cable operations (cont...)
Repaired Formation logs
Conducted electric cable operations
Conducted electric cable operations
Retrieved B ore protector
Rigged up Casing handling equipment
Ran Casing to 7in (120.0 ft OD)
Ran Casing to 6180.0 ft (7in OD) (cont...)
Circulated at 6180.0 ft
Ran Casing to 10570.0 ft (7in OD)
Circulated at 10570.0 ft
Ran Casing to 12310.0 ft (7in OD)
Circulated at 12351.0 ft
Circulated at 12351.0 ft (cont...)
Mixed and pumped slurry - 56.000 bbl
Displaced slurry - 470.000 bbl
Tested Casing - Via string
Installed Slip & seal assembly
Rigged down Casing handling equipment
Rigged up Top ram
Tested BOP stack
Rigged up Drillstring handling equipment
Conducted slickline operations on Slickline equipment - Tool run
Laid down 4500.0 ft of 5-1/2in OD drill pipe
Laid down 12000.0 ft of 5-1/2in OD drill pipe (cont...)
Conducted electric cable operations
Conducted electric cable operations
Ran Tubing to 3-1/2in (2000.0 ft OD)
Ran Tubing to 9515.0 ft (3-1/2in OD) (cont...)
Installed SCSSSV control line
Ran Tubing to 11585.0 ft (3-1/2in OD)
Installed Tubing hanger
Removed Tubing handling equipment
Removed BOP stack
Installed Xmas tree
Facility
Date/Time
NK Main Pad
Progress Report
Well NK-6! Page
Rig ~/~L)D{ 7 Date
03:00-03:30
03:30-06:00
06:00-07:00
07:00-08:00
08:00-09:00
09:00-10:30
Duration
1/2 hr
2-1/2 hr
1 hr
1 hr
lhr
1-1/2 hr
Activity
Removed Hanger plug
Freeze protect well - Diesel of 154.000 bbl
Freeze protect well - 154.000 bbl of Diesel (cont...)
Set packer at 11574.0 ft with 3900.0 psi
Tested Permanent packer
Serviced Hanger plug
4
18 November 98
Performance Enquiry Report
Operator ARCO Date 20:36, 18 Nov 98
Page 1
The analysis is from - 06:30, 04 Jul 98 - to - 06:30, 04 Jul 98
Programs in Result Table: NK-61 Drill and Complete
Well Type Time From Time To Duration Description E.M.W.(ecfuivalent mud weight)
NK-61 Event 06:30, 04 Jul 98 06:30, 04 Jul 98 0 hr 0 min Obtained leak off 13.0
Hole Size MDR
8-1/2
To: Anchorage Productiob=,~gineering --~,-ocation: Niakuk
From' Nordlander Date: 10/21/98
Operation: NK-61 Frac Treatment Cost Code: 731217 - 9335 - 070 - etc
Detail Code: Drlg - Frac - etc
Summary
Rigged up equipment for E-line Data Frac & Frac. Rih w/e-line tools, tagged td @ 12,240, logged up baseline. Parked tools 50'
above per[s @ 11,750 during data frac. Pumped injection test, perf breakdown as per program. Started data frac but had trouble
with the new Iow guar system and pump so had to shut down and corrective the problem while delivering additional additives. There
had been 736 bbls pumped at the time so started the warm back passes. Logs indicated a channel existed from bottom per[ at
11,840 to 11,920, which would put the frac in a possible undesirable zone. Went ahead with data frac as per program and followed
with subsequent warmback passes. Downhole data frac pressure and temp was used in the redesign of the frac. Logs indicated
channel again down to 11,940. Presented town with information and they decided to proceed with frac program and reducing the
size it to limit frac growth downward. Pumped redesigned frac and screened off while 50 bbl into the 98 bbl designed flush.
Estimated sand top is at 5,747 in unbroken gel (or 11,052 if it completely falls out of gel and does not bridge off). Note that Propnet,
and fiber hair like substance, mixed into the prop to curtail sand flowback and was cut out of the last 10 bbls of dirty slurry. Did not
and could not freeze protect well,
Injectivity Test Design Rate Bbls Max Rate Final STP ISlP
& Breakdown bpm Pumped bpm psi psi
30 30 19.9 5676 2200
Data Frac Bbls Bbls XL gel Time XL gel ~ Final. STP ~ ISIP
Pumped to Perfs i on perfs psi psi'
370 250 i' 8'. 3543 -.. 1909
Frac Sand Lead prop Tail prop Design total Tree saver
Pumped behind pipe behind pipe behind pipe Liner Sand rubber left
Job was ..M#.. M #/size M # / size M # M # in hole?
. , /;41,285'- 7,364 NO
Screen 4~ 8,649'". lr3,~52'O",
out "' ~ 20140 cl ' ,6~20 cl" ,. 16/20 cl
Frac
Estimated Final STP ISIP Propnet,
sand top psi psi #
5747 6816 6303 465
Fluid Summary
135 Freshwater w/2% Kcl & bactericide. (note that all frac fluids were mixed with this same water)
700 X-Link
270 Linear Gel
263 X-linkin fracjob
36 Diesel
1404 Total Load Fluid
Operation: NK-61 Frac Treatment, ,~-- '--~ Page: 2
10/21/98
Initial Well Status Siwhp lap 0ap GIp FIp Fit
psi psi psi psi psi °F
Shut-in 1130 0 0 0 0 15
Time Operation
8:00 Miru SWS and HB&R. Tanks are spotted.
9:00 Miru DS Frac equipment.
11:29 Start preping to set tree saver. X-link tested in lab, on site sample ok once heated.
12:53 Tree saver set, continue rigging hard line.
13:08 Start rigging up e-line.
13:49 Hold safety meeting.
14:23 Pressure test backside to 3500. Trips set at 3500. Hold 1500.
15:52 Start engines.
16:51 Start pressure test.
17:02 Test to 7100, trips set at 7200, bleed down, open swab and master. Set cups on tree saver. Increase ia to 2500.
17:11 Run e-line down hole.
18:30 Tag td @ 12,240, log up.
18:36 Bottom hole static pressure is 4493 psi @ 9200 tvdss. Log base line.
19:04 Park 50' above perfs. 4432 psi 182 °F @ 11750.
19:06 19:02 SWS time, correct DS time to SWS (this telex will remain at current setting)
Time Rate Whp lap Total Stage Remarks
bpm psi psi bbls bbls
19:12 1227 2241 Start down hole with kcl water for injection test, bring ia up to ~2800.
19:16 3.0 3300 2560 15 15/k Shut down. 3192 ISIP.
19:32 - 1474 2746 15 BH P 4744 psi, start x-link. Take sample, ph 9.7, looks ok, a little wet.
19:38 4.9 3860 2854 45 30/x Switch to linear gel. Take sample,
19:44 5.1 3488 2874 75 30/I Switch to kcl water.
19:52 5.0 2943 2849 117 42 Start ramping up.
19:53 16.6 4656 2870 123 48/k X-link at perfs, start breakdown, still ramping, pushing tools down hole,
reduce to 20 bpm.
19:57 19.9 5676 2840 195 72/k Shut down. 2200 ISIP. Maxdown hole 6000-6100 psi.
20:16 1236 2732 195 Prepare for data frac. BHP 5233, 117 °F.
20:21 1158 2715 195 Start down hole with x-link.
20:29 5.0 3410 2794 234 39 Not x-linking ??, shutdown.
20:33 - 1735 2762 Re-start, possibly good x-link. Check samples again. Samples not
great.
20:43 5.0 4300 2792 289 94 Shut down to fix fluids.
21:19 - 1150 Start back on line to ensure pumpability.
21:23 3200 309 114/x Shut down. Wait on more fluid loss additives from Prudhoe.
22:22 925 2430 Re-start down hole with x-link. Samples are good, ph 9.5, and less wet.
22:42 5.0 4360 2847 407 98/x Reduce rate to close frac. Cut x-linker.
22:47 2.0 3605 2820 418 10/x Increase rate for data frac. Start x-linker.
22:50 15 5200 2830 40 Had to reduce rate as activator pump not working.
22:51 10 4000 2770 466 48 Shutdown and work on pump.
22:59 - 1840 2740 Re-start.
23:06 15.0 4250 2860 561 143 Reduce rate, pump still not working.
Operation: NK-61 Frac Treatment'- r -.-7., Page: 3
Time Rate Whp lap Total Stage Remarks
bpm psi psi bbls bbls
23:11 10.0 3450 2850 616 198/x Switch to linear gel, increase rate to flush pipe (did not get activator
pump to work).
23:19 15.0 3830 2805 736/ 120/I Shut down. Have to bring more caustic water out to location.
0:22 Start logging intermediate 1 hour warm backs.
3:53 - 787 1735 - - Prepare for data frac, waiting for last warmback Icg.
4:20 Start down hole with x-link. Sample looks ok.
4:39 5.1 4130 2871 98 98/x Reduce rate to close frac.
4:43 2.0 3450 2876 108 10/x BHP 6000. Increase rate for data frac.
4:53 14.9 4650 2874 250 142/x Switch to linear gel.
5:01 15.1 3543 2850 370 120/I Shut down. 1909 ISlP.
5:55 - 1208 2450 Freeze protect turbines, surface lines, and tubing w/diesel.
6:05 406/ 36/d Shut down. Start warm back pass. 29 bbls downhole.
11:10 911 1477 Finished logging, pooh.
12:21 925 1340 At surface, have to unset tree saver as e-line tools seem bird nested.
Line not bird nested.
13:58 Town advises to go forward with the frac. Still rigging off SWS. Work on
redesign.
16:00 Hold safety meeting.
16:19 Rev up engines.
16:37 Pressure test to 7500.
16:47 - 1057 2480 - Start pad down hole. Bring ia up to 2800.
16:50 5.1 2200 2820 16/ 16/ Shut down, activator pump not working.
17:07 1296 2834 Start down hole with pad.
17:11 5.0 2660 2860 21 21.4/ Switch to 1 ppg (20/40 cl). Start propnet.
17:12 4.9 2710 2865 28 6/ Switch to 2 ppg.
17:14 5.0 2760 2871 33 6/ Switch to 3 ppg.
17:16 5.2 2742 2882 47 13/ Switch to 4 ppg.
17:21 5.1 2560 2920 68 21/ Switch to 5 ppg.
17:25 5.2 2255 2920 90 22/ Switch to 6 ppg.
17:28 5.0 2065 2891 108 19 Pad on perfs. Switch to 16/20 cl.
17:29 5.0 2000 2882 112 23/ Switch to 7 ppg. Increase rate.
17:32 15.0 4482 2876 139 28/ Switch to 8 ppg.
17:39 15.0 4463 2920 238 97/ Switch to 9 ppg.
17:40 257 18 Shut off propnet.
17:40 15.1 4083 2909 265 27/ Switch to flush.
17:44 6816 3006 314 50/ Screen out, shutdown. 8.8 ppg on perfs w/propnet.
17:54 2870 Bleed back ia to 500, continue rig down.
21:00 Off location.
AnadrilFSchlumberger Survey Report
WELL INFORMATION
TD Date: 10-Jul-98
Client: BP Exploration (Alaska) Inc.
Field: Niakuk
Well Name: NK-61
Permanent datum: Mean Sea Level
Depth measured from: RKB
Elevation of kelly bushing: 59.60
Elevation of rig floor: 59.60
Elevation of ground level: 19.00
Magnetic Declination: 28.28
Grid Convergence: 0.00
Total Correction: 28.28
RECEIVED
AUG ! ? 1998
BPXA PDC
TIE IN POINT
Measured Depth: 0.00
True Vertical Depth: 0.00
Inclination: 0.00
Azimuth: 0.00
N/S displacement: 0.00
E/W displacement: 0.00
Azimuth from rotory table to target: 328.12
NOV 2 0 :998
Alaska 0,3 & Gas Cces. Commis~b¢..
Measured Station Station Station Vertical Vertical
.Depth Inclination Azimuth Interval Depth Section
(ft) (deg) (deg) (ft) (ft) (ft)
0.00 0.00 0.00 0.00 0.00 0.00
101.00 0.15 106.10 101.00 101.00 -0.10
200.00 0.52 71.00 99.00 200.00 -0.29
300.00 0.35 27.00 100.00 300.00 -0.24
400.00 0.61 11.30 100.00 399.99 0.31
500.00 1.29 318.30 100.00 499.98 1.80
600.00 2.68 335.90 100.00 599.92 5.23
700.00 4.83 332.30 100.00 699.70 11.75
800.00 7.13 332.70 100.00 799.15 22.13
900.00 8.29 330.70 100.00 898.24 35.52
1000.00 10.33 333.60 100.00 996.92 51.65
1100.00 12.06 337.20 100.00 1095.01 70.89
1200.00 13.61 337.20 100.00 1192.51 92.82
1250.00 14.20 336.10 50.00 1241.05 104.71
1300.00 14.65 336.30 50.00 1289.47 117.04
Latitude
¢,T/-S)
Departure
~/-W)
(ft)
Total At Dog Leg
displ Azim Severity
(ft) (deg) (deg/1000
0.00 0.00 0.00 0.00 0.00
-0.04 0.13 0.13 106.10 0.15
0.07 0.68 0.68 83.78 0.41
0.49 1.24 1.34 68.36 0.36
1.29 1.49 1.97 49.11 0.29
2.65 0.84 2.78 17.64 1.04
5.62 -0.86 5.69 351.30 1.50
11.49 -3.77 12.09 341.82 2.16
20.73 -8.58 22.43 337.52 2.30
32.53 -14.95 35.80 335.32 1.19
-22.47 51.96 334.38 2.09
-30.50 71.36 334.70 1.87
-39.11 93.56 335.29 1.55
-43.88 105.57 335.44 1.29
-48.90 118.03 335.52 0~91
46.85
64.52
84.99
96.02
107.42
Anaddll Schlumberger
Page 1
ORIGINAL
7/13/98
Measured Station Station Station Vertical
Depth Inclination Azimuth Interval Depth
(f£) (deg) (deg) (ft) (ft)
1350.00 15.09 335.50 50.00 1337.80
1400.00 15.02 336.30 50.00 1386.08
1450.00 15.02 336.10 50.00 1434.37
1500.00 15.28 336.10 50.00 1482.63
1550.00 15.38 335.80 50.00 1530.85
1600.00 15.35 335.90 50.00 1579.07
1650.00 15.67 335.60 50.00 1627.25
1700.00 15.94 335.70 50.00 1675.36
1750.00 16.53 335.60 50.00 1723.36
1800.00 17.31 335.90 50.00 1771.20
1850.00 18.47 336.70 50.00 1818.78
1900.00 19.55 337.40 50.00 1866.05
1950.00 20.46 337.80 50.00 1913.03
2000.00 21.21 338.00 50.00 1959.76
2050.00 22.28 336.90 50.00 2006.21
2100.00 22.69 336.60 50.00 2052.40
2150.00 23.07 335.50 50.00 2098.47
2200.00 23.24 334.60 50.00 2144.44
2250.00 23.02 331.50 50.00 2190.43
2300.00 23.35 329.50 50.00 2236.39
2350.00 23.96 328.10 50.00 2282.19
2400.00 24.05 327.90 50.00 2327.86
2450.00 25.75 327.00 50.00 2373.21
2500.00 26.90 326.90 50.00 2418.03
2550.00 28.24 327.50 50.00 2462.35
2600.00 29.34 328.10 50.00 2506.17
2650.00 30.82 328.90 50.00 2549.43
2700.00 31.98 328.90 50,00 2592.11
2750.00 32.96 328.60 50.00 2634.29
2800.00 33.76 327.50 50.00 2676.05
2850.00 35.10 326.90 50.00 2717.29
2900.00 36.03 326.30 50.00 2757.97
2950.00 36.93 326.30 50.00 2798.17
3000.00 38.23 326.60 50.00 2837.79
3050.00 39.44 327.30 50.00 2876.74
3100.00 41.32 327.20 50.00 2914.83
3150.00 41.98 327.30 50.00 2952.19
3200.00 42.01 327.50 50.00 2989.35
3250.00 41.91 327.80 50.00 3026.53
3300.00 41.89 327.80 50.00 3063.75
Vertical
Section
(f~)
129.75
142.62
155.45
168.39
181.48
194.61
207.86
221.36
235.22
249.64
264.84
280.93
297.80
315.32
333.60
352.50
371.76
391.27
410.83
43O.5O
450.56
470.90
491.95
514.12
537.25
561.33
586.39
612.44
639.28
666.77
695.04
724.11
753.82
784.30
815.65
848.04
881.26
914.71
948.14
981.53
Latitude
~/-S)
(fO
119.13
130.99
142.84
154.79
166.86
178.95
191.t4
203.55
216.28
229.55
243.61
258.61
274.43
290.90
308.01
325.58
343.34
361.17
378.67
395.80
412.96
430.21
447.95
466.53
485.99
506.36
527.73
550.04
572.99
596.31
620.07
644.35
669.08
694.50
720.78
748.02
775.97
804.15
832.39
860.65
(~/-w)
-54.14
-59.44
-64.67
-69.97
-75.36
-80.78
-86.27-
-91.88
-97.65
-103.62
-109.79
-116.14
-122.66
-129.35
-136.45
-144.00
-151.90
-160.19
-169.09
-178.78
-189.17
-199.95
-211.28
-223.38
-235.91
-248.74
-261.83
-275.28
-289.21
-303.76
-319.08
-335.09
-351.58
-368.43
-385.53
-403.05
-421.03
-439.05
-456.94
-474.73
Total
displ
(ft)
130.86
143.84
156.80
169.87
183.09
196.34
209.71
223.32
237.30
251.85
267.21
283.49
300.59
318.37
336.88-
356.00
375.44
395.10
414.71
434.31
454.23
474.41
495.28
517.25
540.22
564.16
589.12
615.08
641.84
669.22
697.35
726.27
755.83
786.17
817.41
849.70
882.83
916.20
949.56
982.90
335.56
335.59
335.64
335.68
335.70
'335.71
335.71
335.71
335.70
335.70
335.74
335.82
335.92
336.03
336.11
336.14
336.14
336.08
335.94
335.69
335.39
335.07
334.75
334.42
334.11
333.84
333.61
333.41
333.22
333.01
332.77
332.52
332.28
332.05
331.86
331.68
331.52
331.37
331.24
331.12
Severity
(de~JlO00
0.97
0.44
0.10
0.52
0.26
0.08
0.66
0.54
1.18
1.57
2.37
'2.21
1.84
1.51
2.29
0,85
1.14
0.79
2.47
1.71
1.66
0.24
3.48
2.30
2.74
2.27
3.07
2.32
1.99
2.01
2.76
1.99
1.80
2.63
2.57
3.76
1.33
0.27
0.45
0.04
Anaddll Schlumberger Page 2 7/13/98
Measured Station Station -~fation Vertical
Depth Inclination Azimuth Interval Depth
(ft) (deg) (deg). (ft) (ft)
Vertical
Section
3350,00 42,80 328,10 50,00 3100,70 1015.21
3400,00 44,47 328,60 50,00 3136,89 1049,71
3450,00 44,70 328,60 50,00 3172,50 1084,81
3500,00 44,55 329,00 50,00 3208,08 1119,93
3550,00 44,04 329,40 50,00 3243,87 1154,84
3600,00 44,06 330,00 50,00 3279,81
3650,00 44,70 330,30 50,00. 331524
3700,00 45,31 330,30 50,00 3350,89
3750,00 46,44 328,10 50,00 3385,71
3800,00 47,03 327,40 50,00 3419,98
3850,00 47,07 327,90 50,00 3454,04
3900,00 46,65 328,90 50,00 3488,23
3950,00 46,80 329,30 50,00 3522,51
4000,00 46,92 330,00 50,00 3556,70
4050,00 45,51 331,20 50,00 3591,30
4100,00 45,23 331,70 50,00 3626,42
4150,00 45,08 332,00 50,00 3661,68
4200,00 44,72 332,10 50.00 3697,10
4250,00 44,66 332,00 50,00 3732,65
4300,00 44,75 332,10 50,00 3768.18
1189,59
1224,54
1259,87
1295,75
1332,16
136896
1405,24
1441,64
1478,11
1514,17
1549,69
1585,06
1620,27
1655,35
1690,45
Latitude
~/-s)
(ft)
889,19
918,56
948,52
978,57
1008,56
1038,57
1068,90
1099,62
1130,44
1161,23
1.192,15
1223,22
1254,46
1285,94
1317,39
1348,64
1379,90
1411,08
1442,14
1473,19
Departure
(it)
-492,61
-510,71
-528,99
-547,19
-565,07
-582,61
-600,01
-617,53
-635,91
-655,34
-674,92
-694,04
-712,74
-731,17
-748,89
-765,90
-782,63
-799,17
-815,65
-832,16
Total
displ
(ft)
1016,53
1050.99
1086,06
1121,16
1156,07
1190.83
1225,79
1261,15
1297,03
1333,39
1369,94
1406,40
1442,79
1479,28
1515,37
1550,95
1586,39
1621,67
1656,82
1691,98
At
Azlm
(deg)
331,01
330,93
330,85
330,79
330,74
330,71
330,69
330,68
330,64
330,56
330,48
330,43
330,40
330,38
330,38
330,41
330.44
330,47
330,51
330,54
4350,00 44,91 332,20 50,00 3803,64 1725,61 1504,35 -848,66 1727,22 330.57
4400.00 45,02 332,10 50,00 3839.02 1760,85 1535,59 -865,16 1762,54 330,60
4450,00 45,20 332,40 50,00 3874,31. 1796,18 1566,94 -881,66 1_797,94 330,64
4500.00 44,72 332,30 50.00 3909,69 1831,42 1598,23 -898,05 1833,26 330,67
4550,00 44.82 333,10 50.00 3945.18 1866,52 1629,52 -914,20 1868,45 330.71
1901,54
1936,19
1970,35
2004,36
2038,27
2071,95
2105,33
2138,83
2172,99
2207,36
4600.00 44.84 335,90 50,00 3980.65
4650,00 44,33 338,60 50,00 4016,26
4700,00 44,22 341,20 50,00 4052,06
4750,00 44,59 342,10 50,00 4087.78
4800.00 44,09 342.10 50,00 4123,54
1661,33
1693,69
1726,47
1759,67
1792,93
1903,62
1938,49
1972,97
2007,37
2041,70
2075,83
2109,68
2143,70
2178,39
2213,32
2248,06
2282,64
2317,24
2352,12
2387,52
-929,37
-942,95
-954,94
-965,96
-976,70
-987,23
-997,49
-1007,73
-1018,12
-1028,55
1826~04
1858,97
1892,06
1925,83
1959,82
4850,00 43,97 342,60 50,00 4159,49
4900,00 43,26 342,80 50,00 4195,69
4950,00 44,45 342,80 50,00 4231,75
5000,00 45,47 343,00 50,00 4267,13
5050,00 45,17 342,90 50,00 4302,28
5100,00 44,81 343,20 50,00 4337,64 2241,51 1993,64 -1038,85
5150,00 44,63 343,20 50,00 4373,17 2275,48 2027,32 -1049,02
5200,00 44,81 343,20 50,00 4408,70 2309,44 2061,00 -1059,19
5250,00 45,06 340,40 50,00 4444,10 2343,75 2094,54 -1070,22
5300,00 45,85 338,60 50,00 4479,17 2378,68 2127,91 -1082.70
330,78
330,89
331,05
331,24
331.42
331,60
331,78
331,96
332,14
332,31
332,48
332,64
332,80
332,93
333,03
Severity
(deg/lO00
1,86
3,41
0,46
0,64
1,16
0,84
1~35
1,22
3,88
1,56
0,74
1,68
0,66
1,05
3,31
0,91
0.52
0,73
0,18
0.18
0,43
0.26
0.56
0,97
1.14
3,95
3,93
3,64
1,46
1.00
0L74
1,45
2.38
2.06
0,62
0.84
0,36
0,36
3,99
3,01
Anadrill Schlumberger Page 3 7/13/98
Measured Station Station Station Vertical
Depth Inclination Azimuth InterVal Depth
(ft) (deg) (deg) (f0 (ft)
5350.00 46.20 335.50 50.00 4513.90
5400.00 46.10 334.10 50.00 4548.54
5450.00 46.40 333,90 50.00 4583,11
5500.00 46.17 333.60 50,00 4617.66
5550.00 46.03 334.10 50.00 4652.33
Vertical
Section
(f0
2414.21
2450.02
2485.95
2521.91
2557.76
Latitude
(~/-S)
2161.04
2193.66
2226.12
2258.54
2290.88
5600.00 46.39 334,00 50.00 4686.94 2593.66 2323.33
5650.00 46.71 333.90 50,00 4721.32 2629.77 2355,94
5700.00 46.45 333.90 50.00 4755.69 2665.90 2388.56
5750.00 46.42 334.00 50.00 4790.15 2701.94 2421.10
5800.00 46.86 334.10 50.00 4824.48 2738.10 2453.78
~/-w)
-1096.73
-1112.08
-1127.92
-1143.90
-1159.78
-1175.57
-1191.51
-1207.49
-1223.40
-1239.34
Total
displ
(ft)
2423.41
2459.45
2495.56
2531.70
2567.72
2603.81
2640.11
2676.42
2712.65
2749.00
5850.00 47.04 334,20 50.00 4858.61 2774.44 2486.65 -1255.30 2785.53
5900.00 47.13 334.30 50.00 4892.65 2810.85 2519.63 -1271.20 2822.14
5950.00 47.65 334.20 50.00 4926.50 2847.43 2552.77 -1287.19 2858.93
6000.00 47.65 333.90 50.00 4960.19 2884.19 2586.00 -1303.36 2895.88
6050.00 47.74 334.10 50.00 4993.84 2920.97 2619.23 -1319.57 2932.86
6100.00 47.81 333.90 50.00 5027.44 2957.80 2652.51 -1335.80
6150.00 47.66 333.80 50.00 5061.07 2994.61 2685.73 -1352.11
6200.00 47.12 333.80 50,00 5094.92 3031.23 2718.75 -1368.36
6250.00 47.23 333.80 50.00 5128.91 3067.72 2751.65 -1384.55
6300.00 47.56 333.50 50.00 5162.76 3104.35 2784.63 -1400.88
6350.00 47.74 333.60 50.00 5196.44 3141.14 2817.71 -1417.34
6400.00 47.73 333.50 50.00 5230.07 3177.97 2850.84 -1433.82
6450.00 47.74 333.30 50.00 5263.70 3214.81 2883.93 -1450.39
6500.00 47.71 333.40 50.00 5297.33 3251.65 2916.99 -1466.98
6550.00 47.37 333.50 50.00 5331.08 3288.38 2949.99 -1483.47
3324.98
3361.76
3398.91
3436.27
3473.82
3511.54
3549.28
3586.62
3623.48
3660.23
6600.00 47.31 333.90 50.00 5364.97
6650.00 47.94 332.50 50.00 5398.67
6700.00 48.33 331.60 50.00 5432.03
6750.00 48.51 330.10 50.00 5465.22
6800.00 48.90 327.60 50.00 5498.22
-1499.76
-1516.42
-1533.87
-1552.09
-1571.52
-1591.92
-1612.60
-1633.84
-1655.76
-1677.77
6850.00 49.03 326.90 50.00 5531.04
6900.00 49.03 326,70 50.00 5563.83
6950.00 47.77 324.00 50.00 5597.03
7000.00 47.59 323.30 50.00 5630.69
7050.00 47.47 323.40 50.00 5664.45
2982.95
3015.92
3048.81
3081.47
3113.62
3145.34
3176.93
3207.68
3237.46
3267.05
2969.88
3006.88
3043.68
3080.35
3117.15
3154.10
3191.10
3228.11
3265.10
3301.99
3338.76
3375.69
3412.92
3450.28
3487.73
3525.25
3562.77
3599.82
3636.30
3672.67
A~im
333.09
333.12
333.13
333.14
333.15
333.16
333,17
333.18
333.19
333.20
333.21
333.23
333.24
333.25
333.26
333.27
333.28
333.28
333.29
333.29
333.30
333.30
333.30
333.30
333.30
333.31
333.31
333.29
333.27
333.22
333.16
333.09
333.01
332.91
332.82
7100.00 47.27 323.50 50.00 5698.31 3696.90 3296.60 -1699.68 3708.98 332.73
7150.00 47.18 324.00 50.00 5732.27 3733.49 3326.20 -1721.38 3745.23 332.64
7220.26 46.90 322.40 70.30 5780.18 3784.75 3367.39 -1752.20 3795.99 332.51
7309.01 46.54 323.30 88.70 5840.99 3849.05 3418.86 -1791.19 3859.66 332.35
7405.36 48.06 323.90 96.40 5906.36 3919.68 3475.89 -1833.23 3929,70 332.19
Severity
(de~J100O
4.52
2.03
0.67
0.63
0.77
0.73
0.66
0.52
0.16
0.88
0.46
0.23
1.05
0.44
0.35
0.33
0.33
1.08
0.22
0.79
0.39
0.15
0.30
0.16
0.70
0.60
2.42
1.55
2.27
3.84
1.09
0.30
4.76
1.10
0.28
0.43
0.76
1.71
0.84
1.64
Anadrill Schlumberger Page 4 7/13/98
Measured Station Station Station Vertical
Depth Inclination Azimuth Interval Depth
(ft) (deg) (deg) (ft) (ft)
Vertical Latitude De~rture Total
Section (N/S) (El-W) displ
(ft) (ft) (ft) (ft)
7500,57 48,12 324,40 95,20 5969,95 3990,35 3533,31 -1874,72
7595,23 46,90 323,10 94,60 6033,85 4059,91 3589,57 -1915,96
7691,72 46,22 323,90 96,50 6100~1 4129,75 3645,89 -1957,64
7781,13 46,07 323,30 89,40 6162,15 4194,02 3697,78 -1995,90
7871,53 46,44 324,50 90,40 6224,65 4259,15 3750,54 -2034,37
324.30 90.10 6287.39
324.00 101.30 6358.58
324.40 98.80 6427.77
318.30 120.50 6512.55
319.10 93~60 6579.01
7961,58 45.29
8062,85 45,41
8161,70 45,69
8282,15 44,94
8375.81 44,59
8470,26 44,06 317,80 94,50 6646~1
8566,58 43,48 319,30 96,30 6716,15
8660,43 43,24 321,70 93,80 6784,36
8754,10 43,61 322,30 93,70 6852,41
8849,17 44,30 323,50 95,10 6920,87
8943,18 45,07 323,90 94,00 6987,70
9038,25 45,36 323,70 95,00 7054,62
9132,74 45,66 323,10 94.50 7120,85
9227,98 46,54 323,70 95,30 7186,93
9320,53 47,50 323,60 92,50 7249,99
4323.67
4395.~7
4465.93
4550.94
4615.96
4681L06
4746.75
4810.57
4874.62
4940.35
5006.26
5073,49
5140.68
5209,12
5276,58
3803.12 -2072.01
3861..54 ~ -2114.22
3918.74 -2155.48
3985.60 -2208.91
4035.12 -2252.41
4084,53 -2296,20
4134,46 -2340,30
4184,15 -2381,26
4234,90 -2420,92
4287,55 -2460,73
4340,82 -2499,86
4395.23 -2539.68
4449,35 -2579,88
4504,48 -2620,82
4558,98 -2660,93
3999,86
4068,89
4138,22
4202,04
4266,76
4330.93
4402L43.
4472.43
4556.79
4621.21
4685,72.
4750,87
4814,30
4878,03
4943,51
5009.19
5076.22
5143.20
5211.43
5278.72
332.05
331.91
331.77
331.64
331.52
'331.42
331~30
331.19
331.00
330.83
330,66
330,49
330,36
330,25
330,15
330,06
329,98
329.89
329,81
329,73
9413.11 46,96 323,10 92,60 7312,87 5344.33 4613,52 -2701,50 5346,28 329.65
9506,97 46,36 323,50 93,90 7377.32 5412,38 4668.28 -2742,31 5414,16 329,57
9601,06 46,90 322,10 94,10 7441,94 5480,49 4722.76 -2783,67 5482,09 329,48
9694.82 46.54 322,80 93,70 7506,17 5548,37 4776,84 -2825,25 5549,79 329,40
9788.86 45.80 322,80 94,10 7571,34 5615.96 4830.91 -2866,29 5617,23 329,32
9884.92 45.11 321.50 96.00 7638.68 5684.01 4884.93 -2908.27
9972.91 45.57 322.80 88.00 7700.54 5746.26 4934.36 -2946.67
10069.76 45.69 323.50 96.90 7768.30 5815.27 4989.79 -2988.21
10161.81 44.75 323.00 92.00 7833.10 5880.34 5042.11 -3027.28
10255.10 44.91 322.40 93.30 7899'.27 5945.82 5094.43 -3067.14
5685.12
5747,24
5816,13
5881,10
5946,48
6014.39
6081.13
6146.98
6212.10
6275.37
6334,25
6397,02
6455,82
6506,51
6564,46
10351,62 45,30 322,30 96,50 7967,38 6013,84 5148,56 -3108,90
10445,82 45,41 325,20 94,20 8033,59 6080,65 5202,60 -3148,52
10539,12 44,58 325,60 93,30 8099,56 6146,55 5256,90 -3185,98
10632,92 43,49 326,20 93,80 8167,00 6211,70 5310,88 -3222,53
10725,83 42,52 325,30 92,90 8234,93 6275,01 5363,26 -3258,19
325,10 88,00 8300,23
323,10 95,80 8372,43
323,60 93,80 8445,29
322,50 85,70 8514,22
322,80 102,40 8598,43
6333,92
6396,73
6455.58
6506,30
6564,30
5411.67 -3291.90
5462.65 -3328.86
5510.03 -3364.11
5550.73 -3394.71
5597.03 -3430.06
10813,76 41,67
10909,64 40,53
11003,44 37,52
11089,08 35,39
11191,51 33,96
329.23
329,16
329,08
329.02
328,95
328~7
328,82
328,78
328,75
328,72
328,69
328,64
328,59
328,55
328,50
Severity
(degnO00
0,40
1,64
0,93
0,51
1,04
1.29
0.24
0.40
3.65
0.71
1,11
1,23
1,78
0,59
1.14
0.87
0.34
0.55
1,03
1,04
0.71
0.71
1.22
0.67
0.79
1.20
1.17
0.53
1.09
0.48
0,41
2,19
0,94
1,24
1.24
0,99
1,77
3,23
2,60
1,41
Anadrill Schlumberger Page 5 7/13/98
Measured Station Station st~'~on Vertical
Depth Inclination Azimuth Interval Depth
(ft) (dog) (dog) (ft) (ft)
Vertical
Section
(ft)
Latitude
Cfi-s)
(ft)
Departure
(fO
11288.79 31.32 323.60 97.30 8680.35 6616.58 5639.04 -3461.50
11378.16 28.63 323.40 89.40 8757.79 6661.10 5674.95 -3488.06
11470.64 27.36 322.80 92.40 8839.38 6704.30 5709.63 -3514.10
11567.77 24.22 324.30 97.20 8926.88 6746.45 5743.62 -3539.24
11662.83 22.96 324.30 95.00 9013.94 6784.38 5774.50 -3561.43
11755.44 22.09 324.50 92.60 9099.48 6819.78 5803.34 -3582.08
11850.05 21.24 323.60 94.70 9187.49 6854.65 5831.64 -3602.60
11943.41 20.78 324.80 93.30 9274.59 6888.02 5858.77 -3622.17
12037.26 19.98 323.40 93.90 9362.61 6920.64 5885.26 -3641.34
12133.38 19.61 324.10 96.10 9453.03 6953.09 5911.51 -3660.58
6973.33
7005.27
7027.78
9510.77
9604.78
9672.21
5927.99
5954.18
5972.74
12194.61 19.10 324.60 61.20
12293.88 18.48 325.40 99.30
Survey Projected To TD
12365.00 18.48 325.40 71.10
-3672.40
-3690.75
-3703.55
Total
displ
(ft)
6616.71
6661.20
6704.39
6746.52
6784.44
6819.83
6854.69
6888.06
6920.67
6953.11
6973.35
7005.28
7027.79
A~im
328.46
328.42
328.39
328.36
328.34
-328.32
328.29
328.27
328.25
328.23
328.22
328.21
328.20
SeveH~
(deg/lOOf)
2.75
3.01
1.41
3.30
1.33
0.94
0.96
0.68
1.00
0.46
0.88
0.68
0.00
Anadrill Schlumberger Page 6 7/13/98
BP EXPLORATION
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
October 15th, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear AOGCC Representative,
Attached are bluelines and sepias for well Niakuk 61. Per 20.AAC 25.537(d)
BP Exploration would like these logs to be held confidential for 24 months.
The specific attached logs include:
Log Type Company Run Date
CDR MD Schlumberger 6/27-7/10/98
ADN TVD Schlumberger 6/27-7/10/98
ADN MD Schlumberger 6/27-7/10/98
CDR TVD Schlumberger 6/27-7/10/98
Please contact me at 564-5126 if you have any questions.
,% Depths
77~-123~
77
7757Y2~65
/~-123%
Sincerely,
CNS Greater Regional Opportunities
MS
Enclosures
Please sign below and return to Marian SIoan, BPX, Mail Stop MB9-4 for
receipt of transmittal. REoE~VE~
OCT q6
BP EXPLORATION
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
RO. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
October 6th, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear AOGCC Representative,
Attached are bluelines and sepias for well Niakuk 61. Per 20.AAC 25.537(d)
BP Exploration would like these logs to be held confidential for 24 months.
The specific attached logs include:
Log Type
Company Run
Date
Schlumberger 7/11/98
Schlumberger 7/11/98
Schlumberger 7/11/98
Schlumberger 7/11/98
Schlumberger 7/11/98
Platform Express Den/Neu SSTVD
Platform Express Comp Neu/GR
Dipole Shear Sonic Tool (Field print)
Platform Express Neu/Den/GR
RFT
Please contact me at 564-5126 if you have any questions.
Depths
10000-12360
10OOO-12360
10000-12360
10OOO-1236O
10000-12360
Sincerely,
David L. Boyer, Sr. Geologist
CNS Greater Regional Opportunities
MS
Enclosures
Please sign below and return to Marian Sloan, BPX, Mail Stop MB9-4 for
r
RECEIVED
OCT 06 998
Oil & Gas Cons. (.;ommissi~
Anchorage
BP EXPLORATION
BP Exploration (Alaska) Inc.
900 East Benson Boulevard
P.O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
August 12th, 1998
Alaska Oil and Gas Conservation Commission
3001 Porcupine Drive
Anchorage, Alaska 99501
Dear AOGCC Representative,
Attached is core information for the following Niakuk wells. Per 20.AAC
25.537(d) BP Exploration would like this core data to be held confidential for
24 months.
Analysis Type
NK-61 Dry Cuttings
NK-62 Core Analysis report
NK-15 Core Analysis report
Company Interval
10600-12337
Core Lab 11772-11949
Core Lab 20820-21194
Please contact me at 564-5126 if you have any questions.
Sincerely,
David Boyer, Sr. Geolog~
Greater Point Mclntyre Area
RECEIVED
MS
Enclosures
Oil & Gas Cons. C~
Anchorage
Please sign below and return to Marian Sloan, BPX, Mail Stop MB9-4 for
re ~ceipt,of transmi~)~ttal.
TONY KNOWLE$, GOVERNOR
ALASKA OIL AND GAS
CONSERVATION COMMISSION
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
FAX: (907) 276-7542
June 16. 1998
Lowell Crane
Drilling Engineer Supervisor
BP Exploration (Alaska) Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re~
Niakuk NK-61
BP Exploration (Alaska) Inc.
Permit No. 98-114
Sur. Loc.: 1383'NSL, 901~VEL, Sec. 36, T12N, R15E. UM
Btmhole Loc: 1955'NSL,4540'WEL, Sec. 25, T12N, R15E, UM
Dear Mr. Crane:
Enclosed is the approved application for permit to drill the above referenced well.
The permit to drill does not exempt you from obtaining additional permits required by law from
other governmental agencies, and does not authorize conducting drilling operations until all other
required permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035.
Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the
surface casing shoe must be given so that a representative of the Commission mav witness the
test. Notice mav be given by contacting the Commission petroleum field inspector on the North
Slope pager at 659-3607.
Chairman
BY ORDER OF THE COMMISSION
dlf/enclosures
CC;
Department of Fish & Game. Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA O;--AND GAS CONSERVATION COMN,._¢SION
PERMIT TO DRILL
20 AAC 25.005
la. Type of work [] Drill [] Redrill lb. Type of well D Exploratory [] Stratigraphic Test [] Development Oil
[] Re-Entry [] Deepen []Service [] Development Gas []Single Zone D Multiple Zone
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. Plan KBE = 59.7' Niakuk Oil Pool
3. Address 6. Property Designation
P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 034630j
4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025)
1383' NSL, 901' WEL, SEC. 36, T12N, R15E Niakuk
At top of productive interval 8. Well Number Number 2S100302630-277
1889' NSL, 4491' WEL, SEC. 25, T12N, R15E NK-61
At total depth 9. Approximate spud date Amount $200,000.00
1955' NSL, 4540' WEL, SEC. 25, T12N, R15E 06/18/98
12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD)
ADL 034625, 3325'I NK-16, 10.02' at 200' MD 2560 12057' MD / 9385' TVD
16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)}
Kick Off Depth 500' Maximum Hole Angle 46° Maximum surface 3684 psig, At total depth (TVD) 9160'/4600 psig
18. Casing Program Specifications Setting Depth
Size Top Bottom Quantity of Cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
30" 20" 94# H-40 Weld 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx.)
12-1/4" 9-5/8" 47# L-80 BTC 6117' Surface Surface 6158' 5000' 2322 sx PF 'E', 410 sx Class 'G'
8-1/2" 7" 29# L-80 BTC-M 12018' Surface Surface 12057' 9835' 220 sx Class 'G'
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented MD TVD
Structural
Conductor
Surface
~nrtoe~:lumcetid~ante R E C E IV E D
Liner
,' ':.i 0'-' 1998
depth: measured Alaska 0:1 & Gas C0ns. O0mmission ORIGINAL
Perforation Anchorage
true vertical
,
20. Attachments [] Filing Fee 'D Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program
[] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Scott Goldberg, 564-5521 Prepared By Name/Number: Carol Withey, 564-4114
21. I hereby certify that the forgoing,, is true~n~orrect to the best of
my
knowledge
Signed
Lowell C Titl_Le,_Drilling Engineering Supervisor Date
' ~,~_
Commission Use Only
Permit Number APl Number I Approval Date See cover letter
~ ~ - I I'-f' 50- 0.3 '~/- ~ ~ ~ ~'..~~ ~' "' ! ~ -" ~ for other requirements
Conditions of Approval: Samples Required []Yes [~,No Mud Log Required []Yes [:~No
Hydrogen Sulfide Measures [~Yes [] No Directional Survey Required []Yes [] No
Required Working Pressure for DOPE []2M; [] 3M; ~I, 5M; [] 10M; [] 15M
Other: 0rJginal ,k;lgp. c. 0 ~), by order of
^ rom W. on t0, Oomm,ss,one , ecomm ,on
Form 10-401 Rev. 12-01-85 Submit In Triplicate
NK-61 Well Plan _ t -~ -~ Rev 0
NK-61 Well Plan Summary
Surface Location: 1383' FSL 901' FEL Sec 36 T12N R15E
Target Location: 1889' FSL 4491' FEL SeC 25 T12N R15E
Bottom Hole Location: 1955' FSL 4540' FEL Sec 25 T12N R15E
I AFE Number: I 731217 I Rig: ] Pool#7
I Estimated Start Date: I 6-18-98 I I Operating days:
9,385' I
IMD: I 12,057'
Type of Well (producer or injector):
Well Design (conventional, slimhole, etc.):
I
ITVD: I IKBE: I 59.7'
Producer
Ultra-Slimhole Longstring
Formation Markers: (all depths RKB'
Measured True Vertical Formation Mud
Formation Tops Depth, ft Depth, ft Gradient, ppg Weight~, ppg
Base Permafrost 1890 1,860 8.552 8.8
SV3 4988 4,244 8.55 9.2
SV1 5852 4,846 8.55 9.1
Ugnu 6574 5,349 8.8 9.4
West Sak 8891 6,953 8.8 9.4
Colville 9447 7,338 8.80 9.4
Shale Wall 10951 8,403 8.80 10.8
HRZ 11552 8,915 9.40 10.83
Kuparuk 11817 9,160 9.7 10.8
TD 12057 9,385 9.7 10.8
1 Unless otherwise noted, the mud weights are based on a minimum: 125 psi overbalance, if the depth <5000' ss;
and 150 psi overbalance, if the depth >5000' ss.
2 Seawater gradient assumed through the SV sands.
3 10.8 ppg is a result coming from Wellbore Stability Study. Value may change depending on ECD Considerations
from Hydraulics and PWD. Desired Static Bottomhole EMW is 11.0 ppg
2 6-4-98--SG
NK-61 Well Plan " --- Rev 0
Casingfrubing Program: (all depths feet RKB)
Hole Size Csg/Tbg WtfFt Grade Conn. Length Top Btm
OD MDfrVD MDfrVD
30" 20" 94# H-40 WLD 80 GL 80/80
12 1/4" 9 5/8" 47# L-80 BTC 6117 GL 6158/5000
8 1/2 7" 29# L-80 BTC-M 12018 GL 12057/9385
Tubing 3 V2" 9.3# L-80 IBT-Mod 11580 GL 11617/8974
Loggin_eJFormation Evaluation Program:
Surface MWD/GR
Production MWD/GR;
CDR/ADN;/PWD
Wireline: Schlumberger RFT
Cased Hole Logs: Schlumberger USIT/Continuous Gyro/GR
Mud Program:
Surface Hole (0-6158'): Fresh Water Surface Hole Mud
Interval Density Viscosity YP LSR YP Gel-10 sec Fluid
(ppg) (seconds) Loss
Initial 8.6-9.2 300-200 70-50 30-40 35-55 12-15
SV4 8.9-9.4 120-200 40-25 18-11 20-35 6-8
Interval TD 9.0-9.4 60-80 20-35 8-15 20-35 6-8
Production Hole (6158'-12,057'): Low Solids Non-Dispersed
Interval Density Viscosity YP LSR YP pH Fluid
(ppg) (seconds) Loss
Initial 8.6-8.8 42-48 8-14 4-7 10.5-9.0 12-8
Ugnu 9.2-9.4 48-60 18-25 8-12 9.0-10.0 8-6
West Sak 9.2-9.4 48-60 18-25 8-12 9.0-10.0 8-6
Colville 9.2-9.4 48-60 18-25 8-12 9.0-10.0 _+4
Shale Wall 10.8 40-60 18-25 8-12 9.0-10.0 _+4
HRZ 10.8 40-60 18-25 8-12 9.0-10.0 _+4
Kuparuk 10.8 40-60 18-25 8-12 9.0-10.0 _+4
oEC '[VED
Alaska Oil & 6a.s Cons, Commission
AnchoraCe
3 6-4-98--SG
NK-61 Well Plan ....... Rev 0
Cementing Program
Hole Category Casing VolumeI Type of Cement Properties2
Size/Depth
Surface
First Stage 9 5/8" @ Lead3 Lead Lead
6,158' 560 sx Permafrost "E" Den 12.0 ppg
216 bbls Yield 2.17 ft 3/sx
Water 11.6 gps
TT 4.0 hrs
Tail.4 Tail Tail
410 sx Class "G" w/ Den 15.8 ppg
84 bbls 0.2 % CFR-3, Yield 1.15 ft 3/sx
0.2 % Halad 344 Water 5.0 gps
TT 3.5 hrs
Second Stage Stage collar Lead5 Lead Lead_
@ 2,100' 1762 sx Permafrost "E" Same as above
681 bbls
Production 7" @ 220 sx6 Class "G" w/ Den 15.6 ppg
12,057' 45 bbls 0.25% CBL Yield 1.2 ft 3/sx
0.75% Halad 344 Water 3.5 gps
0.4 % CFR-3 TT Batch mix +
0.38 % HR-5 4.5 + hrs
Rounded up to the nearest 10 sacks.
Thickening time required; actual times should be based on job requirements and lab tests.
Open hole volume from top of tail to stage collar + 30% excess.
750' TVD open hole volume + 30% excess + 80' shoe joint.
Open hole volume from stage collar to surface + 350% excess + casing capacity to stage collar.
To 1000' MD above Kuparuk +50% excess + 80 ft shoe joint
4 6-4-98--SG
NK-61 Well Plan - - - Rev 0
Directional:
KOP:
Max. Hole Angle:
Close Approach
Wells:
Survey Program:
500'
Begin build-l.5°/100 ft-build to 46 o @ 335°
azimuth. Azimuth turn to 348° at 3914
46° (Tangent Angle) 4,800'-10,508';
Minimum Normal Distance--Survey-to-Survey
NK- 15 20.19' @ 700'
NK-16 10.02' @ 200'
NK- 17 16.74' @ 400'
Surface- 1,800' Gyro single shots
1,800' - 6,158' Single shot MWD surveys; if magnetic
....................................................... ......
6,158' - TD MWD surveys
Surface - TD Gyro--Gyrodata continuous mode
Hole Cleaning:
· Flowrate is the key parameter to hole cleaning. Field studies have shown that a "hurdle"
exists on the low side of flowrate and diminishing returns exist on the high side.
· This hurdle needs to be established so that ECD effects can be minimized in future ERD
wells. This flowrate is estimated to be 450-500 gpm. Use PWD and especially torque
and drag monitoring to attempt to find this "hurdle" rate.
· Pipe rotation is critical for effective hole cleaning. The preferred surface speed is 100-120
rpm.
· Check with Directional Driller and MWD Engineer to find maximum rotary speed of
tools while circulating
· The term "Bottoms Up" is somewhat meaningless for ERD wells, since the cuttings will
move much slower up the hole than the fluid. To circulate bottoms up before tripping will
not clean the hole. You will simply shift the cuttings or worse, create a dune up the hole.
Usually it takes 2 sometimes 4 bottoms up to clean the hole. BP's recommended circulation
is a minimum of 2 V2 bottoms up. When circulating & reciprocating for extended periods
pull one stand per hour to minimize the effects of circulation on a single area. On past wells
we have seen significant hole enlargement in areas where repetitive circulation and
reciprocation was used. This will create a zone of low annular velocity and therefore a place
for cuttings to settle. These cuttings will pose a serious pack off threat later in the well.
· Remember that a clean hole for drilling and a clean hole for tripping are quite different.
· Monitor hole cleaning at all times by comparing S/O, P/U, Rotating Weight and Torque
readings to predictions provided by Operations Drilling Engineer. Remember that when
taking the readings, the comparison will not be accurate unless the P/U and S/O are taken
with out pumps.
· When tripping out of hole and a tight spot is encountered, assume that the fight spot is
cuttings. RIH until the BHA is clear of the tight spot. Circulate and rotate for 30 minutes.
POOH. If the tight spot has disappeared or moved up hole, then the tight spot was most
likely cuttings. If the tight spot is in the same place, then it is likely a formation condition
5 6-4-98--SG
NK-61 Well Plan '-- ..---~ Rev 0
and back reaming should be applied. If backreaming is necessary, use flowrates similar to
that used while drilling. Do not backream at a low flowrate.
Drilling Hazards/Risks
Reservoir Pressure
Segment 1, which this well will penetrate has been on a waterflood program injecting at 20,000
BWPD. Because of this, the expected reservoir pressure for the Kuparuk formation is expected
to be 4600 psi @ 9160' TVD. This is an Equivalent Mud Weight of 9.7 ppg.
Lost Circulation/Faults
The Niakuk bounding fault is expected to be crossed in this well. In addition there are a large
amount of smaller faults "below" the target. The directional plan is designed as a S-Shape well
to go over this faulted section.
Close Approaches
Close approach issues will be of critical importance on this well. NK-61 is designed to go right
through the main corridor of Niakuk drilling. There are close approach wells both shallow and
deep. The current directional plan passes all appropriate Anti-Collision rules.
Formations
Expect to have full sections of the Tuffs and HRZ. Both formations have shown hole instability
potential in the past. Mud weight will be increased and shale stability treatments will be
performed as needed.
Well Control:
Well control equipment consisting of 5000 psi WP pipe rams, blind rams, and annular preventer
will be installed and is capable of handling maximum potential surface pressures.
Diverter, BOPE and mud fluid system schematics on file with AOGCC.
Contacts:
Office Home Pager
SSD
Drilling Superintendent Dan Stoltz 564-4922 345-9066 275-4570
Engineering Supervisor Lowell Crane 564-4089 868-7711 275-8644
Operations Drlg Engrs Scott Goldberg 564-5521 345-4925 275-4365
Asset Drilling Engineer
ARCO GPMA Contacts
Production Engineer Bob Gerik 564-5494
Geologist Dave Boyer 564-5126
Geophysicist Martin Novak 564-4894
Geoscience Manager Barry Cohn 564-4273
6 6-4-98--SG
NK-61 Well Plan -- .~-~ Rev 0
Brief Summary
Move rig to NK-61. NU diverter
Directionally drill 12 tA" surface hole to section to TD at 6,158' MD.
Run and cement 9 5/8" surface casing with 2 stage job. Ensure cement to surface.
ND diverter NU B OP's and test. Notify AOGCC 24 hours in advance to witness test
Drill 8 1/2" hole to well TD at 12,057' MD
Run open hole logs
Run and cement 7" intermediate casing
Run cased hole logs
Run 3 V2" single completion with tail set into liner
Secure well; RDMO
Post Rig Work
Perforate as per asset requirements
7 6-4-98--SG
Anadrill Schlumberger
Alask~ District
llll East 80th Avenue
Anchorage, AK 99518
(90?] 349~45[1 Fax 344-2160
DIRECTIONAL WELL PLAN for S}{AR~D SERVICES DRILLING
Well ......... : NK-61 (P4)
Pield ........ : Niakuk, Main Pad
Computation..: Minimum Curvature
Units ........ : FEET
Surface Lat..: 70.34741866 N
Surface Loag.: 148,20042083 W
Legal Description
Surface ...... : 1383 FSL 90[ FEL
Target ....... : 1889 PSL 449[ FEL
B~{L .......... : 1955 FSL 4540 FEEL
LOCATIONS - ALASKA Do~e: R
X-Coord ¥-Coord
S36 T12N RiSE UM 721660.01 5979921.52
S25 T12N RL5E UM 717900o00 5985600.00
S25 T12/~ RL5E LTM 717849.16 5985664.20
PROPOSED WEI~L PROFILE
STATION
/DENT[F/CATION
K0P 1,5/[00 BUILD
MEASURED INCL~
DIRECTION
DEPTH ANGLE AZIMUT~t
0.00 0.00 0-00
500.00 0.OO 336.00
600.00 1.50 335.00
700.00 3.00 33~.00
BO0.O0 4.50 335.00
VE/~T I CAL-DE~TI{9 SECT/ON
TUD SUB- ~EA DEPART
0.00 -59.70 0,00
S00.O0 440.30 0.00
599,99 540.29 1.30
699,91 640.21 5.20
799,69 ?~9.99 11.69
Prepared ..... : 03 Jun 1998
Vert sect ~z.: 328.14
KB elevation.: 59.70 ft
Magnetic Dcln: +28.264 (El
Scale Pactor.: 0.99995581
Convergence..: +1.69481545
ANADRILL AKA-DPC
APPROVED
FOR PERM[TI'lNG
ONLY
PLAN
O00RDI~ATES-FROM ALASKA Zone 4 TCOL DL/
WEL//{EAD X Y FACE
O.OO N 0.00 E 721660.01 5979921.52 2EL 0.00
O.OO ~ 0.00 E 721660.01 5979921.52 25L O.OO
1.19 N 0.55 Iq ~21659.42 5979922.69 2~L 1.50
4,74 N 2.21 ~ ~216~7.66 5979926.20 25L ~.50
10,67 N ~.~B ~ 721654.72 5979932.04 25L Z.SO
CURVE 1.5/S00
900,00 6~00 335.00
I000,00 7.50 335.00
~100,00 9.00 335.00
t200,O0 10.50 335.00
[300,00 12.DO 335.00
899.27 B39.57 20.77
998.57 93B.B7 32.4~
1097.54 L03?.B4 46.69
1196.09 1~3G.39 63.50
1294.16 1234.46 82.87
18,96 N 8.B~ ~ 721660.61 5979940,21 IdS 1.50
29,62 X 13,B1 ~ 721645.3~ 5979950.71 ~S 1,50
42,6~ N 19.87 ~ $21638.88 5979963.53 HS 1.50
57,97 N 27.03 ~ 72~631.28 5979978.66 HS 1.50
75.65 N 35,28 ~ 721622.$1 5979996.09 HS 1.50
14oa.oo $3.50 335.00
1500,0O 15.00 335,00
1391.70 1332.00 104.78
1488.62 142~.92 129.22
95,65 N 44,60 W 721612.60 59BOO15.81 HS 1.50
117,96 N 55.01 ~ 721601.54 528003?.80 ~S 1,50
(AnadriLl (c)98 NK61P4 3.2C 12:1{ PM P) k3
STATION
[DENTIFICATr0N
BASE PER]~AI=ROST
CYRVE 1.7~/100
E~D L.75/100 CURVE
CUParS 5.5/[O0
MI~ASUREO [NCLN
DEPTR AMGLE
[600,00 16.50
LT00.OO 18.00
kSO0.O0 19,50
[860.00 20,40
1890,14 20.40
[925,00 20.40
2000.00 21.67
2[00.00 23.36
2200.00 25.06
2300.00 26.77
2400,00 28.48
2S00,00 30.20
2600.00 31.92
2700.00 33.64
2800.00 35.37
2900.D0 37.09
3000.00 38.82
5100.00 ~0.$5
3200,00 42.28
3300,00 4~.02
3337,34 44.66
3913.93 44.66
4000.00 44.62
4L00~00 44.60
4200.00 44.63
4300.00 44.70
4400.00 44.80
4500.00 44.94
(Anadrill (c}98 NK61P4 3.2C ~2:14 PN P)
PROPOSEO WELL PROFILE
D[RECTIO~ V~R~CAL-DE~THS SECT[ON
AZIMUTH TV]) SUB-S2Uk DEPART
==== ..... =====~== ..... =
335.00 1564.86 1525.16 156.17
335.00 1680.36 1620,66 185.61
335,00 1775.05 1715.3S 219.52
335.00 183L.45 1771.7S 237.85
335.00 1859.70 1800.00 248.28
335.00
334.03
332.$9
331.89
331.02
1892.37 1832.67
1962.37 1902.67
2054.75 1995.05
2145.95 2086.25
2235.69 2176.19
3~0.24 2324.49 1264.79
329.54 2411,66 2351.96
328.91 2497,32 2437.62
328.34 2581,39 2S21.69
32~.82 2663.80 2604.~0
327.3~
326.90
326.49
326.11
325.76
2744.46 2684.76
2823.31 2763.6L
2900.26 2840.56
2975.24 2915,54
3048.20 2988.50
32S.63
325.63
327.46
329.60
331.73
3074.90 3015.20
3485.00 3425,.30
3546.24 3486.54
3617~43 3557.73
367S-62 3628.92
333.87
335.99
338.11
3759.75 3700.05
3830.78 3771.08
3901.65 3841.95
03 JUn 1998 Page 2
260.34
257.09
325.22
366.~1
409.74
456.06
505.0~
556.62
6S0.75
667.40
726,49
787,99
851,82
9i~.94
1012.35
1417.27
1477.72
I547.9S
1618.]1
[688.16
1758.05
1827.7(
COORD I ~IATES - FRO~
WELLMEAD
======:=== ........
ALASKA Zo~ 4 TOOL DL/
X Y FACE I00
142,56 N 66.48 W
169.43 N 79.01 W
]98.67 N 92.59 W
217.12 N 101.24 W
226.6~ N 105.69 W
721589.35 5980062,04 HS 1.50
721576.03 5980088.54 HS 1-50
$2176[.59 5980117.25 HS 1.50
721552.39 5980235.54 KS 1.50
~21747.67 5980144.9~ ES 0.00
237.65
265.95
296.19
]32.52
370.91
[~0.$2 W $21542.2~ 5980155.78 16L O,OO
122.4[ W 7215~9.9~ 5980179.72 i~L 1.75
139.53 W 721511.79 5980253.44 14L L.75
158.54 W 721491.71 5980249.19 13L
[79.~4 W 721469.69 ~980286.94 12L
411.31
453.69
498-0[
544.23
592.3L
202.19 W 721445,76 5980326.6~ 12L L.75
226.77 W 72~419,93 5980368.29 11L L.?5
253.17 W 721392.23 $9~0411.81
27[.36 W 721362.69 59SD457.17 10L 1.75
]1~.31 W 72L~1.~3 5950504.34 9L 1,75
642.20
693.8~
747.22
8~2.26
858.91
343.00 W 721298.19 5980553.27 9L 1.75
376.39 N ~1263.29 5980603.91 9L 1.75
411.45 W 721226.66 5980656.21 BL 1.75
448.15 W 721[88.55 5980710.13 8L 1.75
486.46 ~ 721148.58 5980765.62 8L 1.75
880.46
1215.00
1265.45
1325.35
501.L7 ~ 721133.04 5980786.74 HS 1.75
730.00 W 720894.43 5981114.35 93R 0.00
763.34 W 720859.6[ 5981163.$9 9[R 1.50
800.00 W 7208~1.20 5981222.57 90R 1.50
834,40 W 72078S,01 5981282,75 87R 1.50
1449.09
1577.8[
666.52 W 720751,~$ $96134~,27 87R [.50
$96.35 W 720719.35 5971407.13 85~ 1.50
ANADRtLL AKA-O?C
APPROVF, D
FOR P£RMITTiNG
ONLY,
Z
STA? I 0~;
I DE}VEl FI CAT/ON
SV4
PROPOSED ;;~LL PROF!LE
E~'m 1.5/100
CtTRVS 1.5/tO0
b1EASURED I NCLN D I RECTION
DEPTK ANGLE AZ IM]/IS{
4515.62 44.97 338-4¢
4600.00 45.I3 340.21
4700.00 45.35 342.30
4500.00 45.61 344.38
4900.00 45.90 346.43
TT6/SVl
4970.41 46.13
4987.95 46.13
5256 . 78 46 . 13
5300.00 46.04
5400.00 45.86
~o-3/4, csg ~ ~11>
5500.00 15.71
5600.00 45.60
5700.00 45.53
5800.00 45.50
5852.02 45,50
z~,;'D t. 5/lOO CU~'tr~
UG4A
NEST SAK
5900.00 45,51
6000.O0 45,55
6100.00 45,64
6157.73 45,70
6200.00 45,76
6300,00 65.92
6400,00 46.12
6432.63 46.19
6573,86 46.19
8890,83 46.Z9
C~3 9446-96 46.19
DROP 2/100 10507.96 46.19
10600.00 44.35
(Anadrill (c)9~ ~K6194 3.2C ~2:14 PI~ PI
03 Jun 1998
Page 3
VERTICAL-DEPTHS
TVD SUg-SEA
=_-====== ...... = .......
SECT ION COORDINATES - ~ROM
DE PART WELLB~J~D
3912,70 3883.00
3972.32 3912.62
4042,7~ 3983.04
4112.87 4053.~?
4182,65 R122.95
1838.61 1588.06 N 927.94
1597_18 1643.93 N 949.02
1966.32 1711.~6 N 97~.~3
2035.12 [779.45 N 992.26
2~03.52 1848.77 N 1010.31
ALASKA Zo~e 4
Y
720685,55 59814~1.3~
720662,83 5981536.59
720638.04 59~1603.11
720615.60 5951670.77
720595.51 595L739.52
TOOL gL/
FACE 100
84R 1.50
82R 1.50
8LR 1.50
79R 1.50
78R 1,~0
347.86
34~.86
34~.86
346.97
344.9~
4231,55 ~171.~5
4243.70 4184.O0
4430.00 4370.30
445~.97 4400.27
4529.51 ~469.81
2151.42
2163.32
2345,76
2375 . ~4
2443.57
1898.16 N 1D21.55 W 720582.78 5981788.55
1910.52 N 1024.24 W 720579.76 5981800.83
2100.00 N 1065.00 W 7205~3.42 5981989.01
2130.58 N 1071.78 W 720525.74 5982019.18
2200.09 N 1089-25 W 720506.22 5982088.34
~L~ 1.50
~S O.0O
9BL 0.00
981 1,50
961 1,50
342.82
340.72
338.63
336.52
335.43
4599.25 4539.85
4669.15 4609,45
4739.16 4679.~6
4809.24 4749.54
4845.70 4786,00
2812.55
2582.04
2652.00
2722.37
2759.13
2268.93 N 1109.17
2336.85 N 1131.54
2403.80 N 1156.34
2469.75 N 1183.55
2503.64 N 1198.66
720484.27 5982L56.55 951 1-50
720459.90 5982223.?8 931 1.50
720433.~4 59822~9.97 92L
720403.98 5982355.0~ 901 1.50
720387.~8 5982388.~0 901 1.50
334.42
332.32
330.22
329.02
328.13
48~9.~3 4819,63
4949.35 ~889.68
5019.86 4959,66
$059.70 5000.00
5089.2~ 5029-51
2793.11
2864-16
2935.49
2976.77
3007.04
2534,63 N 1213.16 W 720372.47 5982419.05 891 ~.50
2598,42 N ~245.I5 ~ 720338.62 5982481.86 881 1.50
2661.05 N ~279.48 ~ 720302.44 5982543.45 861 1.50
2696.68 N ~300.37 ~ ~20250.52 5982575.44 851 L.50
2722.~1 ~ 5316.~5 W 720263.98 5982603.79 851 ~.50
326,05 515~-~ 5099.18 3078.76
323.99 5225.33 5168.63 3150.60
323.32 5250.93 5~91.23 3174.06
323.32 5348.70 5289.00 327S.61
323.32 6952.70 6893.00 4941.69
2782.73 N 1355,12 W 720223.25 5982662,$3 831
2841o68 N I316.36 W 720180.28 5982720,53 821 L.50
2860.63 N 1430,31 W 720165.77 5982739,06 H$ L-50
2942.16 N 1471.~9 W 720102,$O 5982818,95 HS O.O0
4283.22 N 2470,02 W 719064.50 5984129,62 ~S 0.00
323.32
323,32
323.32
7337,70 7278.80
8072,21 8012.51
8136,98 8077.28
5341.59
610~ .52
6~69
4605.05 N 2709.77 W 7~8815,35 5984444.21 HS 0.00
$2Z9.06 N 3167.16 W 718340.02 s985044.39 LS O,O0
5271-50 ~ 3206.22 W 718299,43 $955095.65 LS 2,00
ANADRILL ,A[<A-DF'-C
APF.ROV D
FOR PERMiT ,'!, .
ON
]>
Z
PROPOSED ~ELL DROFILE
STATION
I SENTI
K-5
MEASUR_ED INCLN DIP~ECTION
DEPTH AI~GL~ kZI~3TH
10~00.00 42,35 323.32
10900.00 38.35 323.32
10951.42 37.32 ~23.32
11000.00 36,35 323.52
VERTIC_kL- 0MPTHS SECTION
TVD SUB - SEA DEPART
8209.70 8170.00 6238.~8
8284.77 8225.0? 6303.9~
$36~.09 8302.39 6367.08
8402.70 8343.00 639~.50
~441.59 8381.89 6427.53
11100.00 34.35
11300.~0 30.35
11400.00 ~8.35
11500.00 26.35
323.32
323.32
323.32
323.32
323.32
8525-15 8463-45 6465.17
8606.68 8546.98 6539.95
~692.07 8632.3V 659~.q9
6779.24 8719.54 6640.62
8868.05 8~08.35 6686.~O
03 JUn 1998 Page 4
COORDI~ATES-PROM AI~kSKA ~on~ 4
53~6.54 N 314V.22 W 718256.82 5985149.45
5379.52 N 3286.67 ~ q17215.81 5~87~D[.24
5430.36 N 3324.56 W 718176.45 5~85250.94
5455.65 N 3343,~0 W 718156.87 5985275.66
5~79.01 N 3360,80 W 7~81~8,~9 5985298.49
5525.41 N 3395,36 W 7~8102.8~ $985343.84
5569.%9 M 3428.20 W 71B068.75 5985386.93
5611.21 N ~459,27 W 7~8036.45 S985427.~1
5650.51 N 3488,55 W 718006.02 5985466.13
5689.35 N 3515.99 W 717977,51 5985502.14
TOOL Db/
FACE
LS 2.00
55 2.00
LS 2.00
LS 2.00
L~S 2.00
~ 2.00
~ 2.00
I.,,9 2.00
~ 2.00
LS 2.00
TOP
2/100 O~OP
~551.B2 25.3l
1~600.00 24,35
11~00.00 22,35
llB00.00 20.35
1181~.4i 20.00
TA3{G~T **"***'****** 11817.4[ 20.00
~i'~2)P KUPARUK 11817.4~ 20.00
~ 2~5/$" CS~ ~<{]> 12056.85 20.00
323.32 891~.70 8855.00 6708.90
323.32 8958.~2 S$98.72 6729.05
323-32 9050.23 8990.53 6760.5~
323.32 9143.36 9083.66 6804.82
323.$2 9159.~0 9T00.00 6810.80
323.$2 9~59.~0 9100.00 6810.80
323.32 9384.~0 9327.00 6892.{0
5705.46 N 3529.48 W
5721.68 N 3541,57 W
5753.46 N 3565,24 W
5782.65 N 3586,99 W
5787.47 N 3590.57 W
7Z7963.49 59~5519.84 LS 2.00
7Z7950.93 5985535.69 ~ 2.00
717926,33 5985566.96 LS 2.00
7~7903,73 5985595.29 1-~ 2.00
7Z7900,00 $9S5600,00 HS 2.00
5787.47 N 3590,57 W 7Z7900.00 $975600.00 H8 2.00
5787.~7 N 3590,57 W 7~900.00 5985600.00 HS 2.00
5853.14 N 3639.50 W 7Z78~9.16 $97566~.20 O.OO
(A~ack'ill <c)98 NK61. P4 ,3.2C 12:14 P>} P)
'-0
C)
06/03/1998 14'17 907-344-2160 ANADRILL DPC PAGE 07
., SHARED SERVICES DRILLING
-- , · ~nll~lln
A) KB 0 0 N 0 E
.~ ~op ~.~/~oo~.z.. ~.o oN o~ /__% PLAN VIEW
D) ENO 1,5/100 CURVE 1860 2t7 N ]01
E) CURVE 1.75/~0D ~925 238 N JJi W CLOSURE ..... : 6892 feet at Azimuth 328,~3
F) ENO ~.75/~00 CURVE 3337 880 N 50~
6) CUR~ ~,5/100 39t4 12~5 N 730 ~ DECLINATION,' +28.264 (E)
H) END 1.5/100 CURVE 4970 ~898 N ~022 W SCALE ' J inCh : ~000 feet
Ii CuRvE ~.5/JO0 ~257 2~00 N t055
d) Jo-3/4" cs6 PT <11> 6~58 2697 N t300 N DRAWN ' 03 Jun J998
K) END 1.5/~00 CURVE 6a33 286~ N ~a~O
L) DROP 2/JO0 t050B 52~9 N 3~67
N) ENO ~/tO0 DROP t~8~7 5787 N 359~
O) TD 7-5/8" CSG PT<l I> i2057 5853 N 3639
, ~ - -6500
Tar ]-eft-
................ 5000
............ 4500
~000
3500
3000
'. FOIL
~ ,.,,
'~ "J ~ 2000
i . ~ H
...... tooo
.
--500
6500 6000 5500 5000 4500 4000 3500 3000 2500 2000 ~500 lO00 5~9 0 500
<- NEST' EAST ->
SHARED
SERVICES
DRILLING
°- J VERTICAL SECTION VIEW
Section at: 328.14
c-= fVO Scale.- 1 inch = 1200 feet
o ~ .... Oep Scale.' 1 inch = J200 feet
Drawn · 03 Jun 1998
°i...... ~'~-~ ~c~~"~r~ ,~ /radii ........ ]1 Schlumberge£
Marker Identification ND BKB SECTN INCLN
o .............. A! KB 0 0 0 0,00
§) KOF 1,5/100 BUILD 500 500 0 0.00
C) CURVE i.5/lO0 1000 999 32 7,50
~-- B) END 1.5/100 CURVE 1860 1831 238 20.40
E] CURVE ~,7§/100 19~5 1892 250 20.40
;~ F) END 1.7§/100 CURVE 3337 3075 1012 44,66
) G) CURVE 1.5/100 39t4 3485 ~4~7 44.66
....... H] ENO ~.§/1OO CURVE 4970 4232 21§1 46.13
I) CURVE ~,5/~00 5257 4430 2346 46.J3
~- ~ ~ J) 10-3/4" CSG PT <II > 6~S8 5060 2977 45.70
)-"s'-='-v3 ~''-"=~=~" ...........~ K) END t,5/JO0 CURVE 6433 525~ 3174 J6,19
L) DROP 2/t00 t0508 807~ 5105 ~6.19
i~ M] END 2/t00 DROP 11817 9~6D 68tl 20.00
N) TARGET ~~~ 11817 g~60 6811 20.00
) ~B~F~- ~ - -~ 0) TO 7-5/8" CSG PT<II > t~057 9385 689~ 20.00
.
x-s e.o3 ANAl)RILL A~.--D PC
Oiq
............. 7,/..~ ~ n
L~...~.. ..................... ~. ........ ~ .................. - ........
....... I
11
0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 :-:- 6600 7200
Section Departure ...
DATE
H 13 4 3 91 o~,-'
._
VENDOR A_.ASK,
DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT
021798 CKO21798N .tOO. O0
HANDLIN(~ INST- s/h kathy campoanoT- x 5122
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIRI;I3 Army=:
· WELL PERMIT CHECKLIST COMPANY ~ ~ ')t. WELL NAME ,/~/'~ - (~ f PROGRAM: exp [] dev,~ redrll [] serv [] wellbore seg II ann. disposal para req II
FIELD & POOL
INIT CLASS D(~ O I - ~' i GEOL AREA.. ~ ~ 0 UNIT# ! I ~ ~-'~ ON/OFF SHORE
ADMINISTRATION
/~,~R DATE ,,
1. Permit fee attached .......................
2. Lease number appropriate ...................
3. Unique well name and number ..................
4. Well located in a defined pool ..................
5. Well located proper distance from drilling unit boundary ....
6. Well located proper distance from other wells ..........
7. Sufficient acreage available in drilling unit ............
8. If deviated, is wellbore plat included ...............
9. Operator only affected party ...................
10. Operator has appropriate bond in force .............
11. Permit can be issued without conservation order ........
12. Permit can be issued without administrative approval ......
13. Can permit be approved before 15-day wait ...........
ENGINEERING
APP_R.,: DATE
14. Conductor string provided ...................
15. Surface casing protects all known USDWs ...........
16. CMT vol adequate to circulate on conductor & surf csg .....
17. CMT vol adequate to tie-in long string to surf csg ........
18. CMT will cover all known productive horizons ..........
19. Casing designs adequate for C, T, B & permafrost .......
20. Adequate tankage or reserve pit .................
21. If a re-drill, has a 10-403 for abandonment been approved...
22. Adequate wellbore separation proposed .............
23. If diverter required, does it meet regulations ..........
24. Drilling fluid program schematic & equip list adequate .....
25. BOPEs, do they meet regulation ................
26. BOPE press rating appropriate; test to ~z:P~ psig.
27. Choke manifold complies w/APl RP-53"(May 84) ........
28. Work will occur without operation shutdown ...........
29. Is presence of H2S gas probable .................
GEOLOGY
/~R DAIE
.
30. Permit can be issued w/o hydrogen sulfide measures .....
31. Data presented on potential overpressure zone_s. ....... ~-.-:--':'"":'"; ......... Y N
32. Seismic analysis of sha?..ow..gas~.ones:-.-"-~"-i-'~-. ....... Y N
33. Seabed condit~j]~y (i~off-shore) ............. Y N
34. C~phon,e.for weekly progress reports ....... Y N
~ lexplora~ory oniyj
ANNULAR DISPOSAL
APPR DATE
35. With proper cementing records, this plan
(A) will contain waste in a suitable receiv~.g, zorre':," . ...... Y N
(B) will not contaminate freshwate.~ause drilling waste... Y N
to surface; ~,..--~
(C) will not impair m~al integrity of the well used for disposal; Y N
(D) will not da~ producing formation or impair recovery from a Y N
pool; am3
(E) will not circumvent 20 AAC 25.252 or 2.,0 AAC 25.412. Y N
GEO!~_G_Y: E N GIN__E.. F_~ LN_~: ,UIC,/~ular COMMISSION:
J D H ~7..."-~ /~'~' RNC ~
co '(.:.o
Comments/Instructions:
M:chet~list rev 05/29/98
dlf: C:\rnsoffice\wor diarq\dial~a\(;hecklisl
