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2022-1019_Location_Clear_KRU_1M-17_ae Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 10-27-2022 P. I. Supervisor FROM: Adam Earl SUBJECT: Final Location Clearance Petroleum Inspector KRU 1M-17 CPAI PTD 2012300; Sundry 320-524 10-19-2022: I traveled to Kuparuk River Unit 1M pad for the final site inspection. Brennen Green was the CPAI representative on location. The wellsite was clean, clear of any visible contaminates, and it looked satisfactory. No Issues. Attachments: 2 pictures 2022-1019_Location_Clear_KRU_1M-17_ae Page 2 of 2 Location Clearance Inspection – KRU 1M-17 (PTD 2012300) Photos by AOGCC Inspector A. Earl 10/19/2022 1 Regg, James B (OGC) From:Regg, James B (OGC) Sent:Thursday, March 3, 2022 1:39 PM To:Denman, Erika /C; Greg.S.Hobbs@conocophillips.com Cc:Roby, David S (OGC) Subject:RE: Kuparuk MP 28243-1 Kuparuk 28243‐1 (PTD 1810350) KRU 1M‐17 (PTD 2012300) Before bond #82583272 can be released, AOGCC requires a location inspection when the site is clear of snow and ice accompanied by ExxonMobil or their designee. I checked well files and find no evidence of any location inspection at KRU 1M‐pad. By regulation (20 AAC 25.170(a)), that inspection should have occurred during summer 2021 since the surface P&A of both KRU 1M‐17 and Kuparuk 28243‐1 were completed in April 2021. Please use the AOGCC web notice form and submit at least 48 hrs in advance of the location inspection. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907‐793‐1236 From: Denman, Erika /C <erika.denman@exxonmobil.com> Sent: Wednesday, March 2, 2022 11:37 AM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Greg.S.Hobbs@conocophillips.com Subject: Kuparuk MP 28243‐1 James, I am working on the release of the ExxonMobil Alaska Production (EMAP) AOGCC bond #82583272. I understand that there may be outstanding AOGCC requirements for the Kuparuk well 28243‐1 (PTD 181‐035) that may need to be addressed prior to bond closure. Do you have some time available to discuss those requirements and allow me to better understand what AOGCC requirements may be outstanding? I’d like to include Greg Hobbs of ConocoPhillips (CPAI) in the discussion since the well is located in Kuparuk and CPAI had helped complete the P&A. Our schedules are pretty open, so let me know if there is a time that would be convenient for you this week. Regards, Erika Erika A. Denman You don't often get email from erika.denman@exxonmobil.com. Learn why this is important CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. ! "# $ %&' %&' &(! )))))))))))))))))) * +*, &! - !. . /! & !0 $ 1 2 %& ! /* (3 ! * 4 5 , 6* -&!& ! (* ,( * % 2703 4 87 , +8*9 : 0,; 5 $ + /* (3 8 .& 24 , : 0,; < &6 & ! (* #= $= >= / ,% #= $= >= / ; : 0,; ,*9 (!( : 0,; , #= $= >= / * %* $ ? 3 *4&1 .( (( 6=0 ,@: 0,; ! * *(! 3( :4 + &0 1 8 ,, : -A B 2- A =5 /- 5B A =5 2 B / * C* D ? & - $ *(* + +*! D ? & ",E%&,"6;3: 4 : &,& F%& 7:,"6%" 2 7 * : ( 37@+.+ ( . *4 E , * ( =:7 , + * =:7 $=%3*4 /=E 6 <6(" F8 8# 1- .*+.F<< = 1- ! " ! 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E=/ 10478' MD/ 6427' TVD By Meredith Guhl at 1:23 pm, May 06, 2021 RBDMS HEW 5/10/2021 Abandonment Date 4/13/2021 HEW x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tefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.05.05 17:13:46 -08'00' !" #"$ %! &' ( !")* " * *&(' $"%+ , * &(' $ "%&&( $'( "%& $ "%&' $( "%+ $' "%" *' )*" ) ""-" ""-" ","") " , ' " . * )/ *", " , *"0' """0 , ""0( ( " " 1 " ",*",'") )" ," " "&'.) ) , , )&* ""' )*)/ ) ) )*, "+ . ) '( &*" *""2" '$ % ' " 3)** "" ' 3)" )'" '( 456789::;:<=4>79=<?@:A47B4:5CAB DDE4<FFG &E:?H DDE7 5:><CD:=74DC6F=4G=:77 ' :>:6A:H2"A479=<?@:5CAB'DDEE:?H4<FFG &(DDE4< FFGE?77 &DDE 4DC6F=4G=:77 ' $ +%I & " & '. $ +%-#-" # ' $ +% +-#- ' $ +% " +-* ' $ +%*"-"" * ' $ +%*"+ &* + Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 10,631.0 2/15/2015 1M-17 lehallf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Pulled Plugs 3/2/2021 1M-17 zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.6 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 62.58 Grade H-40 Top Thread BUTT Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.5 Set Depth (ftKB) 8,042.5 Set Depth (TVD) … 4,608.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" OD (in) 5 1/2 ID (in) 4.95 Top (ftKB) 40.6 Set Depth (ftKB) 11,055.9 Set Depth (TVD) … 7,005.1 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 40.6 Set Depth (ft… 10,477.8 Set Depth (TVD) (… 6,427.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 40.6 40.6 0.14 HANGER FMC TUBING HANGER 3.500 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 40.6 40.6 0.14 Marker Plate Marker Plate- 5' below tundra 4/17/2021 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 10,606.0 10,642.0 6,555.4 6,591.4 C-4, C-3, 1M-17 2/16/2002 6.0 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Stimulation Intervals Interva l Numbe r Type Subtype Start Date Top (ftKB) Btm (ftKB) Proppant Designed (lb) Proppant Total (lb) Vol Clean Total (bbl) Vol Slurry Total (bbl) 1 FRAC 3/21/2002 10,606.0 10,642.0 0.0 0.00 0.00 Cement Squeezes Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Des Com Pump Start Date 10,429.0 10,642.0 6,378.9 6,591.4 Squeeze – Behind Casing Squeeze Plug #1- PUMPED 25 BBLS OF CLASS G CEMENT THROUGH PERF, CEMENTED LOWER COMPLETION 3/27/2021 68.6 8,042.0 68.6 4,608.0 Cement Plug Plug #2-Down squeeze OA from surface to shoe with 133 bbl of 15.8 ppg AS-1, lead 23 bbls AS-1 w/ CemNET fibers 4/6/2021 40.6 10,429.0 40.6 6,378.9 Cement Plug Plug #3-Cemented TxIA to surface with 24 bbl lead of 15.8 ppg AS-1, 176 bbl of 15.8 ppg Class G, 17 bbl AS-1 (IA) 4/7/2021 43.6 11,056.0 43.6 7,005.2 Cement Plug Plug #3-U-Tube TxIA cement (Tubing) 4/7/2021 40.6 68.6 40.6 68.6 Cement Plug Top off OA with 1 bbl 40 gal Cement 4/12/2021 40.6 43.6 40.6 43.6 Cement Plug Top off Tubing w/ 2 gal cement 4/12/2021 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 3,510.1 2,614.0 63.83 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 2 6,903.2 4,108.4 64.87 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 3 9,016.3 5,132.6 47.64 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 4 9,907.0 5,868.7 17.94 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 5 10,393.2 6,343.3 6.67 CAMCO KBG-2- 9 1 GAS LIFT OPEN BTM 0.000 0.0 3/19/2015 4:00 Notes: General & Safety End Date Annotation 4/13/2021 NOTE: Stateman Lou Laubenstein witness TOC in all annulus and marker plate. 12/22/2005 NOTE: WELL STATUS IS SUSPENDED; WELL TYPE IS PRODUCTION 1M-17, 5/5/2021 12:35:36 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5"; 40.6- 11,055.9 IPERF; 10,606.0-10,642.0 FRAC; 10,606.0 Squeeze – Behind Casing Squeeze; 10,429.0 ftKB GAS LIFT; 10,393.2 GAS LIFT; 9,907.0 GAS LIFT; 9,016.3 SURFACE; 40.5-8,042.5 GAS LIFT; 6,903.2 GAS LIFT; 3,510.1 NIPPLE; 533.4 CONDUCTOR; 40.6-120.0 Cement Plug; 68.6 ftKB Cement Plug; 43.6 ftKB Marker Plate; 40.6 Cement Plug; 40.6 ftKB Cement Plug; 40.6 ftKB Cement Plug; 40.6 ftKB KUP PROD KB-Grd (ft) 35.59 Rig Release Date 1/20/2002 1M-17 ... TD Act Btm (ftKB) 11,060.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292305800 Wellbore Status PROD Max Angle & MD Incl (°) 66.01 MD (ftKB) 5,415.62 WELLNAME WELLBORE1M-17 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: NIPPLE ! " #$ % & ''( ) " * + ''(, & +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) ! #$ % ''( ) * ''(, +) -.- . . . /./ +.+0 12 # 3 .4 5 6 # 4.4 . %., 7 2 % # .## * .2 - 8 +.+0 12 # 3 . #! 6# 0 ) $ 9 $:9 $,* ;: ' - ! 0: : ": < =>%6? !?@= A)4.::+":: 2 B @ ! " " #$%&'#% &()'* !!< $!*C )+/66 # < $!*C 0 $ < $!*#0 8# < $!* 4 @ 1, * 2: =3 @=6@D) @ "@ @ D D 4/13/2021 2021-0413_Surface_Abandon_KRU_1 M-17_11.docx Page 3 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 511gl DATE P. I. Supervisor FROM: Lou Laubenstein SUBJECT Petroleum Inspector 4/13/2021 Surface Abandonment KRU 1 M-17 ConocoPhillips Alaska PTD 201-230; Sundry 320-524 4/12/2021: 1 traveled out to KRU 1 M-17 to witness the cement voids after the wellhead had been cutoff. Roger Winter (CPAI) was on location and was the single point of contact for this job. The well had been cut to 5 feet below natural grade — that was 10ft below pad grade. There was a 3 -foot void in the tubing cement and a 35 -foot void in the casing -casing annulus. The conductor cement wasn't hard, and the soft cement was dug out until hard cement was found 11 inches down. 4/13/2021: 1 returned to KRU 1 M-17 to witness the surface abandonment after remedial cementing. I observed hard cement to surface inside the tubing, in all annular spaces, and verified all the correct information was on the marker plate. Attachments: Photos (4) 2021-0413_S urfke_Abandon_KRU_ I M-17 11.doex Page 1 of 3 Surface Abandonment — KRU 1 M-17 (PTD 2012300) Photos by AOGCC Inspector L. Laubenstein 4/12/2021 2021-0413_Surface_Abandon_KRU_1 M-17 11.docx Page 2 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg )Z l , 4(z -z j -A I P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 17 Csg Township: Drilling Rig: N/A Feet Rig Elevation: Cut@ Operator Rep: Mark Adams Feet Casing/Tubing Data (depths a Cut@ Feet Conductor: 16" O.D. Shoe@ Surface: 7 5/8" - O.D. Shoe@ Intermediate: Feet O.D. Shoe@ Production: 51/2' O.D. Shoe@ Liner: O.D. Shoe@ Tubing: 31/2' O.D. Tail@ Plugging Data Test Data: Remarks: 11N N/A DATE: March 29, 2021 SUBJECT: Well Bore Plug & Abandonment KRU 1M-17 ConocoPhillips Alaska PTD 201-236 Sundry 320-524 Range: 11E Meridian: Umiat Total Depth: 11060 ft MD Lease No.: AL 28243 Suspend: P&A: X Casing Removal: 120 Feet Csg Cut@ Feet 8042 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet 11056 - Feet Csg Cut@ Feet Feet Csg Cut@ Feet 10478 - Feet Tbg Cut@ Feet TVpe Pluq ounded on Depth Btm Depth To MW Above Verified Fullbore Retainer - 10540 ft MD 10483 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing 2400 2360 2340 IA 2090 2050 _ 2025 - P OA 550 550 525 Initial 15 min 30 min 45 min Result Tubing IA OA Attachments: none , rev. 11-28-18 2021-0329_Plug_Verification_KRU_1 M-17_bn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y Samantha Carlisle at 9:10 am, Jan 25, 2021 320-524 Stefan Weingarth Digitally signed by Stefan Weingarth Date: 2021.01.22 15:37:02 -09'00' X DLB 01/25/2021 AOGCC inspection required after cutoff and before remedial cementing Well abandonment marker to meet requirements of 20 AAC 25.120 Photo document all steps of surface abandonment X 10-407 DSR-1/27/21 X X VTL 1/27/21 " 1/27/21 dts 1/27/2021 JLC 1/27/2021 RBDMS HEW 1/29/2021 Commissioner Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Stefan Weingarth Wells Engineer ConocoPhillips Alaska, Inc. Commissioner Price: Please find the enclosed revised sundry application from ConocoPhillips Alaska, Inc. for KRU well 1M-17 (PTD#201-230) proposing to plug back and abandon the well. P&A operations are expected to begin early February after building ice to access the pad. A summary of proposed operations is included below. Please contact me at (907) 265-6038 if you have any questions. Sincerely, plug back and abandon the well. P&A operations are expected to begin early February after building ice to access the pad. A 1M-17 P&A Page 1 of 19 ConocoPhillips Alaska Inc. 1M-17 Plug and Abandonment Program Winter 2021 Prepared by: _________________ Stefan Weingarth 907-265-6038 Wells Engineer Approved by: _________________ Ty Senden 907-265-1544 Well Integrity/Intervention Director Distribution: Contractor Team: Well Intervention Director 1 copy Schlumberger Coil email CPAI Wells Superindent 1 copy Schlumberger Cement email Well Supervisors 1 copy Halliburton Wireline email Well Integrity Specialists 1 copy Natalie Berryman-Dye 1 copy Jill Simek 1 copy Claire Mayfield (XOM WI Partner) 1 copy Invoicing Details: Network Number: XXXXXX SAP Reviewer: SGWEING SAP Approver: RTSENDE Prepared by: ___________________ Stefan Weingarth 1M-17 P&A Page 2 of 19 Contents 1. Job Objective: ........................................................................................................................................ 2 2. Well Status / Risks and Concerns: ......................................................................................................... 4 3. Current Well Schematic ........................................................................................................................ 5 Preparation: .................................................................................................................................................. 6 a. Slickline/LRS: ......................................................................................................................................... 6 4. Well Abandonment: .............................................................................................................................. 7 a. Outer Annulus Injectivity Test: ............................................................................................................. 7 b. Cementing Lower Completion / Perforations (Plug #1): ....................................................................... 7 c. Outer Annulus Cement (Plug #2): ......................................................................................................... 8 d. Tubing x Inner Annulus Cement (Plug #3): ........................................................................................... 8 e. Surface P&A .......................................................................................................................................... 9 Well Status (Post-Abandonment): .............................................................................................................. 10 5. Appendix ............................................................................................................................................. 14 a. Current Schematic: ............................................................................................................................. 14 b. Planned P&A Diagram: ........................................................................................................................ 15 c. Weatherford FH-1 3-1/2” Cement Retainer BHA (Provided by Quadco) ........................................... 16 d. GKA Road Map .................................................................................................................................... 17 e. Well History ......................................................................................................................................... 18 1. Job Objective: Conduct a Safe, Injury Free and Spill Free Operation. 1M-17 was originally drilled and tested in the Kuparuk interval during the winter of 2002. The well has had limited utility since being tested and will thus be plugged back and abandoned during the 2021 winter season. The program will include building ice to access 1M pad, preparation work to service 1M-17’s wellhead, and wireline runs to measure wellbore pressure and temperature. Three separate cement plugs will be pumped, with the lower completion plug pumped via coiled tubing. Following final cement setting and testing, surface P&A operations will be completed. The project is estimated to be completed at $500M and 14 days. 1M-17 was originally drilled and tested in the Kuparuk interval during the winter of 2002. The well has had limited utility since being tested and will thus be plugged back and abandoned during the 2021 winter season. 1M-17 P&A Page 3 of 19 High level program summary: 1. Kuparuk Roads & Pads to construct ice bridge across East Creek to allow for access to 1M pad. Roads & Pads will service the pad to allow for safely executing scope. 2. Slickline/Digital Slickline: x Pull BPV. x Drift and pull top CS-A2 plug. x CMIT-TxIA to confirm casing integrity. x Pull lower CS-A2 plug. x Measure static bottomhole pressure. x Drift 3-1/2” string for cement retainer. 3. Perform OA injectivity test. 4. Coiled Tubing/Cement Crew: x Set cement retainer at 10,540’ RKB. x Sting in to cement retainer. Pump 15.8# Class G cement through perforations, cementing off lower completion. x Pressure test cement to 2000 psi after 24 hour curing period. 5. Slickline: x Tag top of cement. 6. Cement Unit: x Bullhead 15.8# Cold Temp Cement down 5-1/2” x 7-5/8” (OA) annulus. x Circulate 15.8# Class G / 15.8# Cold Temp Cement TxIA to surface. Option to pump two separate cement plugs through open gas lift mandrel pockets or tubing punches, pending cement design. 7. DHD, Wells Support, and LRS: x Pressure test tubing, inner annulus, and outer annulus after curing period. x Bleed tubing / inner / outer annuli pressure to 0 psi. x Excavate below grade. Remove wellhead and tree. Weld well identification cap covering all strings. Document scope completed. See detailed procedure for AOGCC state witnessing requirements VTL 1/26/21 1M-17 P&A Page 4 of 19 2. Well Status / Risks and Concerns: x Tree: 5K CIW 3-1/8”; Tree cap connection: Otis 3-1/8” Acme x Tubing leak suspected between 9,924’ RKB and 10,040’ RKB. Leak was not detected by caliper & Microvertilog during 2015 diagnostics. x VR plugs in wellhead valves. x Lowest GLM at 10,393’ RKB has open mandrel pocket. x Fluids in 3-1/2” tubing: o 2233’ of diesel freeze protect (19 bbls) o 9.1 ppg brine from 2233’ to GLM 5 at 10,393’ (71 bbls) x Fluids in 3-1/2” x 5-1/2” inner annulus o 2233’ of diesel freeze protect (27 bbls) o 9.1 ppg brine from 2233’ to GLM 5 at 10,393’ (97 bbls) x Perforated 3-1/2” tubing from 10,606-10,642’ RKB x Permafrost depth at 1754’ TVD (1868’ RKB) x Expected Kuparuk reservoir pressure 2549 psi (at datum of 6200’ TVD) with EMW of 7.9 ppg. Reservoir temperature 152° F. x Well Capacities: o 3-1/2” 9.3# Tubing = .0087 bbl/ft. ID = 2.992” o 3-1/2” x 5-1/2” Annulus = .0227 bbl/ft o 3-1/2” Tubing x 6-3/4” Hole Annulus = .0324 bbl/ft Safety: x Ensure that the on-tour Wells Supervisor can always be reached by radio. x Monitor weather and follow ConocoPhillips Cold Weather Operating Procedures when applicable. x Keep non-intrinsically safe devices such as cell phones out of classified areas x Ensure all equipment and tanks are electrically grounded. x Coordinate with Roads & Pads to scratch & plow ice pad as needed to minimize slips, trips & falls. x Report any accidents or spills to Wells Supervisor and Field Environmental Coordinator. Report near misses to Wells Supervisor. 1M-17 P&A Page 5 of 19 3. Current Well Schematic 1M-17 P&A Page 6 of 19 Preparation: Ensure DHD is available for necessary tree and integrity testing. Verify Schlumberger CTU and cement equipment is ready for P&A. CPAI currently has cement purchased in inventory. Coordinate with SLB to ensure the discounted product is used for the operation. The Alpine cement crew will be utilized between windows where cement support is required by Alpine rig operations. Confirm availability of FH-1 cement retainer with Quadco. FMC or Kuparuk Valve Crew and AES Support: 1. Remove VR plugs. 2. Verify tree cap connection and coordinate for XO from 3-1/8” Otis connection to 4-1/8” Otis connection. 3. AES support to set temporary wellhouse, floor kit, work platform, hardline, etc. a. Slickline/LRS: 1. Rig up and pressure test equipment. 2. Pull BPV. 3. Drift tubing to top of plug set at 533’ RKB. 4. Pull CS-A2 plug set at 533’ RKB. 5. CMIT-TxIA (open mandrel pocket) to 2500 psi, recording initial, 15 and 30 minute T/I/O pressures. 6. Drift tubing to top of plug set at 10,436’ RKB. 7. Pull CS-A2 plug set at 10,436’ RKB. 8. Drift tubing with 2.75” TS (mock cement retainer) to 10,540’ RKB. a. Make note of any debris recovered, tight spots or high tags. 9. RIH with dual Spartek pressure and temperature gauges. Make the following stops: a. 10,624’ RKB: 30 minutes b. 10,506’ RKB: 30 minutes c. 1,800’ RKB: 15 minutes d. 1,754’ RKB: 15 minutes e. 1,700’ RKB: 15 minutes 10. RDMO. 1M-17 P&A Page 7 of 19 Notify AOGCC minimum of 72 hours prior to beginning abandonment operations. Representative may witness tagging, pressure testing, etc. Verify with Wells Engineer that 10-403 sundry has been approved. 4. Well Abandonment: a. Outer Annulus Injectivity Test: LRS: 1. Perform injectivity tests below to verify cement can be pumped away prior to mobilizing cement equipment. 2. Pump 40 bbls warm diesel down tubing at 1 bpm. Note initial and final pump pressures. 3. Pump 100 bbls seawater flush down 5-1/2” x 7-5/8” annulus. Note casing pressures: i. Prior to pumping ii. Final pump pressure iii. 30 minutes after pumping iv. 2 hours after pumping b. If unable to maintain under 900 psi at 0.5-1 bpm, notify Wells Engineer. 4. Displace seawater with 21 bbls diesel freeze protect. b. Cementing Lower Completion / Perforations (Plug #1): Coiled Tubing / Cement Unit: 5. Contact cement crew to verify equipment & product are ready for job. 6. Coordinate with Quadco representative to prepare Weatherford 3-1/2” FH-1 cement retainer. 7. Host Pre-Job safety and identify job hazards. RU CTU, PCE, and Support Equipment. PT Lines. 8. MU nipple locator. 9. RIH with nipple locator to tag DS nipple (2.812” profile) at 10,436’ RKB for depth correction. Flag pipe once tagging nipple. 10. POOH. 11. MU running tool and Weatherford FH-1 cement retainer. 12. RIH & set cement retainer at 10,540’ RKB (66’ above top perforations). Do not pump while RIH. 13. Downsqueeze following fluids through cement retainer while logging initial and pump pressure between each stage: a. 40 bbls warm diesel. b. 10 bbls CW100 to pre-flush wellbore. c. 5 bbls fresh water spacer. d. 25 bbls 15.8# Class G cement. Volume may be adjusted as squeeze pressure is observed. 14. Sting off retainer. Lay 1 bbl cement (115’) while POOH above cement retainer raising cement to 10,425’ RKB. This leaves TOC 32’ below the GLM at 10,393’ RKB. 15. Flush string and equipment as needed. Contaminate and circ out excess cement. g cement to 10,425’ RKB. This leaves TOC 32’ below the GLM at 10,393’ RKB. 1M-17 P&A Page 8 of 19 16. Circulate seawater while POOH, flushing across GLM at 10,393’ to ensure cement stringers are swept and mandrel remains clear. 17. Freeze protect tubing with 22 bbls diesel while POOH. Contaminant will need to be documented, with manifests forwarded to Kuparuk Environmental. 18. Rig down CTU. 19. Allow for a minimum of 24 hours for cement to cure. Slickline / LRS (State Witnessed): 20. Perform CMIT-TxIA (open mandrel pocket and tubing leak) to 2000 psi recording initial, 15 minute, and 30 minute T/I/O pressures. 21. RIH to tag TOC at ~10,425’ RKB. c. Outer Annulus Cement (Plug #2): LRS / Cement: 22. Confirm injectivity and preheat OA by injecting 90 bbls heated seawater down OA, followed by 21 bbls diesel targeting 1-2 BPM for first 85 bbls. Slow pump rate to 0.5 BPM for last 5 bbls. Maintain under 900 psi. 23. Shut in and monitor pressure for 30 minutes. 24. Down-squeeze 10 bbl fresh water spacer followed by 96 bbls 15.8# Cold Temp Cement into 5-1/2” x 7-5/8” outer annulus. 25. Shut down and monitor for 30 minutes, verifying cement remains full to surface. 26. Flush lines and shut down pumps. 27. After minimum of 48 hours, perform MIT-OA to 1000 psi. Record initial, 15 minute & 30 minute pressures. 28. Perform DDT-OA to 0 psi. Record initial, 15 minute & 30 minute pressures. d. Tubing x Inner Annulus Cement (Plug #3): LRS / Cement Unit: 29. Pump 215 bbls seawater followed by a 10 bbl fresh water spacer heated to 150°F down the tubing through the open mandrel pocket, taking returns up the IA to tanks. 30. Pump 215 bbls 15.8# Class G cement down the tubing taking returns up the IA while tracking fluid returns to tanks. 31. After displacing cement to surface, shut in and wait 30 minutes. 32. Verify TxIA remain full to surface. 33. RD cementing equipment. 34. After minimum of 48 hours after pumping cement, perform MIT-T and MIT-IA to 2000 psi. Record initial, 15 minute & 30 minute pressures. 35. Perform DDT to 0 psi on tubing, IA & OA for 30 minutes prior to demob. All pressure to remain bled to 0 psi. Perform CMIT-TxIA (open mandrel pocket and tubing leak) to 2000 psi recording initial, 15 minute, and 30 minute T/I/O pressures. 21.RIH to tag TOC at ~10,425’ RKB. Notify AOGCC 24 hrs in advance to witness tag & pressure test VTL 1/26/21S (State Witnessed) 1M-17 P&A Page 9 of 19 e. Surface P&A AES Support / DHD: 36. Remove surface equipment. Excavate as needed to allow for cutting strings 4 feet below tundra ground level. 37. Cut off wellhead and casing strings at 4 feet below tundra ground level. 38. Top cement in tubing and annuli to surface as needed. 39. Send wellhead with stub for repair / re-dressing. 40. Photo document excavation, final casing cuts, cement topping & measurement below grade. 41. Weld ¼” cover plate over 16” conductor with labeling welded below. Photo document plate & final set. ConocoPhillips 1M-17 PTD # 201-230 API # 50-029-23058-00-00 42. Remove cellar. Backfill with gravel from cellar & conductor as needed. If additional gravel is needed, contact Roads & Pads. Make final spot checks with Wells Supervisor. 43. Photo document site as left. 44. RDMO. AOGCC inspection required after cutoff and BEFORE remedial cementing. VTL 1/26/21 Photo document all steps of surface abandonment VTL 1/26/21 Well abandonment marker to meet requirements of 20 AAC 25.120 VTL 1/26/21 1M-17 P&A Page 10 of 19 Well Status (Post-Abandonment): x Plug 1: 15.8# Class G cement plug pumped in 3-1/2” tubing through cement retainer to perforations, with top of cement at approximately 10,443’ RKB. Tagged and pressure tested to 2500 psi. x Plug 2: Outer Annulus: 15.8# Cold Temp Cement pumped from surface to OA shoe at 8042’ RKB. Pressure tested to 1000 psi. x Plug 3 (Tubing x Inner Annulus): 15.8# Class G Cement / 15.8# Cold Temp Cement plug pumped TxIA through open mandrel pocket at 10,393’ RKB from top of Tubing Plug 1 to surface. x Cellar cut minimum 3 feet below original grade & backfilled with gravel. x Labeled cover plate welded across all strings. See Appendix for well suspension diagram. Upper Completion Tally 1M-17 P&A Page 11 of 19 Directional Survey 1M-17 P&A Page 12 of 19 1M-17 P&A Page 13 of 19 1M-17 P&A Page 14 of 19 5. Appendix a. Current Schematic: 1M-17 P&A Page 15 of 19 b. Planned P&A Diagram: TOC Plug #1 10425' MD 181' above top perf 1M-17 P&A Page 16 of 19 c. Weatherford FH-1 3-1/2” Cement Retainer BHA (Provided by Quadco) 1M-17 P&A Page 17 of 19 d. GKA Road Map 1M-17 P&A Page 18 of 19 e. Well History 1M-17 P&A Page 19 of 19 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 31.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 62.58 Grade H-40 Top Thread BUTT Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 31.1 Set Depth (ftKB) 8,042.5 Set Depth (TVD) … 4,608.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 28.3 Set Depth (ftKB) 11,055.9 Set Depth (TVD) … 7,005.1 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 26.2 Set Depth (ft… 10,477.8 Set Depth (TVD) (… 6,427.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.2 26.2 0.09 HANGER FMC TUBING HANGER 3.500 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 533.4 533.2 3.74 PLUG 2.875" CS-A2 PLUG 3/20/2015 0.000 10,436.5 6,386.4 5.72 PLUG 2.812" CS-A2 PLUG 3/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,606.0 10,642.0 6,555.4 6,591.4 C-4, C-3, 1M- 17 2/16/2002 6.0 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Stimulations & Treatments Min Top Depth (ftKB) Max Btm Depth (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Type Date Com 10,606.0 10,642.0 6,555.4 6,591.4 FRAC 3/21/2002 C-SAND FRAC, 90M# BEHIND PIPE, 9 ppa ON PERFS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,510.1 2,614.0 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 2 6,903.2 4,108.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 3 9,016.3 5,132.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 4 9,907.0 5,868.7 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 5 10,393.2 6,343.3 CAMCO KBG-2- 9 1 GAS LIFT OPEN BTM 0.000 0.0 3/19/2015 4:00 Notes: General & Safety End Date Annotation 12/22/2005 NOTE: WELL STATUS IS SUSPENDED; WELL TYPE IS PRODUCTION 10/6/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE1M-17, 3/22/2015 4:51:53 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5"; 28.3- 11,055.9 IPERF; 10,606.0-10,642.0 FRAC; 10,606.0 LOCATOR; 10,475.0 PLUG; 10,436.5 NIPPLE; 10,436.5 GAS LIFT; 10,393.2 GAS LIFT; 9,907.0 GAS LIFT; 9,016.3 SURFACE; 31.1-8,042.5 GAS LIFT; 6,903.2 GAS LIFT; 3,510.1 NIPPLE; 533.4 PLUG; 533.4 CONDUCTOR; 31.0-120.0 TUBING PUP; 26.9 HANGER; 26.1 Annotation Last Tag: SLM Depth (ftKB) 10,631.0 End Date 2/15/2015 Annotation Rev Reason: GLV C/O, PLUG, TAG Last Mod By lehallf End Date 3/22/2015 KUP PROD KB-Grd (ft) 35.59 Rig Release Date 1/20/2002 Annotation Last WO: End Date 1M-17 H2S (ppm) Date ... TD Act Btm (ftKB) 11,060.0 Well Attributes Wellbore API/UWI 500292305800 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 66.01 MD (ftKB) 5,415.62 From:Weingarth, Stefan To:Wiese, Tyson M; Loepp, Victoria T (CED) Subject:RE: [EXTERNAL]KRU 1M-17(PTD 201-230) and Lookout 1(PTD 201-003) Well Abandonment Marker Date:Wednesday, January 20, 2021 11:39:09 AM Victoria, Here is the market plate information for 1M-17. We expect operations to begin near the end of February / first week of March. I will be submitting an updated sundry package shortly for 1M-17 to include some minor adjustments and added detail from Schlumberger on the cement design. ConocoPhillips 1M-17 PTD: 201-230 API: 50-029-23058-00-00 Regards, Stefan Weingarth Wells Engineer ConocoPhillips Alaska – ATO 1306 Desk: 907-265-6038 | Cell: 907-444-7569 From: Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com> Sent: Wednesday, January 20, 2021 11:18 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov>; Weingarth, Stefan <Stefan.G.Weingarth@conocophillips.com> Subject: RE: [EXTERNAL]KRU 1M-17(PTD 201-230) and Lookout 1(PTD 201-003) Well Abandonment Marker Victoria, Below is the marker plate information for Lookout #1: ConocoPhillips Lookout #1 PTD: 201-003 API #: 50-103-20359-00-00 Note that when I sent over the Lookout #1 P&A sundry application it was written to comply with both AOGCC and BLM regulations. I’ve been informed by the BLM that they will not require a P&A sundry for Lookout #1, so I will remove the BLM specific marker plate weephole from the program. Ice road are expected to be completed by February 10th. The Lookout #1 P&A is expected to start around February 15th. Thanks, Tyson Wiese Wells Engineer ConocoPhillips Alaska, Inc. Desk Phone (907)-265-6093 Cell Phone (907)-230-5388 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, January 20, 2021 10:34 AM To: Weingarth, Stefan <Stefan.G.Weingarth@conocophillips.com>; Wiese, Tyson M <Tyson.M.Wiese@conocophillips.com> Subject: [EXTERNAL]KRU 1M-17(PTD 201-230) and Lookout 1(PTD 201-003) Well Abandonment Marker CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Stefan, Tyson, Please email the well abandonment marker plate information for these two wells consistent with 20 AAC 25.120. What is the updated status of the ice road and the timing of these two P&As? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov ! 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Chmielowski Date: 2021.01.05 14:31:47 -09'00' RBDMS HEW 1/11/2021 1/5/2021 Commissioner Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Price: Please find the enclosed sundry application from ConocoPhillips Alaska, Inc. for KRU well 1M-17 (PTD# 201-230) proposing to extend the suspended well status through May 31st, 2021. The current suspend status is set to expire January 5th, 2021. CPAI intends to plug back and abandon 1M-17 this winter. P&A operations are expected to begin early February after building ice to access the pad. A separate application for 1M-17’s P&A will be submitted with proposed scope. Please contact me at (907) 265-6038 if you have any questions. Sincerely, Stefan Weingarth Wells Engineer ConocoPhillips Alaska, Inc. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 31.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 62.58 Grade H-40 Top Thread BUTT Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 31.1 Set Depth (ftKB) 8,042.5 Set Depth (TVD) … 4,608.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 28.3 Set Depth (ftKB) 11,055.9 Set Depth (TVD) … 7,005.1 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 26.2 Set Depth (ft… 10,477.8 Set Depth (TVD) (… 6,427.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.2 26.2 0.09 HANGER FMC TUBING HANGER 3.500 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 533.4 533.2 3.74 PLUG 2.875" CS-A2 PLUG 3/20/2015 0.000 10,436.5 6,386.4 5.72 PLUG 2.812" CS-A2 PLUG 3/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,606.0 10,642.0 6,555.4 6,591.4 C-4, C-3, 1M- 17 2/16/2002 6.0 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Stimulations & Treatments Min Top Depth (ftKB) Max Btm Depth (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Type Date Com 10,606.0 10,642.0 6,555.4 6,591.4 FRAC 3/21/2002 C-SAND FRAC, 90M# BEHIND PIPE, 9 ppa ON PERFS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,510.1 2,614.0 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 2 6,903.2 4,108.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 3 9,016.3 5,132.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 4 9,907.0 5,868.7 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 5 10,393.2 6,343.3 CAMCO KBG-2- 9 1 GAS LIFT OPEN BTM 0.000 0.0 3/19/2015 4:00 Notes: General & Safety End Date Annotation 12/22/2005 NOTE: WELL STATUS IS SUSPENDED; WELL TYPE IS PRODUCTION 10/6/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE1M-17, 3/22/2015 4:51:53 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5"; 28.3- 11,055.9 IPERF; 10,606.0-10,642.0 FRAC; 10,606.0 LOCATOR; 10,475.0 PLUG; 10,436.5 NIPPLE; 10,436.5 GAS LIFT; 10,393.2 GAS LIFT; 9,907.0 GAS LIFT; 9,016.3 SURFACE; 31.1-8,042.5 GAS LIFT; 6,903.2 GAS LIFT; 3,510.1 NIPPLE; 533.4 PLUG; 533.4 CONDUCTOR; 31.0-120.0 TUBING PUP; 26.9 HANGER; 26.1 Annotation Last Tag: SLM Depth (ftKB) 10,631.0 End Date 2/15/2015 Annotation Rev Reason: GLV C/O, PLUG, TAG Last Mod By lehallf End Date 3/22/2015 KUP PROD KB-Grd (ft) 35.59 Rig Release Date 1/20/2002 Annotation Last WO: End Date 1M-17 H2S (ppm) Date ... TD Act Btm (ftKB) 11,060.0 Well Attributes Wellbore API/UWI 500292305800 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 66.01 MD (ftKB) 5,415.62 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Mr. Shon Robinson Alaska Wells Manager PO Box 100360 Anchorage, AK 99510-0360 Re: Docket Number: OTH-20-057 ConocoPhillips Alaska, Inc. (CPAI) Well Plug and Abandonments for 2021 and 2022 Ice Road Seasons Dear Mr. Robinson, By letter dated November 23, 2020, CPAI proposed well plug and abandonment (P&A) programs for the 2021 and 2022 ice road seasons. The Alaska Oil and Gas Conservation Commission (AOGCC) approves the P&A programs for the wells listed below for the 2021 and 2022 ice road seasons with the P&A work to be completed by May 31, 2021 and May 31, 2022 respectively. May 31, 2021 Lookout 1 (PTD 201-003) KRU 1M-17 (PTD 201-230) Kuparuk 28241-1 (PTD 181-035) May 31, 2022 Scout 1 (PTD 204-006) Cassin 1 (PTD 212-182) Cassin 6 (PTD 212-196) Wells KRU 1M-17 and Kuparuk 28241-1 each require the submission and approval of an Application for Sundry Approvals for suspension renewal in January 2021. Approval of an Application for Sundry Approvals will be required for plugging and abandonment operations for each well. Approval is also granted for the deferral of the Scout 1 suspended well inspection to May 31, 2022. If you have any questions please contact Victoria Loepp at (907)793-1247 or at victoria.loepp@alaska.gov. Sincerely, Jeremy M. Price Chair, Commissioner cc Victoria Loepp, AOGCC JMPi Dear Commissioner Price, Due to low oil prices, budget constraints, and a need to minimize nonessential remote work considering spiking COVID-19 cases statewide, Conocophillips Alaska, Inc. is revising our winter 2021 ice road scope of work. Our initial plan was to execute the following P&A’s: x Lookout 1 x Scout 1 x Cassin 1 x Cassin 6 As has been discussed with AOGCC staff, we now propose to perform the following P&A’s instead, staying closer to infrastructure, in 2021: x Lookout 1 x 1M-17 x Well 28243-1 (for Exxon) With that change, we expect to perform the following P&A’s in 2022: x Scout 1 x Cassin 1 x Cassin 6 The Scout 1 well is overdue for its 5-year suspended well inspection under 20 AAC 25.110(e) because of last year’s early ice road exit due to measures taken to project against the COVID-19 pandemic. We do not believe that deferral of inspection until 2022 would present a safety or environmental risk. For the reasons described above, we seek modification of the inspection deadline for this well to May 31, 2022, as allowed under 20 AAC 25.110(n). Thank you for your consideration, Sincerely, Shon Robinson Manager, AK Wells Shon Robinson Alaska Wells Manager 700 G Street, ATO (99501) P. O. Box 100360 Anchorage, AK 99510-0360 Phone (907)-265-6306 Suspended Welul Inspection Review Reort |nspectNo: susAGE200813110056 Date Inspected: 8/13/2020 _ Inspector: Adam Earl Type of Inspection,: Subsequent ' VVeUName: KUPARUKR|VUNIT 1KX-17 ' Date AOGC[Notified: 7/30/2020 ' Permit Nunober: 2012300 Operator: ConocoPhiUipsA|aska, Inc. Suspension Approval: Sundry - # 303'15O - Operator Rep: Roger K1./Jan 8. Suspension Date: 4/26/2002 ' VVeUbnreDiagramAvail? Location Verified? W Photos Taken? �] If Verified, How? GPS ' Offshore? il Well Pressures (psi),- TubinQ� U Fluid inCellar? se] |X: 5 BPV!nstaUed? El O4: 365 VKP|Ug(s)Installed? [] Wellhead Condition Good working condition, nodrips orleaks. Condition ofCellar There isclean water inthe cellar box. Wellhead and valves/handles all above water. Novisible sheen orleaks - Surrounding Surface Condition Nosigns ofdebris/ trash clean and dry. Comments CPAI will submit photos with their report Supervisor Comments Wednesday, September 2,202O P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 13 August 2020 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7 th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry KRU well 1M-17 (PTD 201-203) Dear Commissioner Chmielowski, Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. KRU well 1M-17 (PTD 201- 203). The following documents are attached: - 10-404 Sundry - Suspended Well Inspection Report - Wellbore Schematic - Location Plot Plan - Photographs Please contact Dusty Freeborn or myself at 659-7224 if you have any questions. Sincerely, Jan Byrne Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-13 14:43:51 Foxit PhantomPDF Version: 10.0.0 jan.byrne@co nocophillips.c om 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended well inspection ConocoPhillips Alaska, Inc. Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11060 feet 533 & 10436 feet true vertical 7009 feet None feet Effective Depth measured 10960 feet 10478 feet true vertical 6909 feet 6428 feet Perforation depth Measured depth 10606 - 10642 feet True Vertical depth 6555 - 6591 feet Tubing (size, grade, measured and true vertical depth) 3.5 L-80 10747 6424 Packers and SSSV (type, measured and true vertical depth)80-40 GBH SEAL ASSEMBLY 10478 MD 6434 TVD NO SSSV 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Contact Name: Authorized Title: Contact Email: 8/13/2020 Contact Phone: 201-230 50-029-23058-00-00 ADL 0028244, 0028243 KRU 1M-17 P.O. Box 100630, Anchorage, Alaska 99508 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: Packer measured true vertical Casing Length Size MD TVD N/A Kuparuk River/ Kuparuk River Oil Plugs measured Junk measured Burst Collapse Conductor 120 16 120 120 N/A N/A N/A Production 10474 5.5 10474 6424 N/A N/A Surface 8040 7.625 8040 4108 N/A N/ALiner 574 3.5 11055 7004 N/A ----- N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Authorized Name: Authorized Signature with date: Senior Engineer: Senior Res. Engineer: 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283 WINJ WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jan Byrne / Dusty Freeborn n1617@conocophillips.com 659-7224 Well Integrity & Compliance Specialist ----- Fra GG Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 3:17 pm, Aug 13, 2020 Digitally signed by jan.byrne@conocophillips.com DN: CN=jan.byrne@conocophillips.com Reason: I am the author of this document Location: your signing location here Date: 2020-08-13 14:44:21 Foxit PhantomPDF Version: 10.0.0 jan.byrne@cono cophillips.com VTL 10/01/20 DSR-8/13/2020 RBDMS HEW 8/14/2020 SFD 8/14/2020 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Field/Pool: Permit # (PTD): API Number: Operator: Date Suspended: 4/26/2002 Surface Location: Section: 17 Township: 11N Range: 11E Nearest active pad or road: Meridian: UMIAT Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good/Clean Pad or location surface: Good/Clean Location cleanup needed: No Pits condition: Good/Clean Surrounding area condition: Good/Clean Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (# and description): 3 photos, front and back of wellhead and up close sign photo. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good/Clean, valves function, all valves above cellar plywood cover. Cellar description, condition, fluids: Steel cellar with plywood cover Rat Hole: N/A Wellhouse or protective barriers: No wellhouse, barrier around wellhead Well identification sign: Yes Tubing Pressure (or casing if no tubing): Tubing= 0 psi. Annulus pressures: IA= 5 psi. OA= 365 psi. Work Required: None Operator Rep (name and signature): Jan Byrne AOGCC Inspector: Adam Earl Other Observers: Roger Mouser Inspection Date: 8/13/2020 AOGCC Notice Date: 8/11/2020 Time of arrival: 7:30AM Time of Departure: 8:30AM Site access method: ATV SPINE ROAD NEAR KRU DS1D/DS1C 618' FSL, 600' FWL ConocoPhillips Alaska, Inc. 201-230 Sundry 302-150 KUPARUK RIV UNIT 1M-17 KUPARUK RIVER 50-029-23058-00-00 Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 31.0 Set Depth (ftKB) 120.0 Set Depth (TVD) … 120.0 Wt/Len (l… 62.58 Grade H-40 Top Thread BUTT Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.875 Top (ftKB) 31.1 Set Depth (ftKB) 8,042.5 Set Depth (TVD) … 4,608.2 Wt/Len (l… 29.70 Grade L-80 Top Thread BTCM Casing Description PRODUCTION 5.5"x3.5" OD (in) 5 1/2 ID (in) 4.950 Top (ftKB) 28.3 Set Depth (ftKB) 11,055.9 Set Depth (TVD) … 7,005.1 Wt/Len (l… 15.50 Grade L-80 Top Thread BTCM Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 26.2 Set Depth (ft… 10,477.8 Set Depth (TVD) (… 6,427.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 26.2 26.2 0.09 HANGER FMC TUBING HANGER 3.500 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°)Des Com Run Date ID (in) 533.4 533.2 3.74 PLUG 2.875" CS-A2 PLUG 3/20/2015 0.000 10,436.5 6,386.4 5.72 PLUG 2.812" CS-A2 PLUG 3/8/2015 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 10,606.0 10,642.0 6,555.4 6,591.4 C-4, C-3, 1M- 17 2/16/2002 6.0 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Stimulations & Treatments Min Top Depth (ftKB) Max Btm Depth (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Type Date Com 10,606.0 10,642.0 6,555.4 6,591.4 FRAC 3/21/2002 C-SAND FRAC, 90M# BEHIND PIPE, 9 ppa ON PERFS Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB)Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com 1 3,510.1 2,614.0 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 2 6,903.2 4,108.4 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 3 9,016.3 5,132.6 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 4 9,907.0 5,868.7 CAMCO KBG-2- 9 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 5 10,393.2 6,343.3 CAMCO KBG-2- 9 1 GAS LIFT OPEN BTM 0.000 0.0 3/19/2015 4:00 Notes: General & Safety End Date Annotation 12/22/2005 NOTE: WELL STATUS IS SUSPENDED; WELL TYPE IS PRODUCTION 10/6/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE1M-17, 3/22/2015 4:51:53 PM Vertical schematic (actual) PRODUCTION 5.5"x3.5"; 28.3- 11,055.9 IPERF; 10,606.0-10,642.0 FRAC; 10,606.0 LOCATOR; 10,475.0 PLUG; 10,436.5 NIPPLE; 10,436.5 GAS LIFT; 10,393.2 GAS LIFT; 9,907.0 GAS LIFT; 9,016.3 SURFACE; 31.1-8,042.5 GAS LIFT; 6,903.2 GAS LIFT; 3,510.1 NIPPLE; 533.4 PLUG; 533.4 CONDUCTOR; 31.0-120.0 TUBING PUP; 26.9 HANGER; 26.1 Annotation Last Tag: SLM Depth (ftKB) 10,631.0 End Date 2/15/2015 Annotation Rev Reason: GLV C/O, PLUG, TAG Last Mod By lehallf End Date 3/22/2015 KUP PROD KB-Grd (ft) 35.59 Rig Release Date 1/20/2002 Annotation Last WO: End Date 1M-17 H2S (ppm) Date ... TD Act Btm (ftKB) 11,060.0 Well Attributes Wellbore API/UWI 500292305800 Field Name KUPARUK RIVER UNIT Wellbore Status PROD Max Angle & MD Incl (°) 66.01 MD (ftKB) 5,415.62 zol- 23o • • 26vt t gall. BAKER PRINT DISTRIBUTION LIST HUGHES Please sign and return one copy of this transmittal form to: COMPANY Conoco Phillips Alaska Inc BP Exploration(Alaska)Inc. (mandatory) Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME 1M-17; 1D-108;CD2-53;2L-311 900 E. Benson Blvd. `3/3i2o15 ivl.K.BENDER (mandatory) Anchorage, Alaska 99508 FIELD KUPARUK RIVER UNIT;W.SAK;ALPINE;TARN to acknowledge receipt of this data. (mandatory) COUNTY North Slope LOG TYPE MVRT-WireLine (mandatory) (mandatory) STATE Alaska BH DISTRICT Alaska (mandatory) (mandatory) LOG DATE: TODAYS DATE: 29-Aug-15 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares EMAIL: Paul.CanizaresAbakerhughes.com (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? No COMPANY FIELD FINAL CD CD ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS (digital/image) Surveys (Final Surveys) PERSON ATTENTION #OF PRINTS #Ur PKIN 15 #OF COPIES #OF COPIES #OF COPIES 1 ConocoPhillips Alaska Inc. 0 1 Attn:Ricky Elgaricio � E D ATO 3-344 700 G Street SEP Anchorage,AK 99510 SEP 01 2 U I 2 State of Alaska -AOGCC I I 0 1 1 I AO(3 C yyy��� Attn:Makana Bender b 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 3 Chevron/KRU Rep I 0 1 I I Attn:Glenn Fredrick 310 K Street,Suite 406 Anchorage,AK 99501 4 BP Exploration(Alaska)Inc. I 0 1 I I I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. .•r•w.—,— .-. Anchorage,Alaska 99508 Attn:David Douglas 5 DNR-Division of Oil&Gas *** I 0 I 1 I I I Attn:Sean Clifton 550 West 7th Avenue,Suite 802 icA$tiED MAI' 0 2201 Anchorage,Alaska 99501 I***Stamp"confidential"on all material deliver to DNR 6 ConocoPhillips Alaska Inc. 0 0 I Attn:Mick Davasher ATO-1490 700 G Street Anchorage,AK 99510 TOTALS FOR THIS PAGE: 0 0 5 0 0 0 TOTALS FOR ALL PAGES: 0 0 5 0 0 0 P717 261 -2, 3 v Loepp, Victoria T (DOA) From: Hunt,Jennifer L(DOA) Sent: Friday, May 15, 2015 11:01 AM To: Loepp,Victoria T(DOA) Subject FW: 1M-17 date of suspension Follow Up Flag: Follow up Flag Status: Flagged Victoria, I have corrected the status of this well. SCANNED MAY 2 9 201c Thanks, Jenni From: Allsup-Drake, Sharon K[mailto:Sharon.K.Allsup-Drake@conocophillips.com] Sent: Friday, May 15, 2015 10:02 AM To: Hunt,Jennifer L(DOA) Cc: NSK Well Integrity Proj; Simek,Jill Subject: 1M-17 date of suspension Jenni— Please use 3/20/2015 as the date of suspension for Kuparuk well 1M-17. If you have any questions, please call me. Thanks, Sharon 263-4612 1 PrC� Azg ! -z3o Hunt, Jennifer L (DOA) From: Allsup-Drake, Sharon K <Sharon.K.Allsup-Drake@conocophillips.com> Sent: Friday, May 15, 2015 10:02 AM To: Hunt,Jennifer L(DOA) Cc: NSK Well Integrity Proj; Simek,Jill Subject: 1M-17 date of suspension Jenni — Please use 3/20/2015 as the date of suspension for Kuparuk well 1M-17. If you have any questions, please call me. Thanks, Sharon 263-4612 SCANNED MAY 2 12015 1 RBDMS* MAY 1 5 2015 Kr` 1,A4-(7 Pit 24l Z3ta o Regg, James B (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Saturday, May 02, 2015 9:51 AM5I4jiS To: Regg,James B (DOA) C( t Cc: Scheve, Charles M (DOA) Subject: RE: KRU 1M-17 Suspended Well Inspection (PTD 2012300) Attachments: 1M-17 perm Signjpg Jim, An additional follow up item for suspended well inspection 1M-17. The permanent sign arrived and was installed in place of the prior set temporary sign. Please let me know if you have any questions. MJ Loveland I Martin Walters �CAUNED JUN 0 8 2.015 Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 MJ's Cell (907) 943-1687 From: NSK Well Integrity Proj Sent: Saturday, April 11, 2015 1:22 PM To: Regg,James B (DOA) Cc: Scheve, Charles M (DOA); NSK Well Integrity Proj Subject: RE: KRU 1M-17 Suspended Well Inspection Attached is the completed Deficiency Report for the suspended well inspection on 1M-17 performed on 3/27/2015. I have also attached a photo indicating the removal of visqueen and scaffolding and installation of a well sign. Please let me know if there is anything else that is required. Martin Martin Walters/MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907-659-7043 Cell: 907-943-1720 Pager: 907-659-7000#937 Home: 907-854-9949 From: Regg,James B (DOA) [mailto:'im.re:: • alas...:ov] Sent:Thursday, April 09, 2015 9:28 AM 1 ConocoPhitlIPs Alaska • Well Name: 1M-17 • API Number. 50-029-23058-00-00 PTD: 201-230 Sur. location: 618' FSLY 6 RUE, UfA 17 '' 201 - 230 r ons fillips Alas , Inc his photo is copyrigf 6 d b ConocoPhill * Alaska , Inc . _ nd nnbt �e released or published without exprNow, �, written consent of ConocoPhil i s AIaka K€t I it4 Pr') ZOC z;oo Re'gg, James B (DOA) From: NSK Well Integrity Proj <N1878@conocophillips.com> Sent: Saturday, April 11, 2015 1:22 PM Q•Ilu'I To: Regg, James B (DOA) t Cc: Scheve, Charles M (DOA); NSK Well Integrity Proj Subject: RE: KRU 1M-17 Suspended Well Inspection Attachments: 2015-0327_Deficiency_KRU_1M-17_cs_Corrected.pdf; 1M-17 #1.JPG D2O1` a3O Attached is the completed Deficiency Report for the suspended well inspection on 1M-17 performed on 3/27/2015. I have also attached a photo indicating the removal of visqueen and scaffolding and installation of a well sign. Please let me know if there is anything else that is required. Martin Martin Walters/MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office: 907-659-7043 NEV Cell: 907-943-1720 Pager: 907-659-7000#937 Home: 907-854-9949 From: Regg,James B (DOA) [mailto:jim.regg@alaska.gov] Sent:Thursday, April 09, 2015 9:28 AM To: NSK Well Integrity Proj Cc:Scheve, Charles M (DOA) Subject: [EXTERNAL]KRU 1M-17 Suspended Well Inspection Attached please find a new form AOGCC is using to capture and track resolution of exceptions noted during field inspections. In this particular case the Inspector noted during a Suspended well inspection at KRU 1M-17 (PTD 2012300) that visquene and scaffolding were over the wellhead and the well sign was missing. This form is not intended to duplicate failures that would normally be captured on the inspection forms; instead it is being used to identify and track exceptions/deficiencies that an Inspector would include in the comment section of his test report, or in lieu of verbal/email communications to a company's field rep regarding needed corrective actions. Please confirm these issues have been corrected at KRU 1M-17 and return the "Deficiency Report"to me by 4/17/15. Call me if you have any questions. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 1 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. 2 State of Alaska Oil and Gas Conservation Commission Deficiency Report Location: KRU 1M-17 Date: 3/27/2015 PTD: 2012300 Operator: CPAI Type Inspection: Suspend Operator Rep: MJ Loveland Inspector: Chuck Scheve Position: Well Integrity Project Supervisor Op. Phone: 907-659-7043 Correct by(date): 4/17/2015 Op. Email: n1878@conocophillips.com Follow Up Req'd: Detailed Description of Deficiencies Date Corrected Visquene and scaffolding over wellhead / Missing well sign /2 71/4c,'!5 /)/1 ''I Form not left with CPAI representative at time of inspection Operator Rep Signatures: J.Regg(AOGCC)for C,Scheve AOGCC Inspector *After signing,a copy of this form is to be left with the operator. Follow-up Instructions Return a copy of this Deficiency Report to AOGCC(Attention:Inspection Supervisor)within 7 days of receipt. Include the"Date Corrected"and attach supporting documentation for each corrective action implemented to address the deficiencies. If a follow-up inspection was performed by AOGCC,include the date and name of Inspector. Extensions for corrective actions taking longer than the"correct by"date must requested and accompanied by justification(Attention:Inspection Supervisor). Failure to provide the required documentation of corrective actions constitutes a violation of 20 AAC 25.300 and is subject to enforcement action under 20 AAC 25.535 Revised 04/2015 ' 1-17 PTD 201 -230 t ConocoPhillips r Alaska, Inc This photo is copyrighted by ono coPhillips Alaska, nc. and cannot be 4 released or published without express written consent of ConocoPhillips Alaska 1ii, 0 M 4 l C ONOCO PtHii.IIP5 lamµ...: "I-0 ALASKA ‘ i API t •ikr:.Ss i o0 00 %; pro: 2ot-230 Sar C«• •�: 6o*F51.6OO I WL 5t /j' TI I N R IlE tATA L n Ani - * ;3 ,,. - STATE OF ALASKA AL .:A OIL AND GAS CONSERVATION CONS. JSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Suspended Well Inspection Alter Casing r Pull Tubing r Stimulate- Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-230 3.Address: 6.API Number Stratigraphic r Service r P. 0 Box 100360,Anchorage,Alaska 99510 50-029-23058-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0028244, 0028243 k9..v 1M-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s) KUPARUK RIVER FIELD/KUPARUK RIVER OIL 11.Present Well Condition Summary: 2.875"CCX PLUG -533' Total Depth measured 11060 feet Plugs(measured) 2.812"CS-A2 PLUG - 10436' true vertical 7009 feet Junk(measured) NONE Effective Depth measured 10960 feet Packer(measured) 10478 true vertical 6909 feet (true vertical) 6428 Casing Length Size MD ND Burst Collapse CONDUCTOR 120 16 120 120 1640 630 SURFACE 8040 7 5/8 8040 4108 6890 4790 PRODUCTION 10474 51/2 10474 6424 7000 49990 LINER 594 31/2 11055 7004 10160 10540 RECEIVED , Perforation depth: Measured depth: 10606-10642 True Vertical Depth: 6555-6591 SC.ANIIED APR 0 3 2 015 Tubing(size,grade,MD,and ND) 3 5, L-80, 10474 MD,6424 TVD AOG C v Packers&SSSV(type,MD,and ND) SEAL-80-40 GBH SEAL ASSEMBLY @ 10478 MD and 6428 TVD SSSV-2 CAMCO'DS'LANDING NIPPLE @ 533 MD/TVD and 10436 MD,6386 ND 12.Stimulation or cement squeeze summary: NA Intervals treated(measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14 Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16 Well Status after work• Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r VVINJ r WAG r GINJ r SUSP r SPLUG r 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C 0 Exempt NA Contact MJ Loveland/Martin Walters Email n1878@cop.com Printed Name mi- Ld t/e(c1 ci Title Well Integrity Project Signature �/iV v 1 / / Phone 659-7043 Date: /Va �7 ��l°� `5 RBDMS k APR - 7 2015 `1%05 Form 10-404 Revised 10/2012 Submit Original Only RECEIVED 4PRo32.015 ConocoPhillips Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 1, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 1M-17 (PTD 201-230) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 1M-17 (PTD 201-230). The inspection was completed on March 27, 2015 and witnessed by State Inspector Chuck Scheve. The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call Martin Walters or me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 1M-17 Field/Pool: KUPARUK RIVER Permit#(PTD): 201-230 Sundry 302-150 API Number: 50-029-23058-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 4/26/2002 Surface Location: 618' FSL, 600' FWL Section: 17 Township: 11N Range: 11E Nearest active pad or road: SPINE ROAD NEAR KRU DS1D/DS1C Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Sfto a, Cc Pere c✓ 9rgae/ ^4< Pad or location surface: Sypw co vett-c✓ W ice / Location cleanup needed: -S'cq-Pie,/e/ d to/ vi' truee't Gvi// 6e ceorct/e'd• Pits condition: No Surrounding area condition: 9aod Water/fluids on pad: yooe Discoloration, Sheens on pad, pits or water: AVM) Samples taken: !96/Teo_ Access road condition: i'ce/wa e/ coq 01— Do Photographs taken (#and description): Si p. /o s 3 o.F 4,/el7he4. f ct,a 74e 6, (.i it-IL 4 attic_ .56.�+.%1 at rP✓Gtn�i i P' ci/2 C or Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: ,t /1 L,,/ue Cyc of q Jevep' cool:4/6h .q 6J Cellar description, condition, fluids: Hee / ce/%/ .Ace f/v/cf , p/ywooJ cover; Rat Hole: Wellhouse or protective b rriers: `to cveg`jdoeje / ��-riP/ 4/av,,I Ge//a4-- Well identification sign: Wane on �pi sil-q I/e34e//s- Tubing Pressure (or casing if no tubing): fy Annulus pressures: �/� - 12( Wellhead Photos taken (#and description): p/. -Z1/0 Work Required: Gr S/9// /O co¢iak c/9,, . — Ci -p/-2 A€G/ / a an4/1- / Operator Rep (name and signature): ivl S t v e-/Gr nG/ AOGCC Inspector: �.h u L SGhp v Other Observers: 7/7 , too.' Inspection Date: a-7iY2 /2C h/ 5 AOGCC Notice Date: /014-i2/S-- Ti me Time of arrival: U00 Time of Departure: 0$ 30 Site access method: _TG e. i?o c CI KUP PROD 1M-17 ConocoPhillips ; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Inc!/3 MD(ftKB) Act Btm(ftKB) Cnn..artl9iP, 500292305800 KUPARUK RIVER UNIT PROD 66.01 5,415.62 11,060.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1M-17,3/2220154.6153 PM SSSV:NIPPLE Last WO: 35.59 1/20/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,631.0 2/15/2015 Rev Reason:GLV CIO,PLUG,TAG lehallf 3/22/2015 HANGER;26.1 i--I' Casing Strings Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(1.7 Grade Top Thread CONDUCTOR 16 15.062 31.0 120.0 120.0 62.58 H-40 BUTT TUBING PUP;269 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i I- t SURFACE 75/8 6.875 31.1 8,042.5 4,608.2 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' PRODUCTION 5.5"x3.5" 5 12 4.950 28.3 11,055.9 7,005.1 15.50 L-80 BTCM F Tubing Strings - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...WI(Ibm) Grade Top Connection • TUBING 312 2.992 26.2 10,477.8 6,427.5 9.30 L-80 EUE8RDMOD Completion Details on-A CONDUCTOR;31.0.120.0-e Nominal lD Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) 26.2 26.2 0.09 HANGER FMC TUBING HANGER 3.500 PLUG;533.4 NIPPLE;533.4, 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 I H 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) ("1 Des Com Run Date ID(In) 2.875"CS-A2 PLUG 320/2015 0.000 GAS LIFT;3.510.1 10,436.5 6,386.4 5.72 PLUG 2.812'CS-A2 PLUG 3/82015 0.000 11. Perforations&Slots 111 Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (tt(B) (ftKB) Zone Date t) Type Com GAS LIFT;6,903.2 10,606.0 10,642.0 6,555.4 6,591.4 C-4,C-3,1M- 2/16/2002 6.0 IPERF 2.5"HSD,2506 HJ 17 Chgs,60 Deg phase Stimulations&Treatments Min Top Max Btm r Depth Depth Top(TVD) Btm(ND) (ttKB) (ftKB) (ftKB) (ftKB) Type Date Corn 10,606.0 10,642.0 6,555.4 6,591.4 FRAC 3/21/2002 C-SAND FRAC,90M#BEHIND PIPE,9 ppa ON • PERFS • Mandrel Inserts • St SURFACE.:11 1-8.042 5 a an . on Top(ND) Valve Latch Port Size TRO Run N Top(66131 (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com I' 3,510.1 2,614.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 9 GAS LIFT,9016.3 2 6,9032' 4,108.4'CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 • • 9 ' 3 9,016.3 5,132.6 CAMCO KBG-2- ' 1 GAS LIFT, 'DMY INT 0.000 0.0 1/17/2002 900 i- 9 ' 4 9,907.0 5,868.7 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 9 5 10,3932 6,343.3 CAMCO KBG-2- 1 GAS LIFT OPEN BTM 0.000 0.0 3/19/2015 4:00 GAS LIFT;9,9070 ' 1 9 Notes:General&Safety End Dale Annotation 12/22/2005 NOTE:WELL STATUS IS SUSPENDED;WELL TYPE IS PRODUCTION 10/6/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;10,393.2 a i NIPPLE;10.436 5 PLUG;10,436.51 III LOCATOR;10,475.0 FRAC;10,642.0 (PERF;10,606.0.10,612.0 PRODUCTION 5.52/3.5";26.3AJ L - 11,055.9 REV DATE BY CK APPI `ESCRIPTION REV DATE BY Cr1 APP I DESCRIPTION I I LEGEND T12N 'kr \ Tt1N O FUTURE CONDUCTORS q,� • EXISTING CONDUCTORS 2 1 6 West U 5 ® AS—STAKED CONDUCTORS —THIS SURVEY Sok 24A N W.S.'.T+ i 11.,„ . .P. • ._ DS-1C 11 . .. -.. , 12 7 8j�� ,` � ,SUR Y SCALE: po TI-II' 9X 18 17 1" --- 200' 1ill j�"�13 US-1D c QS 1M 23 24 )-9 0 m— mm VICINITY MAP SCALE: 1" = 1 MILES WELL 1M-17 • LOCATED WITHIN PROTRACTED I SEC. 17, TWP. 11 N., R. 11 E. UMIAT MERIDIAN Y = 5,960,383.6 0017 X = 571,907.4 LAT = 7018'07.40" ri LONG = 149'25'03.24" J 618' F.S.L., 600' F.W.L. •MP 1 NOTES: 1. ALL COORDINATES ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. of3. ALL DISTANCES ARE TRUE. 4. DATE OF SURVEY: 12/7/01, F.B. L01-64, PG'S 64-66. -i8 17 1920 LOUNSBURY I & ASSOCIATES, INC.. SURVEYORS ENGINEERS PLANNERS 0 AREA: IM MODULE:XXXX UNIT: 01 PHILLIPSA. PHILLIPS Alaska, Inc. DS 1M 6V A Subsidiary of PHILLIPS PETROLEUM COMPANY WELL CONDUCTOR 17 AS—STAKED LOCATION CADLK6113D2 12/6/01 I DRAWING NO: NSK 6.113 — d2 SHEET: 1 OF 1 REV: 0 i •-17PTD2OI -230 L ©ConocoPhillips Alaska, Inc This photo is copyrighted by onocoPhillips Alaska, nc. and cannot be i I released or published without express written consent of 4. ConocoPhillips Alaska III 1 1 iiiitio. I t II CONOCO PHILLIP5 Well Tawe: IM—IT ALASKA API 1+414mber:56-029-23058-00 .• PID: 201-230 Sqf,Location 06.'FSL.boo'FWL Ste,17 TIIN RITE Ulf d..... i 1 M=17 PTD 201 -24 ©ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. ; Iiii and cannot be released or published without express '` written consent of )11 ConocoPhillips Alaska 4 1 'aa. 9 ,, ° <... ; 411#.1/: r r ,'^- it t.. S 1 M-1 7 OrD 201 -230 ©ConocoPhillips Alaska, Inc This photo is copyrighted by .46 ConocoPhillips Alaska, Inc. and cannot be released or published without express .. - written consent ofz,-,;„,.,.,_,...„.„.•,.,....._... , _„...,, 40-7.--,- ConocoPhillips Alaska ...... ....„.............. . : .....,..,,,,r r.,rAr.r r....my..,' .....J.r.......5...ryir,,..,.I r,....-..;r..,r,I/...........,r.,' ... - ,, ...._.... -..10 ......q. . , . rii 40.f. , .....v:/ f,: , U!i, f. ‘ • , iii_ rile , 01111111•06.,.... 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Y M us,.�\ !A 3xY,�pY.tJ �y;.�i_.�"c A ��M t..�` �.t@ Fxi kv" T"'" n1""" d Q o STATE OF ALASKA AL A,,KA OIL AND GAS CONSERVATION COM,_...)SION • REPORT OF SUNDRY WL L OPERATIONS 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other r Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 201-230 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service �` 50-029-23058-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 28244,28243 KRU 1 M-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s). none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 11060 feet Plugs(measured) 533, 10437 true vertical 7009 feet Junk(measured) none Effective Depth measured 10960 feet Packer(measured) none true vertical 6909 feet (true vertical) none Casing Length Size MD TVD Burst Collapse CONDUCTOR 89 16 120 120' SURFACE 8011 7.625 8043 4608 PRODUCTION 11028 5.5 x 3.5 11056 7005' RECEIVED Perforation depth. Measured depth: 10606-10642 True Vertical Depth: 6555-6591 SCANNED MAR 3 1 N9 Tubing(size,grade,MD,and ND) 3 5, L-80, 10478 MD,6428 ND AOGCC Packers&SSSV(type,MD,and ND) no packer NIPPLE-CAMCO DS LANDING NIPPLE @ 533 MD and 533 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14 Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development f Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WIND r WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 315-034 Contact Jill Simek a 263-4131 Email JiII.Simek(c�conocophillips.com Printed Name All Simek Title Staff Well Integrity Engineer Signature '784y-- )4&____ Phone:263-4131 Date 3/94 / RDM APR - 6 2015 1'r i- 'f//o! / -- ,1. 401/c Form 10-404 Revised 10/2012 Submit Original Only s KUP PROD 1M-17 Conoco Phillips u Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t rrrrn hO4n 500292305800 KUPARUK RIVER UNIT PROD 66.01 5,415.62 11,060.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1M-17,3/22/20154.5153 PM SSSV:NIPPLE Last WO: 35.59 120/2002 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag.SI M 10.631.0 2/15/2015 Rev Reason:GLV C/O,PLUG,TAG lehallf 3/22/2015 HANGER;26.1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WOLen(I...Grade Top Thread _ CONDUCTOR 16 15.062 31.0 120.0 120.0 62.58 11-40 BUTT TUBING PUP;26.9 Casing Description OD(in) ID lin) Top((KB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread SURFACE 7 5/8 6.875 31.1 8,042.5 4,608.2 29.70 L-80 BTCM r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread PRODUCTION 5.5"x3.5" 5 1/2 4.950 28.3 11,055.9 7,005.1 15.50 L-80 BTCM Tubing Strings -- Tubing Description String Ma...ID lin) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 26.2 10477.8 6,427.5 9.30 L-80 EUE8RDMOU o ' Completion Details CONDUCTOR:31.0-120.0-4 Mei Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 26.2 26.2 0.09 HANGER FMC TUBING HANGER ' 3.500 PLUE:533.4 NIPPLE;533.41111 533.4 533.2 3.74 NIPPLE CAMCO DS LANDING NIPPLE 2.875 10,436.5 6,386.4 5.72 NIPPLE CAMCO DS NIPPLE 2.812 10,475.0 6,424.7 4.87 LOCATOR G-22 LOCATOR 3.000 I 10,477.8 6,427.5 4.81 SEAL ASSY GBH 80-40 SEAL ASSEMBLY 3.000 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID lin) 533.4 533.2 3.74 PLUG 2.875"CS-A2 PLUG 3/20/2015 0.000 GAS LIFT;3,510.1lij _ 10,436.5 6,386.4 5.72 PLUG 2.812"CS-A2 PLUG 3/8/2015 0.000 Perforations&Slots Shot Dens Top(TVD) Ben(TVD) (shotslf Top(ftKB) Btm(MO) (MB) (ftKB) Zone Date t) Type Con GAS UFT;6,903.2 10,606.0 10,642.0 6,555.4 6,591.4 C-4,C-3,1M- 2/162002 17 6.0 IPERF 2.5"HSD,2506 HJ Chgs,60 Deg phase Stimulations&Treatments ~-' Min Top Max Btm Depth Depth Top(TVD) Btm(ND) (ftKB) (ftKB) ((KB) (ftKB) Type Date Com 10,606.0 10,642.0 6,555.4 6,591.4 FRAC 3/21/2002 C-SAND FRAC,90M#BEHIND PIPE,9 ppa ON PERFS Mandrel Inserts St SURFACE;31.14,042.5-- - ati on Top(TVD) Valve Latch Pon Size TRO Run N Top(ftKB) (IB(13) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com - - 1 3,510.1 2,614.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 D 9 GAS LIFT;9,018.3 �.. 2 6,903.2 4,108.4'CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 4/26/2002 11:00 3 9,016.3 5,1326 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 1/17/2002 9:00 4 9,907.0 5,868.7 CAMCO °KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 3/29/2002 6;00 __ 9 5 10,3932 6,343.3 CAMCO °KBG-2- 1 GAS LIFT OPEN BIM 0.000 0.0 3/19/2015 4:00 GAS LIFT;9,907.0 9 Notes:General&Safety End Date Annotation ,-- 12/22/2005 NOTE:WELL STATUS IS SUSPENDED;WELL TYPE IS PRODUCTION 10/6/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;10,393.2111 NIPPLE;10,436 5, PLUG;10,436 5 LOCATOR;10,475.0 FRAC; ,642. I- I IPERF;10FRAC1010,642.00 PRODUCTION 5.55x35",283- , 11,055,9 1M-1Y WELL WORK SUMMARY ,DATE SUMMARY 2/15/2015 PULLED 2.875" CCX PLUG FROM 533' RKB. PULLED 2.81" CS-A2 PLUG FROM 10,436' RKB. W/2.75" CENT& 2.5" BAILER, TAGGED @ 10,631' SLM. READY FOR E-LINE. 2/19/2015 REMOVE WATER FROM CONDUCTOR AND CELLAR. MEASURE TOC 2/25/2015 LOG BAKER MICROVERT TOOL FROM SURFACE TO 10450'AND REPEATED BACK TO SURFACE. TOOLSTRING GOT HELD UP AT 10393' GLM AND 9906' GLM GOING IN AND OUT OF HOLE. DATA TO BE FURTHER PROCESSED. READY FOR ELINE CALIPER/SBHP. 2/28/2015 RIH W/CALIPER, PRES, TEMP. TAG BOTTOM AT 10662'. LOG SBHP AT 10624' MD (2646 PSI @ 153 DEG)AND 10400' MD (2567 PSI @ 145 DEG). LOG CALIPER SURVEY FROM 10650'TO 3100'. UNABLE TO COMPLETE LOG DUE TO WEATHER. PCE AND TOOLS STILL STUCK ON WELLHEAD DUE TO EXTREMELY HIGH WINDS. STANDING BY ON LOCATION FOR WEATHER TO SUBSIDE. JOB IN PROGRESS. 3/8/2015 SET 2.81 CA-2 PLUG © 10436' RKB, SET AVA STYLE CATCHER ON PLUG © SAME. PULLED DV @ 10393' RKB, CMIT TBG x IA PASS, LOAD TBG & IA WITH INHIBITED SW WITH DSL FREEZE PROTECT, SET DV @ 10393' RKB. IN PROGRESS. 3/9/2015 TBG TEST FAILED, IA TEST FAILED, PULLED DV© 10393' RKB PACKING LIGHTLY DAMAGED, SET NEW DV @ SAME, TBG TEST FAILED. JOB POSTPONED PHASE 2 FIELD WIDE. IN PROGRESS. 3/9/2015 PUMP CEMENT INTO CONDUCTOR (COMPLETE) 3/11/2015 W/ HOLEFINDER IDENTIFIED POSSIBLE TBG LEAK BETWEEN 9924' & 10,040' RKB. 3/19/2015 PULLED DV(MISSING BTM LATCH) @ 10,393' RKB. READY FOR CIRC OUT. 3/20/2015 PUMPED 175 BBLS 9.1 PPG BRINE AND 46 BBLS DIESEL TBG x IA. U-TUBED TBG x IA. PULLED CATCHER (w/MISSING LATCH) © 10,436' RKB. SET 2.875" CS-A2 PLUG © 533' RKB. PERFORMED MIT-T © 2500 PSI. *FAILED* IN PROGRESS. 3/21/2015 MIT-T © 2500 PSI *PASSED* T/IA= 0 PSI. OA STILL NEEDS TO BE BLED TO 0 PSI. READY FOR DHD 3/22/2015 1M-17= PUMP RG-2401 SEALANT INTO CONDUCTOR (COMPLETE) 3/22/2015 (SEC)T-DDT (PASSED), IA-DDT (PASSED), OA-DDT (IN PROGRESS). 3/23/2015 BLEED OA FOR WELL SUSPENSION (IN PROGRESS) 3/25/2015 BLEED T/I/O TO 0 PSI (IN PROGRESS) • Allsup-Drake, Sharon K From: Simek,Jill Sent: Thursday, March 26, 2015 9:32 AM To: NSK Well Integrity Proj;Allsup-Drake, Sharon K Subject: FW: [EXTERNAL]RE: 1M-17 (PTD#201-230, Sundry 315-034) Sent with Good (www.good.com) From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Thursday, March 12, 2015 12:50:54 PM To:Simek,Jill Subject: [EXTERNAL]RE: 1M-17 (PTD#201-230,Sundry 315-034) Jill, The amended steps listed below are approved. Please update the approved sundry with this approval. Please outline the future utility of this well. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeor @alaska.ciov From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Wednesday, March 11, 2015 4:15 PM To: Loepp, Victoria T(DOA) Subject: 1M-17 (PTD# 201-230) Victoria, While performing well work on 1M-17 (Sundry#315-034 for Re-entry of Suspended Well),a tubing leak was discovered below the gas lift mandrel at station#4. Original plan was to re-suspend the well with mechanical plugs set at 10,436.5 ftKB and 533.4 ftKB, providing two tested barriers to surface. Currently,the first plug has been re-set at 10,436.5 ftKB. A passing CMIT-TxIA to 2500psi has been obtained, showing competent plug and production casing. 1 With failure of tubing,the recommended amended steps to suspend are: 1. Pull dummy gas lift valve at 10,393 ftKB 2. Circulate kill weight fluid in tubing and tubing x production casing annulus(IA) 3. Set 2.875" CCX plug in Camco DS Landing Nipple at 533.4 ftKB 4. MIT-T to 2500psi 5. Bleed T/I/O to zero and leave well secured This would ensure two tested barriers from reservoir to surface (Kill weight fluid,and production casing). If desired,an additional mechanical barrier could be obtained by adding a second deep plug below the tubing leak. The above steps do not fix the tubing leak,which would require additional diagnostic services to determine exact leak location,followed by installation of a tubing patch, if feasible. Since there are no plans to place the well back in service, ConocoPhillips requests to not repair the tubing, instead suspending the well with barriers as explained above. Please reply with your approval or contact me if you have questions or comments. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected 03/27/15 Inspector: Chuck Scheve Operator Conoco Phillips Well Name. 1M-17 Oper Rep: M J Loveland PTD No 201-230 Oper.Phone: 659-7043 Location Verified? No Oper.Email If Verified,How? Onshore/Offshore Onshore Suspension Date 04/26/02 Date AOGCC Notified: 03/25/15 Sundry No 302-150 Type of Inspection Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi). Tubing 0 Photos Taken? No IA 0 OA 240 Condition of Wellhead Good Condition of Surrounding Surface Location Snow and ice covered gravel pad No visable problems Follow Up Actions Needed. Remove visquene and scafold over wellhead Obtain and post well sign Comments Deficiency Report sent to CPAI for above-noted"Follow-up Actions Needed" /c n A,\1115 Attachments none REVIEWED BY: f Insp Supry 3-Pg— 4111i5 Comm PLB 12/2014 2015-0327_Suspend_KRU_1M-17_cs xlsx 1 ConocoPhillips Alaska scow MAR 3 12°15 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 25, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission ,�n 1 333 West 7th Avenue, Suite 100 rV` Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water,from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 3-22-2015 1M PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls(7 ft gal 1M-17 50029230580000 20123000 6 0.60 18" 3/9/2015 7.6 3/22/2015 20(.-23O 2-5513 WELL LOG TRANSMITTAL DATA LOGGED Alga 5 i K BENDER To: Alaska Oil and Gas Conservation Comm. March 5, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 MAR 2 4 2015 AOGCC RE: Multi Finger Caliper(MFC)/Static Bottom Hole Pressure Survey: 1M-17 Run Date: 2/28/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1M-17 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23058-00 Static Bottom Hole Pressure Survey 1 Color Log 50-029-23058-00 SCANNED ' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: P').4/7-0-#za-• 6-eogzeit PTL a6/ - 23O Loepp. Victoria T (DOA) From: Simek,Jill <Jill.Simek@conocophillips.com> Sent: Thursday, March 12, 2015 1:10 PM To: Loepp, Victoria T (DOA) Cc: NSK Well Integrity Proj Subject: RE: 1M-17 (PTD# 201-230, Sundry 315-034) Follow Up Flag: Follow up Flag Status: Flagged Thank you,Victoria. I have amended the approved sundry procedure and communicated to operations. Regarding future utility,the well may be used for monitoring purposes(pressures,fluid contacts) should field redevelopment opportunities arise. Thanks, Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone: 907-263-4131 I Cell: 907-980-7503 SCANNED MAR 19 2015 From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Thursday, March 12, 2015 9:51 AM To: Simek, Jill Subject: [EXTERNAL]RE: 1M-17 (PTD# 201-230, Sundry 315-034) Jill, The amended steps listed below are approved. Please update the approved sundry with this approval. Please outline the future utility of this well. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a.a laska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 From: Simek, Jill [mailto:Jill.Simek@conocophillips.com] Sent: Wednesday, March 11, 2015 4:15 PM To: Loepp, Victoria T(DOA) Subject: 1M-17(PTD# 201-230) Victoria, While performing well work on 1M-17(Sundry#315-034 for Re-entry of Suspended Well),a tubing leak was discovered below the gas lift mandrel at station#4. Original plan was to re-suspend the well with mechanical plugs set at 10,436.5 ftKB and 533.4 ftKB, providing two tested barriers to surface. Currently,the first plug has been re-set at 10,436.5 ftKB. A passing CMIT-TxIA to 2500psi has been obtained,showing competent plug and production casing. With failure of tubing,the recommended amended steps to suspend are: 1. Pull dummy gas lift valve at 10,393 ftKB 2. Circulate kill weight fluid in tubing and tubing x production casing annulus(IA) 3. Set 2.875" CCX plug in Camco DS Landing Nipple at 533.4 ftKB 4. MIT-T to 2500psi 5. Bleed T/I/O to zero and leave well secured This would ensure two tested barriers from reservoir to surface(Kill weight fluid,and production casing). If desired, an additional mechanical barrier could be obtained by adding a second deep plug below the tubing leak. The above steps do not fix the tubing leak,which would require additional diagnostic services to determine exact leak location,followed by installation of a tubing patch, if feasible. Since there are no plans to place the well back in service, ConocoPhillips requests to not repair the tubing, instead suspending the well with barriers as explained above. Please reply with your approval or contact me if you have questions or comments. Jill Simek ConocoPhillips Alaska Staff Well Integrity Engineer 700 G Street, ATO 1000, Anchorage, AK 99501 Phone. 907-263-4131 I Cell. 907-980-7503 2 (cOF \�jj sv THE STATE Alaska Oil and Gas s���� o Conservation Commission _ __ fALASI�:A ..itlit+E_— 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0 Main: 907.279.1433 FALAS5� t C Ij:: Fax: 907.276 7542 �,,��g� 1 ..1: 'i www.aogcc.alaska gov Jill Simek �1R Staff Well Integrity Engineer ?� ConocoPhillips Alaska, Inc. a,o,____.(- D-30 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1M-17 Sundry Number: 315-034 Dear Ms. Simek: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P.1oerster Chair DATED this day of January, 2015 Encl. STATE OF ALASKA i AL A OIL AND GAS CONSERVATION COMM, DN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown p Re-enter Susp.Well r Stimulate r Alter casing r Other: I-- 2.Operator Name: ' 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development P 201-230 • 3.Address: Stratigraphic r Service I- P. 6.API Number: O. Box 100360,Anchorage,Alaska 99510 50-029-23058-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes IT No rv7 KRU 1 M-17 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 28244,28243 - Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 11060 - 7009 - 10960' . 6909' • 533, 10437 none Casing Length Size MD TVD Burst Collapse CONDUCTOR 89 16 120' 120' SURFACE 8011 7.625 8043' 4608' PRODUCTION 11028 5.5 x 3.5 11056' 7005' RECEIVED JAN 2 201115 AO CC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10606-10642 • 6555-6591 3.5 L-80 10478 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) no packer no packer NIPPLE-CAMCO DS LANDING NIPPLE MD=533 TVD=533 ' 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 117• Service r 14.Estimated Date for Commencing Operations. 15. Well Status after proposed work: 2/4/2015 Oil r Gas f WDSPL r Suspended r 16.Verbal Approval. Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jill Simek @ 263-4131 Email: Jill.Simekaconocophillips.com Printed Name IIL.Sim Title: Staff Well Integrity Engineer Signature _ Phone:263-4131 Date 1/2.I/IS-- Commission SCommission Use Only Sundry Number: Conditions of approval. Notify Commission so that a representative may witness 3\S- 03 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [Z Subsequent Form Required: /G — 4 c 4- APPROVED BY 2 ---- Approved Approved by: COMMISSIONER THE COMMISSION Date: /' 2 ��S pproved application is valid for 12 months tro the�r^late of approval. p� ■� q C Form 10-403(Revised 10/2012) ,17o. I i2Zl1 J Submit Form and Attachmentstin uplicate - 4 2015 Yfil- i/2- / l'f ORIGINAL ,�7 ,3 - lIb /-3 - , RECEIVED ConocoPhillips JAN 2 2 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 21 January 2015 Commissioner Dan Seamount State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7`h Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska,Inc.hereby applies for an Application for Sundry Approval to re-enter 1M-17 (PTD#: 201-230)for tubing evaluation and corrosion protection operations. ✓ Well 1M-17 was drilled in January 2002 and tested in March 2002,after which it was shut-in and secured with two mechanical plugs in the tubing string. The well was last entered in December of 2005 to measure reservoir pressures in support of development drilling in the area. In September 2010,a suspended well inspection was performed and results submitted on a 10-404. An application for suspended well renewal was submitted with a 10-403 in December,2010 and approval received January,2011. While it is unlikely the well will be placed back in service,potential remains for 1M-17 to be used for the menitorig of reservoir pressures and/or fluid saturations to aid in the understanding of fluid movement in the area. This data would be essential for working possible re-development options in this area of the field. The well has 7-5/8" surface casing to 8,043 ftKB and 5.5"x 3.5"production casing to 11,056 ftKB. There is 3-1/2" tubing with seal assembly at 10,478 ftKB. Perforations are located from 10,606.0 to 10,642.0 ftKB. Currently, the well is secured with plugs at 533.4 ftKB and 10,436.5 ft KB. There is no permanent road to the well;access to perform the work is planned via winter ice road. Per this procedure, plugs will be pulled and tubing corrosion and caliper logs will be run to evaluate the present condition of the 3.5" tubing. Existing wellbore fluids will be displaced with corrosion inhibited seawater and diesel freeze protect,plugs will be re-set,and the well returned to suspended status. If you have any questions or require any further information,please contact me at 263-4131. Sincerely, : sivic_ ii. - imek 1 Integrity Engineer CPAI Drilling and Wells ConocoPhi..ips 1M-17 Well Work Permit to Drill #: 201-230 The objective of this procedure is to perform tubing evaluation and corrosion protection operations on 1M-17. After logging with caliper and electromagnetic tubing inspection logs, existing wellbore fluids will be displaced with corrosion inhibited seawater and diesel freeze protect. The well will then be re-suspended by placing two mechanical plugs in the tubing. Proposed Procedure: Slickline/Little Red Services: Objective: Pull Plugs, SBHP, run memory logs, set plug, create circulation point, circulate inhibited fluid and freeze protect, CMIT-TxIA, reset dummy valve, MIT-T, set upper plug, MIT-T. 1. Conduct safety meeting and identify hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 2. RU IA jumper, returns tanks & hard line. 3. RU Slickline (SL) and PT equipment as required. 4. RIH and pull CCX plug at 533.4 ftKB. 5. RIH and pull CS-A2 plug at 10,436.5 ftKB 6. Perform drift/tag with 2.7"OD GR/JB to 10,624 ftKB. 7. RIH with Dual Spartek gauges to 10,624 ftKB for SBHP; perform a gradient stop at 10,400 ftKB 8. RIH with Memory MicroVertilog and Caliper tools to 10,475 ftKB or deepest possible depth. Log to surface. 9. RIH reset CS-A2 plug @ 10,436.5 ftKB. 10. RIH and set catcher on plug at 10,436.5 ftKB; pull DV at 10,393.2 ftKB. 11. Perform CMIT TxIA to 2500psi. Record initial, 15min, 30min TIO pressures. Report issues and results to PWS. 12. RU Little Red Services (LRS) and PT surface equipment as required. 13. RU to tubing; pump 170 bbls of corrosion inhibited seawater and 46 bbls of diesel freeze protect, taking returns up IA to tanks. 14. Jumper tubing and IA to U-tube freeze protect. 15. RIH and reset DV at 10,393.2 ftKB. 15. RIH with 2.875" CCX plug and set in Camco DS Landing Nipple at 533.4 ftKB. 16. Perform MIT-T to 2500psi. Record initial, 15min, 30min TIO pressures. Report issues & results to PWS. 17. Bleed T/I/O to zero and leave well secured. JS - a Wellbore Schematic: / KUP 1M-17 ConocoPhillips `, Wen Attrbutea Max An MD ,Tp. _ A:1!L..� . 1tC..AFtJ .a lN.l:a--s r I i' A } , .i:3Cigla, 1:•~._..f-'.l--._r4,.. I.'., E601 ?A"_.6: 1• 1,11_ Car=wt L 7.t . es M•a4er --o.J.1* ....Or/,i1 'Alp Peieee Lore 33 2V eilf fl. 1 al NO 3'_.5: :4'1:015 r-+-..en artMS• Wee. - .m,•Toy. 1:is--: 1..2.2:2-..:6. 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BEVERL y ROBIN VINCENT SHER r'L @WINDY Other OATE¡3 ~O if' VY1 P 0 Project Proofing Scanning Preparation <~ x 30 = h{) + DATED~~ Olf Jt! ~ TOTAL PAGES 79 OA TE2> Jð tN1>1 VV1 P VI1P S'(, BEVERL'( ROBIN VINCENT SHERYL ~INDY BY' BEVERL Y ROBIN VINCENT SHER,(~IND ( Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: ()£7 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: V YES - NO BEVERL'( ROBIN VIIJCENT SHER'(L MARIA WIN(){ DATE '71,cc/vC( /s/ #- B'(: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO B {: BEVERL,' ROBIN VINcEr~T SI-IER'(L MARIA WIND'( DATE: /s/ (SCAli/IllIG IS COMPLETE A T THIS POll IT UNLESS SPECIAL A !TErmON IS REQUIRED 01/ Atl ItlDlVlDUAL PAGE BASIS DUE TO aUAUT f. GRJlVSCALE OR COLOR IMAGES) ReScanned 1/11:111'1,1,." /.1f,I"",{,,,,"/.ll ,>/I(I1II'I'I} ',f .""IIIII,,"'II"/," "N/ RESCANNED B"(: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: Quality Checked irhHIf' 12/10/02ReI/3NOTScanned wpd 7.1VFLE SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CODIIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. ii 0,36 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1M-17 Sundry Number: 310 -424 Dear Ms. Loveland: NINSEID 10 2 ' 16 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. 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 reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, C Daniel T. Seamount, Jr. Chair DATED this day of January, 2011. Encl. Conoco Phillips Alaska ~#' IVED P.O. BOX 100360 DEC y 4 2� 10 ANCHORAGE, ALASKA 99510 -0360 aof3. Commission ,- err13r8(�e December 11, 2010 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Renewal of Suspended Well 10 -403 Status Kuparuk River Unit 1M -17 (PTD 201 -230) Dear Commissioner Seamount: ConocoPhillips Alaska Inc. (CPAI) hereby submits a request for renewal of the suspension status of Kuparuk River Unit well 1M -17 (PTD 201 -230) per 20 AAC 25.110. The well was visually inspected September 27, 2010 and the results submitted on a 10- 404. The condition of the well is noted on an attached schematic and 10 -403 form. Please note the following: - The wellbore is secured with 2 tubing plugs. - This well is currently not accessible by road. CPAI request the renewal of the suspension because the well is being held for future development of drill site 1M. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor STATE OF ALASKA O ,/ ALASIIILL AND GAS CONSERVATION COMMISSIW 1 ,k APPLICATION FOR SUNDRY APPROVALS ,LIE , 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend Rug Perforations r Perforate r Pill Tubing r Time Extension T , • st • // Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Otherk Sus s;ar 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Num er: ConocoPhillips Alaska, Inc. Development r . Exploratory r 201 - 230 • 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23058 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: 0 fF ' Cs Spacing Exception Required? Yes r No r 1M -17 9. Property Designation: 10. Field /Pool(s): ADL0028244 / ADL0028243 Kuparuk River Field / Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 11060 • 7009 10960' • 6909' ' 533' & 10436' None Casing Length Size MD ND Burst Collapse CONDUCTOR 120 16 120' 120' SURFACE 8040 7.625 8040' 4108' PRODUCTION 10474 5.5 10474' 6424' LINER 594 3.5 11055' 7004' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10606 - 10642' 6555 -6591 3.5 L -80 10474 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) NIP - CAMCO 'DS' LANDING NIPPLE - no SSSV MD= 533 ND= 533 PLUG - 2.875" CCX PLUG SET 12/22/2005 MD= 533 ND= 533 NIP - CAMCO 'DS' NIPPLE MD= 10436 ND= 6386 PLUG - 2.812" CS -A2 PLUG SET 12/22/2005 MD= 10436 ND= 6386 SEAL - 80 -40 GBH SEAL ASSEMBLY MD= 10478 ND= 6428 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r . Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: NA Oil r Gas IT WDSPL r Suspended r' 16. Verbal Approval: Date: WWINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Loveland Title: Well Integrity Project Supervisor Signature •/ -- „--y, - �_,„�.�__ - -" Phone 659-7535 Date /.2 -// / Commission Use Iv Sundry Number ?) 1 a n q Conditions of approval: Notify Commission so that a representative may witness IJ �� C Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r IVED Other: DEC 1 4 2010 ^/ -/--Li.,.... fug 6;as Cons. Commission Form Required: / " Anchorage APPROVED BY �� -4* 'i Approved by: COMMISSIONER THE COMMISSION Date: D JAN 0'6 201 Form 10-403 Revi • • R Submit in D l 1 . ConocoPhillips Alaska, Inc. 1M-17 KRU 1M-17 API: 500292305800 Well Type: PROD Angle p TS: 3 deg C 1 10605 TUBING SSSV Type: Nipple Orig 1/20/2002 Angle @ TD: 2 deg @ 11060 (0 00:3.500, Completion: 10:2.992) Annular Fluid: Last W /O: Rev Reason: Tag, reset plugs PRODUCTION Reference Log: Ref Log Date: Last Update: 1/2/2006 (0 10474, Last Tag: 10665 TD: 11060 ftKe OD:5.500, Last Tag Date: 12/22/2005 Max Hole Angle: 66 deg C@ 5416 Wt:15.50) Casin String -ALL STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 120 120 62.58 H -40 Buttress SURFACE 7.625 0 8040 4607 29.70 L -80 Buttress PRODUCTION 5.500 0 10474 6424 15.50 L -80 BUTTX8rd SURFACE LINER 3.500 10461 11055 7004 9.30 L -80 BUTTX8rd (0 -8040, Tubing String - TUBING OD:7.625, I Size Top Bottom TVD Wt Grade Thread wt:29.70) 3.500 0 10474 6424 9.30 L -80 EUE8RD Perforations Summary Type Interval TVD Zone Status Ft SPF Date T e Comment 10606 - 10642 6555 - 6591 C -4,C -3 36 6 2/16/2002 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Gas Lift Stimulations & Treatments ill 3ndrel /Dummy Interval Date Type Comment Valve 10606 - 10642 3/21/2002 FRAC C -SAND FRAC, 90M# BEHIND PIPE, 9 ppa ON PERFS (6903-6904, I Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date VII/ Mfr Run Cmnt 1 3510 2614 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 1/17/ DMY 1.0 BTM 0.000 0 4/26/2002 2002 2 6903 4108 CAMCO KBG-2-9 Gas Lin 3 9016 5133 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 1/17/2002 3ndrel /Dummy 4 9906 5868 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 3/29/2002 Valve 3 5 10393 6343 CAMCO KBG -2 -9 DMY 1.0 BTM 0.000 0 4/26/2002 (9016-9017, Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description ID 533 533 NIP CAMCO 'DS' LANDING NIPPLE 2.875 533 533 PLUG 2.875" CCX PLUG set 12/22/2005 0.000 10436 6386 PLUG 2.812" CS -A2 PLUG set 12/22/2005 0.000 Gas Lift 10436 6386 NIP CAMCO 'DS' NIPPLE 2.812 andreuoummy 10475 6425 LOCATOR G -22 LOCATOR 3.000 Valve 4 10478 6428 SEAL 80 -40 GBH SEAL ASSEMBLY 3.000 (9906 -9907, OD:4.725) 1 I . General Notes Date Note 5/4/2002 BPV set in tubing hanger Gas Lift ndrel /Dummy .. Valve 5 (10393 - 10394, OD:4.725) NIP - (10436- 10437, 00:4.520) LOCATOR (10475- 10478, OD:4.500) LINER (10461- 11055, OD:3.500, W t:9.30) Perf ._....... .. 10606- 10642) FRAC ;10606 - 10642) Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, October 25, 2010 3:49 PM ` .._. To: 'Allsup- Drake, Sharon K Cc: Alvord, Chip; NSK Well Integrity Proj Subject: RE: 1 M -17 frac Thanks Sharon, et al. This should complete the information that was not submitted when the well was tested. Call or message with any questions. Tom Maunder, PE AOGCC From: Allsup- Drake, Sharon K [mailto: Sharon.K.Alisup - Drake @conocophillips.com] Sent: Friday, October 22, 2010 10:44 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; NSK Well Integrity Proj Subject: RE: 1M -17 frac Tom - Attached is more data for 1 M -17 frac. DEC_ Zul Thank you, Sharon 263 -4612 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Friday, October 15, 2010 9:27 AM To: Allsup- Drake, Sharon K Cc: Alvord, Chip; NSK Well Integrity Proj Subject: RE: 1M -17 frac Thanks Sharon, Is there detailed testing information for the period — March 23 — March 27? Tom Maunder, PE AOGCC From: Allsup- Drake, Sharon K [mailto: Sharon.K.Allsup - Drake @conocophillips.com] Sent: Friday, October 15, 2010 9:04 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; NSK Well Integrity Proj Subject: FW: 1M -17 frac Tom — Attached is more details about the frac on 3/20/2002 you requested. You also wanted to know if there is any other work accomplished since 12122/2005 and the inspection on 4/21/2010. There isn't any documented write -up about any more work during this time period. If you have any other questions about this well, please feel free to call. Thank you, Sharon 263 -4612 10/25/2010 Injection I Production Date Water Diesel McOH Total Oil Water McOH Total Operation 2/3/02 0 0 0 0 Preperf slickline 2/14/02 0 0 0 0 Pressure test tubing & inner annulus 2/15/02 0 0 0 0 Cement log 2/16/02 0 0 0 0 Perforate 10606- 10642'MD 271 shots 3/19/02 0 0 0 0 Prefrac slickline 3/20/02 350 0 145 495 Datafrac, temp log, set BHP gauges 3/21/02 789 0 0 789 Frac w/ 90 Mlb, 9 ppa @ perfs CT FCO >1:1 returns. 159 bbl flowed w/ FCO in excess 3/23/02 0 0 0 0 318 145 463 of circ fluids. 3/24/02 393 39 432 Produced & injected McOH at WH 3/25/02 341 47 388 Produced until hydrate plug formed. 3/26/02 CTU thaw ice plug 85'- 2785' MD 580 bbi diesel 3/27/02 0 0 30 30 circulated, Attempt to pull DH BHP 3/28/02 0 43 82 125 Set valve catcher, pull Spartec BHP. Replaced Petredat w/ dummy. Set OV @6903'MD. Set 3/29/02 0 82 150 232 252 23 40 315 DHSITw /dual Spartek 3/30/02 140 140 551 34 150 735 Produced and injected McOH down IA 0.057866 3/31/02 100 100 498 83 140 721 Produced and injected McOH down IA 0.143161 Produced & injected McOH down IA. 430 bbl McOH 4/1/02 100 100 520 187 100 807 cumulative delivered to 1 M pad for well test operations 0.264459 4/2/02 70 70 571 165 100 837 Produced and injected McOH down IA 0.224471 4/3/02 65 65 901 251 70 1222 Produced and injected McOH down IA 0.217565 4/4/02 50 50 947 437 65 1450 Produced and injected McOH down IA 0.31585 4/5/02 50 50 980 547 50 1577 Produced and injected McOH down IA 0.358528 4/6/02 8 8 192 110 8 309 Downhole shut -in tool closed at 04:30 0.364038 Injection (bbls) Production (bbls) Water Diesel McOH Total Oil Water McOH Total Total 1139 125 990 2254 6463 1924 868 9255 3:Phase a u F1 l,Is' 'rd Tfersrrxn:l t:. I! : Lau f Chan e 71 =1 i1: :2 00. Gre Nt ENTER ALL PLOT HEADER DATA & TITLES BELOW Customer Nacre: Phillips Alaska, Inc. Well .Name & Number: IM -17 Flow Period: Test 91 - Clean Up Flow Date Hours Minutes Chart Start Date 4' T, rrre: 23- Mar -02 15 30 Chart End Date & Time: 24- Mar -02 5 30 Major Divisions in (hours & minutes) 0 30 31inor Divisions in (hours & minutes) 0 15 i " ENTER REPORT HEADER INFORMATION BELOW -, Customer: Phillips Alaska, Inc. Perf. Interval: 10,606' - 10,642' Well Name : IM- 17 Test No. Test #1 - Clean Up Flow Date: 23- Mar - 0215:30 to 24- Mar -02 05:30 Customer Rep.: Mark Cheney Rig : Wellhead Hes Supervisor: Craig Convey Base: Anchorage, AK ENTER CUMMULATIVES FROM PREVIOUS FLOWS BELOW Oil (hbls) : 0.00 Water (bbls) : 0.00 ... Gas (nnnscf) 0.0000 is HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS I CUSTOMER : Phillips Alaska, Inc. TEST No. :Test #1 - Clean Up Flow WELL 1M - 17 RIG NAME : Wellhead DATE TIME OPERATIONS 23- Mar -02 15:20 Open gas line in vertical separator. 23- Mar -02 15:27 Line up to flow to Tank #1 O/G = 0" 23- Mar -02 16:09 Open wing valve. 23- Mar -02 16:12 Open well on 8 /65ths adj. choke and gradually increase to 20 /64ths adj. choke. 23- Mar -02 16:13 Increase choke to 24/64ths adj. choke. 23- Mar -02 16:14 Light gas flare. 23- Mar -02 16:15 BS &W = 1% water w /trace of sediment 23- Mar -02 16:16 Increase choke to 28/64ths adj. choke. 23- Mar -02 16:20 Oil level in the horizontal separator sight glass. 23- Mar -02 16:21 Well shut -in to coil tubing. 23- Mar -02 16:22 Fluid to tanks. 23- Mar -02 16:30 BS &W = 0.25% water w /trace of sediment. Switch from Tank #1 to Tank #2. 23- Mar -02 16:31 Outer annulus = 150 psi 23- Mar -02 16:35 Increase back pressure to bring separator up to +/- 150 psi. 23- Mar -02 16:42 Increase back pressure to bring separator up to +/- 300 psi. 23- Mar -02 16:45 BS &W = 0% water 23- Mar -02 16:46 Small leak on Tank #2. Might be condensation, switch to Tank #3. 23- Mar -02 17:00 Switch from Tank #2 to Tank #1. 23- Mar -02 17:10 1.50 -inch orifice plate in service on Horizontal separator. 23- Mar -02 17:15 BS &W = 0.5% water w /trace of sediment 23- Mar -02 17:19 0.75 -inch orifice plate in service on horizontal separator. 23- Mar -02 17:28 1 -inch orifice plate in service on horizontal separator. 23- Mar -02 17:29 Gas gravity = 0.626 23- Mar -02 17:30 BS &W = 0% water Switch from Tank #1 to Tank #3. 23- Mar -02 17:31 Night shift on location Denis Henrion, David Reid, Livia Power 23- Mar -02 17:32 Kelvin Smith, Joseph Dixon 23- Mar -02 17:50 Flush sand to sand tank from horizontal separator - sparge horizontal separator. 23- Mar -02 18:00 BS &W = 0% water Switch from Tank #3 to Tank #1. 23- Mar -02 18:30 BS &W = 0% water Switch from Tank #1 to Tank #2. Outer annulus = 225 psi Page 1 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. :Test #1 - Clean Up Flow WELL : 1M - 17 RIG NAME : Wellhead DATE TIME OPERATIONS 23- Mar -02 18:35 Oil gravity = 47.8 API @ 60 F 23- Mar -02 18:45 CO2=1% H2S = 0 ppm BS &W = 0% water w /trace of sediment 23- Mar -02 19:00 Gas gravity = 0.632 Switch from Tank #2 to Tank #1. 23- Mar -02 19:30 BS &W = 0% water w /trace of sediment. Switch from Tank #1 to Tank #2. 23- Mar -02 19:31 Sparge horizontal separator - caused a level decrease in horizontal separator. 23- Mar -02 19:45 BS &W = 0% water w /trace of sediment. 23- Mar -02 20:00 Switch from Tank #2 to Tank #1. 23- Mar -02 20:30 BS &W = 0% water Switch from Tank #1 to Tank #2. Outer Annulus = 250 psi 23- Mar -02 20:45 BS &W = 0% water w /trace of sediment 23- Mar -02 20:47 Sparge horizontal separator. 23- Mar -02 21:00 Switch from Tank #2 to Tank #1. 23- Mar -02 21:14 Horizontal separator water LSHH alarm tripped shutting the safety valve. 23- Mar -02 21:15 Open safety valve. BS &W = 0% water and 40% sediment 23- Mar -02 21:20 Sparge horizontal separator. 23- Mar -02 21:25 BS &W = 0% water and 0.1 % sediment 23- Mar -02 21:30 Switch from Tank #1 to Tank #2. 23- Mar -02 21:35 Oil gravity = 51.5 API @ 60 F 23- Mar -02 21:45 BS &W = 0% water 23- Mar -02 22:00 BS &W W = 0% water Switch from Tank #2 to Tank #1. 23- Mar -02 22:15 BS &W = 0% water 23- Mar -02 22:17 Sparge horizontal separator. 23- Mar -02 22:20 1 -inch orifice plate out of service on the horizontal separator. 23- Mar -02 22:25 Outer annulus = 160 psi 23- Mar -02 22:30 Well shut -in at wing valve. Shut -in choke. Shut -in Tank #1. 23- Mar -02 22:31 Shut -in gas flare. 23- Mar -02 23:00 Finish injecting methanol downhole through the tree. Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606' - 10,642' WELL TEST DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BU RTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHP WHT CSG GAS OIL WATER GOR 7RESTE BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) M (%) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 23 -Mar 15:30 21 62 169 23 -Mar 15:35 21 62 161 23 -Mar 15:40 21 62 150 23 -Mar 15:45 21 62 139 23 -Mar 15:50 21 1 62 130 23 -Mar 15:55 21 62 122 23 -Mar 16:00 22 62 116 23 -Mar 16:05 22 61 103 23 -Mar 16:10 1031 62 100 BS &W = 1 % water w /trace of sediment 23 -Mar 16:15 20 1.0 969 61 1 92 Oil level in the horizontal separator sight 23 -Mar 16:20 28 1.0 818 59 91 1 1 Iqlass. 23 -Mar 16:25 28 1.0 887 59 119 BS &W = 0.25% water w /trace of 23 -Mar 16:30 28 0.3 895 58 132 1067 72 61 3.7 47.8 sediment. Switch from Tank #1 to Tank Increase back pressure to bring separator 23 -Mar 16:35 28 0.3 901 58 150 1 1067 102 58 1 7.4 47.8 1 up to +/- 150 psi. 23 -Mar 16:40 28 0.3 914 57 159 1067 1 159 62 11.1 47.8 23 -Mar 16:45 28 0.0 918 57 160 1067 244 61 14.8 47.8 BS &W = 0% water 23 -Mar 16:50 28 0.0 993 57 160 1067 304 1 64 18.5 47.8 23 -Mar 16:55 1 28 0.0 836 57 163 1067 260 57 22.2 47.8 23 -Mar 17:00 28 0.0 942 57 174 1480 1 282 56 27.4 47.8 Switch from Tank #2 to Tank #1. 23 -Mar 17:05 28 0.0 1006 57 174 1480 310 60 32.5 47.8 1.50 -inch orifice plate in service on 23 -Mar 17:10 28 1 0.0 974 1 56 1 174 1480 1 291 1 57 37.6 47.8 Horizontal separator. Page 1 i CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BURTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 23 -Mar 17:15 28 0.5 948 56 174 0.59 1480 0.4 284 56 0.00 42.8 47.8 0.626 BS &W = 0.5% water w /trace of sediment 23 -Mar 17:20 28 0.5 919 56 183 0.70 1 1480 1 0.5 275 54 0.00 47.9 47.8 0.626 23 -Mar 17:25 28 0.5 1005 56 187 0.97 1480 0.7 305 57 0.01 53.1 47.8 0.626 BS &W = 0% water Switch from Tank #1 23 -Mar 17:30 28 0.0 952 56 185 1280 1 281 54 57.5 1 47.8 to Tank #3. 23 -Mar 17:35 28 0.0 987 56 183 1.29 1280 1 1.0 299 54 0.01 62.0 47.8 1 0.626 23 -Mar 17:40 28 0.0 971 56 181 1 0.97 1280 0.8 283 54 0.02 66.4 47.8 0.626 23 -Mar 17:45 28 0.0 1000 56 189 0.94 1280 1 0.7 280 1 52 0.02 70.8 47.8 0.626 Flush sand to sand tank from horizontal 23 -Mar 17:50 28 0.0 1054 56 190 0.96 1280 0.7 276 55 0.02 75.3 1 47.8 0.626 separator - s ar a horizontal separator. 23 -Mar 17:55 28 0.0 1016 56 193 1.18 1280 0.9 300 55 0.03 79.7 47.8 0.626 BS &W = 0% water Switch from Tank #3 23 -Mar 18:00 28 0.0 1097 56 196 1.29 1040 1.2 302 55 1 0.03 83.4 47.8 1 0.626 to Tank #1. 23 -Mar 18:05 28 0.0 1071 56 195 1.26 1040 1.2 287 54 0.04 87.0 47.8 0.626 23 -Mar 18:10 28 0.0 1082 56 198 1.18 1040 1.1 293 51 0.04 90.6 47.8 0.626 23 -Mar 18:15 28 0.0 1093 56 200 1.25 1 1040 1.2 291 1 53 0.04 94.2 47.8 0.626 23 -Mar 18:20 28 0.0 1109 56 200 1.26 1040 1.2 296 51 0.05 97.8 1 47.8 0.626 23 -Mar 18:25 28 0.0 1155 56 200 1.43 1040 1.4 293 51 0.05 101.4 47.8 0.626 BS &W = 0% water Switch from Tank #1 23 -Mar 18:30 28 0.0 1116 55 204 1.28 1480 0.9 293 50 0.06 106.5 47.8 0.626 to Tank #2. Outer annulus = 225 psi' 23 -Mar 18:35 28 0.0 1075 55 210 1.20 1480 0.8 284 1 51 1 0.06 111.7 47.8 0.626 Oil gravity = 47.8 API @ 60 F 23 -Mar 18:40 28 0.0 1132 55 213 1.30 1 1480 0.9 292 50 0.07 1 116.8 1 47.8 0.626 CO2=1% H2S = 0 ppm BS &W = 23 -Mar 18:45 28 0.0 1127 55 210 1.26 1480 0.8 287 51 0.07 122.0 47.8 0.626 0% water w /trace of sediment 23 -Mar 18:50 28 0.0 1152 55 208 1.42 1480 1.0 298 51 0.08 127.1 47.8 0.626 23 -Mar 18:55 28 0.0 1 1140 1 55 205 1.32 1480 0.9 1 291 1 49 1 1 0.08 132.2 1 47.8 0.626 Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BU RTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP. Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZTBS&W WHIP WHT CSG GAS OIL WATER GOR T . BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64th (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (%) ( %) (MMscf) (bbls) (bbls) (API @60 0 0 (Air =1) Gas gravity = 0.632 Switch from Tank 23 -Mar 19:00 28 0.0 1146 55 206 1.42 1400 1.0 299 51 0.09 137.1 47.8 0.626 #2 to Tank #1. 23 -Mar 19:05 28 0.0 1155 55 206 1.38 1400 1.0 289 50 0.09 142.0 47.8 0.626 23 -Mar 19:10 28 0.0 1115 55 208 1.31 1400 0.9 283 50 0.09 146.8 47.8 0.626 23 -Mar 19:15 28 0.0 1154 55 209 1.32 1 1400 0.9 301 1 49 0.10 151.7 47.8 0.626 23 -Mar 19:20 28 0.0 1163 55 208 1.43 1400 1.0 313 51 0.10 156.6 47.8 0.626 23 -Mar 19:25 28 0.0 1158 55 200 1.44 1400 1.0 313 50 0.11 161.4 47.8 0.626 BS &W = 0% water w /trace of sediment. 23 -Mar 19:30 28 0.0 1149 55 197 1.44 1320 1.1 304 50 0.11 166.0 47.8 0.626 1 Switch from Tank #1 to Tank #2. 23 -Mar 19:35 28 0.0 1 1142 1 55 195 1 1.47 1320 1.1 287 50 0.12 170.6 47.8 0.626 23 -Mar 19:40 28 0.0 1140 55 194 1.43 1 1320 1.1 295 49 0.12 175.2 47.8 0.632 23 -Mar 19:45 28 0.0 1135 55 192 1.44 1320 1 1.1 301 BS &W = 0% water w /trace of sediment. 49 0.13 179.8 47.8 0.632 l 23 -Mar 19:50 28 0.0 1125 55 190 1.44 1320 1.1 302 49 0.13 184.3 47.8 0.632 23 -Mar 19:55 28 0.0 1120 55 188 1.44 1320 1 1.1 304 49 0.14 188.9 47.8 0.632 23 -Mar 20:00 28 0.0 1123 55 185 1.45 1120 1.3 305 49 0.14 192.8 47.8 0.632 Switch from Tank #2 to Tank #1. 23 -Mar 20:05 28 0.0 1103 55 181 1.45 1120 1.3 308 1 49 0.15 196.7 47.8 0.632 23 -Mar 20:10 28 0.0 1092 55 179 1.44 1120 1.3 308 48 0.15 200.6 47.8 0.632 23 -Mar 20:15 28 0.0 1078 1 55 175 1.43 1120 1 1 1.3 309 49 0.16 204.5 47.8 0.632 23 -Mar 20:20 28 0.0 1071 56 170 1.43 1120 1.3 311 49 0.16 208.4 47.8 0.632 23 -Mar 20:25 28 0.0 1061 56 164 1.43 1120 1.3 310 1 48 0.17 212.3 47.8 0.632 BS &W = 0% water Switch from Tank #1 23 -Mar 20:30 28 0.0 1067 57 160 1.43 1200 1.2 311 48 1 0.17 216.4 47.8 0.632 Ito Tank #2. Outer Annulus = 250 psi' 23 -Mar 20:35 28 0.0 1043 57 1 155 1.42 1 1200 1.2 309 48 0.18 220.6 47.8 0.632 23 -Mar 20:40 28 0.0 1022 58 149 1 1.41 1 1200 1.2 307 48 0.18 224.8 1 1 47.8 0.632 Page 3 i CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BU RTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney � BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) (%) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) (%) ( %) (MMscf (bbls) (bbls) (API @60 °f) (Air =1) 23 -Mar 20:45 28 0.0 1001 58 143 1.36 1200 1.1 295 48 0.19 228.9 47.8 0.632 BS &W = 0% water w /trace of sediment 23 -Mar 20:50 28 0.0 988 58 138 1.42 1200 1.2 304 46 0.19 233.1 47.8 0.632 23 -Mar 20:55 28 0.0 970 59 132 1.38 1200 1.2 300 48 0.20 237.3 47.8 0.632 23 -Mar 21:00 28 0.0 948 59 123 1.36 1280 1.1 292 1 47 0.20 241.7 47.8 0.632 Switch from Tank #2 to Tank #1. 23 -Mar 21:05 28 0.0 921 59 117 1.34 1280 1.0 286 47 0.21 246.2 47.8 0.632 23 -Mar 21:10 28 0.0 877 59 111 0.94 1280 0.7 219 47 0.21 250.6 47.8 0.632 Open safety valve. BS &W = 0% water 23 -Mar 21:15 28 40.0 1454 1 59 132 1 1.74 1280 1.4 342 44 0.22 255.1 47.8 0.632 and 40% sediment 23 -Mar 21:20 28 40.0 1377 58 130 1.80 1280 1.4 325 47 0.22 259.5 47.8 0.632 Sparge horizontal separator. 23 -Mar 21:25 28 0.1 1354 58 138 2.00 1280 1 1.6 369 48 0.23 263.9 47.8 0.632 BS &W = 0% water and 0.1 % sediment 23 -Mar 21:30 28 0.0 1339 57 148 1.92 1000 1.9 355 46 0.24 267.4 47.8 1 0.632 Switch from Tank #1 to Tank #2. 23 -Mar 21:35 28 1 0.0 1329 57 156 1.91 1000 1 1.9 354 45 0.24 270.9 47.8 0.632 Oil gravity = 51.5 API @ 60 F 23 -Mar 21:40 28 1 0.0 1342 57 162 1.99 1000 2.0 372 45 0.25 274.4 51.5 0.632 23 -Mar 21:45 28 0.0 1290 56 170 1.88 1000 1.9 362 1 46 0.26 277.8 1 51.5 0.632 1 BS &W = 0% water 23 -Mar 21:50 28 0.0 1308 1 57 178 1 1.83 1000 1.8 350 44 0.26 281.3 51.5 0.632 23 -Mar 21:55 28 0.0 1301 57 182 1.81 1 1000 1 1.8 346 45 0.27 284.8 51.5 0.632 BS &W W = 0% water Switch from Tank 23 -Mar 22 :00 28 0.0 1320 57 188 1.84 1000 1.8 351 44 0.28 288.3 51.5 0.632 #2 to Tank #1. 23 -Mar 22:05 28 0.0 1317 56 191 1.83 1000 1.8 351 1 44 1 0.28 291.7 1 51.5 0.632 23 -Mar 22:10 28 0.0 1318 56 195 1.83 1000 1.8 350 45 0.29 295.2 51.5 0.632 23 -Mar 22:15 28 0.0 1323 56 199 1.72 1 1000 1 1.7 330 45 0.29 298.7 51.5 0.632 BS &W = 0% water 1 -inch orifice plate out of service on the 23 -Mar 22:20 28 0.0 1321 56 201 0.71 1000 0.7 355 42 1 0.30 1 302.1 51.5 0.632 horizontal separator. 23 -Mar 22:25 28 0.0 1327 56 203 0.00 1000 0.0 359 47 0.30 305.6 51.5 0.632 Outer annulus = 160 psi Page 4 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BURTO N DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHP WHT CSG 7AS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64th s) ( %) (psig) ( °F) (psig) (bpd) (bpd) (mscf /bbl) (psig) ( °F) (%) ( %) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) Well shut -in at wing valve. Shut -in choke. 23 -Mar 22:30 1329 56 210 Shut -in Tank #1. 23 -Mar 22:35 236 55 220 23 -Mar 22:40 203 55 191 23 -Mar 22:45 204 55 146 23 -Mar 22:50 205 55 75 23 -Mar 22:55 206 55 0 Finish injecting methanol downhole 23 -Mar 23:00 204 55 0 through the tree. 23 -Mar 23:15 205 54 0 23 -Mar 23:30 205 1 54 1 0 23 -Mar 23:45 206 53 0 24 -Mar 00:00 199 53 0 24 -Mar 00:15 203 54 0 24 -Mar 00:30 207 55 0 24 -Mar 00:45 208 56 0 24 -Mar 01:00 209 55 0 24 -Mar 01:15 1 206 55 0 24 -Mar 01:30 206 54 0 24 -Mar 01:45 203 1 54 0 24 -Mar 02:00 205 53 0 24 -Mar 02:15 206 53 0 24 -Mar 02:30 209 53 0 Page 5 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLIBURTON DATE: 23- Mar - 0215:30 to 24-Mar-02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZTBS&W WHIP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64th (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbis) (API @60 °f) (Air =1) 24 -Mar 02:45 207 53 0 24 -Mar 03:00 211 1 53 1 0 24 -Mar 03:15 208 52 0 24 -Mar 03:30 208 52 0 24 -Mar 03:45 208 52 0 24 -Mar 04:00 207 51 0 24 -Mar 04:15 1 209 51 0 24 -Mar 04:30 207 51 0 24 -Mar 04:45 202 51 1 0 24 -Mar 05:00 203 52 0 24 -Mar 05:15 1 1 206 53 0 24 -Mar 05:30 208 53 0 I II I Page 6 1 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow I PHILLIPS HALLIBURTON DATE: 23- Mar - 0215:30 to 24-Mar-02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= C' *24 *SQRT(PPHw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf * Hw) (mmscf /d) 23 -Mar 17:00 28 297 0 56 0.000 0.2 0.000 1.0000 1.0000 1.1950 1.0037 0.0000 1.0000 1.0320 0.00 0.000 Switch from Tank #2 to Tank #1. 23 -Mar 17:05 28 324 0 60 0.000 0.0 0.000 1.0000 1.0000 1.1950 1.0002 0.0000 1.0000 1.0340 0.00 0.000 1.50 -inch orifice plate in service on 23 -Mar 17:10 28 306 1 57 0.000 1.3 0.000 1.0000 1.0000 1.1950 1.0025 0.0000 1.0000 1.0320 0.00 0.000 Horizontal separator. 23 -Mar 17:15 28 299 6 56 1.500 6.4 455.030 1.0000 1.0000 1.1950 1.0040 1.0009 1.0001 1.0320 563.99 0.589 BS &W = 0.5% water w /trace of sediment 23 -Mar 17:20 28 289 150 54 0.750 149.7 112.748 1.0000 1.0000 1.1950 1.0060 1.0004 1.0035 1.0310 140.32 0.701 23 -Mar 17:25 28 320 1 258 57 1 0.750 258.3 112.748 1.0000 1.0000 1.1950 1.0025 1.0003 1.0054 1.03401 140.48 0.969 BS &W = 0% water Switch from Tank 23 -Mar 17:30 28 296 61 54 0.000 60.9 0.000 1.0000 1.0000 1.2640 1.0062 0.0000 1.0014 1.0270 0.00 0.000 #1 to Tank #3. 23 -Mar 17:35 28 314 133 54 1.000 133.3 200.955 1.0000 1.0000 1.2640 1.0057 1.0003 1.0028 1.0290 263.60 1.295 23 -Mar 17:40 28 297 80 54 1.000 80.1 200.955 1.0000 1.0000 1.2640 1.0054 1.0004 1.0018 1.0270 262.80 0.973 23 -Mar 17:45 28 295 76 52 1.000 75.7 200.955 1.0000 1.0000 1.2640 1.0077 1.0004 1.0017 1.0270 263.44 0.944 Flush sand to sand tank from horizontal 23 -Mar 17:50 28 291 79 55 1.000 79.3 200.955 1.0000 1.0000 1.2640 1.0046 1.0004 1.0018 1.0260 262.41 0.956 separator - s are horizontal separator. 23 -Mar 17:55 28 315 111 55 1.000 1 111.4 200.955 11.0000 1.0000 1.2640 1.0046 1.0003 1.0024 1.0290 263.14 1 1.183 BS &W = 0% water Switch from Tank 23 -Mar 18:00 28 317 131 55 1.000 131.3 200.955 1.0000 1.0000 1.2640 1.0049 1.0003 1.0028 1.0290 263.39 1.290 #3 to Tank #1. 23 -Mar 18:05 28 302 132 54 1.000 132.5 200.955 1.0000 1.0000 1.2640 1.0059 1.0003 1.0029 1.0270 263.36 1.263 23 -Mar 18:10 28 308 113 51 1.000 112.7 200.955 1.0000 1.0000 1.2640 1.0086 1.0003 1.0024 1.0290 264.24 1.181 23 -Mar 18:15 28 305 128 53 1.000 128.1 200.955 1.0000 1.0000 1.2640 1.0067 1.0003 1.0028 1.0280 263.67 1 1.251 23 -Mar 18:20 28 311 128 51 1.000 127.7 200.955 11.0000 1.0000 1.2640 1.0086 1.0003 1.0027 1.0290 264.39 1.264 23 -Mar 18:25 28 307 164 51 1.000 164.4 200.955 1.0000 1.0000 1.2640 1.0084 1.0003 1.0036 1.0290 264.46 1.427 BS &W = 0% water Switch from Tank 23 -Mar 18:30 28 308 132 1 50 1.000 131.6 200.955 1.0000 1.0000 1.2640 1.0101 1.0003 1.0029 1.0290 264.82 1.279 #1 to Tank #2. Outer annulus = 225 psi 23 -Mar 18:35 28 298 121 51 1.000 120.7 200.955 1.000011.000011 2640 1.0083 1.000311.002711.02801 263.96 1.203 Oil gravity = 47.8 API @ 60 F 23 -Mar 18:40 28 307 136 50 1.000 135.9 1 200.955 1 1.0000 1.0000 1.2640 1.0095 1.0003 1.0030 1.0290 264.61 1 1.297 Pagel CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M - 17 TEST No. : Test #1 - Clean Up Flow PHILLIPS HALLI BURTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= C' *24 *SQRT(Pf *Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) (°f) (inch) (Pf * Hw) (mmscf /d) CO2=1% H2S = 0 ppm BS &W = 23 -Mar 18:45 28 302 130 51 1.000 198.2 200.955 1.0000 1.0000 1.2640 1.0086 1.0003 1.0029 1.0280 264.20 1 1.257 0% water w /trace of sediment 23 -Mar 18:50 28 313 159 51 1.000 159.1 200.955 1.0000 1.0000 1.2640 1.0083 1.0003 1.0034 1.0290 264.50 1.415 23 -Mar 18:55 28 306 142 49 1.000 142.0 200.955 1.0000 1.0000 1.2640 1.0109 1.0003 1.0031 1.0290 265.06 1.325 Gas gravity = 0.632 Switch from Tank 23 -Mar 19:00 28 314 159 51 1.000 158.6 200.955 1.0000 1.0000 1.2640 1.0089 1.0003 1.0034 1.0290 264.71 1.417 #2 to Tank #1. 23 -Mar 19:05 28 303 1 156 49 1 1.000 156.0 1 200.955 1.0000 1.0000 1.2640 1.0108 1.0003 1.0034 1.0290 265.06 1.384 23 -Mar 19:10 28 297 144 50 1.000 143.6 200.955 1.0000 1.0000 1.2640 1.0096 1.0003 1.0032 1.0280 264.47 1.312 23 -Mar 19:15 28 316 136 49 1.000 136.0 200.955 1.0000 1.0000 1.2640 1.0105 1.0003 1.0029 1.0300 265.15 1.319 23 -Mar 19:20 28 328 153 51 1.000 153.2 200.955 1.0000 1.0000 1.2640 1.0087 1.0003 1.0031 1.0310 264.98 1.426 23 -Mar 19:25 28 328 156 50 1.000 156.3 200.955 1.0000 1.0000 1.2640 1.0093 1.0003 1.0032 1.0310 265.18 1.441 BS &W = 0% water w /trace of sediment. 23 -Mar 19:30 28 318 162 50 1.000 161.9 200.955 1.0000 1.0000 1.2640 1.0099 1.0003 1.0034 1.0300 265.16 1.445 Switch from Tank #1 to Tank #2. 23 -Mar 19:35 28 302 177 50 1.000 177.0 200.955 1.0000 1.0000 1.2640 1.0098 1.0003 1.0039 1.0280 264.84 1.470 23 -Mar 19:40 28 310 163 49 1.000 163.5 200.955 1.0000 1.0000 1.2580 1.0110 1.0003 1.0035 1.0300 264.16 1.427 23 -Mar 19:45 28 316 163 49 1.000 163.1 200.955 1.0000 1.0000 1.2580 1.0103 1.0003 1.0034 1.0300 264.08 1.439 BS &W = 0% water w /trace of sediment. I 23 -Mar 19:50 28 317 162 49 1.000 162.2 200.955 1.0000 1.0000 1.2580 1.0105 1.0003 1.0034 1.0300 264.18 1.438 23 -Mar 19:55 28 318 1 162 49 1.000 162.0 200.955 1.0000 1.0000 1.2580 1.0108 1.0003 1.0034 1.0310 264.29 1.440 23 -Mar 20:00 28 320 162 49 1.000 162.1 200.955 1.0000 1.0000 1.2580 1.0111 1.0003 1.0034 1.0310 264.44 1.445 Switch from Tank #2 to Tank #1. 23 -Mar 20:05 28 323 161 49 1.000 161.1 200.955 1.0000 1.0000 1.2580 1.0111 1.0003 1.0033 1.0310 264.49 1.447 23 -Mar 20:10 28 1 323 159 48 1.000 159.2 200.955 1.0000 1.0000 1.2580 1.0113 1.0003 1.0033 1.0310 264.57 1.440 23 -Mar 20:15 28 324 158 49 1.000 157.5 200.955 1.0000 1.0000 1.2580 1.0112 1.0003 1.0032 1.0310 264.54 1.433 23 -Mar 20:20 28 325 157 49 1.000 156.9 200.955 1.0000 1.0000 1.2580 1.0111 1.0003 1.0032 1.0310 264.55 1.434 23 -Mar 20:25 28 324 156 48 1 1.000 155.9 1 200.955 11.0000 1.0000 1.2580 1.011311.0003 1 1.428 Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BURTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q =C" 24'sQRT(Pf"Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf' Hw) (mmscf /d) BS &W = 0% water Switch from Tank 23 -Mar 20:30 28 326 156 48 1.000 225.2 200.955 1.0000 1.0000 1.2580 1.0116 1.0003 1.0032 1.0320 264.70 1.431 #1 to Tank #2. Outer Annulus = 250 psi 23 -Mar 20:35 28 324 155 48 1.000 154.6 200.955 1.0000 1.0000 1.2580 1.0117 1.0003 1.0032 1.0310 264.68 1.422 23 -Mar 20:40 28 322 154 48 1.000 153.8 200.955 1.0000 1.0000 1.2580 1.0117 1.0003 1.0032 1.0310 264.63 1.413 23 -Mar 20:45 28 309 148 48 1.000 148.5 200.955 1.0000 1.0000 1.2580 1.0120 1.0003 1.0032 1.0300 264.39 1.360 BS &W = 0% water w /trace of sediment 23 -Mar 20:50 28 319 1 155 1 46 1.000 1 155.1 200.955 1.0000 1.0000 1.2580 1.0138 1.0003 1.0032 1.03101 265.22 1.415 23 -Mar 20:55 28 315 151 48 1.000 150.9 200.955 1.0000 1.0000 1.2580 1.0119 1.0003 1.0032 1.0300 264.48 1.383 23 -Mar 21:00 28 307 150 47 1.000 149.6 200.955 1.0000 1.0000 1.2580 1.0125 1.0003 1.0033 1.0300 264.50 1.361 Switch from Tank #2 to Tank #1. 23 -Mar 21:05 28 301 148 47 1.000 148.2 200.955 11.0000 1.0000 1.2580 1.0129 1.0003 1.0033 1.0290 264.46 1 1.341 23 -Mar 21:10 28 234 96 1 47 1.000 1 95.6 200.955 1.0000 1.0000 1.2580 1.0132 1.0004 1.0027 1.0220 262.61 0.943 Open safety valve. BS &W = 0% water 23 -Mar 21:15 28 357 206 44 1.000 205.7 200.955 1.0000 1.0000 1.2580 1.0159 1.0002 1.0039 1.0360 267.11 1.736 and 40% sediment 23 -Mar 21:20 28 340 233 47 1.000 233.3 200.955 1.0000 1.0000 1.2580 1.0131 1.0002 1.0046 1.0330 265.94 1.797 S ar a horizontal separator. 23 -Mar 21:25 28 384 254 48 1.000 254.0 200.955 11.0000 1.0000 1.2580 1.0114 1.0002 1.0044 1.0380 266.56 1 1.998 BS &W = 0% water and 0.1% sediment 23 -Mar 21:30 1 28 370 1 243 46 1 1.000 242.6 200.955 1.0000 1.0000 1.2580 1.0140 1.0002 1.0044 1.0370 267.02 1.920 Switch from Tank #1 to Tank #2. 23 -Mar 21:35 28 368 241 45 1.000 240.6 200.955 1.0000 1.0000 1.2580 1.0147 1.0002 1.0044 1.0370 267.20 1.909 Oil gravity = 51.5 API @ 60 F 23 -Mar 21:40 28 387 249 45 1.000 248.6 200.955 1.0000 1.0000 1.2580 1.0146 1.0002 1.0043 1.0390 267.68 1.993 23 -Mar 21:45 28 377 229 46 1.000 229.0 200.955 1.0000 1.0000 1.2580 1.0138 1.0002 1.0041 1.0380 267.06 1.882 13S &W = 0% water 23 -Mar 21:50 28 365 222 44 1.000 222.1 200.955 1.0000 1.0000 1.2580 1.0161 1.0002 1.0041 1.0370 267.48 1.828 23 -Mar 21:55 28 361 220 45 1.000 219.9 200.955 1.0000 1.0000 1.2580 1.0150 1.0002 1.0041 1.0360 267.02 1.806 BS &W W = 0% water Switch from Tank 23 -Mar 22:00 28 366 225 44 1.000 225.5 200.955 1.0000 1.0000 1.2580 1.0154 1.0002 1.0041 1.03701 267.31 1.843 #2 to Tank #1. 23 -Mar 22:05 28 365 224 44 1.000 224.0 200.955 1.0000 1.0000 1.2580 1.0153 1.0002 1.0041 1.0370 267.24 1.835 23 -Mar 22:10 28 365 223 45 1.000 223.1 1 200.955 11.0000 11. 0000 11.2580 1.0041 1.0370 267.14 1.828 Page 3 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLIBURT ©N DATE: 23- Mar - 0215:30 to 24-Mar-02 05:30 CUSTOMER REP. : Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= c' *24`SQRT(PfHw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf' Hw) (mmscf /d) 23 -Mar 22:15 28 345 210 45 1.000 269.2 200.955 1.0000 1.0000 1.2580 1.0149 1.0002 1.0041 1.0340 266.52 1.722 13S &W = 0% water 1 -inch orifice plate out of service on the 23 -Mar 22:20 28 370 33 42 1.000 32.8 200.955 1.0000 1.0000 1.2580 1.0173 1.0005 1.0006 1.0380 267.19 0.706 horizontal separator. 23 -Mar 22:25 28 1 373 0 47 0.000 0.1 0.000 1.0000 1.0000 1.2580 1.0127 0.0000 1.0000 1.0370 0.00 0.000 Outer annulus = 160 psi Well shut -in at wing valve. Shut -in choke. 23 -Mar 22:30 0 290 0 45 0.000 0.1 0.000 1.0000 1.0000 1.2580 1.0145 0.0000 1.0000 1.0280 0.00 0.000 Shut -in Tank #1. Page 4 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow I PHILLIPS HALLI BU RTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL FLOW INJ OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) (1) (bbls) (bbls) (bbls) (bbls) (@ 601) ( % ) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 23 -Mar 16:15 20 54.1 0.00 1.000 0.0 1.000 0.00 0.0 1.003 1.000 47.8 1.0 0.000 1 0.0 0.00 0.0 BS &W = 1 % water w /trace of sediment Oil level in the horizontal separator sight 23 -Mar 16:20 28 54.0 0.00 1.000 0.0 1.000 0.00 0.0 1.003 1.000 47.8 1.0 0.000 0.0 0.00 0.0 glass. 23 -Mar 16:25 28 58.2 0.00 1.000 3.0 1.000 0.00 0.0 1.001 1.000 47.8 1.0 3.024 871.0 0.00 0.0 BS &W = 0.25% water w /trace of 23 -Mar 16:30 1 28 56.5 1 0.00 1.000 1 7.8 1.000 13.34 0.0 1 1.002 1.000 47.8 0.3 4.779 1376.4 0.00 0.0 sediment. Switch from Tank #1 to Tank Increase back pressure to bring 23 -Mar 16:35 28 53.8 0.00 1.000 13.0 1.000 18.48 0.0 1.003 1.000 47.8 0.3 5.188 1494.2 0.00 0.0 separator up to +/- 150 psi. 23 -Mar 16:40 28 52.1 0.00 1.000 18.5 1.000 23.62 0.0 1.003 1.000 47.8 0.3 5.507 1585.9 0.00 0.0 23 -Mar 16:45 28 51.8 0.00 1.000 23.7 1.000 28.76 0.0 1.004 1.000 47.8 0.3 5.261 1515.31 0.00 0.0 1 BS &W = 0% water 23 -Mar 16:50 1 28 51.8 0.00 1.000 29.4 1.000 33.90 0.0 1.004 1.000 47.8 0.3 5.692 1639.3 0.00 0.0 23 -Mar 16:55 28 52.5 0.00 1.000 33.1 1.000 39.04 0.0 1.003 1.000 47.8 0.3 3.759 1082.7 0.00 0.0 23 -Mar 17:00 28 50.4 0.00 1.000 38.7 1.000 44.18 0.0 1.004 1.000 47.8 0.3 5.614 1617.0 0.00 0.0 Switch from Tank #2 to Tank #1. 23 -Mar 17:05 28 53.2 0.00 1.000 45.9 1.000 48.63 0.0 1.003 1.000 47.8 0.3 1 7.245 2086.61 0.00 0.0 1.50 -inch orifice plate in service on 23 -Mar 17:10 28 52.6 0.00 1.000 51.6 1.000 53.07 0.0 1.003 1.000 47.8 0.3 5.696 1640.3 0.00 0.0 Horizontal separator. 23 -Mar 17:15 28 51.1 0.00 1.000 56.9 1.000 57.52 0.0 1.004 1.000 47.8 0.5 5.306 1528.2 0.00 0.0 BS &W = 0.5% water w /trace of sediment 23 -Mar 17:20 28 51.2 0.00 1.000 1 61.5 1.000 1 61.96 0.0 1 1.004 1.000 47.8 0.5 4.596 1323.5 0.00 0.0 23 -Mar 17:25 28 52.9 0.00 1.000 68.1 1.000 66.41 0.0 1.003 1.000 47.8 0.5 6.660 1918.21 0.00 0.0 BS &W = 0% water Switch from Tank 23 -Mar 17:30 28 52.0 0.00 1.000 73.4 1.000 70.85 0.0 1.004 1.000 47.8 0.5 5.303 1527.3 0.00 0.0 #1 to Tank #3. 23 -Mar 17:35 28 51.4 0.00 1 1.000 78.7 1 1.000 74.45 1 0.0 1.004 1 1.000 47.8 1 0.0 5.351 1541.1 0.00 0.0 23 -Mar 17:40 28 51.7 0.00 1.000 83.4 1.000 78.07 0.0 1.004 1.000 47.8 0.0 4.649 1338.8 0.00 0.0 23 -Mar 17:45 28 50.5 0.00 1.000 88.9 1.000 81.69 0.0 1.004 1.000 47.8 0.0 5.521 1590.2 0.00 0.0 Flush sand to sand tank from horizontal 23 -Mar 17:50 28 52.4 0.00 1.000 95.4 1.000 85.30 0.0 1.003 1.000 47.8 0.0 6.606 1902.4 0.00 0.0 1 separator - s ar a horizontal separator: Page 1 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLI BURTON DATE : 23- Mar -02 15:30 to 24- Mar -02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL FLOW INJ OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °t) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 23 -Mar 17:55 28 52.1 0.00 1.000 96.1 1.000 88.91 0.0 1.004 1.000 47.8 0.0 0.639 183.9 0.00 0.0 BS &W = 0% water Switch from Tank 23 -Mar 18:00 28 52.1 0.00 1.000 96.1 1.000 92.52 0.0 1.004 1.000 47.8 0.0 0.017 5.0 0.00 0.0 #3 to Tank #1. 23 -Mar 18:05 28 51.3 0.00 1.000 101.1 1.000 97.66 0.0 1.004 1.000 47.8 0.0 5.071 1460.4 0.00 0.0 23 -Mar 18:10 28 49.9 1 0.00 1 1.000 106.7 1.000 102.80 0.0 1.004 1.000 47.8 0.0 5.591 1610.2 0.00 0.0 23 -Mar 18:15 28 50.6 0.00 1.000 112.7 1.000 107.941 0.0 1.004 1.000 47.8 0.0 5.971 11719.71 0.00 0.0 23 -Mar 18:20 28 50.3 0.00 1.000 118.0 1.000 113.08 0.0 1.004 1.000 47.8 0.0 5.373 1547.5 0.00 0.0 23 -Mar 18:25 28 50.5 0.00 1.000 123.6 1 1.000 118.22 0.0 1.004 1 1.000 47.8 1 0.0 5.653 1628.0 0.00 0.0 BS &W = 0% water Switch from Tank 23 -Mar 18:30 28 50.0 0.00 1.000 128.8 1.000 123.36 0.0 1.004 1.000 47.8 0.0 5.206 1499.4 0.00 0.0 1 #1 to Tank #2. Outer annulus = 225 23 -Mar 18:35 28 49.4 0.00 1.000 134.1 1.000 128.22 0.0 1.005 1.000 47.8 0.0 5.290 11523.5 0.00 0.0 Oil gravity = 47.8 API @ 60 F 23 -Mar 18:40 28 49.5 0.00 1.000 139.6 1.000 133.081 0.0 1.005 1.000 47.8 0.0 5.506 1585.6 0.00 0.0 CO2=1% H2S = 0 ppm BS &W = 23 -Mar 18:45 28 50.1 0.00 1.000 145.1 1 1.000 137.95 0.0 1.005 1 1.000 47.8 0.0 5.534 1593.9 0.00 0.0 0% water w /trace of sediment 23 -Mar 18:50 28 49.5 1 0.00 1.000 150.6 1 1.000 142.81 0.0 1.005 1.000 47.8 0.0 5.587 1609.1 0.00 0.0 23 -Mar 18:55 28 49.5 0.00 1.000 155.7 1.000 147.67 0.0 1.005 1.000 47.8 0.0 5.134 11478.5 0.00 0.0 Gas gravity = 0.632 Switch from 23 -Mar 19:00 28 48.9 0.00 1.000 161.3 1.000 152.531 0.0 1.006 1.000 47.8 0.0 5.604 1614.1 0.00 0.0 Tank #2 to Tank #1. 23 -Mar 19:05 1 28 48.4 0.00 1.000 1 166.5 1.000 157.12 0.0 1 1.006 1.000 1 47.8 0.0 5.233 1507.11 0.00 0.0 23 -Mar 19:10 28 48.6 0.00 1.000 171.8 1 1.000 161.70 0.0 1.006 1.000 47.8 0.0 5.367 1545.8 0.00 0.0 23 -Mar 19:15 28 48.4 0.00 1.000 177.3 1 1.000 166.29 0.0 1.006 1.000 47.8 0.0 5.499 1583.6 0.00 0.0 23 -Mar 19:20 28 49.0 0.00 1.000 182.6 1.000 1170.87 0.0 1.006 1.000 47.8 1 0.0 5.365 11545.2 0.00 0.0 23 -Mar 19:25 28 48.6 0.00 1.000 187.6 1.000 175.46 0.0 1.006 1.000 47.8 0.0 5.011 1443.0 0.00 0.0 BS &W = 0% water w /trace of sediment. 23 -Mar 19:30 28 47.6 0.00 1.000 192.6 1.000 180.04 0.0 1.006 1.000 47.8 0.0 5.006 1441.8 0.00 0.0 Switch from Tank #1 to Tank #2. Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLIBURTON DATE: 23- Mar - 0215:30 to 24-Mar-02 05:30 CUSTOMER REP.: Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL FLOW [NJ OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) (10 (bbls) (bbls) (bbls) (bbls) (@ 60 *0 N (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 23 -Mar 19:35 28 47.5 0.00 1.000 193.7 1.000 183.93 0.0 1.007 1.000 47.8 0.0 1.101 317.0 0.00 0.0 23 -Mar 19:40 28 46.7 0.00 1.000 198.7 1.000 187.82 0.0 1.007 1.000 47.8 0.0 5.005 1441.5 0.00 0.0 23 -Mar 19:45 28 46.7 0.00 1.000 203.5 1.000 191.71 0.0 1.007 1.000 47.8 0.0 4.913 1414.9 0.00 0.0 BS &W = 0% water w /trace of sediment. 23 -Mar 19:50 28 46.5 0.00 1.000 208.4 1.000 195.60 0.0 1.007 1 1.000 47.8 0.0 4.867 1401.7 0.00 0.0 23 -Mar 19:55 28 46.3 0.00 1.000 213.2 1.000 199.49 0.0 1.007 1.000 1 47.8 0.0 4.890 1408.2 0.00 0.0 23 -Mar 20:00 28 46.2 0.00 1.000 218.0 1.000 206.38 0.0 1.007 1.000 47.8 0.0 4.800 1382.4 0.00 0.0 Switch from Tank #2 to Tank #1. 23 -Mar 20:05 28 46.1 0.00 1.000 222.6 1 1.000 207.55 0.0 1.007 1.000 47.8 0.0 1 4.629 1333.1 0.00 0.0 23 -Mar 20:10 28 46.1 0.00 1.000 227.2 1 1.000 211.72 0.0 1 1.007 1.000 47.8 0.0 4.647 1338.5 0.00 0.0 23 -Mar 20:15 28 46.1 0.00 1.000 231.7 1.000 215.89 0.0 1.007 1.000 47.8 0.0 4.537 1306.5 0.00 0.0 23 -Mar 20:20 28 46.2 0.00 1.000 236.1 1.000 220.05 0.0 1.007 1.000 47.8 1 0.0 4.424 11274.1 0.00 0.0 23 -Mar 20:25 28 46.3 0.00 1.000 240.5 1.000 224.22 0.0 1.007 1.000 47.8 0.0 4.469 1287.1 0.00 0.0 BS &W = 0% water Switch from Tank 23 -Mar 20:30 28 46.3 0.00 1.000 244.8 1 1.000 228.391 0.0 1.007 1.000 47.8 0.0 4.325 1245.5 0.00 0.0 #1 to Tank #2. Outer Annulus = 250 psi 23 -Mar 20:35 28 46.4 0.00 1.000 249.1 1.000 232.84 0.0 1.007 1.000 47.8 0.0 4.337 11249.0 0.00 0.0 23 -Mar 20:40 28 46.3 0.00 1.000 253.4 1.000 237.28 0.0 1,007 1 1.000 47.8 0.0 4.296 1237.31 0.00 0.0 23 -Mar 20:45 28 46.3 0.00 1.000 257.6 1.000 241.73 0.0 1.007 1.000 47.8 0.0 4.174 1202.0 0.00 0.0 BS &W = 0% water w /trace of sediment 23 -Mar 20:50 28 45.9 0.00 1.000 260.3 1 1.000 245.171 0.0 1.007 1.000 47.8 0.0 2.807 808.3 0.00 0.0 23 -Mar 20:55 28 45.7 0.00 1.000 261.8 1.000 250.62 0.0 1.007 1.000 47.8 1 0.0 1.456 1 419.4 0.00 0.0 23 -Mar 21:00 28 45.6 0.00 1.000 265.6 1.000 255.06 0.0 1.008 1 1.000 47.8 0.0 3.849 1108.5 0.00 0.0 Switch from Tank #2 to Tank #1. 23 -Mar 21:05 28 45.3 0.00 1.000 269.3 1.000 258.53 0.0 1.008 1.000 47.8 0.0 3.747 1079.1 0.00 0.0 23 -Mar 21:10 28 1 45.0 1 0.00 1.000 1 273.0 1 1.000 1262.011 0.0 1.008 1.000 47.8 0.0 3.668 1056.4 0.00 0.0 Page 3 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Clean Up Flow PHILLIPS HALLIBURTON DATE: 23- Mar - 0215:30 to 24-Mar-02 05:30 CUSTOMER REP. Mark Cheney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL FLOW INJ OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) Open safety valve. BS &W = 0% water 23 -Mar 21:15 28 43.0 0.00 1.000 277.8 1.000 265.48 0.0 1.009 1.000 47.8 40.0 4.880 1405.5 0.00 0.0 and 40% sediment 23 -Mar 21:20 28 44.2 0.00 1.000 285.4 1.000 268.95 0.0 1.008 1.000 47.8 40.0 7.646 2202.0 0.00 0.0 S ar a horizontal separator. 23 -Mar 21:25 28 44.6 0.00 1.000 285.7 1.000 272.43 0.0 1.008 1.000 47.8 0.1 0.316 91.0 0.00 0.0 BS &W = 0% water and 0.1 % sediment 23 -Mar 21:30 28 44.6 0.00 1.000 289.1 1.000 275.90 0.0 1.008 1.000 47.8 0.0 3.395 977.8 0.00 0.0 Switch from Tank #1 to Tank #2. 23 -Mar 21:35 28 45.3 0.00 1 1.000 294.4 1 1.000 279.371 0.0 1.008 1 1.000 47.8 1 0.0 5.387 11551.3 0.00 0.0 Oil gravity = 51.5 API @ 60 F 23 -Mar 21:40 28 45.8 0.00 1.000 299.7 1.000 282.85 0.0 1.008 1.000 51.5 0.0 5.382 1550.1 0.00 0.0 23 -Mar 21:45 28 46.0 0.00 1.000 304.9 1.000 286.32 0.0 1.008 1.000 51.5 0.0 5.223 1504.1 0.00 0.0 13S &W = 0% water 23 -Mar 21:50 28 46.5 0.00 1.000 309.9 1.000 289.79 0.0 1.007 1.000 51.5 0.0 5.040 1451.5 0.00 0.0 23 -Mar 21:55 28 46.4 0.00 1.000 1 315.2 1.000 1293.27 0.0 1 1.008 1.000 1 51.5 0.0 1 5.334 1536.2 0.00 0.0 BS &W W = 0% water Switch from 23 -Mar 22:00 28 46.5 0.00 1.000 320.6 1.000 296.74 0.0 1.007 1.000 51.5 0.0 5.455 1570.9 0.00 0.0 Tank #2 to Tank #1. 23 -Mar 22:05 28 46.0 0.00 1.000 326.1 1.000 301.88 0.0 1.008 1.000 51.5 0.0 5.543 1596.4 0.00 0.0 23 -Mar 22:10 28 45.7 0.00 1.000 331.5 1.000 307.02 0.0 1.008 1.000 51.5 0.0 5.423 1561.9 0.00 0.0 23 -Mar 22:15 28 45.5 0.00 1 A00 336.9 1.000 312.16 0.0 1.008 1.000 51.5 0.0 5.443 1567.6 0.00 0.0 BS &W = 0% water 1 -inch orifice plate out of service on the 23 -Mar 22:20 28 45.4 0.00 1.000 339.8 1.000 317.30 0.0 1.008 1.000 51.5 0.0 2.924 842.2 0.00 0.0 horizontal separator. 23 -Mar 22:25 28 45.4 0.00 1.000 340.5 1.000 322.44 0.0 1.008 1.000 51.5 0.0 0.724 208.6 0.00 0.0 Outer annulus = 160 psi Well shut -in at wing valve. Shut -in 23 -Mar 22:30 0 45.0 0.00 1.000 345.9 1.000 327.58 0.0 1.008 1.000 51.5 0.0 5.409 1557.9 0.00 0.0 choke. Shut -in Tank #1. Page 4 w Choke & Temperature N w rn O O O o 0 0 0 0 0 15:30 - N 16:00 O O O 16:30 O 17:00 0 17:30 0 18:00 18:30 O 19:00 O = 19:30 y 20:00 n y 20:30 + 21:00 g 0 An 21:30 - o � _ � 22:00 - V 22:30 � D Q = 23:00 D y ° D 23:30 -� 0:00 0 E3 n o ❑ 0:30 O ❑ 1:00 0 El o ❑ c 1:30 0 E3 O ❑ 2:00 o ❑ 2:30 0 El O ❑ 3:00 El o ❑ 3:30 O ❑ 4:00 o ❑ 4:30 o ❑ 5:00 o ❑ N 5:30 El A O N A O co O O O O O N A O 9 O O O O O O O O • N (6isd) ainssaad • w Separator Pressure (psig) U1 O U1 o U1 O U1 O O O O O O o O O O 0 ° 15:30 - -- 16:00 16:30 D D O O O 17:00 D DDD D O 17:30 18:00 0 18:30 19:00 = 19:30 g ti 20:00 n ;v 20:30 - O D 21:00 - P D D 21:30 0 o D D 3 CA O D D CD 0 m 22:00 g o 22:30 y M <D a 23:00 -- 23:30 0:00 n c� 0:30 a 1:00 0 1:30 2:00 2:30 3:00 3:30 4:00 4:30 5:00 N 1' 5:30 v o 0 o O O O O o (;,) a.in;ejadwal aoleiedeS y Phillips Alaska, Inc. 1M - 17 Test #1 - Clean Up Flow Peiu�rs 2.5 1600 1400 2.0 ° 1200 ° v 1000 r 1.5 � rn ° a E ° ° ap ° X E 800 K c ° IT as � 1.0 ° 600 a ° 400 0.5 200 0.0 �t 0 O O o o O O O O O O O O O O o O o 0 0 0 o O o o O o 0 0 0 M O M O M O M O M O M O M O M O M O M O M O M O M O M O M LO 0 CD fl- I M M O O O O N N M M O O - - N N M M It � LOU') N N N N N N N N Time F23-Mar-021 ° GAS X OIL TANK O WATER TANK 24- Mar -02 Production Plot NJ Gas -Oil Ratio (MSCF /BBL) C) N N W 0 15:30 — -- N 16:00 16:30 17:00 17:30 ❑ 18:00 ❑ 18:30 ❑ 19:00 ❑❑ 19:30 ti 20:00 n d 20:30 x 21:00 ❑ 130 0 21:30 0 p 22:00 3 Q. 0 3 22:30 o w m cn 23:00 °- 23:30 0:00 n 0:30 1:00 In 1:30 2:00 2:30 3:00 3:30 4:00 4:30 5:00 5:30 0 0 0 0 0 0 0 0 0 0 0 9 0 0 0 0 0 0 0 0 0 0 i ° (;uaoied) MVS13 Phillips Alaska, Inc. 1M - 17 Test #1 - Clean Up Flow PH�uiPs 0.4 350.0 0.3 300.0 0 0.3 250.0 v y 0.2 200.0 M E S. E Q- Cr 0.2 150.0 y 0.1 100.0 0.1 50.0 0.0 0.0 C) O o 0 0 0 0 0 o O o O o 0 0 0 0 0 0 0 o O o 0 0 o O o 0 M O M O M O M O M O M O M O M O M O M O M O M O M O M O M LO (D CO N h 00 00 O O O O N CO M O O N N M M "T qt U LO N N N N N N N N Time 23- Mar -02 p GAS X OIL TANK O WATER TANK 24- Ma r -02 Cummulatives aseraYr2 "ietd fie " crsto""rt "No. 2. Chan +e 11 �Il f1(111. _'•:.. .: d 8 : Ni e`Mead ENTER ALL PLOT HEADER DATA & TITLES BELOW Customer Name: Phillips Alaska, hie. Well Name & Number: IM -17 Flow Period: Test #1 - Extended Flow Date Hours Minutes Chart Start Date & Time: 24-Mar-02 70 0 Chart End Date & Time: 25- Mar -02 5 30 Mujor Divisions in (hours & minutes) 0 30 Minor Divisions in (hours & minutes) 0 15 ENTER REPORT HEADER INFORMATION BELOW Customer: Phillips Alaska, Inc. Perf. interval: 10,606' 10,642' Well Name: IM 17 Test No. Test #1 - Extended Flow Date: 24- Mar -02 I I:00 - 25- Mar -02 05:30 Customer Rep.: Mark Chaney ,. Rig : Wellhead Hes Supervisor : Craig Convey Base : Anchorage, AK ENTER CUMMULATIVES FROM PREVIOUS FLOWS BELOW Oil (bbls) : 0.00 Water (bbls) : 0.00 Gas (nnnsco 0.0000 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. : Test #1 - Extended Flow WELL 1M - 17 RIG NAME : Wellhead DATE TIME OPERATIONS 24- Mar -02 10:50 Close Upstream Choke Valve 24- Mar -02 10:58 Light Flare Pilot 24- Mar -02 11:10 Line up to inject Methanol at data header 24- Mar -02 11:15 Open Master Valve 24- Mar -02 11:15 Open Surface Safety Valve 24- Mar -02 11:16 Open Wing Valve 24- Mar -02 11:17 Start injecting methanol at data header 24- Mar -02 11:20 Open Well to Tank #1 O/G = 0'9.5" on 8/64 the Adj. 24- Mar -02 11:21 Increase choke to 18/64 then 22/64 the Adj. 24- Mar -02 11:21 Gas Flare Lite 24- Mar -02 11:24 Increase to 24/64ths Adj 24- Mar -02 11:36 Increase to 26/64 the Adj 24- Mar -02 11:38 Gas Scrubber pressure at 45 and increasing 24- Mar -02 11:40 Gas Meter run temperature below zero 24- Mar -02 11:41 Increase choke to 28/64 the Adj 24- Mar -02 11:45 Fluid to Surface Open 2" meter Run 24- Mar -02 11:45 BS &W = 0% 24- Mar -02 12:00 Switch from Tank #1 CG = F5.5" to Tank #2 O/G = 0'9.5" 24- Mar -02 12:00 BS &W = 0% 24- Mar -02 12:14 Vac Truck returned to location 24- Mar -02 12:15 BS &W = 0% 24- Mar -02 12:30 Switch from Tank #2 CG = 2'8.5" to Tank #1 O/G = 1'5.5" 24- Mar -02 12:30 BS &W = 0.25% Water 24- Mar -02 12:53 Lower 1.000" Orifice Plate 24- Mar -02 13:00 Switch from Tank #1 CG = 2'9.5" to Tank #2 O/G = 2'8.5" 24- Mar -02 13:05 Start injecting Defoamer at data header. 24- Mar -02 13:10 Outer Annulus = 0 psi 24- Mar -02 13:15 BS &W = 2% Water 24- Mar -02 13:30 Switch from Tank #2 CG = 3' 11.75" to Tank #1 O/G = 2' 9.5" Page 1 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. : Test #1 - Extended Flow WELL 1M - 17 RIG NAME Wellhead DATE TIME OPERATIONS 24- Mar -02 13:30 Oil Gravity = 22.6 @ 48 deg F. Corrected = 23.3 @ 60 deg F. 24- Mar -02 13:45 BS &W = 2% Water 24- Mar -02 13:58 Increase back pressure on separator to lower Differential Pressure 24- Mar -02 14:00 Switch from Tank #1 CG = 4' 1" to Tank #2 O/G = 3' 11.75" 24- Mar -02 14:15 BS &W = 0.5% Water 24- Mar -02 14:27 Stop Injecting Methanol at Data Header 24- Mar -02 14:30 Switch from Tank #2 CG = 5'2.5" to Tank #1 O/G = 4'1" 24- Mar -02 14:36 Increase back pressure on separator to lower Differential Pressure 24- Mar -02 14:39 Raise 1.000" Orifice Plate 24- Mar -02 14:45 Lower 1.250" Orifice Plate 24- Mar -02 14:45 Gas Gravity = 0.631 24- Mar -02 15:00 Switch from Tank #1 CG = 5'2.25" to Tank #2 O/G = 5'2.5" 24- Mar -02 15:00 BS &W = 0% Water 24- Mar -02 15:29 Open Water leg 24- Mar -02 15:30 Switch from Tank #2 CG = 5' 10.5" to Tank #1 O/G = 5' 2.5" 24- Mar -02 15:30 BS &W = I% Water 24- Mar -02 15:45 Rock Choke 24- Mar -02 16:00 Switch from Tank #1 CG = 6'2.25" to Tank #2 O/G = 5' 10.5" 24- Mar -02 16:15 BS &W = 0.5% Water 24- Mar -02 16:27 Well Shut In at Surface Safety Valve 24- Mar -02 16:31 Open Surface Safety Valve 24- Mar -02 16:36 Decrease to 26/64 the Adj 24- Mar -02 16:40 Sparge vessel 24- Mar -02 16:47 Rock Choke 24- Mar -02 17:00 Switch from Tank #1 C/G = 6'98.5" to Tank #2 O/G = 7 24- Mar -02 17:04 Rock Choke 24- Mar -02 17:06 Shut -in at Surface Safety Valve. Tank #2 Inlet Valve shut -in. 24- Mar -02 17:21 Shut down chemical injection pump Page 2 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. : Test #1 - Extended Flow WELL : 1M - 17 RIG NAME : Wellhead DATE TIME OPERATIONS 24- Mar -02 17:23 Open Hydraulic Surface Safety Valve at tree to monitor WHP. 24- Mar -02 17:24 Lower 1.250" Orifice Plate 24- Mar -02 17:30 Switch from Tank #2 C/G = 7' 11" to Tank #1 O/G = 6'9.5" 24- Mar -02 17:31 Night shift on location Denis Henrion, David Reid, Livia Power 24- Mar -02 17:32 Joseph Dixon, Kelvin Smith 24- Mar -02 17:43 Open Surface Safety Valve 24- Mar -02 17:47 Open well on 16/64 the Adj. Inject defoamer. 24- Mar -02 17:48 Increase choke to 22/64 the Adj 24- Mar -02 18:00 Switch from Tank #1 C/G = 6' 10.5" to Tank 92 O/G = 7' 11" 24- Mar -02 18:01 Increase choke to 24/64 the Adj 24- Mar -02 18:04 Lower 1.250" Orifice Plate 24- Mar -02 18:11 Switch generator 24- Mar -02 18:25 BS &W = 0.03% Solids 0% Water 24- Mar -02 18:30 Switch from Tank #2 C/G = 8'8" to Tank #1 O/G = 6'9.5" 24- Mar -02 18:45 Shut -in defoamer injection 24- Mar -02 18:55 Divert flow through water line on the Horizontal separator 24- Mar -02 19:00 Switch from Tank #1 C/G = 7'9" to Tank #2 O/G = 8'8" 24- Mar -02 19:05 Oil Gravity = 23.2 @ 42 deg F. Corrected = 24.3 @ 60 deg F. 24- Mar -02 19:14 Divert flow through 2" oil line on the Horiz. Sep. - switch back and forth to set lev 24- Mar -02 19:15 BS &W = 0.1% Solids 0% Water 24- Mar -02 19:30 Switch from Tank #2 C/G = 9'4.5" to Tank #1 O/G = 7'9" 24- Mar -02 19:35 BS &W = 0.5% Solids 0% Water 24- Mar -02 20:00 Switch from Tank #1 C/G = 8'6" to Tank #2 O/G = 9'4.5" 24- Mar -02 20:05 Gas Gravity = 0.628 CO2 = 0.05% H2S = 0 ppm 24- Mar -02 20:15 Sparge vessel 24- Mar -02 20:30 Switch from Tank #2 C/G = 10' to Tank #1 O/G = 8'6" 24- Mar -02 20:49 Surface Safety Valve shut -in due to Vertical Separator oil section LSHH 24- Mar -02 20:52 No air pressure to Vertical Separator - cause the LSHH to alarm Page 3 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. : Test #1 - Extended Flow WELL 1M - 17 RIG NAME : Wellhead DATE TIME OPERATIONS 24- Mar -02 20:56 Run new air line to Vertical Separator 24- Mar -02 21:00 Switch from Tank #1 C/G = 8' 7" to Tank #2 O/G = 10' 24- Mar -02 21:20 Open Surface Safety Valve Open choke on 16/64 the Adj at 21:22 24- Mar -02 21:22 Open choke on 16/64 the Adj and increase to 20/64 the Adj. 24- Mar -02 21:30 Switch from Tank #2 C/G = 10'11.5" to Tank #1 O/G = 7' 9" 24- Mar -02 21:35 Increase choke to 24/64 the Adj 24- Mar -02 21:37 Inject defoamer 24- Mar -02 22:00 Switch from Tank #1 C/G = 9'3" to Tank #2 O/G = 10' 11.5" 24- Mar -02 22:01 Shut -in defoamer injection 24- Mar -02 22:30 Switch from Tank #2 C/G = 11'8.5" to Tank #1 O/G = 9'3" 24- Mar -02 22:40 Outer Annulus = 0 psi 24- Mar -02 22:41 Inject methanol and defoamer 24- Mar -02 23:00 Switch from Tank #1 C/G = 10' to Tank #2 O/G = I F 8.5" 24- Mar -02 23:07 Increase choke to 26/64 the Adj 24- Mar -02 23:10 Increase choke to 26/64 the Adj at 23:07 24- Mar -02 23:30 Switch from Tank #2 C/G = 12' 6.5" to Tank #1 O/G = 10' 24- Mar -02 23:35 BS &W = 0% Water w /trace of solids 24- Mar -02 23:45 Defoamer injection shut -in due to loss suction on chemical pump 25- Mar -02 0:00 Switch from Tank #I C/G = 10' 10" to Tank #3 O/G = I' 1" 25- Mar -02 0:01 Transfer fluid from Tank #2 O/G = 12'6.5" to Vac Truck 25- Mar -02 0:30 Switch from Tank #3 C/G = F 10.5" to Tank #1 O/G = 10' 10" 25- Mar -02 1:00 Switch from Tank #1 C/G = I F 10.5" to Tank #3 O/G = F 10.5" 25- Mar -02 1:04 Gas Gravity = 0.629 25- Mar -02 1:30 Switch from Tank #3 C/G = 2' 11.5" to Tank #1 O/G = I F 10.5" 25- Mar -02 1:46 Lower back pressure in the Horizontal Separator 25- Mar -02 2:00 Decrease choke to 24/64 the Adj at 01:59 25- Mar -02 2:01 Switch from Tank #1 C/G = 12' 10.5" to Tank #3 = 2' 11.5" at 02:00 25- Mar -02 2:10 Complete Transfer from Tank #2 (C /G = 1'6.5") Fluid Transfer = 220.04 bbls Page 4 HALLIBURTON ENERGY SERVICES PRODUCTION TEST DETAIL REPORT SEQUENCE OF OPERATIONS CUSTOMER : Phillips Alaska, Inc. TEST No. : Test #1 - Extended Flow WELL 1M - 17 RIG NAME Wellhead DATE TIME OPERATIONS 25- Mar -02 2:30 Switch from Tank #3 C/G = to Tank #1 O/G = 12' 10.5" 25- Mar -02 2:40 Oil Gravity = 24.5 @ 66 deg F. Corrected = 24.1 @ 60 deg F. 25- Mar -02 3:00 Switch from Tank #1 C/G = 13'7.5" to Tank #2 O/G = F6.5" 25- Mar -02 3:30 Switch from Tank #2 C/G = 2'2.5" to Tank #3 O/G = 3'8.5" 25- Mar -02 4:00 Switch from Tank #3 C/G = 4'4" to Tank #2 O/G = 2'2.5" 25- Mar -02 4:30 Switch from Tank #2 C/G = 2'6.5" to Tank #3 O/G = 4'4" 25- Mar -02 4:31 Inject defoamer 25- Mar -02 4:55 Vac Truck on location to transport fluid 25- Mar -02 5:00 Switch from Tank #3 C/G = 4' 11.5" to Tank #2 O/G = 2'6.5" 25- Mar -02 5:08 Start transfer fluid from Tank #1 (O /G = 13'7.5") to Transport 25- Mar -02 5:30 Switch from Tank #2 C/G = 3' 1.5" to Tank #3 O/G = 4' 11.5" Page 5 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZT WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (641h (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (prig) ( °F) ( %) ( %) (MMscf) (bbls) (bbls) (API @60 °0 (Air =1) 24 -Mar 10:51 204 49 24 -Mar 10:52 205 49 24 -Mar 10:53 205 49 24 -Mar 10:54 204 49 24 -Mar 10:55 204 1 49 24 -Mar 10:56 204 49 24 -Mar 10:57 205 49 24 -Mar 10:58 205 49 1 1 1 Light Flare Pilot 24 -Mar 10:59 203 49 24 -Mar 11:00 203 49 24 -Mar 11:01 204 49 i 24 -Mar 11:02 203 49 24 -Mar 11:03 205 49 24 -Mar 11:04 205 49 24 -Mar 11:05 204 49 24 -Mar 11:06 204 49 24 -Mar 11:07 204 49 24 -Mar 11:08 203 49 24 -Mar 11:09 1 205 49 24 -Mar 11:10 203 49 Line up to inject Methanol at data header 24 -Mar 11:11 205 49 Page 1 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR TRESTE . BS &W WCT G AS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) ( % ) ( %) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 11:12 202 49 24 -Mar 11:13 204 49 24 -Mar 11:14 209 49 24 -Mar 11:15 209 49 Open Surface Safety Valve 24 -Mar 11:16 208 49 Open Wing Valve 24 -Mar 11:17 1881 49 Start injecting methanol at data header 24 -Mar 11:18 1885 49 24 -Mar 11:19 1888 49 Open Well to Tank #1 O/G = 0'9.5" on 24 -Mar 11:20 8 1891 49 8/64 the Ad'. 24 -Mar 11:21 8 1878 49 Gas Flare Lite 24 -Mar 11:22 8 1856 49 24 -Mar 11:23 22 1843 1 50 24 -Mar 11:24 22 1835 50 Increase to 24/64ths Adj 24 -Mar 11:25 24 1804 50 24 -Mar 11:26 24 1766 50 24 -Mar 11:27 24 1745 1 49 24 -Mar 11:28 24 1726 48 24 -Mar 11:29 24 1716 47 24 -Mar 11:30 24 1703 46 24 -Mar 11:31 24 1 1 1695 45 24 -Mar 11:32 1 24 1687 44 Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZT WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd- mmmhh:mm) (64th (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) N (%) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 11:33 24 1680 43 24 -Mar 11:34 24 1674 42 24 -Mar 11:35 24 1667 41 24 -Mar 11:36 24 1654 40 Increase to 26/64 the Adj 24 -Mar 11:37 26 1620 39 Gas Scrubber pressure at 45 and 24 -Mar 11:38 26 1536 38 increasin 24 -Mar 11:39 26 1470 37 24 -Mar 11:40 1 26 1411 37 Gas Meter run temperature below zero 24 -Mar 11:41 26 1350 36 Increase choke to 28/64 the Adj 24 -Mar 11:42 28 1235 1 35 24 -Mar 11:43 28 1120 34 �I 24 -Mar 11:44 28 999 34 24 -Mar 11:45 28 981 33 0 0 175 50.0 0.0 0.0 51.5 BS &W = 0% 24 -Mar 11:46 28 1006 32 24 -Mar 11:47 28 1015 31 24 -Mar 11:48 28 1026 32 24 -Mar 11:49 28 1036 32 24 -Mar 11:50 28 1046 33 24 -Mar 11:51 28 1056 33 24 -Mar 11:52 28 1 1069 1 34 24 -Mar 11:53 1 28 1083 1 34 Page 3 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) M (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbls) (API @60 °0 (Air =1) 24 -Mar 11:54 28 1098 34 24 -Mar 11:55 28 1110 34 24 -Mar 11:56 28 1123 34 24 -Mar 11:57 28 1134 34 24 -Mar 11:58 28 1146 35 24 -Mar 11:59 28 1158 35 24 -Mar 12:00 28 1173 35 1280 0 190 19 0.0 13.3 0.0 51.5 BS &W = 0% 24 -Mar 12:01 28 1189 36 24 -Mar 12:02 28 1205 36 24 -Mar 12:03 28 1223 1 36 24 -Mar 12:04 28 1243 37 24 -Mar 12:05 28 1260 37 24 -Mar 12:06 28 1281 37 24 -Mar 12:07 28 1298 38 24 -Mar 12:08 28 1310 38 24 -Mar 12:09 28 1317 1 38 24 -Mar 12:10 28 1333 38 24 -Mar 12:11 28 1352 38 24 -Mar 12:12 28 1373 39 24 -Mar 12:13 1 28 1395 1 39 24 -Mar 12:14 28 1410 39 Vac Truck returned to location Page 4 i I CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR TRESTE . BS &W WCT G AS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) ( %) (%) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 12:15 28 1417 40 BS &W =0% 24 -Mar 12:16 28 1418 40 24 -Mar 12:17 28 1401 40 24 -Mar 12:18 28 1391 40 24 -Mar 12:19 28 1403 1 40 24 -Mar 12:20 28 1417 40 24 -Mar 12:21 28 1420 40 24 -Mar 12:22 28 1424 40 24 -Mar 12:23 28 1447 1 40 24 -Mar 12:24 28 1463 41 24 -Mar 12:25 28 1470 41 24 -Mar 12:26 28 1449 41 24 -Mar 12:27 28 1430 41 24 -Mar 12:28 28 1426 42 24 -Mar 12:29 28 1433 42 24 -Mar 12:30 28 1453 42 1820 0 257 35 0.0 51.3 0.0 51.5 BS &W = 0.25% Water 24 -Mar 12:31 28 1479 42 24 -Mar 12:32 28 1510 42 24 -Mar 12:33 28 1 1518 42 24 -Mar 12:34 28 1518 42 24 -Mar 12:35 1 28 1513 42 Page 5 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI B U RTO N DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey I , DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) (%) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 12:36 28 1508 42 24 -Mar 12:37 28 1508 1 42 24 -Mar 12:38 28 1507 42 24 -Mar 12:39 28 1504 41 24 -Mar 12:40 28 1503 42 24 -Mar 12:41 28 1499 1 42 24 -Mar 12:42 28 1493 42 24 -Mar 12:43 28 1486 42 24 -Mar 12:44 28 1478 42 24 -Mar 12:45 28 1477 43 24 -Mar 12:50 28 1467 44 24 -Mar 12:55 28 1493 45 1.74 270 1 37 0.01 0.632 Switch from Tank #1 CG = 2' 9.5" to 24 -Mar 13:00 28 1488 46 1.76 1280 0 1.4 271 38 0.0 0.01 1 77.9 0.0 51.5 0.632 1 Tank #2 O/G = 2' 8.5" 24 -Mar 13:05 28 1493 1 46 1 1.79 1 1 274 37 0.02 0.632 Start injecting Defoamer at data header. 24 -Mar 13:10 28 1507 47 1.85 277 38 1 0.02 0.632 Outer Annulus = 0 psi 24 -Mar 13:15 28 1505 48 1.79 277 1 37 0.03 0.632 BS &W = 2% Water 24 -Mar 13:20 28 1515 49 1.88 280 37 0.04 0.632 24 -Mar 13:25 28 1518 1 49 1 1.85 1 280 37 0.04 0.632 Oil Gravity = 22.6 @ 48 deg F. Corrected 24 -Mar 13:30 28 1519 49 1.85 1220 0 1.5 280 36 1 0.0 0.05 103.4 0.0 1 51.5 0.632 = 23.3 60 deg F. 24 -Mar 13:35 28 1520 50 1.85 1 281 1 36 0.06 0.632 24 -Mar 13:40 1 28 1526 50 1.88 1 1 282 1 36 1 0.06 1 1 0.632 Page 6 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTO N DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M (%) (MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 13:45 28 1525 50 1.83 280 36 0.07 0.632 BS &W = 2% Water 24 -Mar 13:50 28 1536 50 1.92 280 37 0.08 0.632 24 -Mar 13:55 28 1541 50 1.88 287 36 0.08 0.632 Switch from Tank #1 CG = 4' 1" to Tank 24 -Mar 14:00 28 1539 50 1.89 1240 0 1.5 312 37 0.0 0.09 129.2 0.0 23.3 0.632 #2 O/G = 3' 11.75" 24 -Mar 14:05 28 1534 50 1.89 317 37 0.10 0.632 24 -Mar 14:10 28 1531 50 1.85 1 316 36 0.10 1 0.632 24 -Mar 14:20 28 1545 50 1.91 315 37 0.12 0.632 Switch from Tank #2 CG = 5' 2.5" to 24 -Mar 14:30 28 1558 50 1.94 1180 1.6 320 37 0.13 162.0 23.3 0.632 jTank#1 O/G = 4' 1" 24 -Mar 14:40 28 1570 1 50 1 0.88 320 34 0.14 0.632 24 -Mar 14:50 28 1568 50 1.93 1 321 36 0.15 1 0.631 24 -Mar 15:00 28 1577 50 1.97 1060 1.9 324 35 0.16 184.1 23.3 0.631 BS &W = 0% Water 24 -Mar 15:10 28 1573 50 1.99 331 34 0.18 0.631 24 -Mar 15:20 28 1575 49 2.01 329 34 0.19 1 0.631 24 -Mar 15:30 28 1575 49 2.02 1 640 3.2 325 32 0.20 1 197.4 23.3 0.631 BS &W = 1% Water 24 -Mar 15:40 28 1574 49 2.08 323 33 0.22 0.631 24 -Mar 15:50 28 1554 49 2.00 1 324 32 0.23 0.631 Switch from Tank #1 CG = 6' 2.25" to 24 -Mar 16:00 28 1574 49 2.01 960 2.1 325 33 0.25 217.4 23.3 0.631 Tank #2 O/G = 5' 10.5" 24 -Mar 16:10 28 1571 1 49 1 2.05 1 327 1 33 0.26 1 0.631 24 -Mar 16:20 28 1567 49 1.78 1 299 32 1 0.27 1 0.631 24 -Mar 16:30 28 1729 49 1.96 1540 1.3 317 26 0.29 249.5 23.3 0.628 24 -Mar 16:40 26 1639 49 1.55 324 31 0.30 0.628 Sparge vessel Page 7 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar- 0205:30 CUSTOMER REP. Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIP WHT :SG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) (OF) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbls) (API @60 °0 (Air =1) 24 -Mar 16:50 26 1684 49 1.83 325 33 0.31 0.628 Switch from Tank #1 C/G = 6'98.5" to 24 -Mar 17:00 26 1697 49 1.45 1 580 2.5 287 29 0.32 251.9 23.3 0.628 ITank #2 O/G = T5.75" 24 -Mar 17:10 26 1959 49 0.14 108 33 0.32 0.628 24 -Mar 17:20 26 1949 48 0.04 79 34 0.32 0.628 Switch from Tank #2 C/G = 7' 11" to Tank 24 -Mar 17:30 2148 49 #1 O/G = 6'9.5" 24 -Mar 17:40 2165 48 24 -Mar 17:50 22 2044 48 Switch from Tank #1 C/G = 6' 10.5" to 24 -Mar 18:00 22 1954 1 46 185 297 27 255.8 23.3 Tank #2 O/G = 7' 11" 24 -Mar 18:10 24 1799 46 2.08 297 21 0.34 0.628 24 -Mar 18:20 24 1779 46 2.07 1 293 20 0.35 1 0.628 Switch from Tank #2 C/G = 8'8" to Tank 24 -Mar 18:30 24 1792 45 2.38 720 3.3 296 19 0.37 270.8 23.3 0.628 #1 O/G = 6'9.5" 24 -Mar 18:40 24 1726 1 45 1 2.29 299 11 0.38 0.628 24 -Mar 18:50 24 1567 45 1.62 1 286 12 0.39 1 1 0.628 Switch from Tank #1 C/G = 7'9" to Tank 24 -Mar 19:00 24 1648 46 1.61 840 1.9 296 22 0.41 288.3 23.3 0.628 #2 0/13 = 8'8" 24 -Mar 19:10 24 1744 47 1.86 298 28 0.42 0.628 24 -Mar 19:20 24 1 1739 47 1 1.85 1 299 24 0.43 1 1 0.628 Switch from Tank #2 C/G = 9'4.5" to 24 -Mar 19:30 24 1719 47 1.81 1 680 2.7 296 24 0.44 302.4 24.3 0.628 Tank #1 O/G = 7'9" 24 -Mar 19:40 24 1725 47 1.76 289 27 0.46 0.628 24 -Mar 19:50 24 1722 46 1.80 292 27 0.47 1 0.628 Switch from Tank #1 C/G = 8'6" to Tank 24 -Mar 20:00 24 1715 46 1.82 720 1 1 2.5 1 293 1 25 1 0.48 317.4 24.3 0.628 #2 O/G = 9'4.5" 24 -Mar 20:10 24 1711 46 1.61 284 27 0.49 0.628 Page 8 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606' - 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP. Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHP WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) ( %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) ( %) ( %) (MMscf) (bbls) (bbls) (API @60 °0 (Air =1) 24 -Mar 20:20 24 1706 46 1.50 297 28 0.50 0.628 Switch from Tank #2 C/G = 10' to Tank #1 24 -Mar 20:30 24 1701 45 1.89 600 3.2 300 27 0.52 329.9 24.3 0.628 O/G = 8'6" 24 -Mar 20:40 24 1671 45 2.43 291 27 0.53 0.628 24 -Mar 20:50 24 1878 45 0.28 1 183 29 0.53 0.628 Switch from Tank #1 C/G = 8'7" to Tank 24 -Mar 21:00 1920 45 1 1 1 #2 O/G = 10' 24 -Mar 21:10 1918 44 Open Surface Safety Valve Open choke 24 -Mar 21:20 1624 44 on 16/64 the Ad' at 21:22 Switch from Tank #2 C/G = 10'11.5" to 24 -Mar 21:30 20 2138 43 2761 1 1 279 32 390.1 24.3 Tank #1 O/G = 7'9" 24 -Mar 21:40 24 1757 43 2.09 285 12 0.55 1 0.628 24 -Mar 21:50 24 1766 42 2.12 295 19 0.56 1 0.628 Switch from Tank #1 C/G = 9'3" to Tank 24 -Mar 22:00 24 1767 42 2.25 640 3.5 285 15 1 0.58 403.4 24.3 0.628 #2 O/G = 10' 11.5" 24 -Mar 22:10 24 1688 41 2.04 1 1 279 11 1 0.59 0.628 24 -Mar 22:20 24 1701 1 41 1.87 287 13 0.61 1 0.628 Switch from Tank #2 C/G = 11'8.5" to 24 -Mar 22:30 24 1635 41 1.89 720 2.6 281 1 19 0.62 418.4 24.3 0.628 Tank #1 O/G = 9' 3" 24 -Mar 22:40 24 1612 41 1.70 1 1 285 26 1 0.63 0.628 Outer Annulus = 0 psi 24 -Mar 22:50 1 24 1642 41 1.77 280 28 1 0.64 0.628 Switch from Tank #1 C/G = 10' to Tank #2 24 -Mar 23:00 24 1627 41 1.87 720 2.6 287 26 0.66 433.4 24.3 0.628 O/G = 11' 8.5" 24 -Mar 23:10 26 1485 41 2.11 292 26 0.67 0.628 Increase choke to 26/64 the Adj at 23:07 24 -Mar 23:20 26 1405 42 2.02 1 1 1 299 27 1 0.69 1 0.628 Switch from Tank #2 C/G = 12'6.5" to 24 -Mar 23:30 26 1383 43 1.98 800 2.5 305 29 0.70 450.1 24.3 0.628 Tank #1 O/G = 10' 24 -Mar 23:40 26 1369 44 2.00 316 31 0.71 0.628 Page 9 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney • • BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIR WHT C.' GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) I %) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) M ( %) ( MMscf) (bbls) (bbls) (API @60 °f) (Air =1) 24 -Mar 23:50 26 1349 46 1.97 311 31 0.73 0.628 Switch from Tank #1 C/G = 10' 10" to 25 -Mar 00:00 26 1 1336 1 47 1.93 800 2.4 307 30 0.74 466.8 24.3 0.628 Tank #3 O/G = 1' 1" 25 -Mar 00:10 26 1327 49 1.93 307 31 0.75 0.628 25 -Mar 00:20 26 1316 50 1.93 306 31 0.77 0.628 Switch from Tank #3 C/G = 1' 10.5" to 25 -Mar 00:30 26 1306 52 1 1.98 760 2.6 312 31 0.78 482.6 24.3 0.628 Tank #1 O/G = 10' 10" 25 -Mar 00:40 26 1560 1 53 2.15 316 33 0.80 0.628 25 -Mar 00:50 26 1666 54 2.39 310 32 0.81 0.628 Switch from Tank #1 C/G = 11' 10.5" to 25 -Mar 01:00 26 1647 55 1 2.33 1000 1 2.3 319 30 0.83 503.4 24.3 0.628 1 Tank #3 O/G = 1' 10.5" 25 -Mar 01:10 26 1640 55 2.32 1 321 1 31 0.84 0.629 25 -Mar 01:20 1 26 1631 56 2.26 320 32 0.86 0.629 Switch from Tank #3 C/G = 2' 11.5" to 25 -Mar 01:30 26 1634 57 2.28 1040 2.2 327 32 0.88 525.1 24.3 0.629 1 Tank #1 O/G = 11' 10.5" 25 -Mar 01:40 26 1622 58 1 2.29 1 314 31 0.89 0.629 25 -Mar 01:50 26 1622 59 2.29 1 295 1 31 0.91 1 0.629 25 -Mar 02:00 24 1653 59 1.93 960 2.0 279 30 0.92 545.1 24.3 0.629 Decrease choke to 24/64 the Adj at 01:59 Complete Transfer from Tank #2 (C /G = 1' 25 -Mar 02:10 24 1711 60 1.91 277 30 0.93 0.629 6.5" ) Fluid Transfer = 220.04 bbls 25 -Mar 02:20 24 1734 60 1 1.90 1 1 272 29 0.95 0.629 Switch from Tank #3 C/G = to Tank #1 25 -Mar 02:30 24 1754 60 1.91 720 2.6 271 1 28 1 0.96 1 560.1 24.3 0.629 O/G = 12' 10.5" 25 -Mar 02:45 24 1740 59 1.95 273 25 0.98 0.629 Switch from Tank #1 C/G = 13'7.5" to 25 -Mar 03:00 24 1752 59 2.02 720 1 2.8 272 25 1.00 580.1 24.1 1 0.629 Tank #2 O/G = 1'6.5" 25 -Mar 03:15 24 1 1732 1 58 1 1 2.00 1 270 24 1.02 1 0.629 Switch from Tank #2 C/G = 2'2.5" to Tank 25 -Mar 03:30 1 24 1751 1 58 1.92 1 640 3.0 1 260 1 24 1 1 1 1.04 1 600.1 24.1 0.629 #3 O/G = 3'8.5" Page 10 r CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' WELL TEST DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP. Mark Chaney ME BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE FLOW RATES SEPARATOR CUMULATIVE SPECIFIC GRAVITY TIME SIZE BS &W WHIR WHT CSG GAS OIL WATER GOR PRES. TEMP. BS &W WCT GAS OIL WATER OIL GAS REMARKS TANK TANK TANK TANK (dd -mmm hh:mm) (64ths) (%) (psig) ( °F) (psig) (MMscfd) (bpd) (bpd) (mscf /bbl) (psig) ( °F) (%) ( %) (MMsco (bbls) (bbis) (API @60 °f) (Air =1) 25 -Mar 03:45 24 1734 57 1.88 268 25 1.06 0.629 Switch from Tank #3 C/G = 4'4" to Tank 25 -Mar 04:00 24 1711 56 1.90 600 3.2 274 25 1.08 1 618.9 24.1 0.629 #2 O/G = 2'2.5" 25 -Mar 04:15 24 1714 56 1.85 275 24 1.10 0.629 Switch from Tank #2 C/G = 2'6.5" to Tank 25 -Mar 04:30 24 1713 55 1.83 1 320 1 5.7 270 1 23 1.12 628.9 24.1 0.629 #3 O/G = 4'4" 25 -Mar 04:45 24 1706 55 1 1.81 270 23 1.14 0.629 Switch from Tank #3 C/G = 4' 11.5" to 25 -Mar 05:00 24 1658 54 1.75 600 2.9 258 22 1.16 1 647.6 24.1 0.629 Tank #2 O/G = 2'6.5" 25 -Mar 05:15 24 1645 53 1.92 259 20 1.18 0.629 Switch from Tank #2 C/G = 3' 1.5" to Tank 25 -Mar 05:30 24 1626 53 1.90 560 1 3.4 1 256 1 25 1.20 653.5 24.1 0.629 #3 O/G = 4' 11.5" Page 11 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Ex Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q =C' 24`SQRT(PfHw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf Hw) (mmscf /d) 24 -Mar 10:51 0 215 42 24 -Mar 10:52 0 215 42 24 -Mar 10:53 0 215 42 24 -Mar 10:54 0 214 1 42 24 -Mar 10:55 0 214 42 24 -Mar 10:56 0 214 42 24 -Mar 10:57 0 213 42 24 -Mar 10:58 0 213 42 Li ht Flare Pilot 24 -Mar 10:59 0 213 42 24 -Mar 11:00 0 212 42 24 -Mar 11:01 0 211 42 24 -Mar 11:02 0 211 42 24 -Mar 11:03 0 211 42 24 -Mar 11:04 0 210 42 24 -Mar 11:05 0 210 42 24 -Mar 11:06 0 209 42 24 -Mar 11:07 0 209 42 24 -Mar 11:08 0 208 42 24 -Mar 11:09 0 195 42 24 -Mar 11:10 0 195 42 Line up to inject Methanol at data header 24 -Mar 11:11 0 194 42 T Page 1 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE: 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= C' *24 *SQRT(PfHw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( * (inch) (Pf * Hw) (mmscf /d) 24 -Mar 11:121 0 194 1 1 42 24 -Mar 11:13 0 194 42 24 -Mar 11:14 0 194 42 24 -Mar 11:15 0 194 42 Open Surface Safety Valve 24 -Mar 11:16 0 194 42 Open Wing Valve 24 -Mar 11.17 0 193 42 Start injecting methanol at data header 24 -Mar 11:18 0 193 42 24 -Mar 11:19 0 192 42 Open Well to Tank #1 O/G = 0'9.5" on 24 -Mar 11:20 8 196 42 8/64 the Ad'. 24 -Mar 11:21 8 229 42 1 Gas Flare Lite 24 -Mar 11:22 8 258 43 24 -Mar 11:23 22 180 48 24 -Mar 11:24 22 178 45 Increase to 24/64ths Adj 24 -Mar 11:25 24 202 45 24 -Mar 11:26 24 203 44 24 -Mar 11:27 24 206 41 24 -Mar 11:28 24 208 38 24 -Mar 11:29 24 204 35 24 -Mar 11:30 24 202 31 24 -Mar 11:31 24 202 28 24 -Mar 11:32 1 24 201 26 Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney P BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SORT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= C' *24 *SQRT(Pf *Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( * (inch) (Pf * Hw) (mmscf /d) 24 -Mar 11:33 24 201 24 24 -Mar 11:34 24 206 22 24 -Mar 11:35 24 206 22 24 -Mar 11:36 24 205 19 Increase to 26/64 the Ad' 24 -Mar 11:37 26 231 17 Gas Scrubber pressure at 45 and 24 -Mar 11:38 26 234 13 increasin 24 -Mar 11:39 26 229 5 24 -Mar 11:40 26 222 Gas Meter run temperature below zero 24 -Mar 11:41 26 228 Increase choke to 28/64 the Ad' 24 -Mar 11:42 28 231 24 -Mar 11:43 28 221 24 -Mar 11:44 28 213 24 -Mar 11:45 28 189 BS &W = 0% 24 -Mar 11:46 28 184 24 -Mar 11:47 28 180 24 -Mar 11:48 28 178 24 -Mar 11:49 28 176 24 -Mar 11:50 28 173 2 24 -Mar 11:51 28 172 4 24 -Mar 11:52 28 164 6 24 -Mar 11:53 28 161 7 Page 3 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q =C' * 24 * SQRT(Pf Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf * Hw) (mmscf /d) 24 -Mar 11:54 28 164 9 24 -Mar 11:55 28 166 11 24 -Mar 11:56 28 163 12 24 -Mar 11:57 28 177 13 24 -Mar 11:58 28 200 15 24 -Mar 11:59 28 205 17 24 -Mar 12:00 28 205 19 BS &W = 0% 24 -Mar 12:01 28 206 20 24 -Mar 12:02 28 204 21 24 -Mar 12:03 28 197 22 24 -Mar 12:04 28 195 1 23 24 -Mar 12:05 28 200 23 24 -Mar 12:06 28 1 204 25 24 -Mar 12:07 28 209 26 24 -Mar 12:08 28 212 27 24 -Mar 12:09 28 212 28 24 -Mar 12:10 28 1 207 29 24 -Mar 12:11 28 199 29 24 -Mar 12:12 28 201 29 24 -Mar 12:13 28 202 30 24 -Mar 12:14 28 218 731 Vac Truck returned to location Page 4 l CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C• GAS RATE TIME SIZE TEMP SIZE (Q=C'•24`SQRT(Pf - Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf Hw) (mmscf /d) 24 -Mar 12:15 28 262 33 BS &W = 0% 24 -Mar 12:16 28 277 36 24 -Mar 12:17 28 286 37 24 -Mar 12:18 28 268 37 24 -Mar 12:19 28 264 35 24 -Mar 12:20 28 267 34 24 -Mar 12:21 28 279 34 24 -Mar 12:22 28 264 35 24 -Mar 12:23 28 260 34 24 -Mar 12:24 28 263 1 34 24 -Mar 12:25 28 278 35 24 -Mar 12:26 28 282 37 24 -Mar 12:27 28 278 36 24 -Mar 12:28 28 274 35 24 -Mar 12:29 28 270 35 24 -Mar 12:30 28 272 35 BS &W = 0.25% Water 24 -Mar 12:31 28 270 35 24 -Mar 12:32 28 271 35 24 -Mar 12:33 28 282 36 24 -Mar 12:34 28 285 37 24 -Mar 12:35 28 286 36 Page 5 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SORT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q=C'•24 SQRT(Pf *Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf Hw) (mmscHd) 24 -Mar 12:36 28 281 1 1 35 24 -Mar 12:37 28 278 34 24 -Mar 12:38 28 282 33 24 -Mar 12:39 28 283 33 24 -Mar 12:40 28 285 33 24 -Mar 12:41 28 286 33 24 -Mar 12:42 28 286 33 24 -Mar 12:43 28 286 33 24 -Mar 12:44 28 284 32 24 -Mar 12:45 28 279 32 24 -Mar 12:50 28 278 75 34 144.2 1.0000 1.0000 1.2580 1.0262 11.0018 1.0290 24 -Mar 12:55 28 284 259 37 1.000 271.2 200.955 1.0000 1.0000 1.2580 1.0227 1.0002 1.0061 1.0290 267.76 1.743 Switch from Tank #1 CG = 2' 9.5" to 24 -Mar 13:00 28 285 263 38 1.000 274.1 200.955 1.0000 1.0000 1.2580 1.0222 1.0002 1.0062 1.0290 267.67 1.761 Tank #2 O/G = 2'8.5" 24 -Mar 13:05 28 289 270 37 1.000 279.1 200.955 1.0000 1.0000 1.2580 1.0225 1.0002 1.0063 1.0300 267.87 1.794 Start injecting Defoamer at data header. 24 -Mar 13:10 28 292 285 1 38 1.000 1 288.3 200.955 1.0000 1.0000 1.2580 1.0222 1.0002 1.0065 1.0300 267.95 1.854 Outer Annulus = 0 psi 24 -Mar 13:15 28 291 265 37 1.000 277.7 200.955 1.0000 1.0000 1.2580 1.0233 1.0002 1.0061 1.0300 268.18 1.788 13S &W = 2% Water 24 -Mar 13:20 28 295 288 37 1.000 291.4 200.955 1.0000 1.0000 1.2580 1.0225 1.0002 1.0065 1.0310 268.15 1 1.875 24 -Mar 13:25 28 294 282 37 1.000 288.1 200.955 1.0000 1.0000 1.2580 1.0231 1.0002 1.0064 1.0310 268.30 1.855 Oil Gravity = 22.6 @ 48 deg F. 24 -Mar 13:30 28 294 279 36 1.000 286.5 200.955 1.0000 1.0000 1.2580 1.0237 1.0002 1.0063 1.0310 268.44 1.846 Corrected = 23.3 @ 60 deg F. 24 -Mar 13:35 28 296 278 36 1.000 286.9 200.955 1.0000 1.0000 1.2580 1.0240 1.0002 1.0063 1.0310 268.59 1.849 24 -Mar 13:40 1 28 1 296 287 36 1 1.000 291.6 200.955 1.0000 1.0000 1.2580 1.0237 1.0002 1.0065 1.0310 268.56 1.879 Page 6 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS i7 In HALLI B U RTO N DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP. Mark Chaney BASE: Anchorage, AK I RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q=C' 24 SQRT(Pf *Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf Hw) (mmscf /d) 24 -Mar 13:45 28 295 275 36 1.000 284.5 200.955 1.0000 1.0000 1.2580 1.0239 1.0002 1.0062 1.0310 268.51 1.833 BS &W = 2% Water 24 -Mar 13:50 28 295 300 37 1.000 297.6 200.955 1.0000 1.0000 1.2580 1.0230 1.0002 1.0068 1.0310 268.38 1.917 24 -Mar 13:55 28 301 282 36 1.000 291.3 200.955 1.0000 1.0000 1.2580 1.0236 1.0002 1.0063 1.0310 268.60 1.878 Switch from Tank #1 CG = 4' 1" to Tank 24 -Mar 14:00 28 326 264 37 1.000 293.5 200.955 1.0000 1.0000 1.2580 1.0226 1.0002 1.0054 1.0340 268.82 1 1.894 #2 O/G = 3' 11.75" 24 -Mar 14:05 28 332 258 37 1.000 292.8 200.955 1.0000 1.0000 1.2580 1.0231 1.0002 1.0052 1.0350 269.10 1.891 24 -Mar 14:10 28 331 248 36 1.000 286.6 200.955 1.0000 1.0000 1.2580 1.0234 1.0002 1.0050 1.0350 269.12 1.851 24 -Mar 14:20 28 330 266 37 1.000 296.3 200.955 1.0000 1.0000 1.2580 1.0231 1.0002 1.0054 1.0350 269.09 1.913 Switch from Tank #2 CG = 5' 2.5" to 24 -Mar 14:30 28 335 270 37 1.000 300.9 200.955 11.0000 1.0000 1.2580 1.0224 1.0002 1.0054 1.0350 269.03 1.943 Tank #1 O/G = 4'1" 24 -Mar 14:40 28 335 55 34 1.000 136.2 200.955 1.0000 1.0000 1.2580 1.0263 1.0004 1.0011 1.0360 269.21 0.880 24 -Mar 14:50 28 336 108 36 1.250 190.5 314.946 1.0000 1.0000 1.2590 1.0244 1.0002 1.0021 1.0360 421.60 1.927 24 -Mar 15:00 28 339 111 35 1.250 194.4 314.946 1.0000 1.0000 1.2590 1.0246 1.0002 1.0022 1.0360 421.89 1.968 BS &W = 0% Water 24 -Mar 15:10 28 345 111 34 1.250 195.7 314.946 1.0000 1.0000 1.2590 1.0261 1.0002 1.0021 1.0370 422.96 1.986 24 -Mar 15:20 28 344 113 34 1.250 197.5 314.946 1.0000 1.0000 1.2590 1.0264 1.0002 1.0022 1.0370 423.07 2.005 24 -Mar 15:30 28 340 116 32 1.250 198.6 314.946 1.0000 1.0000 1.2590 1.0277 1.0002 1.0023 1.0370 423.60 2.019 BS &W = 1 % Water 24 -Mar 15 :40 28 338 123 33 1.250 204.2 314.946 1.0000 1.0000 1.2590 1.0274 1.0002 1.0024 1.0370 423.39 2.075 24 -Mar 15:50 28 338 115 32 1.250 196.9 314.946 1.0000 1.0000 1.2590 1.0279 1.0002 1.0023 1.0370 423.63 2.002 Switch from Tank #1 CG = 6' 2.25" to 24 -Mar 16:00 28 339 116 33 1.250 198.0 314.946 1.0000 1.0000 1.2590 1.0269 1.0002 1.0023 1.0370 423.16 2.011 Tank #2 O/G = 5' 10.5" 24 -Mar 16:10 28 342 119 33 1.250 201.9 314.946 1.0000 1.0000 1.2590 1.0270 1.0002 1.0023 1.0370 423.31 2.051 24 -Mar 16:20 28 313 99 32 1.250 175.8 314.946 1.0000 1.0000 1.2590 1.0279 1.0003 1.0021 1.0340 422.31 1.782 24 -Mar 16:30 28 332 110 26 1.250 191.3 314.946 1.0000 1.0000 1.2620 1.0339 1.0002 1.0022 1.0370 427.28 1 1.961 24 -Mar 16:40 26 338 69 31 1.250 1 152.3 1 314.946 1.0000 1.0000 1.2620 1.0289 1.0003 1.0013 1.0370 424.65 1.552 Spar a vessel Page 7 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q=C' * 24 * SaRT(Pf*Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf * Hw) (mmscf /d) 24 -Mar 16:50 26 340 95 33 1.250 179.8 314.946 1.0000 1.0000 1.2620 1.0268 1.0003 1.0019 1.0360 423.87 1.829 Switch from Tank #1 C/G = 6'98.5" to 24 -Mar 17:00 26 302 67 29 1.250 142.3 314.946 1.0000 1.0000 1.2620 1.0307 1.0003 1.0015 1.0330 423.84 1.447 Tank #2 O/G = T5.75" 24 -Mar 17:10 26 123 2 33 1.250 13.7 314.946 1.0000 1.0000 1.2620 1.0272 1.0035 1.0001 1.0120 414.45 0.136 24 -Mar 17:20 26 94 0 34 1.250 4.2 314.946 1.0000 1.0000 1.2620 1.0264 1.0115 1.0000 1.0080 416.09 1 0.042 Switch from Tank #2 C/G = 7' 11" to Tank 24 -Mar 17:30 #1 O/G = 6'9.5" 24 -Mar 17:40 24 -Mar 17:50 22 245 0 39 7.0 1.0000 1.0000 1.2620 1.0211 1.0000 1.0240 Switch from Tank #1 C/G = 6' 10.5" to 24 -Mar 18:00 22 312 67 27 144.0 1.0000 1.0000 1.2620 1.0337 1.0014 1.0350 Tank #2 O/G = 7' 11" 24 -Mar 18:10 24 311 130 21 1.250 201.5 314.946 1.0000 1.0000 1.2620 1.0395 1.0002 1.0028 1.0360 429.28 2.076 24 -Mar 18:20 24 308 130 20 1.250 200.3 314.946 1.0000 1.0000 1.2620 1.0408 1.0002 1.0028 1.0360 429.80 2.066 Switch from Tank #2 C/G = 8'8" to Tank 24 -Mar 18:30 24 310 170 19 1.250 229.8 314.946 1.0000 1.0000 1.2620 1.0417 1.0002 1.0037 1.03601 430.76 2.376 #1 O/G = 6'9.5" 24 -Mar 18:40 24 314 154 11 1.250 219.5 314.946 1.0000 1.0000 1.2620 1.0507 1.0002 1.0033 1.0390 435.44 2.293 24 -Mar 18:50 24 301 81 12 1.250 155.8 314.946 1.0000 1.0000 1.2620 1.0501 1.0003 1.0018 1.0370 433.77 1.622 Switch from Tank #1 C/G = 7'9" to Tank 24 -Mar 19:00 24 311 79 22 1.250 156.7 314.946 1.0000 1.0000 1.2620 1.0382 1.0003 1.0017 1.0360 428.20 1.610 #2 O/G = 8'8" 24 -Mar 19:10 24 313 106 28 1.250 181.8 314.946 1.0000 1.0000 1.2620 1.0324 1.0003 1.0022 1.03501 425.55 1.857 24 -Mar 19:20 24 314 103 24 1.250 180.1 314.946 1.0000 1.0000 1.2620 1.0367 1.0003 1.0022 1.0360 427.76 1.849 Switch from Tank #2 C/G = 9'4.5" to 24 -Mar 19:30 24 311 100 24 1.250 176.2 314.946 1.0000 1.0000 1.2620 1.0365 1.0003 1.0021 1.0350 427.49 1 1.807 Tank #1 O/G = 7'9" 24 -Mar 19:40 24 304 98 27 1.250 172.2 314.946 1.0000 1.0000 1.2620 1.0335 1.0003 1.0021 1.0340 425.55 1.759 24 -Mar 19:50 24 1 306 101 27 1.250 175.9 314.946 1.0000 1.0000 1.2620 1.0330 1.0003 1.0022 1.0340 425.46 1.797 Switch from Tank #1 C/G = 8'6" to Tank 24 -Mar 20:00 24 308 103 25 1.250 178.1 314.946 1.0000 1.0000 1.2620 1.0352 1.0003 1.0022 1.0350 426.70 1.824 #2 O/G = 9'4.5" 24 -Mar 20:10 24 299 84 27 1 1.250 157.9 314.946 1.0000 1.0000 1.2620 1.0336 1.0003 1.0019 1.0330 425.26 1.612 Page 8 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q= C' ^24 ^SORT(PfHw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf * Hw) (mmscf /d) 24 -Mar 20:20 1 24 311 1 70 28 1.250 1 147.5 314.946 1.0000 1.0000 1.2620 1.0320 1.0003 1.0015 1.0340 424.97 1.505 Switch from Tank #2 C/G = 10' to Tank #1 24 -Mar 20:30 24 314 109 27 1.250 185.0 314.946 1.0000 1.0000 1.2620 1.0336 1.0003 1.0023 1.0350 426.25 1.892 O/G = 8'6" 24 -Mar 20:40 24 305 184 27 1.250 237.2 314.946 1.0000 1.0000 1.2620 1.0334 1.0002 1.0040 1.0340 426.36 2.427 24 -Mar 20:50 24 197 4 29 1.250 27.9 314.946 1.0000 1.0000 1.2620 1.0311 1.0017 1.0001 1.0200 418.90 0.280 Switch from Tank #1 C/G = 8'7" to Tank 24 -Mar 21:00 #2 O/G = 10' 24 -Mar 21:10 Open Surface Safety Valve Open choke 24 -Mar 21:20 on 16/64 the Ad' at 21:22 Switch from Tank #2 C/G = 10' 11.5" to 24 -Mar 21:30 20 294 89 32 161.8 1.0000 1.0000 1.2620 1.0285 1.0020 1.0310 1 Tank #1 O/G = 7'9" 24 -Mar 21:40 24 300 134 12 1.250 200.6 314.946 1.0000 1.0000 1.2620 1.0501 1.0002 1.0030 1.0370 434.22 2.091 24 -Mar 21:50 24 310 135 19 1.250 204.6 314.946 1.0000 1.0000 1.2620 1.0425 1.0002 1.0029 1.0370 430.80 2.116 Switch from Tank #1 C/G = 9'3" to Tank 24 -Mar 22:00 24 300 156 15 1.250 216.5 314.946 1.0000 1.0000 1.2620 1.0462 1.0002 1.0035 1.0360 432.41 2.247 #2 O/G = 10' 11.5" 24 -Mar 22:10 24 294 131 11 1.250 196.3 314.946 1.0000 1.0000 1.2620 1.0505 1.0002 1.0030 1.0360 434.05 2.045 24 -Mar 22:20 24 302 107 13 1.250 180.1 314.946 1.0000 1.0000 1.2620 1.0487 1.0003 1.0024 1.0370 433.34 1.873 Switch from Tank #2 C/G = 11'8.5" to 24 -Mar 22:30 24 295 113 19 1.250 182.8 314.946 1.0000 1.0000 1.2620 1.0423 1.0003 1.0025 1.0350 429.78 1.886 Tank #1 O/G = 9'3" 24 -Mar 22:40 24 300 93 26 1.250 166.6 314.946 1.0000 1.0000 1.2620 1.0344 1.0003 1.0021 1.0330 425.79 1.703 Outer Annulus = 0 psi 24 -Mar 22:50 24 295 102 28 1.250 173.8 314.946 1.0000 1.0000 1.2620 1.0320 1.0003 1.0023 1.0320 424.45 1.770 Switch from Tank #1 C/G = 10' to Tank #2 24 -Mar 23:00 24 301 111 26 1.250 182.6 314.946 1.0000 1.0000 1.2620 1.0348 1.0003 1.0024 1.0340 426.23 1.868 O/G = 11'8.5" 24 -Mar 23:10 26 307 139 26 1.250 206.3 314.946 1.0000 1.0000 1.2620 1.0345 1.0002 1.0030 1.0340 426.61 2.112 Increase choke to 26/64ths Ad'at23:07 24 -Mar 23:20 26 314 125 27 1.250 197.7 314.946 1.0000 1.0000 1.2620 1.0329 1.0002 1.0026 1.03501 425.99 2.021 Switch from Tank #2 C/G = 12'6.5" to 24 -Mar 23:30 26 320 118 29 1.250 194.4 314.946 1.0000 1.0000 1.2620 1.0313 1.0002 1.0025 1.0350 425.40 1 1.985 Tank #1 O/G = 10' 24 -Mar 23:40 26 331 116 31 1.250 195.7 1 314.946 1.0000 1.0000 1.2620 1.0295 1.0002 1.0023 1.0360 424.98 1.996 Page 9 I I I CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PNILLIPs HALLI BURTO N DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney � i I BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE of DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (Q =C' * 24 * SQRT(Pf Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf * Hw) (mmscf /d) 24 -Mar 23:50 26 326 115 31 1.250 193.7 314.946 1.0000 1.0000 1.2620 1.0296 1.0002 1.0024 1.0350 424.76 1.975 Switch from Tank #1 C/G = 10' 10" to 25 -Mar 00:00 26 322 112 30 1.250 189.5 314.946 1.0000 1.0000 1.2620 1.0297 1.0002 1.0023 1.0350 424.64 1.932 Tank #3 O/G = 1' 1" 25 -Mar 00:10 26 322 111 31 1.250 189.3 314.946 1.0000 1.0000 1.2620 1.0289 1.0002 1.0023 1.0350 424.25 1 1.927 25 -Mar 00:20 26 321 111 31 1.250 189.0 314.946 1.0000 1.0000 1.2620 1.0292 1.0002 1.0023 1.0350 424.33 1.925 Switch from Tank #3 C/G = 1' 10.5" to 25 -Mar 00:30 26 326 115 31 1.250 194.0 314.946 1.0000 1.0000 1.2620 1.0295 1.0002 1.0024 1.0350 424.79 1.978 Tank #1 O/G = 10' 10" 25 -Mar 00:40 26 331 135 33 1.250 211.0 314.946 1.0000 1.0000 1.2620 1.0270 1.0002 1.0027 1.0350 423.83 2.146 25 -Mar 00:50 26 325 170 32 1.250 234.9 314.946 1.0000 1.0000 1.2620 1.0279 1.0002 1.0035 1.03501 424.35 2.392 Switch from Tank #1 C/G = 11' 10.5" to 25 -Mar 01:00 26 334 155 30 1.250 227.8 314.946 1.0000 1.0000 1.2620 1.0297 1.0002 1.0031 1.0360 425.57 2.327 Tank #3 O/G = 1' 10.5" 25 -Mar 01:10 26 335 155 31 1.250 227.6 314.946 11.0000 1.0000 1.2610 1.0292 1.0002 1.0031 1.0370 425.07 2.322 25 -Mar 01:20 26 335 146 32 1.250 221.4 314.946 1.0000 1.0000 1.2610 1.0284 1.0002 1.0029 1.0360 424.55 1 2.256 Switch from Tank #3 C/G = 2' 11.5" to 25 -Mar 01:30 26 341 146 32 1.250 223.3 314.946 1.0000 1.0000 1.2610 1.0280 1.0002 1.0029 1.0370 424.64 2.276 Tank #1 O/G = 11'10.5" 25 -Mar 01:40 26 329 154 31 1.250 224.8 314.946 1.0000 1.0000 1.2610 1.0292 1.0002 1.0031 1.0360 424.73 2.291 25 -Mar 01:50 26 1 309 164 31 1.250 225.3 314.946 1.0000 1.0000 1.2610 1.0293 1.0002 1.0035 1.0330 423.99 2.293 25 -Mar 02:00 24 294 123 30 1.250 190.3 314.946 1.0000 1.0000 1.2610 1.0296 1.0002 1.0028 1.0320 423.10 1.933 Decrease choke to 24/64ths Ad'at01:59 Complete Transfer from Tank #2 (C /G = 1' 25 -Mar 02:10 24 292 122 30 1.250 188.4 314.946 1.0000 1.0000 1.2610 1.0305 1.0002 1.0028 1.0320 423.43 1.915 6.5 ") Fluid Transfer = 220.04 bbls 25 -Mar 02:20 24 287 122 29 1.250 186.9 314.946 1.0000 1.0000 1.2610 1.0317 1.0002 1.0028 1.0310 423.82 1.901 Switch from Tank #3 C/G = to Tank #1 25 -Mar 02:30 24 286 123 28 1.250 187.2 314.946 11.0000 1.0000 1.2610 1.0325 1.0002 1.0029 1.0310 424.15 1.905 O/G = 12' 10.5" 25 -Mar 02:45 24 288 127 25 1.250 191.1 314.946 1.0000 1.0000 1.2610 1.0352 1.0002 1.0029 1.0320 425.62 1.952 Switch from Tank #1 C/G = 13'7.5" to 25 -Mar 03:00 24 286 136 1 25 1.250 197.4 314.946 1.0000 1.0000 1.2610 1.0357 1.0002 1.0032 1.0320 425.92 1 2.018 Tank #2 O/G = 1'6.5" 25 -Mar 03:15 24 284 134 24 1.250 195.5 314.946 1.0000 1.0000 1.2610 1.0361 1.0002 1.0031 1.0320 425.99 1.999 T Switch from Tank #2 C/G = 2'2.5" to 25 -Mar 03:30 24 275 129 24 1.250 188.3 314.946 1.0000 1.0000 1.2610 1.0367 1.0002 1.0031 1.0310 425.79 1.925 Tank #3 O/G = 3' 8.5" Page 10 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' GAS FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE Pf DIFF GAS ORIFICE SQRT Fb Fpb Ftb Fg Ftf Fr Y Fpv C. GAS RATE TIME SIZE TEMP SIZE (a =c 24'SORT(Pf - Hw) REMARKS (dd -mmm hh:mm) (64ths) (psia) (inH2O) ( °f) (inch) (Pf' Hw) (mmscf /d) 25 -Mar 03:45 24 283 120 25 1.250 184.2 314.946 1.0000 1.0000 1.2610 1.0359 1.0003 1.0028 1.0320 425.70 1.881 Switch from Tank #3 C/G = 4'4" to Tank 25 -Mar 04:00 24 289 120 25 1.250 186.2 314.946 1.0000 1.0000 1.2610 1.0357 1.0002 1.0028 1.0320 425.89 1.903 #2 O/G = 2'2.5" 25 -Mar 04:15 24 290 113 24 1.250 181.1 314.946 1.0000 1.0000 1.2610 1.0370 1.0003 1.0026 1.0330 426.49 1 1.853 Switch from Tank #2 C/G = 2'6.5" to 25 -Mar 04:30 24 285 112 23 1.250 178.5 314.946 1.0000 1.0000 1.2610 1.0381 1.0003 1.0026 1.0320 426.79 1.829 Tank #3 O/G = 4'4" 25 -Mar 04:45 24 284 110 23 1.250 177.3 314.946 1.0000 1.0000 1.2610 1.0374 1.0003 1.0026 1.0320 426.43 1.814 Switch from Tank #3 C/G = 4' 11.5" to 25 -Mar 05:00 24 273 107 22 1.250 171.3 314.946 1.0000 1.0000 1.2610 1.0386 1.0003 1.0026 1.0310 426.44 1.753 Tank #2 O/G = 2'6.5" 25 -Mar 05:15 24 274 127 20 1.250 186.8 314.946 1.0000 1.0000 1.2610 1.0404 1.0002 1.0031 1.03101 427.57 1.917 Switch from Tank #2 C/G = 3' 1.5" to 25 -Mar 05:30 24 270 128 25 1.250 186.1 314.946 1.0000 1.0000 1.2610 1.0356 1.0003 1.0032 1.0300 425.01 1.898 Tank #3 O/G = 4' 11.5" I I Page 11 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M - 17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAY. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) Co (bbls) (bbls) (bbls) (bbls) (@ 60 °f) ( %) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 10:51 0 37.5 24 -Mar 10:52 0 37.5 24 -Mar 10:53 0 37.5 24 -Mar 10:54 0 37.6 24 -Mar 10:55 0 37.6 24 -Mar 10:56 0 37.5 24 -Mar 10:57 0 37.4 24 -Mar 10:58 0 37.6 Li ht Flare Pilot 24 -Mar 10:59 0 37.5 24 -Mar 11:00 0 37.6 24 -Mar 11:01 0 37.5 24 -Mar 11:02 0 37.5 24 -Mar 11:03 0 37.6 24 -Mar 11:04 0 37.5 24 -Mar 11:05 0 37.5 24 -Mar 11:06 0 37.6 24 -Mar 11:07 0 1 37.6 24 -Mar 11:08 0 37.5 24 -Mar 11:09 0 37.5 24 -Mar 11:10 0 37.5 Line up to inject Methanol at data header Page 1 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL EIS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAY. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 11:11 0 37.5 24 -Mar 11:12 0 37.5 24 -Mar 11:13 0 37.6 24 -Mar 11:14 1 0 37.6 24 -Mar 11:15 0 37.7 Open Surface Safety Valve 24 -Mar 11:16 0 37.8 Open Wing Valve 24 -Mar 11:17 0 37.8 Start injecting methanol at data header 24 -Mar 11:18 1 0 37.7 24 -Mar 11:19 0 37.8 Open Well to Tank #1 O/G = 0'9.5" on 24 -Mar 11:20 8 37.9 8/64 the Ad'. 24 -Mar 11:21 8 37.8 Gas Flare Lite 24 -Mar 11:22 8 37.9 24 -Mar 11:23 22 38.0 24 -Mar 11:24 22 38.1 Increase to 24/64ths Ad' 24 -Mar 11:25 24 38.1 24 -Mar 11:26 24 38.0 24 -Mar 11:27 24 38.0 24 -Mar 11:28 24 38.1 24 -Mar 11:29 24 38.1 24 -Mar 11:30 24 38.2 Page 2 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606- 10,642' LIQUID FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLIBURTON DATE: 24- Mar - 0211:00 -25- Mar - 0205:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °17 (bbls) (bbls) (bbls) (bbls) (@ 60 °t) ( %) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 11:31 24 38.2 24 -Mar 11:32 24 38.2 24 -Mar 11:33 24 38.2 24 -Mar 11:34 24 38.2 24 -Mar 11:35 24 38.2 24 -Mar 11:36 24 38.1 Increase to 26/64 the Ad' 24 -Mar 11:37 26 38.2 Gas Scrubber pressure at 45 and 24 -Mar 11:38 26 38.2 increasin 24 -Mar 11:39 26 38.3 24 -Mar 11:40 26 38.2 Gas Meter run temperature below zero 24 -Mar 11:41 26 38.4 Increase choke to 28/64 the Ad' 24 -Mar 11:42 28 38.3 24 -Mar 11:43 28 38.3 24 -Mar 11:44 28 38.3 24 -Mar 11:45 28 38.3 0.00 1 BS &W = 0% 24 -Mar 11:46 28 38.2 0.00 0.3 24 -Mar 11:47 28 38.1 0.10 137.6 24 -Mar 11:48 28 38.0 24 -Mar 11:49 28 38.0 1 1 0.00 1 2.1 24 -Mar 11:50 28 37.8 1 0.01 1 15.2 Page 3 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) (%) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 11:51 28 38.1 0.13 1.000 1.012 51.5 0.133 192.1 24 -Mar 11:52 28 38.7 1.16 1.000 1.012 51.5 1.024 1475.1 24 -Mar 11:53 28 32.3 3.07 1.000 1.015 51.5 1.916 2759.4 24 -Mar 11:54 28 29.2 5.11 1.000 1.017 51.5 2.040 2938.1 24 -Mar 11:55 28 27.9 6.43 1.000 1.018 51.5 1 1.318 11898.1 24 -Mar 11:56 28 24.0 8.54 1.000 1.020 51.5 2.108 3035.41 1 24 -Mar 11:57 28 20.3 10.82 1.000 1.022 51.5 2.278 3279.9 24 -Mar 11:58 28 19.9 13.01 1.000 1.022 51.5 2.190 3154.1 24 -Mar 11:59 28 22.4 14.72 1.000 1.021 51.5 1 1.713 12466.7 24 -Mar 12:00 28 27.3 16.36 1.000 13.34 1.018 51.5 1.636 2355.6 BS &W = 0% 24 -Mar 12:01 28 30.1 18.09 1.000 1.016 51.5 1.728 2488.3 24 -Mar 12:02 28 30.4 19.80 1.000 1 1 1.016 51.5 1.711 2463.2 24 -Mar 12:03 28 30.6 21.57 1.000 1.016 51.5 1 1.772 12551.5 24 -Mar 12:04 28 31.2 23.36 1.000 1.016 51.5 1.791 2579.3 24 -Mar 12:05 28 31.9 25.09 1.000 1.016 51.5 1.733 2495.6 24 -Mar 12:06 28 32.5 26.77 1.000 1.015 51.5 1.681 2421.3 24 -Mar 12:07 28 33.0 28.44 1.000 1.015 51.5 1 1.663 2395.3 24 -Mar 12:08 28 33.4 29.96 1 1.000 1.015 51.5 1.527 2198.31 1 24 -Mar 12:09 28 34.0 31.39 1.000 1.014 51.5 1.425 2052.5 24 -Mar 12:10 28 34.7 32.77 1.000 1.014 51.5 1 1.386 1995.8 Page 4 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BU RTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney 0 BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °t) (bbls) (bbls) (bbls) (bbls) (@ 60 °t) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 12:11 28 35.2 34.25 1.000 1.014 51.5 1.473 2120.7 24 -Mar 12:12 28 35.5 35.81 1.000 1.014 51.5 1.559 2244.5 24 -Mar 12:13 28 35.8 37.32 1.000 1.013 51.5 1.510 2173.9 24 -Mar 12:14 28 36.1 38.84 1.000 1.013 51.5 1.519 2187.81 1 Vac Truck returned to location 24 -Mar 12:15 28 36.4 40.16 1.000 1.013 51.5 1.325 1907.6 1 BS &W = 0% 24 -Mar 12:16 28 36.5 41.38 1.000 1.013 51.5 1.221 1758.8 24 -Mar 12:17 28 36.6 42.43 1 1.000 1 1 1.013 51.5 1.053 11516.4 24 -Mar 12:18 28 36.8 43.26 1.000 1.013 51.5 0.821 1182.5 24 -Mar 12:19 28 37.1 44.53 1.000 1.013 51.5 1.271 1830.3 24 -Mar 12:20 28 37.3 45.99 1.000 1.013 51.5 1.468 2113.7 24 -Mar 12:21 28 37.0 47.49 1.000 1.013 51.5 1.494 2151.1 24 -Mar 12:22 28 36.5 48.80 1.000 1.013 51.5 1.315 1893.2 24 -Mar 12:23 28 36.2 49.80 1.000 1.013 51.5 0.993 1430.3 24 -Mar 12:24 28 36.2 50.90 1.000 1.013 51.5 1.103 1588.9 24 -Mar 12:25 28 36.5 52.39 1.000 1.013 51.5 1.486 2139.4 24 -Mar 12:26 28 36.8 53.70 1.000 1.013 51.5 1.316 1894.9 24 -Mar 12:27 28 37.0 54.58 1.000 1.013 51.5 0.875 1259.6 24 -Mar 12:28 28 37.1 55.56 1.000 1.013 51.5 0.981 1412.8 24 -Mar 12:29 28 36.8 56.75 1.000 1.013 51.5 1 1.196 1722.1 24 -Mar 12:30 28 36.4 58.07 1.000 51.26 1.013 51.5 1.317 1895.9 BS &W = 0.25% Water Page 5 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) ( %) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 12:31 28 36.1 59.08 j 1.000 1.013 51.5 1.012 1457.7 24 -Mar 12:32 28 36.1 60.20 1.000 1.013 51.5 1.117 1607.8 24 -Mar 12:33 28 36.4 61.66 1.000 1.013 51.5 1.465 2108.9 24 -Mar 12:34 28 36.6 62.85 1.000 1.013 51.5 1 1.185 1706.7 24 -Mar 12:35 28 36.5 63.95 1.000 1.013 51.5 1.106 1593.1 24 -Mar 12:36 28 36.2 65.02 1.000 1.013 51.5 1.069 1538.9 24 -Mar 12:37 28 35.7 66.07 1.000 1.013 51.5 1.047 1507.4 24 -Mar 12:38 28 35.1 67.27 1.000 1.014 1 51.5 1 1.200 1727.6 24 -Mar 12:39 28 34.4 68.39 1.000 1.014 51.5 1.118 1609.9 24 -Mar 12740 28 34.0 69.50 1.000 1.014 51.5 1.112 1601.2 24 -Mar 12:41 28 33.7 70.51 1.000 1.015 51.5 1.010 1455.0 24 -Mar 12:42 28 33.5 71.39 1.000 1.015 51.5 0.882 1269.8 24 -Mar 12:43 28 33.1 72.19 1.000 1.015 51.5 0.794 1143.2 24 -Mar 12:44 28 32.6 72.94 1.000 1.015 51.5 1 0.755 1086.9 24 -Mar 12:45 28 32.0 73.76 1.000 1.015 51.5 1 0.823 1185.6 24 -Mar 12:50 28 31.0 79.08 1.000 1.016 1 51.5 5.313 1530.1 24 -Mar 12:55 28 33.5 84.65 1.000 1.015 51.5 5.572 1604.7 Switch from Tank #1 CG = 2'9.5" to 24 -Mar 13:00 28 35.2 89.19 1.000 77.93 1.014 51.5 4.542 1308.0 Tank #2 O/G = 2'8.5" 24 -Mar 13:05 28 35.5 94.26 1.000 1.014 51.5 5.069 1460.0 1 Start injecting Defoamer at data header. 24 -Mar 13:10 1 28 1 35.1 99.05 1.000 1.014 51.5 1 4.787 11378.7 Outer Annulus = 0 psi Page 6 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney M BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) Vf) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) N (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 13:15 28 35.1 103.59 1.000 1.014 51.5 4.545 1309.0 13S &W = 2% Water 24 -Mar 13:20 28 35.0 108.30 1.000 1.014 51.5 4.706 1355.4 24 -Mar 13:25 28 35.2 112.35 1.000 1.014 51.5 4.054 1167.6 Oil Gravity = 22.6 @ 48 deg F. 24 -Mar 13:30 28 353 116.80 1.000 103.25 1.013 51.5 4.443 1279.6 Corrected = 23.3 @ 60 deg F. 24 -Mar 13:35 28 36.0 121.38 1.000 1.009 23.3 4.586 1320.6 24 -Mar 13:40 28 36.4 125.90 1.000 1.009 23.3 4.515 1300.41 1 24 -Mar 13:45 28 36.6 130.19 1.000 1.009 23.3 4.298 1237.7 BS &W = 2% Water 24 -Mar 13:50 28 36.7 134.92 1.000 1.009 23.3 4.722 1360.0 24 -Mar 13:55 28 37.1 139.11 1.000 1.009 23.3 4.196 11208.6 Switch from Tank #1 CG = 4' 1" to 24 -Mar 14:00 28 37.3 143.73 1.000 129.19 1.009 23.3 4.621 1330.8 Tank #2 O/G = 3' 11.75" 24 -Mar 14:05 28 37.5 147.92 1.000 1.009 23.3 4.184 1205.0 24 -Mar 14:10 28 37.7 152.78 1.000 1.009 23.3 4.858 1399.1 24 -Mar 14:20 28 37.8 161.81 1.000 349.1 1.000 1.009 23.3 9.036 1301.2 Switch from Tank #2 CG = 5' 2.5" to 24 -Mar 14:30 28 38.1 170.56 1.000 349.1 1.000 153.78 1.009 23.3 8.752 1260.4 Tank #1 O/G = 4' 1" 24 -Mar 14:40 28 38.0 177.83 1.000 349.1 1.000 1.009 23.3 7.266 1046.3 24 -Mar 14:50 28 38.4 188.32 1.000 349.1 1.000 1.008 23.3 10.495 11511.3 24 -Mar 15:00 28 38.7 197.90 1.000 349.1 1.000 175.87 1.008 23.3 9.577 1379.1 13S &W = 0% Water 24 -Mar 15:10 28 36.4 207.43 1.000 349.1 1.000 1.009 23.3 9.525 1371.7 24 -Mar 15:20 28 1 34.6 215.77 1.000 349.1 1.000 1.010 23.3 1 8.342 1201.3 24 -Mar 15:30 28 35.1 225.27 1.000 349.1 1.000 175.87 1.010 23.3 9.506 11368.91 1 13S &W = 1 % Water Page 7 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAY. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) (%) (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 24 -Mar 15:40 28 33.8 232.21 1.000 349.1 1.000 1.010 23.3 6.934 998.5 24 -Mar 15:50 28 35.6 240.721 1.000 349.1 1.000 1.010 23.3 8.507 1225.0 Switch from Tank #1 CG = 6' 2.25" to 24 -Mar 16:00 28 35.5 249.25 1.000 349.1 1.000 209.21 1.010 23.3 8.539 1229.6 Tank #2 O/G = 5' 10.5" 24 -Mar 16:10 28 35.8 259.11 1.000 349.1 1.000 1.010 23.3 9.851 1418.6 24 -Mar 16:20 28 34.5 267.09 1.000 349.1 1.000 1 1.010 23.3 7.986 1150.01 1 24 -Mar 16:30 28 36.4 275.54 1.000 349.1 1.000 241.30 1.009 23.3 8.451 1216.9 24 -Mar 16:40 26 36.3 282.91 1.000 349.1 1.000 1.009 23.3 7.369 1061.2 Spar a vessel 24 -Mar 16:50 26 36.7 286.33 1.000 349.1 1.000 1 1.009 23.3 3.423 1 492.9 Switch from Tank #1 C/G = 6'98.5" to 24 -Mar 17:00 26 38.1 289.36 1.000 349.1 1.000 253.38 1.009 23.3 3.024 435.4 Tank #2 O/G = 7'5.75" 24 -Mar 17:10 26 38.3 289.38 1.000 349.1 1 1.000 262.14 1.009 23.3 0.017 2.4 24 -Mar 17:20 26 33.0 298.80 1.000 349.1 1.000 1.011 23.3 9.425 1357.2 Switch from Tank #2C /G= 7'11 "to 24 -Mar 17:30 1 Tank #1 O/G = 6'9.5" 24 -Mar 17:40 24 -Mar 17:50 22 31.8 298.80 1.000 349.1 1.000 1.011 23.3 Switch from Tank #1 C/G = 6' 10.5" to 24 -Mar 18:00 22 30.4 300.33 1.000 349.1 1.000 263.80 1.012 23.3 1.527 219.9 Tank #2 O/G = 7' 11" 24 -Mar 18:10 24 29.5 305.33 1.000 349.1 1.000 1.012 23.3 5.000 720.0 24 -Mar 18:20 24 25.1 309.92 1.000 349.1 1 1.000 1.014 23.3 4.593 661.4 Switch from Tank #2 C/G = 8'8" to 24 -Mar 18:30 24 20.2 315.05 1.000 349.1 1 1.000 278.81 1.016 23.3 5.130 738.7 Tank #1 O/G = 6'9.5" 24 -Mar 18:40 24 15.3 320.44 1.000 349.1 1.000 1.018 23.3 5.391 776.3 i 24 -Mar 18:50 24 12.1 324.98 1.000 1 1.019 23.3 4.542 1 654.0 Page 8 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: 1M-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) Switch from Tank #1 C/G = 7'9" to 24 -Mar 19:00 24 15.1 333.00 1.000 349.1 1.000 296.31 1.018 23.3 8.019 1154.7 Tank #2 O/G = 8'8" 24 -Mar 19:10 24 17.5 341.95 1.000 349.1 1.000 1.017 24.3 8.947 1288.3 24 -Mar 19:20 24 16.8 342.81 1.000 349.1 1.000 1.017 24.3 0.863 124.3 Switch from Tank #2 C/G = 9'4.5" to 24 -Mar 19:30 24 24.5 347.33 1.000 349.1 1.000 310.48 1.014 24.3 4.515 650.2 Tank #1 O/G = 7'9" 24 -Mar 19:40 24 32.3 351.52 1.000 349.1 1.000 1.011 24.3 4.192 603.6 24 -Mar 19:50 24 35.7 358.68 1.000 349.1 1.000 1.010 24.3 7.162 1031.3 Switch from Tank #1 C/G = 8'6" to Tank 24 -Mar 20:00 24 32.6 365.22 1.000 349.1 1.000 325.48 1.011 24.3 6.536 1 941.2 1 #2 O/G = 9'4.5" 24 -Mar 20:10 24 34.2 369.12 1.000 349.1 1.000 1.010 24.3 3.903 562.1 24 -Mar 20:20 24 33.8 379.02 1.000 349.1 1.000 1.010 24.3 9.906 1426.4 Switch from Tank #2 C/G = 10' to Tank 24 -Mar 20:30 24 33.1 386.03 1.000 349.1 1.000 337.98 1.011 24.3 7.003 1008.5 #1 O/G = 8'6" 24 -Mar 20:40 24 34.6 388.77 1.000 349.1 1.000 1.010 24.3 2.742 1 394.8 24 -Mar 20:50 24 35.9 390.93 1.000 349.1 1.000 339.65 1.010 24.3 2.161 311.2 Switch from Tank #1 C/G = 8'7" to 24 -Mar 21:00 1 Tank #2 O/G = 10' 24 -Mar 21:10 Open Surface Safety Valve Open choke 24 -Mar 21:20 on 16/64 the Ad' at 21:22 Switch from Tank #2 C/G = 10' 11.5" to 24 -Mar 21:30 20 29.2 403.51 1.000 349.1 1.000 358.82 1.012 24.3 Tank #1 O/G = 7'9" 24 -Mar 21:40 24 29.4 406.26 1.000 349.1 1.000 1.012 24.3 2.742 394.8 24 -Mar 21:50 24 29.4 407.35 1.000 349.1 1.000 1.012 24.3 1.092 157.2 Switch from Tank #1 C/G = 9' 3" to 24 -Mar 22:00 24 29.4 411.17 1.000 349.1 1.000 372.16 1.012 24.3 3.823 550.6 Tank #2 O/G = 10' 11.5" 24 -Mar 22:10 24 29.5 417.49 1.000 349.1 1.000 1.012 24.3 6.314 909.7 Page 9 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PHILLIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) (°T] (bbls) (bbls) (bbls) (bbls) (@ 60 °f) ( %) (bbls) (bbls /d) (bbis) (bbls /d) (ppm) 24 -Mar 22:20 24 29.5 424.14 1.000 349.1 1.000 1.012 24.3 6.656 958.5 Switch from Tank #2 C/G = 11'8.5" to 24 -Mar 22:30 24 29.7 431.67 1.000 349.1 1.000 387.16 1.012 24.3 7.528 1084.0 Tank #1 O/G = 9'3" 24 -Mar 22:40 24 29.7 435.60 1.000 349.1 1.000 1.012 24.3 3.925 565.2 Outer Annulus = 0 psi 24 -Mar 22:50 24 29.8 442.75 1.000 1 349.1 1.000 1.012 24.3 7.158 1030.8 Switch from Tank #1 C/G = 10' to Tank 24 -Mar 23:00 24 29.9 450.00 1.000 349.1 1.000 402.16 1.012 24.3 7.244 1043.2 #2 O/G = 11'8.5" 24 -Mar 23:10 26 30.0 457.05 1.000 349.1 1.000 1.012 24.3 7.050 1015.3 Increase choke to 26/64 the Ad' at 23:07 24 -Mar 23:20 26 30.2 464.78 1.000 349.1 1.000 1.012 24.3 7.730 11113.11 1 Switch from Tank #2 C/G = 12'6.5" to 24 -Mar 23:30 26 30.6 472.77 1.000 349.1 1.000 418.83 1.012 24.3 7.992 1150.9 ITank #1 O/G = 10' 24 -Mar 23:40 26 31.2 480.70 1.000 349.1 1.000 1.011 24.3 7.926 1141.3 24 -Mar 23:50 26 31.5 488.39 1.000 349.1 1.000 1.011 1 24.3 1 7.698 1108.6 Switch from Tank #1 C/G = 10' 10" to 25 -Mar 00:00 26 32.0 495.89 1.000 349.1 1.000 435.50 1.011 24.3 7.497 1079.6 Tank #3 O/G = 1'1" 25 -Mar 00710 26 32.6 501.75 1.000 349.1 1.000 1.011 24.3 5.860 1 843.9 25 -Mar 00:20 26 33.0 508.98 1.000 349.1 1.000 1.011 24.3 7.228 1040.8 Switch from Tank #3 C/G = 1' 10.5" to 25 -Mar 00:30 26 33.3 516.43 1.000 349.1 1.000 45134 1.011 24.3 7.453 1073.2 Tank #1 O/G = 10' 10" 25 -Mar 00:40 26 33.6 523.58 1.000 349.1 1.000 1.010 1 24.3 7.151 1029.8 25 -Mar 00:50 26 33.9 534.271 1.000 349.1 1.000 1.010 24.3 10.682 1538.2 Switch from Tank #1 C/G = 11' 10.5" to 25 -Mar 01:00 26 33.6 543.59 1.000 349.1 1.000 472.18 1.010 24.3 9.325 1342.8 Tank #3 O/G = 1' 10.5" 25 -Mar 0 1: 10 26 34.1 553.47 1.000 349.1 1.000 1.010 24.3 9.877 1422.3 25 -Mar 01:20 26 34.5 562.86 1.000 349.1 1.000 1.010 24.3 9.395 1352.8 Switch from Tank #3 C/G = 2' 11.5" to 25 -Mar 01:30 26 34.7 572.66 1.000 349.1 1.000 493.85 1.010 24.3 9.802 1411.5 Tank #1 O/G = 11'10.5" Page 10 CUSTOMER: Phillips Alaska, Inc. PERFORATION INTERVAL: 10,606'- 10,642' LIQUID FLOW DATA SHEET WELL NAME: IM-17 TEST No. Test #1 - Extended Flow PNItIIPS HALLI BURTON DATE : 24- Mar -02 11:00 - 25- Mar -02 05:30 CUSTOMER REP.: Mark Chaney BASE: Anchorage, AK RIG: Wellhead HES SUPERVISOR: Craig Convey DATE & CHOKE OIL OIL OIL OIL OIL OIL WATER OIL OIL OIL BS &W OIL OIL WATER WATER SALINITY TIME SIZE TEMP LOW LOW HIGH HIGH TANK TANK K Wf API FLOW FLOW FLOW FLOW FLOW Mf FLOW Mf FACTOR FACTOR GRAV. INTERVAL INTERVAL REMARKS (dd -mmm hh:mm) (64ths) ( °f) (bbls) (bbls) (bbls) (bbls) (@ 60 °f) M (bbls) (bbls /d) (bbls) (bbls /d) (ppm) 25 -Mar 01:40 26 34.7 582.11 1.000 349.1 1.000 1.010 24.3 9.444 1360.0 25 -Mar 01:50 26 34.9 591.33 1.000 349.1 1.000 1.010 24.3 9.216 1327.1 Decrease choke to 24/64 the Adj at 25 -Mar 02:00 24 34.5 600.97 1.000 349.1 1.000 513.85 1.010 24.3 9.647 1389.2 01:59 Complete Transfer from Tank #2 (C /G = 25 -Mar 02:10 24 34.0 607.93 1.000 349.1 1.000 1.010 24.3 1 6.958 1002.0 1'6.5") Fluid Transfer = 220.04 bbls 25 -Mar 02:20 24 33.7 614.71 1.000 349.1 1.000 1.010 24.3 6.781 976.5 Switch from Tank #3 C/G = to Tank #1 25 -Mar 02:30 24 33.4 620.48 1.000 349.1 1.000 528.861 1.011 24.3 1 5.771 1 831.1 0/13 = 12'10.5" 25 -Mar 02:45 24 33.1 627.06 1.000 349.1 1.000 1.011 24.1 9.868 947.4 Switch from Tank #1 C/G = 13'7.5" to 25 -Mar 03:00 24 33.0 633.68 1.000 349.1 1.000 543.86 1.011 24.1 9.920 952.4 Tank #2 O/G = 1'6.5" 25 -Mar 03:15 24 32.9 639.49 1.000 349.1 1.000 1.011 24.1 8.728 837.9 Switch from Tank #2 C/G = 2'2.5" to 25 -Mar 03:30 24 32.9 645.20 1.000 349.1 1.000 557.19 1.011 24.1 1 8.563 822.1 Tank #3 O/G = 3'8.5" 25 -Mar 03:45 24 32.9 650.70 1.000 349.1 1.000 1.011 24.1 8.247 791.7 Switch from Tank #3 C/G = 4'4" to Tank 25 -Mar 04:00 24 32.9 656.21 1.000 349.1 1.000 569.70 1.011 24.1 8.266 793.5 #2 O/G = 2'2.5" 25 -Mar 04:15 24 32.5 658.55 1.000 349.1 1.000 1.011 24.1 3.507 336.6 Switch from Tank #2 C/G = 2'6.5" to 25 -Mar 04:30 24 33.3 658.55 1.000 349.1 1.000 576.37 1.011 24.1 0.800 76.8 Tank #3 O/G = 4'4" 25 -Mar 04:45 24 33.7 658.55 1.000 349.1 1.000 1.010 24.1 0.722 1 69.3 Switch from Tank #3 C/G = 4' 11.5" to 25 -Mar 05:00 24 33.7 658.55 1.000 349.1 1.000 588.87 1.010 24.1 5.799 556.7 Tank #2 O/G = 2'6.5" 25 -Mar 05:15 24 33.8 658.55 1.000 349.1 1.000 1.010 24.1 5.912 567.5 Switch from Tank #2 C/G = 3' 1.5" to 25 -Mar 05:30 24 29.4 658.55 1.000 349.1 1.000 600.54 1.012 24.1 7.328 703.5 Tank #3 O/G = 4' 11.5" Page 11 Phillips Alaska, Inc. 1M - 17 Test #1 - Extended Flow I �u�rs 70 2500 60 ❑ � ° ❑ ❑ ❑ 2000 o ❑ 50 0 00 ❑ >C;0<0 0 0 0 o 00 ba 40 1500 y bta CL o E c a� F- 06 d 30 0 --1000S + 44-11 s U + + + + + + 4 20 500 10 0 A A a A A a, A - 0 O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O c') O M O M O M O M O M O M O M O M O M O c? O M O M O CO O M O M O M O CO O M O CO O O N N M M �T V CO CO f� I� a0 0 0 0 0 <— N N M M O O N N M M V tf) N N N N N N N N Time 24- Mar -02 + CHOKE ❑ WHT O WHP A CSG 25- Mar -02 Wellhead Plot rxuuvs Phillips Alaska, Inc. 1M - 17 Test #1 - Extended Flow 350 40 ° o ° 40 6A '&' 00 0 300 35 0 0 0 o n p o o° o o 0 0 0 0 oo 0 o 30 ° 250 0 rn 0° o ° M 0 Q ° 0 0 0 6 25 00 0 200 ° o o � m p o 0 - 20 3 IL C o 0 150 a, Cu a 15 m cn o 0 100 0 10 50 5 0 - 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O N N 66 M 4 4 L6 L6 C6 C6 ti 66 00 6 6) O O .- r- N N M M O O N N M &i 4 4 6 L6 .- e- N N N N N N N N Time 24- Mar -02 25- Mar -02 A PRES. O TEMP. Separator Plot 0 Phillips Alaska, Inc. 1M-17 Test #1- Extended Flow a I 3.0 3000 2.5 2500 A 0 2.0 o A A 2000 A r 0 �p D c y � Q E o 1.5 1500 �a a 1.0 1000 D 0.5 500 0 0 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O CO O M O M O M O M O M O M O M O M O M O M O M O M O M O M O M O M O M O M O M 0 0 N N M M L6 L6 C6 C6 I� ti 60 60 0 0 0 0 6V N M M O O N N M M 4 6 Lb — N N N N N N N N Time 24- Mar -02 A GAS X OIL TANK O WATER TANK 25- Mar -02 Production Plot ,Phillips Alaska, Inc. IM-17 Test #1 - Extended Flow P "lairs 6 100.0 90.0 5 80.0 70.0 4 m m U 60.0 N Qo 13 11 11 a 3 50.0 m O 40.0 U) tv 2 30.0 Q 13 20.0 1 10.0 0 Dom 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O M O M O M o c? O M O M O 1 O M O M O M O M O CO O CO O CO O CO O CO O CO O M O CO O M O O •- — N N CO M 'IT "t LO L6 CO CO Il- ti 00 60 6 6 0 0 N N M M O o N N M M 4 4Li� L = N N N N N N N N Time 24- Mar -02 ' 25- Mar -02 ❑ GOR O BS& W Production Ratio's Phillips Alaska, Inc. 1M-17 Test #1- Extended Flow 1.4 700.0 1,2 600.0 D 1.0 0 500.0 0 0 0 o� 0.8 400.0 E �� c E o� s N � 0.6 300.0 in m o� 0.4 200.0 o� o� 0.2 0 100.0 0 00 w 0.0 0.0 O O O O O o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O M O M O M O M O M O M O M O M O M O M O M O M O M O M O Co O M O Co O Co O M O co O O N N Co M It '�T LD Lo CO CO h f-- 00 00 0) M 0 0 N N M M O O N N M M 4 4 Ln L6 = N N N N N N N N Time 24- Mar -02 A GAS X OIL TANK O WATER TANK 25- Mar -02 Cummulatives Page 1 of 1 Maunder, Thomas E (DOA) From: Allsup- Drake, Sharon K [Sharon. K.Allsup- Drake @conocophillips.com] Sent: Friday, October 15, 2010 9:34 AM To: Maunder, Thomas E (DOA) Cc: Alvord, Chip; NSK Well Integrity Proj Subject: FW: 1 M -17 frac Attachments: 2010101512303430. pdf Tom — Attached is another report for the frac work on 3/21/2002 with more information. Thank you, Sharon 263 -4612 From: Allsup- Drake, Sharon K Sent: Friday, October 15, 2010 9:31 AM To: Allsup- Drake, Sharon K Subject: 10/25/2010 Well Service Report 1M -17 ' DRIL SUPP ORT- CA _ ODELL -- 3/21/2002_ U nknown INITIAL T/UO = 940 / 2600 - - - -- - - - -- - -- -- - -- 0 FINAL TWO — 0 / 500 / Initial & 150, Arr/Dep comment: Final EXPLORATION WELL NO Field: KUPARUK RIVER UNIT Pressures: s WELLHOUSE, LINES --HOOKED UP, ETC. LIMPED C SAND FRAC. SAW TSO — 25 MINUTES INTO JOB-, HAD NWBSO W/ 9 PPA ON PERFS. 90M# BEHIND PIPE, 53% OF DESIGN. LEFT . 28M# IN WE LLBORE. [Frac- Refrac] 11:00 AM DS CREW ON LOCATION. MAKE GEL FOR FRAC JOB. 11:45 AM PRE -JOB SAFETY MEETING. (14 DS, 3 APC,1 PAI). JOB REVIEW, HALLIBURTON ON LOCATION. 12:00_ PM PT LINES TO 9000 PSI. PRIME UP AND WARM UP LINES. SET TEESAVER. - - - -- - -- -- -- — - - — - - -- — - - - -- - - -- -- -- --- ..- - -- -- - - .. -.. - _- PUMP FRAC. 230 BBL 30# LG GEL, 20 BPM. 5100 PSI. 100 BBLS 2 PPA STAGE, 20 BPM, 4900 PSI. 266 BBLS 2 -6 PPA RAMP STAGE, 5470 PSI. 133 01:05 PM BBLS 6 -8 PPA RAMP, 20 BPM, 6000 PSI. 150 BBLS 8 -10 PPA RAMP, 20 BPM, 6200 PSI. GOT 23 BBLS OF 10 PPA FLAT INTO WELLBORE, HAD NWBSO.9 PPA ON PERFS, 90344# BEHIND PIPE. SAW TSO —25 MINUTES INTO JOB. SHUT DOWN DUE TO NWBSO.A FLUSH LINES, RIG DOWN DS :02:05 PM EQUIPMENT. RECOVERED ALL TREESAVER RUBBERS. WILL TENT WELLHEAD AND INSTALL HEATER. 03:45 PM DS RIGGED OFF OF WELL, WELL SECURED. 789 BBLS FRESH WATER IN 30# XL LG GEL. Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, October 15, 2010 9:27 AM To: 'Allsup- Drake, Sharon K Cc: Alvord, Chip; NSK Well Integrity Proj Subject: RE: 1 M -17 frac Thanks Sharon, Is there detailed testing information for the period - March 23 - March 27? Tom Maunder, PE AOGCC From: Allsup- Drake, Sharon K [mailto: Sharon. K.Allsup- Drake @conocophillips.com] Sent: Friday, October 15, 2010 9:04 AM To: Maunder Thomas E DOA Cc: Alvord, Chip; NSK Well Integrity Proj Subject: FW: 11VI-17 frac Tom - Attached is more details about the frac on 3/20/2002 you requested. You also wanted to know if there is any other work accomplished since 12/22/2005 and the inspection on 4/21/2010. There isn't any documented write -up about any more work during this time period. If you have any other questions about this well, please feel free to call. Thank you, Sharon 263 -4612 10/25/2010 Well Service Report job Scope 1M -17 — DRI LLING SUPP CAPITAL - -- _ - - - - - ODELL - -- 3/20 Unknown INITIAL T/I/O =1250 / 0 / 0 FINAL T/I /O =1200 / 500 / Initial & 0, Arr/Dep comment: FRAC Final EQUIPMENT RIGGED UP Field: KUPARUK RIVER UNIT Pressures: ON WELL TO COMPLETE JOB TOMORROW. PUMPED BREAKDOWN AND DATAFRAC WITH E -LINE IN THE WELL FOR TEMPERATURE BASELINE AND WARM -BACK PROFILES FOR FR H EIGHT DE [Frac- Refrac] HES SL RIGGED OFF OF WELL, FINISH RIGGING UP APC FLOW -CROSS 10:30 AM AND HARDLINE. PT LINE, GREASE COMPANION VALVE. PT HALLIBURTON TESTING LINE TO WELLHEAD. MIRU DS EQUIPMENT (HARDLINE AND TREESAVER). 12:00 PM RIG UP SWS E -LINE EQUIPMENT. PRE -JOB SAFETY MEETING (11 DS, 4 SWS, 4 APC, 1 PAI) MUSTER AREA, 04:15 PM JOB REVIEW, WIRELINE CONCERNS, HALLIBURTON PERSONNEL ON LOCATIO 04:40 PM RIG UP E -LINE TO TOP OF TREESAVER. 05:15 PM WARM UP AND PRIME UP PUMPS. GET SEAL ON E -LINE LUBRICATOR, SET TREESAVER. PT LINES TO 8500 PSI, GOOD TEST. RIH WITH SWS E -LINE FOR BASELINE TEMP PASS. LOG DOWN TO 10721', 06:15 PM SAW TEMPERATURE FLUCTUATION ACROSS THE PERFS. MADE UP AND DOWN PASSES TO VERIFY TEMP FLUCTUATION AND TIE -IN. PARK TOOLSTRING WITH TOP AT 10668'. PACKOFF FOR PUMPING. 08:20 PM RESTART PUMPS, LINE OUT FOR - BREAKDOWN. PUMP BREAKDOWN, 176 BBLS LINEAR 20# GEL. HAD TO REDUCE RATE 08:30 PM EARLY TO STAY BELOW PARTING STRESS OF E -LINE. SAW BREAKDOWN AT 30 BPM, 6770 PSI TO 5600 PSI. PERFORMED SDT, XS FRIC =1130 PSI @ 30 BPM, —550 PSI @ 20 BPM. MAKE GEL FOR DATAFRAC. PUMP DATAFRAC. DISPLACE TUBING AT 5 BPM, PUMP 150 BBL 304 LG 09:15 PM GEL AT 20 BPM. FLUSHED WITH LINEAR GEL AND FREEZE PROTECTED WITH —30 BBLS DIESEL. FWHTP = 5338 PSI. SHUT DOWN, PERFORM DECLINE ANALYSIS. ISIP = 2187 PSI, FG = 0.78 PSI/FT. TC = 24 MIN, PC =1841 PSI. EFFC = 61 %. HAD PRESSURE TRANSDUCER DROP OUT AFTER CLOSURE, SWITCHED TO SECOND 09 :40 PM TRANSDUCER, MONITORED PRESSURE DECLINE. WILL USE BOTTOMHOLE PRESSURE DATA FOR DATAFRAC ANALYSIS. 1030 PM SHUT -IN DS HARDLINE TO WELL TO BEGIN TEMPERATURE LOGGING PASSES. 10:45 PM MAKE 1 ST PASS TO 9500', LOG BACK TO BOTTOM. TAG BOTTOM AT 10730'. START SECOND WARMBACK LOG. VERY STICKY ON BOTTOM, PULLED TO 2700# TO GET MOVING. PULLING VERY HEAVY BELOW PERFS DUE TO GEL IN RATHOLE. LOGGED TO 9500'. 00:30 MADE THIRD LOGGING PASS FROM 10700' TO 10,000' AT 80 FPM 01:30. LOGGED FROM 10700' TO 11:30 PM 10,000' AT 80 FPM. 02:30 MADE FINAL LOGGING RUN FROM 10700' TO 10,000'. TEMPERATURE RESPONSE INCONCLUSIVE, UNABLE TO SEE ANY RESPONSE BELOW ZONE DUE TO INABILITIY TO LOG IN RATHOLE WITH THICK GEL. POOH, RIG DOWN SWS. 05:00 SWS OFF OF WELL WELL TEMPORARILY SECURED, FRAC WILL BE COMPLETED LATER TODAY. 75 BBLS DIESEL 350 BBLS SEAWATER IN LINEAR AND XL'D GEL. Page 1 of �YA Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 06, 2010 10:26 AM To: 'NSK Well Integrity Prof Cc: 'Allsup- Drake, Sharon K Subject: RE: 1M -17 (201 -230) Attachments: 1 M- 17_201- 230_summary_report.pdf MJ /Perry, Sorry it has taken a couple of days to get back. Here is the summary report that Sharon filed with the 404. 1 have annotated where items are missing. I have also copied this to Sharon. Thanks to both of you for the assistance here. Tom Maunder, PE AOGCC F m: NSK Well Integrity Proj [mailto: N 1878@conocophillips.com] In ' •Thursday, September 30, 2010 5:03 PM To: Ma der, Thomas E (DOA) Subject: E: 1M -17 (201 -230) 1 also asked Sh on to revisit. She is out until Monday. MJ From: Maunder, Thomas (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, September 0, 2010 2:24 PM To: NSK Well Integrity Proj Subject: RE: 1M -17 (201 -230) MJ, I will check the document again. As I rem ber, there were ly a few pages of information filed and the testing am familiar with would have resulted in man ore pages an that. Tom From: NSK Well Integrity Proj [mailto:N1878 onoco illips.com] Sent: Thursday, September 30, 2010 2:22 To: Maunder, Thomas E (DOA) Subject: RE: 1M -17 (201 -230) Tom, Was the testing information t in Sharon's 10 -404? I'll ask her to re send it if i asn't, as well as a 407. MJ From: M der, Thomas E (DOA) [ mailto:tom.maunder@alaska.gov] Sent: ursday, September 30, 2010 11:00 AM To: K Well Integrity Proj . Schwartz, Guy L (DOA); Allsup- Drake, Sharon K; McMains, Stephen E (DOA) ubject: RE: 1M -17 (201 -230) 10/25/2010 I M -17 Well Events Summary � –..` DATE SUMMARY D � �' _ � �'' � 2/3 DRIFTED TBG W/ 22'X 2.65" DUiv,,AY GUN TO 10,810' WLM. SET DV @ 10,�3y3' RKB, TESTED CSG 3000 PSI, OK. ATTEMPTED 3000 PSI TBG TEST; LOST 10% IN 5 MIN, REPEAT TESTS, SAME RESULT. [PT Tbg -Csg, Tag] 2/14/02 PRESSURE TESTED TBG TO 3500 PSI AND IA TO 3000 PSI . LOST LESS THAN 5% OF PRESSURE IN 30 MINS ON BOTH TESTS. [PT Tbg -Csg] 2/15/02 COMPLETED SCMT CBL, LOGGED CEMENT 10775' UP TO 10461'. 0 PSI PASS (MARGINAL) AND 2400 PSI PASS (GOOD). ON PRESSURE PASS MAJOR CHANGE IN QUALITY OF CEMENT OVER 0 PSI PASS.-- LOG TEMP PASS 10775' TO 10400'. TAGGED FILL @ 10780'. 2/16/02 PERFORATED C SAND INTERVAL 10606' TO 10642'W/ 2.5 HSD, 6SPF, 2506 HYPERJET CHGS, 60 DEG PHASING (TOTAL OF 36 FT IN 2 RUNS) - PENTRATION IS 7.0 IN - - -- ENTRANCE IS .42 TOTAL OF 271 SHOTS. OBTAINED SBHP OF 3887 PSI W/ BHT OF 155 DEG @ 10624', ALSO MADE A GRADIENT STOP @ 10524'. [Perf, Pressure Data] 3/19/02 TAGGED @ 10711 SLM, EST. 69' RATHOLE. PIT TEST EQUIPMENT 4500 PSI_ SET VALVE CATCHER @ 10436' RKB. CONTINUE WSR 03/20/2002. IN PROGRESS. [Tag, Hydrates -Ice] 3/20/02 SET 1 "" SPARTEC SPM GAUGE @ 10393' RKB. SET 1 "" PETRADAT SPM GAUGE @ 9906' RKB. IA P/T'D TO 3000 PSI, GOOD. CATCHER PULLED @ 10436' RKB. [GLV, Pressure Data, PT Tbg - Csg] 3/20/02 PUMPED BREAKDOWN AND DATAFRAC WITH E -LINE IN THE WELL FOR TEMPERATURE BASELINE AND WARM -BACK PROFILES FOR FRAC HEIGHT DETERMINATION. [Frac - Refrac] .� Lc "V ` A'. ? 3/21/02 PUMPED C SAND FRAC. SAW TSO -- 25 MINUTES INTO JOB, HAD NWBSO W/ 9 PPA ON PERFS. 90M# BEHIND PIPE, 53% OF DESIGN. LEFT 28M# IN WELLBORE. [Frac- Refrac] 3/23/02 POST -FRAC FCO COMPLETED. CLEANED FRAC SAND DOWN TO 10775' RKB. MAINTAINED 1 FOR 1 RETURNS THROUGH OUT THE JOB. UPON CT REACHING SURFACE FLOWED BACK AN ADDITIONAL 159 BBLS (1 -1/2+ WELLBORE VOL), TURNED INTO THE HES TEST SEPARATOR TO BEGIN WELL TEST. 3�D'�i_ [FCO] -�- 3/27/02 PERFORMED A ICE PLUG REMOVAL. ENCOUNTERED ICE FROM 85' -2785. RAN NOZZLE TO 4000' CTMD. FREEZE PROTECTED WELL TO 10,000'. LEAVE WELL SHUT IN FOR WIRELINE. [Hydrates -Ice, Vortech] 3/27/02 TAGGED OBSTUCTION @ 1932' SLM. PUSHED TO 2060' SLM. IN PROGRESS. [Tag] 3/28/02 FREEZE PROTECTED TBG TO 5000' WITH METHANOL. SET 2.81 "" CATCHER SUB @ 10436' RKB. REPLACED 1 "" SPARTEK GAUGE @ 10343' RKB W/ DV. IN PROGRESS. [Pressure Data] 3/29/02 REPLACED PETREDAT SPG @ 9906' RKB W/ DV. PULLED DV @ 6903' RKB, LOADED CSG W/ 82 BBL McOH, SET 5/16 "" OV @ 6903' RKB. BLED PRESS. OFF IA, CONFIRM VALVES SET. PULLED CATCHER @ 10436' RKB. SET DHSIT & DUAL SPARTEK GAUGES ON 2.81 "" CR LOCK @ 10436' RKB. * ** *''NOTE: TOOL PROGRAMMED TO SHUT IN WELL FOR PBU @ 0424 HRS. 04/06/03 * * * ** [Pressure Data] 4/7/02 ATTEMPTED PULL DHSIT @ 10436' RKB. BAILED FRAC SAND ABOVE DHSIT. IN PROGRESS. [Pressure Data] 4/8/02 BAILED FRAC SAND ABOVE DHSIT @ 10,436' RKB. UNABLE TO LATCH. DEFER TO CTU. 4/12/02 JOB POSTPONED DUE TO EQUIPMENT FAILURE (O -RING SEALS IN ELBOW AT COIL X REEL CONNECTION LEAKING BADLY), UNIT REPAIRED, WILL RE -START THIS MORNING @ 05:30. [FCO, Equip. Breakdown] I M -17 Well Events Summary 4/13'02 CLEANED OUT TO TOP OF DHS, o AT 10,436' RKB W/ SEAWATER J313 ANL SLICK DIESEL USING A 2.25 JETSWIRL NOZZLE. PULLED DHSIT W/ GAUGES FROM DS NIPPLE USING WF FISHING BHA; VERIFIED FISH AT SURFACE BY ATTEMPTING TO CLOSE MASTER, UNABLE TO REMOVE FROM WELL (CTU'S SHORT MAST PROHIBITED NECESSARY LUBRICATOR); LET FISH GO AT 3500'. WELL FREEZE PROT'D W/ DIESEL TO 2500' +. [FCO, Fish] 4/14102 PULLED DHSIT & GAUGES @ 3550' WLM. TAGGED FILL @ 10664' RKB. EST.22' RATHOLE. SET SPARTEK @ 10393' RKB. GAUGE STARTED @ 16;00. 4/2+6/02 PULLED SPARTEC SPG @ 10393' & OV a@ 6903' RKB; REPLACED WITH DVs_ SET 2.81""' CA2 PLUG @ 10436' RKB, TESTED TBG 2500 PSI, GOOD; IA TO 2000 PSI, GOOD. SET 2.875' "' CCX PLUG @ 533' RKB. BLED TBG ABOVE CCX TO 0 PSI. [Pressure Data, PT Tbg -Csg] 4/16/04 PULLED 2.875 "" CCX PLUG @ 533' RKB. PULLED 2.812 "" CA -2 PLUG @ 10436 RKB. IN PROGRESS. [Pressure Data] 4117/04 TAGGED FILL @ 10671' RKB, EST. 65' RATHOLE. MEASURED BHP @ 10606' RKB: 3448 PSI. SET 2.812 "" CA -2 PLUG @ 10436' RKB, BLED TBG TO 200 PSI. SET 2.875 "" CX,X PLUG @ 533' RKB, BLED TBG TO 150 PSI. APC TO SET BPV TOMORR W, t. [Pressure Data] *� `�`'' 12/19/05 PULLED BPV W/ GREASE CREW, PULLED 2.785" CXX PLUG, RIG DOWN AND TRAVEL TO 1R 18. ``--V� C'4 \z 4 "\. 12/21/05 PULLED 2.81" CA -2 FROM 1043611<13, TAGGED 10665' RKB, EST. 23' RATHOLE, RAN SBHPS TO 10606' RK 60 MIN. STOP OBTAINED SBHP OF 3248 PSI W/ BHT OF 152 DEG F, MADE GRADIENT STOP @ 10,506' RKB, LDFN, JOB IN PROGRESS. 12/22/05 SET 2.81" CS -A2 @ 10436' RKB, SET 2.875" CCX @ 533' RKB. ) ,,� d k t .- c - t Page 1 of Y j A Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N 1 878@conocophillips.com] Sent: Thursday, September 30, 2010 5:03 PM To: Maunder, Thomas E (DOA) Subject: RE: 1M -17 (201 -230) 1 also asked Sharon to revisit. She is out until Monday. MJ From: Maunder, Thomas E (DOA) [mailto:tom.maunder @ alaska.gov] Sent: Thursday, September 30, 2010 2:24 PM To: NSK Well Integrity Proj Subject: RE: IM-17 (201 -230) MJ, I will check the document again. As I remember, there were only a few pages of information filed and the testing I am familiar with would have resulted in many more pages than that. Tom From: NSK Well Integrity Proj [ mailto :N1878 @conocophillips.comI Sent: Thursday, September 30, 2010 2:22 PM To: Maunder, Thomas E (DOA) Subject: RE: 1M -17 (201 -230) Tom, Was the testing information not in Sharon's 10 -404? I'll ask her to re send it if it wasn't, as well as a 407. MJ From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, September 30, 2010 11:00 AM To: NSK Well Integrity Proj Cc: Schwartz, Guy L (DOA); Allsup- Drake, Sharon K; McMains, Stephen E (DOA) Subject: RE: 1M -17 (201 -230) MJ, et al, We have received the 404 documenting the well inspection. Previously we received the 404 documenting the final well work accomplished in spring 2002. There are two additional items needed for the file. 1. A new 407 (just the form) with suspended as the completed status. 2. The detailed testing information as requested in my original message. Thanks much. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, September 21, 2010 3:26 PM To: 'NSK Well Integrity Proj'; Alvord, Chip Cc: Schwartz, Guy L (DOA); Allsup- Drake, Sharon K; Cawvey, Von; Kanady, Randall B; DOA AOGCC Prudhoe Bay Subject: RE: 1M -17 (201 -230) 10/25/2010 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 27, 2010 SEP q 'two „" °jinn M Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 1 M -17 (PTD 201 -230) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well IM-17 (PTD 201 -230). The following documents are attached: - 10 -404 Sundry - Suspended Well Check List N� 0 2 - Wellbore Schematic - Location Plot Plan - Photographs Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures STATE OF ALASKA • ALASAIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air w ell Suspended /SI r p � Plug Perforations � Stimulate r Other After Casing r Pull Tubing r Perforate New Pool Waiver well inspection r � Time Extension r Change Approved Program Operat. Shutdow n r Perforate Re -enter Suspended Well 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory \ 201 -230 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r '% 50 - 029 - 23058 - Q 7. Property Designatior` 8. Well Name and Number: ADL0028244 / ADL0028243 1M-17 9. Field /Pool(s): 1% Kuparuk River Field / Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 11060 feet Plugs (measured) 533'& 10436' true vertical 7009 feet Junk (measured) None Effective Depth measured 10960 feet Packer (measured) 10478 true vertical 6909 feet (true vertucal) 6428 Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 120 120 SURFACE 8040 7.625 8040 4108 PRODUCTION 10474 5.5 10474 6424 LINER 594 3.5 11055 7004 R E Perforation depth: Measured depth: 10606 - 10642' S E P 29 20 True Vertical Depth: 6555 -6591 �h t9n. Tubing (size, grade, MD, and TVD) 3.5, L -80, 10474 MD, 6424 TVD Packers & SSSV (type, MD, and TVD) NIP - CAMCO 'DS' LANDING NIPPLE @ 533 MD and 533 TVD PLUG - 2.875" CCX PLUG SET 12/22/2005 @ 533 MD and 533 TVD NIP - CAMCO'DS' NIPPLE @ 10436 MD and 6386 TVD PLUG - 2.812" CS -A2 PLUG SET 12/22/2005 @ 10436 MD and 6386 TVD SEAL - 80-40 GBH SEAL ASSEMBLY @ 10478 MD and 6428 TVD Nipple - Type Not Found (Manual Entry Required) @ 0 MD and 0 TVD 11. Stimulation or cement squeeze summary: NA Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r, Service r r GO tus a fter work: Suspended /SI [x] Oil �` Gas r WDSPL Daily Report of Well Operations X r WAG r GASINJ r WINJ r SPLUG r 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact MJ Loveland /Perry Klein Printed Name MJ Lovelan Title Well Integrity Project Supervisor Signature y Phone: 659 -75 Date 0 .71 Form 10-404 vised 7/2009 RBDMS SE ' W4 Aa Y. .�,� Submit Original Only Suspended VNell Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 1W 17 Field /Pool: KRU/ Kuparuk ° Permit # (PTD): 201 -230 API Number: 5002023058.00 Operator: ConocoPhillips Date Suspended: 46/2002 - Z- _Surface Location: Section: 17 Twsp: 11N Range: 11 E UM Nearest active pad or road: Spine road near DS 10 and DS 1 C Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: aa "-morki AV, SkIPWdots Pad or location surface: P-,6yP Location cleanup needed: Pits condition: (i. Surrounding area condition: (' ' Water /fluids on pad: 4A2 ° Discoloration, Sheens on pad pits or water: Samples taken: ., Access road condition: �r < < Photographs taken (# and description): ' Condiition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, ,j^ ¢ 3) photographs showing the wellhead condition f Wellhead /tree /valve description, condition: ezcp yh f &- = K- Cellar description, condition, fluids: &ZO /' SCI Or 3 Rat,Hole: _ r ,.: Wellhouse or protective barriers: A1 W �l , a/ 0L9 fb - L® �l R 1 f Well identification sign: # 1P44 A11'Xt> r J.r/0V&, Tubing Pressure (or casing if no tubing): jtWA&Jr Z 5,69W110 f Annulus pressures: f/V ;, t/* _ s Wellhead Photos.taken (# and description): _ U0 W&k/2equired: Operator Rep (name and signature): - -Vkµl :Nf6 AOGCC Inspector: T" Other Observers: M&g( Inspection Date: AOGCC Notice Date: 9/20/2010 Time of arrival: —� Time of Departure: Site access method KRU 1M-17 ConocoPhillips Alaska, Inc. 1M-17 API: 1500292305800 Well Type: PROD Angle TS: 3 deg @ 10605 TUBING - SS §V Type: Nipple Orig 1/20/2002 Angle @ TD: 2 deg @ 11060 (0- 10474, OD:3.500, Completion: iD:2.992) Annular Fluid: Last W /O: Rev Reason: Tag, reset plugs - RODUCTION Reference Log: Ref Log Date: Last Update: 1/2/2006 (0- 10474, Last Tag: 10665 TD: 11060 ftKB OD:5.500, Last Tag Date: 12/22/2005 Max Hole Angle: 66 deg @ 5416 Wt: 15.50) Casing String - ALL STRINGS Description Size I Top Bottom TVD I Wt Grade I Thread CONDUCTOR 16.000 0 120 120 62.58 H -40 Buttress SURFACE 7.625 0 8040 4607 29.70 L -80 Buttress PRODUCTION 5.500 0 10474 6424 15.50 L -80 BUTTX8rd SURFACE LINER 3.500 10461 11055 1 7004 9.30 L -80 BUTTX8rd (0 -6040, Tubing String - TUBING OD:7.625, Size I Top I Bottom I TVD I Wt I Grade I Thread Wt:29.70) 3.500 1 0 1 10474 1 6424 9.30 1 L -80 I EUE8RD Perforations Summa Interval I TVD I Zone I Status I Ft 1SPFj Date I Type I Comment 10606 - 10642 6555 - 6591 C -4,C -3 36 1 6 1 2/16/2002 IPERF 2.5" HSD, 2506 HJ Chgs, 60 Deg phase Gas Lift Stimulations & Treatments 3ndrel /Dummy Interval Date Type Comment Valve 2 10606 - 10642 3/21/2002 FRAC C -SAND FRAC, 90M# BEHIND PIPE, 9 a ON PERFS (6903-6904 j Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 3510 2614 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 1/17/2002 2 6903 4108 CAMCO KBG -2 -9 DMY 1.0 BTM 0.000 0 4/26/2002 Gas Lift 3 9016 5133 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 1/17/2002 3ndrel /Dummy 4 9906 5868 CAMCO KBG -2 -9 DMY 1.0 INT 0.000 0 3/29/2002 Valve 5 10393 6343 CAMCO KBG -2 -9 DMY 1.0 BTM 0.000 0 4/26/2002 ( OD:4725) Other (plugs, equip., etc. - JEWELRY Depth TVD Type Description ID 533 533 NIP CAMCO'DS' LANDING NIPPLE 2.875 533 533 PLUG 2.875" CCX PLUG set 12/22/2005 0.000 10436 6386 PLUG 2.812" CS -A2 PLUG set 12/22/2005 0.000 Gas Lift 10436 6386 NIP CAMCO 'DS' NIPPLE 2.812 3ndrel /Dummy 10475 6425 LOCATOR G -22 LOCATOR 3.000 Valve 4 10478 6428 SEAL 80 -40 GBH SEAL ASSEMBLY 3.000 (9906 -9907, ODA.725) General Notes Date Note 5/4/2002 BPV set in tubing hanger Gas Lift 3ndrel /Dummy Valve 5 (10393 - 10394, OD:4.725) NIP (10436- 10437, OD:4.520) LOCATOR (10475- 10478, OD:4.500) LINER (10461- 11066, OD:3.500, Wt:9.30) Peif ;10606 - 10642) FRAC 10606- 10642) REVi DATE I BY I CK I APP RIPTION REV I DATE I BY ` P DESCRIPTION LEGEND T1 2N T11 N 0 FUTURE CONDUCTORS • EXISTING CONDUCTORS 2 1 s est 5 •O AS— STAKED CONDUCTORS —THIS SURVEY Sa 24A N W. S. T. P. DS -1C 1 1 11 12 7 8 �SUR Y SCALE: �o, TFII 1" = 200' X 14 13 18 17 ...... ... \V) — DS 1 M 23 24 _ 19 0 mm VICINITY MAP SCALE 1" 1 MILES WELL 1M-17 LOCATED WITHIN PROTRACTED Q� SEC. 17, TWP. 11 N., R. 11 E. UMIAT MERIDIAN c-�cl� Y = 5,960,383.6 �� 017 X = 571,907.4 �� 5 �C�t -23C� LAT = 70'18'07.40" LONG = 149'25'03.24" 618' F.S.L., 600' F.W.L. • MP 1 �✓ l� NOTES: 1. ALL COORDINATES ARE ALASKA STATE PLANE, NAD 27, ZONE 4. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. 3. ALL DISTANCES ARE TRUE. 4. DATE OF SURVEY: 12/7/01, F.B. L01 -64, PG'S 64 -66. 180 19120 LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS AREA: IM MODULE:XXXX UNIT: D1 PHILLIPS Alaska, Inc DS 1M A Subsidiory of PHILLIPS PETROLEUM COMPANY WELL CONDUCTOR 17 AS— STAKED LOCATION CADD FILE N0. [ DRAWING NO: SHEET: REV: LK6113D2 12/ NSK 6.113 — d2 1 o 1 1 0 I M -17 PTD 201 -230 @ConocoPhillips Alaska, Inc This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published "�*► without express written consent of ConocoPhillips Alaska AL y s n ..i�� •. fix, �,.,�.. - { ' w Y. a , r m , 1 M -17 PTD 201 -230 ° c ConocoPhillips Alaska. Inc o- '- his photo is copyrighted by ConocoPhillips Alaska, Inc. and annot be released or published ithout express written consent f ConocoPhilli s Alaska f 9— W M ZZ • L- � Q r' fZ c� cA — O — U U� — N N - i2 W yea !E N N � r Q CL CL p U Q O p O CU r,4 + } A . • • 4 I q 1 13 Ao _uwwwmm&, .., i..k ,...a,»........ " T ,. ,... u . 4 1 M -17 PTD 201 -230 c ConocoPhillips Alaska, Inc , his photo is copyrighted by ConocoPhillips Alaska, Inc. and • i • _ annot be released or published ithout express written consent of ConocoPhillips Alaska . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc I ~ VI - . ,) , (f].Jí._l.m L( DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2012300 Well Name/No. KUPARUK RIV UNIT 1 M-17 Operator CONOCOPHILLlPS ALASKA INC S'ft wi, J J..... ,( 0 0 1.- API No. 50-029-23058-00-00 MD 11 060 ./ TVD 7009 ,.- Completion Date 2/16/2002 --- Completion Status 1-01L Current Status 1-01L UIC N ------- -- -- --- -- - ----- - ----- --.----_._-- -------- ---- -- -- ----- ---- -._------------------ ------- -------- ----- ----- - ---- ---- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey ~ ---- ---------------- ------ --------- --.-- --------------------- ---- -----. - - ------- - -- --- --- ---- --- -- -" --- ---- -- ----- ----- -- ----- ----- --- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~--C- --~9-US Verification (data taken from Logs Portion of Master Well Data Maint) ------ Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ----- ----------- ----- -------- ---- --- 1 129 10968 Open 4/19/2002 - --.----- - -------- -------------------- --- ---------- ----- --- --------. -- -- - - --- Well Cores/Samples Information: Cuttings Sample Interval Set Start Stop Sent Received Number Comments -- -- - --- -- ------ - ----------- ------- 8040 11060 1057 Name - ------------- 1- ------------- ------ ----- ----- ----- --- --- ------ .---- - - --------_.~- - -- -- -- Well Cored? ADDITIONAL INFORMATION Y~ Daily History Received? ~ Chips Received? ..- Y / N Formation Tops Analysis Received? ¥/N - -- ----- -- - -- ------- -------------------------.-------- ----- -- --- ---- ----- --- ----------- --- ------------- ----- ---------- ---- -- --- - - - - - .- - - - Comments: ~O~PIi:ce Re~:wed By: . ~ - ---'~== ==-=-=-=- -'==~~ate: - i fa ~ -;..~~(- 04/26/02 Scblum~erger NO. 2030 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Sepia 1 M-17...:JO J~"" PRESSrrEMP SURVEY 03/20/02 1 1 2P-441d~~oI1 STATIC BOTTOMHOLE 03/30/02 1 1 2K-25 I q()-OJ ~ RST -WFL 03/08/02 1 1 2K-27 ~()J-J~q LEAK DETECTION LOG 03/11/02 1 1 2K-27 J, LEAK DETECTION LOG 03/08/02 1 1 3H-21 IW~Dcß PRODUCTION PROFILE 03/07/02 1 1 Kuparuk CD Color SIGNE~ í) DATE: RECEIVED , r", '7 C "no? ,1- r-' r -; v ' L. >II - Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ~aska Uii & Gas ConS. CommlSSiar. ~nchoraae J M-17 Suspension Monitoring Subject: IM-17 Suspension Monitoring Date: Mon, 29 Apr 2002 19:21 :42 -0800 From: "NSK Problem We1l Sup\''' <n 1617(~ ppco.com> To: winton- aubert@admin.state.ak.us CC: "NSK Problem \Vell Supv" <n 1617@~ppco.com> Winton: I'm not sure of ~our email address, so I will talk to ~ou i~ the morning. Apparently the Otter FLIR Ïlights take place every week. The Aviation department is hesitant to say the7 will do all flights e~er~ week due to weather, plane demands, 111ness, et~. But generall~ they do it e~ery Heek. The Operations staff is concerned about the safet:/ of their Ope-rators walking a mile out into the tundra regarding bears, etc. So tney are hes i tant to commit to DSO '.'is i ts to the \.¡e 11 head unless we \.¡ere requi red to. Something as simple as putting a culvert in the creek 50 th~~' caD drive raises huge issues with ADEC, so that is not reall~. an option. That is one of the reasons we proposed adding a 5econdar~' downhole plug to reduce the risk of the well left alone. Please consider the "almost" weekl~' FLIR monitoring in touch wi th ~'Ou. in the morning. Thanks! ,ç... ft.. Jerr~' Dethlefs ;. Phillips Problem Well Super~is0r 65,9-"722-1 of the well. I will get ~) "^ tv -'"'" ,4 :: L::~ .', ¡) (! ;þ, {J, I. .".'....1 ft,l"",,, J.J...._. , '.- ( r ,/ r (?t1 \ - '" 1 ~. C£I- G ( --"- I of I -J, 3Ü 2002 8:.+-J Al\'( tPHiLiiPS\ PHilLIPS Alaska, Inc. ,m, A Subsidiary of PHilLIPS PETROLEUM COMPANY ,..... ' , ' ~ ~ .. " : ~. ....-. Ìo, . -r. . ... ..J Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 t\~~~Ùs u:: ¿. :~, ~' ,~:~. -;..: ~:~';l!ir:I:;:;lC!' ~~ c:.IQrE:~~ ~ t\/tarch 26. 2002 t\'ls. Can1my Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue. Suite 100 Anchorage. Alaska 99501 Subject: llVt-17 Application for Sundry Approval (APD 201-230) Dear Commissioner: ¡ I ~ \J 6A SIL'^;,t. .A. - Phillips AJaska, Inc. hereby files this Application for Sundry Approval ro s~~ the Kuparuk \\'ell 1l'vI-17. If you have any questions regarding this maUer. please contact Todd l\1usho\'ic at 265-697-1-. SincereJy. ~\~. R. Thomas Kuparuk Drilling Team Leader PAl DriJling RT/skad ~ý^ 1/3') /02- it- '4 (--so- o--:~ 1') ,.~ S"' J ¿ /G ¿ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 618' FSL. 600' FWL, Sec, 17, T11N, R11E. UM At top of productive interval 959' FSL, 754' FWL, Sec. 21, T11 N, R11 E, UM At effective depth At total depth 958' FSL, 770' FWL. Sec. 21, T11 N, R11 E, UM 12, Present well condition summary Total depth: measured true vertical Effective depth: 11 060 7009 10960 6909 measured true vertical Casing Conductor Surface Length 26' 8012' 1 0431' 594' Size 16" 7.625" 5.5" 3.5" Production Production Liner Perforation depth: measured 10606' - 10642' Irue vertical 6555' - 6591' Tubing (size, grade, and measured deplh Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (ASP: 571907, 5960384) (ASP: 577405, 5955499.7) (ASP: 577419, 5955497) feet feet feet feet Plugs (measured) Junk (measured) Cemented "0 sx AS 1 600 sx AS Lite, 326 sx LlTeCrete 200 sx Class G (Included above) 3.5",9.3#, L-80 @ 10478' Packers & SSSV (type & measured depth) No packer Camco Nipple @ 533' 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation April 26, 2002 16. If proposal was verbally approved ,/ Re-enter suspended well - Trme extension - Stimulale - Vanance - Perforate - 6. Datum elevation (OF or KB feet) RKB 30' feet 7. Unit or Property name Other )( Sku t .r:~ Kuparuk River Unit 8. Well number 1 M-17 9. Permit number / approval number 201-230 10. API number 50-029-23058-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool Measured Depth 110' 8042' 1 0461' 11 055' True vertical Depth 110' 4608' 6411 ' 7004' ~) E~ r F ~ 'l F f), ~'\. ... "," I.,.,' ,. \.. ~ /.;JO ~) ,l~ ?ünro f-" " - U '-- ..L~ Alas!{a Oii & Gas Cons. ljmmmsStorl Anchorage Detailed operations program - 15, Status of well classification as: Oil_X Name of approver Date approved SeNice - t7. I hereby certify that the foregoing is true and correct to The best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - BOP Test - Location clearance - . J" J Mechamcallntegrity Test - Subsequent form required 10- 'f O"'T Ongll\al Signed B)' çammy Qechsh T ay\o¡ Signed ~~ R Thomas , \~ Approved by order of the Commission Form 10-403 Rev 06/15/88 . Title: Kuparuk Drilling Team Leader BOP sketch - Gas- Suspended - Questions? Call Todd !I.1ushovlc 265-6974 Date ~(c6 (02 Prapared OJ' S",ar~'n A/lsup-Drak~ I Approval no. -A ":;;0';). -I S" u Commissioner f/~/or Date \.. I ." . ~~........ SUBMIT IN TRIPLICATE ~ Gary W Targac 04/26/2002 10:50 AM ",.L!l To: Sharon AlIsup-Drake/PPCQ@Phillips, Todd J Mushovic/PPCQ@Phillips cc: CP F 1 Prod Engr/PPCQ@ Phillips, Jerry C Dethlefs/PPCQ@ Phillips Subject: Re: 1 M-17 Plugging Procedure f~r 4~3 ,,~ubmi~al G It- .~ ¡.( ) r~.W Lt L'-~ \J Sharon. the recommended procedure for abgn~nt-et:1 M-17 is as follows. - S h iA,:tti ~<J c...... 1. Freeze protect the well; 2. Pull OV and Petredat gauge and replace with DV's @ 6903' MD~RKB and 10393' MD-RKB, respectively. 3. Pressure test IA to ensure DV's are set. 4. Set a Camco CA-2 Plug in the D-nipple @ 10436' MD-RKB. 5. Set a Camco CA-2 Plug in the SSSV landing nipple @ 5331 MD-RKB. 6. Set a BPV in the wellhead; ./' 7. Do FUR fly-by inspections with Kuparuk Otter every 4 weeks while 1 M access road is out of service. I'll get you an annotated well schematic after lunch. Thanks Gary { ./?'I ~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHIL IPS PETROLEUM COMPANY 1M-17 TUBING (0-10474, 003.500. 10,2992) CA,2. 6kv1\Ki ~\ ?\~\ SURFACE (0-8040 00:7,625, Wt 29 70) ~OOUCTION (G-10474, 00 5,500. Wt1550) IIIP (1043&10437, 00:4 520) LOCATOR (10475-10478, 00:4,500) LIllER (10461.11055, 00 3,500, W1:930) Perf (10606-1~2) FRAC (10606-10642) ~ ~ ~ API: 500292305800 SSSV Type' Nipple Annular Fluid: - C.A -2. 'Ö\lItJC (--i~ n 120/)0)£ O( , / 4/;0 5éHEMJì'T\ L KRU 1 M-17 Well Type: PROD Ong Completion, Las! W/O, Angle @2 TS: 3 deg @ 10605 Angle @ TD: 2 deg @ 11060 Ref Log Date: TD, 11060 hKB Max Hole Angle: 66 deg @ 5.116 Rev Reason: Tag, GLV, FRAC by ImO Las! Update: 4118/2002 Top 0 0 0 10461 Bottom 120 8040 10474 11055 TVD Wt Grade Thread 120 62,58 H-.10 Buttress 4607 29.70 L-80 Bultress 6424 15.50 L-SO BUTTX8rd 7004 9,30 L-BO BUTTX8rd Bottom 10474 Wt 9.30 I Grade I L-80 Reference Log: Last Tag: 10664 Last Tag Date: 4/14/2002 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 7.625 PRODUCTION 5.500 LINER 3,500 Tubing String - TUBING Size I Top 3.500 0 Perlorations Summary Interval TVD Zone 10606 - 10642 6555 - 6591 C-4,C-3 TVD 6424 Thread EUE8RD Status Ft SPF Date Type Comment 36 6 2/1612002 IPERF 2,5" HSD, 2506 HJ Chgs, 60 Deg phase I Comment C-SAND FRAC, 90M# BEHIND PIPE. 9 ppa ON PERFS V Mfr V Type V OD Latch Port TRO DMY 1.0 INT 0.000 0 VM'{ ~ 1.0 INT 0.313 0 Dr...1Y 1,0 INT 0.000 0 D1\-1Y . ~ ,0 INT 0.000 0 VM"{ 3PA~ 1.0 INT O.OÙO 0 -- Description CA1\ICO 'OS' LANDING NIPPLE CA1\1CO 'DS' NIPPLE G-22 LOCATOR 8040GBHSEALASSEMBLY ~\ \J 't Date Run 1117/2002 3129/2002 1117/2002 3.'29/2002 4,.14/2002 Vlv Cmnt Stimulations & Treatments Interval I Date I Type 10606 - 10642 3121/2002 FRAC Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 3510 2614 CAMCO KBG-2-9 2 6903 41 DB CAMCO KBG-2-9 3 9016 5133 CAMCO KBG-2-9 4 9906 5868 CAMCO KBG-2-9 5 10393 6343 CAMCO KBG-2-9 Other l:Jlugs, equip., etc.,' - JEWELRY Depth TVD Type 533 533 NIP 10436 6386 NIP 10475 6425 LOCATOR 10478 6428 SEAL ID 2,875 2.812 3.000 3,000 1 M-17 Suspended well monitoring Subject: 1 M-17 Suspended well monitoring Date: Thu, 25 Apr 2002 07:40:20 -0800 From: IINSK Problem Well SUpVIl <n1617@ppco.com> To: tom_maunder@admin.state.ak.us CC: IINSK Problem Well SUpVIl <n1617@ppco.com> ~ dO \ -d"3Ù Tom: I got your voice-mail this morning; I won't be able to call you today since I will be out with John Spaulding catching up on some new well MIT's. My question had to do with what constitutes IImonitoringll of a suspended well like 1 M-17. The well is located on a gravel pad that has an access road that is closed during the summer (it is crossed by at least one stream). There is a problem with ready access; an Operator would need to hike a mile or so or ride a 4-wheeler. Another alternative is to do a periodic fly-by with the FUR system they use for pipelines (forward looking infrared radar). Another alternative is to use kill-weight fluid with the tubing plug and BPV. 1111 try and get back with you about this. This seems a rather simple item but it has our Operations folks in a tizzy. \'O\~ 0 f'- \-.J\. ÖS-c"- \ d- --\ ~ \;- \-~0I G \é ~ -\¡ ""'y T~~~'.Y?~:..L d-~S -<;~~~ dl-.\O -S'lL\O Jerry Dethlefs 1 of 1 4/26/028:44 AN a 0 /-c93ù '''ELL LOG TRANSl\ITITAL To: State of Alaska A]aska Oil and Gas Conservation Comnl, Ann.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, AJaska April] 6, 2002 RE: l\..1WD Formation EvaJuation Logs 1 rvl-17, AK-Ml\1-11217 1 LDWG fomatted CD Rom with verification listing. API#: 50-029-23058-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Sen;ce Ann: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Da.t~. /, --',," , ;' ~ ~t."'1IQf¡\ 'A <.,. Î :Y" -- ., ,I . ~~...!....~E' ~.§ ~~!'-"¡? .)T l~~: If.~..,.~ Signe~m uikopD .. ., ", .' , r . ': ,ìn;. ... - .. "'--- 1~~~"Iott,~,tlI t""..~" .:J¡ G' . .,',l\1,1',Jt tJl~ I~ 'as c,, ,' ,...,.... , ' ... \JIM:), loÚ,l'hrmS8jO¡1 j,n,ol,IIt.1lI'"'''''' , :"",','r..I!.r?~~r-' ~ PHilLIPS Alaska, Inc. ,m A SubsIdiary of PHilLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 April 19, 2002 Commissioner CamnlY Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 71h Avenue Suite 100 Anchorage. Alaska 99501 Subject: Completion Report for 1 M-17 (201-230) Dear Commissioner: Phillips Alaska. Inc. subn1irs the attached Completion Report for the drilling operations on the Kuparuk well 1 M-17. If you have any questions regarding rhis matter. please contacr Todd lVlushovic at 265-697-1-. Sincerely, ~v-_~)0---~ R. Thonlas Greater Kuparuk Team Leader PAl Drilling RT/skad I STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of well Oil 0 Gas 0 2, Name of Operator Phillips Alaska. Inc. 3 Address Suspended 0 Service 0 Abandoned 0 P. 0, Box 100360, Anchorage. AK 99510-0360 4, Location 01 well at surface ~. ~. 618' FSL. 600' FWL. Sec. 17. T11N. R11E. UM At Top Producing Imerval 959' FSL. 754' FWL, Sec. 21. T11 N. R11 E. UM At Total Depth (ASP: 571907, 5960384) -- --,' ,,~"1!Io .~ L.O.':.A) ¿~ >( ~~.~. 1J .~ . '-" ~~ f :, ~"" ~~~f' . -."1'" , - ~'/_4:-~-~', . - . . (ASP: 577405, 5955499.7) ',bþ-' I .-I'~..._..'-,,, -. ."''' _.- .... ......' 958' FSL. 770' FWL, Sec. 21, T11 N. R11 E. UM (ASP: 577419, 5955497) 5, Elevation In leet (indicate KB, DF, etc.) 6, Lease Designation and Senal No, RKB 30 feet 12, Date Spudded January 1, 2002 17, Total Depth (MD T TVD) 11060' MD 1 7009' TVD 22. Type Electric or Other Logs Run GR/Res/PWD. CBL 23. CASING SIZE 16" 7.625" 5.5" 3.5" WT. PER FT. 62,6# 29.7# 15.5# 9.3# ADL 28244 & 28243, ALK 2293 13 Date T.D Reached 14. Da~<:S?mPl!usP, Or Aba~~", 1 5, Water DePth, II offshore January 14, 2002 J~QLlíiry æ, 2002 /j.JI N/A fee! MSL / 18, Plug Back Depth (MD... TVD) 19. Directional Survey 20, Depth where SSSV set 10960' MD I 6909' TVD YES 0 No 0 Cameo Nipple @ 533' GRADE B L-80 L-80 L-80 HOLE SIZE 42" 9.875" 6.75" 6,75" CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 110' Surface 8042' Surface 10461' 10474' 11055' 24. Perforations open to Production (MD + TVD 01 Top and Bottom and interval, size and number) 25. SIZE 10606' - 10642' MD 6555' - 6591' TVD 6 spf 27, Dale First Production March 23, 2002 Date 01 Test Hours Tested 4/14/2002 Flow Tubing press. psi 5 days Casing Pressure not available 28. Classllicatlon of Service Well 7, Permit Number 201-230 1 8 API Number 50-029-23058-00 9 Unit or Lease Name Kuparuk River Unit 1o, Well Number 1 M-17 1 1, Field and Pool Kuparuk River Field Kuparuk River Pool 16. No. 01 Completions 21, Thickness of Permafrost 1998' CEMENTING RECORD 110 sx AS 1 AMOUNT PULLED 600 sx AS Lite, 326 sx LrteCrete 200 sx Class G included above Baker rntlatable bndge plug set at 3300' TUBING RECORD DEPTH SET (MDI 10478' 3.5" PACKER SET (MDI N/A ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD¡ AMOUNT & KIND OF MATERIAL USED 10606' - 10642' 90M# behind pipe, left 28MIt in we-Ilbore 26, PRODUCTION TEST Method of Operation (Flowing, gas litt, etc.) Flowing GAS-MCF Production lor OIL-BBL Test Penod > Calculated OIL-BBL GAS-MCF 1450 2320 CORE DATA WATER-BBL WATER-BBL Bnet descnptlon of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev, 7-1-80 24-Hour Rate> CHOKE SIZE 48/64 OIL GRAVITY - API (corr) 23.6" GAS-OIL RATIO 1600 RE(~EIVED ;, r"l C, I) /" ?on f) f~ J, ~ L ..: (.. v t.. Alas!Œ Oil & Gas Cons. Goa'íil"!î¡SSIOn Anchora!)e (ì:f'Tr~ f~\~rvp~S[ SIDE r, - ,: " :: I ~ ¡ '1 ,; ~ v,- : B D M 5 B F L Submit n duplicate APR ') c' "V,,,,,., , L. - ': I Ii '-.: Gç: 29 ,( GEOLOGIC MARKERS 30, FORMATION TESTS NAME MEAS,DEPTH TRUE VERT. DEPTH Include Interval tested, pressure data, all fluids recovered and gravity GOR. and lime of each phase Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A 6763' 6830' 1 0739' 1 0820' 4048' 4077' 6688' 6769' Annulus left open - freeze protected with diesel. R E ("- f: I \ I E D , ,~ L ~ ~ , . . I~.r) ,-. ,) i"'tOl/'l,~ ,\ ,_f!-,' ,.! , -, ,\ .- '- I- 31, LIST OF ATTACHMENTS Summary of Daily Operations. Directional Survey 32. I hereby certify that the following IS true and correct to the best of my knowledge. Alaska LJd & l>" \,,":i.~, ".¡j,ILI'II.;,".,¡l!1 I!,: !I.hid:\:),' Questions? Call Todd MushOVIC 265-697.1 ----:-::. Signed \ c.::....~ ~~ R, Thomas1 - 'I hie Kuparuk Dnlilna Team Leader Date L / / '.1 (C, C. 7 Prepared by Sharon Allsup-Drake 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 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 1 0-407 ~ 1"', ~ Ii ~. ~ ~~ PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 12/30/2001 16:00 - 21 :00 5.00 MOVE MOVE MOVE 12/31/2001 111/2002 1/2/2002 21 :00 - 00:00 3.00 t\,10VE RURD r...10VE 00:00 - 15:00 15.00 DRILL RIRD SURFAC 15:00 - 18:00 3,00 DRILL OTHR SURFAC 18:00 - 20:00 2.00 DRILL OTHR \ SURFAC 20:00 - 00:00 -1.00 I DRILL OTHR SURFAC 00:00 - 02:30 2.50 DRILL PULD SURFAC 02:30 - 04:00 1.50 DRILL PULD SURFAC 04:00 - 05:00 1,00 RIGMNT RGRP SURFAC 05:00 . 06:00 1.00 DRILL PULD SURFAC 06:00 - 07:00 1.00 RIGMNT RSRV SURFAC 07:00 - 08:00 1.00 DRILL CIRC SURFAC 08:00 - 10:00 2.00 DRILL DRLG SURFAC 10:00 - 11 :00 1.00 DRILL CIRC SURFAC 11 :00 - 13:00 2.00 DRILL PULD SURFAC 13:00 - 00:00 11,00 DRILL DRLG SURFAC 00:00 - 02:30 2,50 DRILL DRLG SURFAC 02:30 - 03:00 0.50 DRILL RIRD SURFAC 03:00 - 22:30 19,50 DRILL DRLG SURFAC 22:30 - 23:30 1.00 DRILL CIRC SURFAC 23:30 - 00:00 0.50 DRILL TRIP SURFAC Page 1 of 8 Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: Description of Operations Remove element from 11" annular preventer & install new one. Move rig from 1 D pad to 1 M pad 4 miles & spot same-set tanks & rig u p 11 and y b e r m . A c c e p t rig Ig' 2 1 0 0 h r s. 1.2 I 3 Ù ' 2 0 (\ 1 - 0 f f I 0 a d e sp spool off rig floor-nipple up diverter. Nipple up diverter-Ioad pipe shed wi .t" ht38 d p, ,Load bha-pick up .t" dp è: stand In derric~;. INiPple up riser & attempt to test annular, \ P i 0:; k u P .t" oj p 3.. s [ a n Ij I n d err I c k . Continue to Pu & stand back .t" dp. Pu 5" hwdp. Jars. Flex pipe & dc for bha. X - out tds saver sub & pipe guide to 4 1/2" IF. Rih from derrick bha to top of cmt in condu ctor @ 110' rkb Nordic 3. Service rig & tds. Ck crown & crownomatic, Cir con mud / prepare to spud well. Spud well in @ 0800 hrs. Drlg surface hol e110-223' Cir hole clean & pull 2 stands, PJSM - installing source material in Iwd equ ip. Rih to 223' installing / up loading / test ing mwd - Iwd tools. Drlg 223 - 862'. Parameters: Pump pr ess max - min - avg = 1450 - 1200 - 1200 P si Flow Rate max - min - avg = 450 - 400 - 430 gpm Bit wts = 10 - 15 k Ibs Torque = 3400 avg w/ peaks to 4000 ft-Ibs. Rpm {slid e / rot} = 64 /135 Ecd = 10,00 / 9.5 I avg 9.7 ppg ART = ,15, AST = 3,75, Total 10.9 hrs. Dir Drlg Ahd 862' md [ 858' tvd ] -- 1043' m d Pull one stand, rig up pump in sub & ci r we I I @ 300 psi /120 gpm m, X-Out 4 1/2 IF sa ver sub & guide to 4" HT-38 & guide, Servic e t d s. Dir Drlg 1043 - 2656' md [ 2231 tvd], Para meters Pump press max / min / avg = 1400 /1250 /1325 psi Pump rate = 443 gpm Rp m max / min [slide] = 140 / 72 Torque = 3 - 3,9k ft - Ibs Weight = 45 k Ibs slide' 50 k rot. PU / SO / Rot weights = 75 /70 I 75K Ibs @ 70 rpm ADT =- 28.25, AST = 4.5, A RT = 23.75 hrs MW = 9.4 ppg @ perafrost ECD 9.9 - 10,14 ppg. Ops planning meetin 9 @ 0700 hrs - subject next 24 hrs, Pump pill & cir bottoms up, very light c uttin gs to surface. Short trip, incomplete @ rpt time. Pnnted: 1/3012002 1:33: 10l PM 1PHiWPS.. TfI'lI ~~ PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date Sub From - To Hours Code Code Phase 1/3/2002 5.00 DRILL WIPR SURFAC 00:00 - 05:00 05:00 - 00'00 19,00 DRILL DEQT SURFAC 1/4/2002 6.00 DRILL DRLG SURFAC 00:00 - 06:00 06:00 - 08:00 2,00 DRILL CIRC SURFAC 08:00 - 14:30 6.50 DRILL TRIP SURFAC 14:30 - 16:00 1.50 DRILL TRIP SURFAC 16:00 - 17:00 1.00 DRILL TRIP SURFAC 17:00 - 18:00 1.00 DRILL OBSV SURFAC 18:00 - 20:30 2.50 DRILL TRIP SURFAC 20:30 - 21 :30 1.00 DRILL TRIP SURFAC 21 :30 - 00:00 2,50 DRILL TRIP SURFAC 1/5/2002 00:00 - 00:30 0.50 DRILL CIRC SURFAC 00:30 - 03:30 3,00 DRILL DRLG SURFAC 03:30 - 04:30 1,00 RIGMNT RGRP SURFAC 04:30 - 00:00 19.50 DRILL DRLG SURFAC Page 2 of 8 Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: Description of Operations Continue short trip {to 1st flex dc, leaving n eutron source tool below ground level]. Tig ht off bottom [@ ?2575'], back reamed to 16 50', then pulled free. Tight on way back in tJ, 2-100', wash ream to Id of 2t356', did not detect fill on bottom Had no problem w: a 6? dag leg 2600', Lost no fluid on trip. Dir drlg 2656' - -I21ü' md [ 2925' tvd] Ast = 1"¡. -: 5, Art = 2 8 . 0 ü A d (.::; -I 2 , "7 5 h r 5 r, OTE: abundant asphalt like oil 011 shakers 3 1 '3 0 .' .2"¡ -; 5 - 3 J 1 5' m ,j , ::: 5 3 I~I' I v '], L (, :. t -; 5 t, bl mud due to screen blinding, Good GR res ponce over interval. Caught sample. Para meters: P Press max " min I avg = 1900 11 400 I 1600 psi Q =390 - 460 gpm Bit wts m ax I min I avg = 35 I 20 I 30k Ibs Torque m ax I min I avg = 8k I 6k I 7.4k ft-Ibs @ 74 r pm PU SO Rot wts = 80k I 65k 175k ECDs = 10 ppg ? .2 ppg Dir Drlg ahd 4210 md [2500'tvd] -- 4645 md [3116' tvd). Problems wi bit balling & assm by tracking right. Drlg rates from 80 to 180 fph during homogeneous lithology. Pump sweep I prepare for trip. Pooh. back reaming [650 psi I 200 gpm] to 1 053' . PJSM. Pull neutron density tool to floor & remove source, Down load mwd & Iwd tools, Complete pooh laying down motor, componen ts not able to stand back, & bit. Clean floor & prepare for tih, Mu bha, to mwd I Lwd tools. Pjsm. Upload Iwd I mwd tools & install neutral source. R ih below ground level. Rih wi hwdp, install HT-38 saver sub to tds. pipe guide & test tools. Rih wI 4" dp [wash ream 2496 - 2559'], conti nue to rih wI stands to 4611', precaution wa shing & reaming to td of 4645' @ rpt time. Complete wash I ream to td [4645' md]. Drlg Drlg 4645' md - 4864'. Replace #2 pod liner on pump # 2. Dir drlg 4864' md {3116tvd] -- 6663' md {400 5' tvd}. Some minor difficulity holding angl e in rotate mode @ < 180 fph, this resu Its i n more slide time being required. ECOs,9. 9 ppg ?2 ppg, Motor rpm factor = .33 rpm I gallon. Prameters: Pump rates & pressure 465 gpm 12400 psi Rprns 154 slide 12 24 rot Torque @ 70 rpm = 10000 I 7500 185 00 ft Ibs Weight on bit [Rot] 25 40 k IbS), s lide 15 - 35 k Ibs Weights pu I so I rot 40 r Pnmed: '130/2002 , :33: 14 PM ~þ ~ ,~¡ PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date From - To Hours Code Sub Phase Code 1/5/2002 04:30 - 00:00 19.50 DRILL DRLG SURFAC 1/6/2002 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01 :00 - 02:30 1.50 DRILL CIRC SURFAC 02:30 - 07'00 I -+ 50 I DRILL WIPR SURF;C 07:00 - 09:00 2.00 RIGr'.,1t IT RSRV SURFAC 09:00 - 13:00 -+,00 DRILL TRIP ~,URF,;C 13:00 - 00:00 11.00 DRILL DRLG SURFAC 1/7/2002 00:00 - 03:30 3,50 DRILL DRLG SURFAC 03:30 - 06:00 2,50 DRILL CIRC SURFAC 06:00 - 12:00 6.00 DRILL TRIP SURFAC 12:00 - 12:30 0,50 DRILL OTHR SURFAC 12:30 - 15:00 2.50 DRILL OTHR SURFAC 15:00 - 17:00 2,00 CASE OTHR SURFAC 17:00 - 00:00 7.00 DRILL SURFAC 1/8/2002 00:00 - 02:30 2.50 CASE CIRC SURFAC 02:30 - 03:30 1.00 CASE OTHR SURFAC 03:30 - 05:00 1,50 CASE CIRC SURFAC 05:00 - 14:00 9.00 CASE OTHR SURFAC 14:00 . 16:00 16:00.17:30 17:30 - 18:00 18:00 - 00:00 2.00 CASE OTHR SURFAC 1.50 CASE RURD SURFAC 0.50 CASE SFTY SURFAC 6,00 CASE PUTB SURFAC 1/9/2002 00:00 - 04:30 4.50 CASE RUNC SURFAC Page 3 of 8 Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: Description of Operations pms = 80 / 64 I 75k Ibs Dir Drlg 6663' md -- 6723' md [4031' tVdj, Cir cond, pump sweep, cir until clean shaker s, S h () r t r rip, p u I I t I) 1 8 I) I)' m,j, H ':' I e I n 0] 0 0 d c onditlon Cut drlg line & service tds. R i h f r ,) m 1 8 0 0' - 6 ì 2 '3 '. [t ,j 0 r bit 11 1 '.": 3 S -+ 6 -t 5 ' I Hit t i 9 h t s P 0 r 1,1' 5 2 1 7' . 5 2 J :3 ' . Was h .. r leam same. Continue to wash! ream tight 20 I n ~ s 5 3 I) 0 - 3 1. 5 -+ 9:: . :,:' -! ;-. [, 1 t;, (I . I:, 2. -+ 0 '. T hen continued to precautionary was i ream t 0 td of 6723'. Dir drlg 6723 - 7763' [448-1 tVd , Dir drlg 7763 -- 8060' md. 4616' tvd. Pump sweep / cir cond mud, Pooh. Tight zone @ 6896' (60'), 1685', & @ 703', Lost 12 bbl mud on trip out. Clean floor & organize floor. Remove sources from Iwd tools & down load same. LD bha. Service tds / rig, change out worn saver sub & dump valve on draw works. Rih wI 9,875" reaming assmby to td of 8060' Tight spots @ 1820 & 6890', wash / ream same. Cir & con mud, adjust pv from 24 to 18 & yp 24 to 20. Mud weight to 9.6 from 9.7 ppg. Pooh for csg, tight spots 1st 4 stands, Was h ream back to td, no restrictions observed. Cir I cond mud. Pooh for csg, 1st stand overpulled 20k Ibs. Pulled tight from 2313 - 2200', wash & rea m same 2x times & sweep {420 gpm / 1200 P si} from 2370. Recovered a minimum amt 0 f debris. Complete tooh to reaming tools. Ld reaming assmby. Ru csg crew. PJ S M Pu / mu shoe track as per csg detail, check operation of float equipment. Continue to ri h wI a total of 105 of 187 jts of 7.625" x B T&MC x L-80 x 29.7 ppf , filling each joint. Break circulation @ 2750, & 4500. JOb inco mplete @ rpt time. NOTE 1 : Worked thro ugh bridge @ 2370'. NOTE 2: Establish BT&MC make up torque of 8000 ft-Ibs over 10 jts utilizing index marks. Continue to rih wI of 186 its of 7.625" x B T&MC x L-80 x 29.7 ppf , filling each joint. Break circulation @ 6650'. Pnnted: 1/30/2002 1:33: 14 PM t;~1 TjTfI ~, Page 4 of 8 PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/9/2002 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Sub From - To Hours Code Code Phase 04:30 - 05:00 0.50 CASE RUNC SURFAC 105:00 - 08'30 3 50 CE~.1Er IT¡ CIRC I SURF,ô,C I û3:31} - 09:30 109:30 - 10:00 I I 1 00 I CEr.1Er IT¡ PULD 0,50 CE~.lEr IT¡CIRC I ! I 4.00 CEMENT DISP SURFAC I SURF,..\C I SURF,L\C I 10:00 - 14:00 14:00 - 20:00 6.00 CEMENT RURD SURFAC 20:00 - 22:00 2.00 CASE OTHR SURFAC 22:00 - 00:00 2.00 CASE NUND SURFAC 1/10/2002 00:00 - 05:30 5,50 CASE NUND SURFAC 05:30 - 06:00 0.50 WELCTL OTHR SURFAC 06:00 - 06:30 0,50 RIGMNT RSRV SURFAC 06:30 - 10:30 4.00 WELCTL BOPE SURFAC Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: G ro up: Description of Operations Ld fill up tool ck valve assmby & stinger M u hanger jt [jt # 187] wI hanger & cir down. Mu Idg jt & cir down. Idg out in well hd - P u { 2 0 5 k I b s} 3' 0 t f sea t . C s g 5 t u c k ,~, 1 d , I C Ire 0 n "ã' 3 (j 0 P '3 i 5. 6 b p m uti I i Z In') I I I I u P t Û 0 I. P v = 1 6, '( P , 1 -+ ~~ m \V = '). 6 P P 9 , Una b Ie to free csg wi over pulls 10 90k Its over 5 t r i n 9 \'1 t , I L d fill u pt.:; 0 I ~: rn u c m t 11 oj I c¡ -:; s oJ sir I n 9 . I P J S ~.1 C 0 n tin u e t 'J C Ire u I .3 t e 1,1 i a c m tho:: d .j , I U n ?1 to I 0:: t ':' u n 5, I I ': k ::, t r i n oJ \'1' ':' ': 0 r p LJ I I ~ I <) 1 (I ':' k Ibs over string. Dowell crnted 7,625" csg as follows: Pumpe d 45 bbl CW 100 chern wash [pt lines 10 350 0 psi] @ 600 psi / 6,2 bpm, then 50 bbl 10. 5 weighted spacer @ 550 psi / 6.2 bpm. Ora p bottom plug, Pump 600 sx [474 bbl] of Ie ad ARTICSET liTE CMT CI G [ 10,7 ppg, wtr = 20.7 gal/sx, 4.45 cft I sx. Adds = D079 1 , 5 o'ó, S 00 1 1. 5 °ó, D 04 6 . 6 0 ~o, D 065 . 5 %, D 1 2 4 5 0 %. & 0 0 5 3 3 0 ~,¡, a II B WaC] . Pre s s / r a tes max - min - avg = 600 - 300 - 450 psi, 6 .5 - 5,7 - 6.0 bpm. FOLLOW WI 326sx [44 bbl] tail LiteCRETE cmt [12.0 ppg, wtr = 7. 45 gal I SX, yield = 2,23 cft / sX.-- Dry adds : D046 = .20%, S001 = .25%, all BWaC, wet phase: D185 = .09 gal / sx blend] Pres s I Rates max - mon - avg = 570 - 300 - 470 psi / 3 - 5 - 5 bpm. Drop top plug, Dowell pumped 10 bbl fw then handed to rig, displa ce w/ 365 of 367 [total disp numbers] calcul ated bbl 9.6+ ppg mud [34 strokes early]. P ress I rates max - min - avg = 1370 - 700 - 1250 psi / 6.1 - 2.4 - 6.0 bpm, Bumped fro m 1100 to 2100 psi holding for 10 min, bled off, plugs held good. Full returnes throug haul. 60 bbl [75sx] 10.7 ppg cmt to surface CIP @ 1352 hrs. SO & Idg csg hanger in starting head[170k Ibs tension]. Nd diverter Ldg I mu FMC Ger 5 csg hd assmby & test to 1000 psi. Nu bops, incomplete @ rpt time. Continue to nu bope. Mu annular to stack [ had been removed for routine maintenance]. Set test plug in well hd. Rig service, Test Bope to 300 I 5000 psi 5in -- annular 3 00 / 3500 psi 5 min, Necessary to re-tighte n annular to ram flange, Repair test pu mp. 10:30 - 15:00 4.50 CASE OTHR SURFAC L d 30 j t sot tub I a r s [h w d P & too Is] fro m d e rr Pnnled: , /3012002 l' )3'14 PM /~. I¡TfI ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/1 0/2002 1 1 1 2('¡~12 PHILLIPS ALASKA INC. Operations Summary Report 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Page 5 of 8 Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: 4.50 CASE 2.00 CASE OTHR SURFAC RURD SURFAC OTHR I SURFAC Sub From - To Hours Code Code Phase 10:30 - 15:00 15:00 - 17:00 ,17:00 - 20:00 120,00 - 00:00 ,(¡Ü.Üü - Ü2:0Ü I 02:00 - 03:00 03:00 - o.. .:oo 04:00 - 05:00 05:00 - 06:30 06:30 - 07:30 07:30 - 09:30 09:30 - 10:30 10:30 - 16:00 16:00 - 18:30 18:30 - 00:00 3,00 CASE ..LOr) C.';SE OTHR 2,00 C.';SE OTHR ISIJRF^C ¡C,LII--'C' r, '- " toiL, 1.00 CASE CIRC SURFAC 1,00 CASE DEQT SURFAC 1.00 RIGMNT RSRV SURFAC 1.50 WELCTL OTHR SURFAC 1.00 DRILL DRLG PROD 2,00 DRILL CIRC PROD 1.00 WELCTL OTHR PROD 5,50 DRILL DRLG PROD 2.50 DRILL DRLG PROD 5.50 DRILL DRLG PROD 1/12/2002 00:00 - 03:30 3,50 DRILL DRLG PROD 03:30 - 08:30 5.00 DRILL TRIP PROD 08:30 - 12:00 3,50 DRILL TRIP PROD 12:00 - 16:30 16:30 - 00:00 4.50 DRILL TRIP PROD 7.50 DRILL DRLG PROD Description of Operations ick requiring 27 breaks. Change out tongs, pipe spinners & pipe han dling equip. ~.1 U b h a & r i h . U P I 0 :3 d m \V d l I w d . P J S M - I , n ~ I a I I n e u t r (I n S ,j U r eel f) ':' I , R ,) I ate :3 I ':. ':1 I y t h r 0 ugh Tam C 0 I I a r ¡,j' 9 9 t3 '. Pre s s t est t 0 1 Ù 0 Ü psi,' 5 min good. R I h I,'J' -I" (J p, r p t t i m ~ bit ,j ~ r,1 f h = 5 -I -I i) , C ,j n 1 i n U ~ t (I r I I-, t ':' :-- ,) .:: :- '. ': I ~ ~ n ,j ute m t ~ '~I .:: :-- I - -;- 9 ~ -I ~ ) ~ I ;, :3 t s h ':' ~. fro m ,:; s I) t a I I 'J w, P lug ~' f , c, ..;, .'~:J..: j. Clr bottoms up. Ipressure test csg to 3580 psi I 30 mln, no I eak off, charted. Cut & slip drlg line. Drlg float collar 7944 - 7946' [ 8' high]. Dr Ig float shoe @ 8031', Clean out cmt I mud to td of 9.875" hole @ 8060', Drlg new hole 8060 - 8077'. Slow drilling, Disp well to new Isnd 8,6 ppg mud [580 bbl t 0 surface & hole]. Pull into csg. Conduct leak off test to 12,3 9 ewt wI 8.6 ppg mud in hole, tvd = 4623', I eak off pressure [imposed] = 910 psi, EMW 8.6 ppg +{ 910psi ? [.052 x 4623]} = 12.3 9 P p g. Dir drlg 8077 - 8155'. Rops 10 - 25 fph. W ork string, vary parameters & sweep hole wI nutplug. Not sufficient cuttings to surface to obtain good lithology, GR in the 105 stan dard GR range, Dir Drlg 8155 - 8380' , rops held to 150 fph @ 1 - 5k Ibs [logging constraint]. Dir drlg 8380 - 8564' [4856' tvd] Rop in the 20 - 40 fph, Vary parameters wI little chan ge. Lithology sd to 30% wI remainder sh, ADT = AST of .25 + ART of 11,1 = 11.35 hr s. BGG 104 u from 8157', Avg = 23, Con G as = 0 Dir drlg 8564md [4856tvd] -8659md [4908' tv d]. ROPs 25 to 35 fph. Varied parameters wI no signigficant effect on rop. Pooh [ bit change] to bha to include rig ser vie e. Pull bha, PJSM, recover radiation source fr om neutron tool. down load Iwdlmwd, x-out b it, rih wI bha, program Iwd/mwd, install radi at ion source & run below ground level, Bit had 2.5 of 6 water courses packed off & on e plugged jet. No damage to cutters. Rih wI 4" dp to 8566', precautionary wash - ream to td of 8659' [no fill]. Directional drlg 8659 - 9322 md [5356' tvd]. Pnnted: 1/30/2002 1::13: 14 PM ~. ~ ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1/12/2002 1 '1 :. '2(i(1~ 1 114/2002 1/15/2002 1/16/2002 Date PHILLIPS ALASKA INC. Operations Summary Report 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Page 6 of 8 Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: Sub From - To Hours Code Code Phase 16:30 - 00:00 IIY' ¡lll - n~'¡ll) I - . , . - . - . - I 1'6 "c ", 3'"\ I I U :U) - 1)0: IJ 1 - , - 1 ~ -. 1 II.L',.".'- ;:;,,'.11) I I 18:00 - 18:30 13:30 - 23:30 23:30 - 00:00 00:00 . 01 :30 01 :30 . 02:00 02:00 - 03:30 03:30 - 04:30 04:30 - 19:30 19:30 - 22:30 7.50 DRILL DRLG PROD I i I 6,00 DRILL I DRLG I PROD (¡,50 RIGrVI~'JTI RSRV : PROD 11 5r) DRILL i DRLG : PROD 0.50 RIGMNT RSRV PROD 5.00 DRILL DRLG PROD 0,50 DRILL crRC PROD 1.50 DRILL DRLG PROD 0,50 DRILL OTHR PROD 1,50 WELCTL OTHR PROD 1,00 WELCTL TRIP PROD 15.00 DRILL DRLG PROD 3.00 CASE CIRC PROD 22:30 - 00:00 1,50 CASE OTHR PROD 00:00 - 03:30 3.50 DRILL TRIP PROD 03:30 - 05:30 2.00 DRILL PULD PROD 05:30 - 09:00 3,50 DRILL TRIP PROD 09:00 - 11 :00 2.00 DRILL CIRC PROD 11 :00 - 12:00 1.00 DRILL TRIP PROD 12:00 - 19:30 7,50 DRILL crRC PROD 19:30 - 22:30 3,00 DRILL TRIP PROD 22:30 - 23:30 1.00 DRILL OTHR PROD 23:30 - 00:00 0.50 DRILL TRIP PROD 00:00 - 04:30 4,50 DRILL TRIP PROD 04:30 - 06:00 1,50 DRILL OTHR PROD Description of Operations 100 - 125 fph [no conn time]. PARAMET ERS: 2600 - 2750 psi @ 6.3 bpm, wI = 2 -1 Ok rbs, rpm = 203 slide I 280 rot. Tq = ì500 tl-Ibs on botlom, 5500 ofl bottom, ECOs 10 - 1 0 ,5 P p 9 ' \0"/ T '3 IJ p',] \V n r ':' t = 1 1 5 / r:¡ 0 1 0 û~; I b s r û t ..â' 8 0 r pm, .-\ d 1 = 6, 1 5 = a '3 t 1."¡ + art -1.,75 D i r d r I '] 9 3 ? 2 m d ':: 3 5 I:, f '.' Ii) t ,) 9 -;' 0 I) m d (5 f. I -; -: t '. ,j ¡ R I) P 1 (I (I . 1 ~ '~I I P 1"1 IService rig and tds, I D I r ,j r I 'J ,):- (I I) il"I ,j I:' I~, :- -: t '.' ,] I 1 (I ,¿ ,3:- m ,j \ t3 2 1 ,j I 1 v d) IService rig & tds. IDir drlg 10267 md (6218 Ivd) 10480 md (643 Olvd). Rop 50 -100fph. POOH to the shoe, incomplete ,go' rpl time. Continue to pooh 10 7998'. Clean rig floor & service tds, Pjsm. Ru test lines for LOT. Conduct LOT as follows: Mw = 9,9ppg, [vd = 6430', Leak off pressure = 680 psi. EMW = 9.9 ppg + { 680 psi?( .052 x 6430')} EMW = 9.9 ppg + 2.034 = 11,93 ppg emw Pumped 94.5 gallon S, Recovered 58.8 gallons RD test equipm en 1. Rih to 10630', wash I ream last stand to td of 10480', no fill. Dir drlg 10480' md - 11060' md [7045' tvd]. Control drlg [50 fph] from 10550' to td [110 60'] for aquiring sonic & neutron-density dat a. Cir - condition pump sweep & cir until shake rs clean [minor amt debris to surface], Dr ¡I ling Gas: current back ground 50 w/10.1+ ppg mud, max connection 1040 wi 9.9 ppg m ud. Numerous gas peaks to 800u during drl 9 production section. Pooh for reamer run assmby, POH wi 4" dp. PJSM-Radioactive source-lay down bha-clea n floor. Well bubbling wi gas-pick up hole opener & rih to 8010'. Circ. well thru choke =build mud wt. to 10,4 #. RIH from 8010' to 11060', Circ. condition mud to 10,6#-pump sweeps-m onitor well OK, POH slow to 7918'. Slip & cut drlg. line. POH to run csg, POH wI 4" dp & hole opener-lay down bha. Clean floor & pull wear ring. Pnnted: 1/30/2002 1 :33: 14 PM ~.. r¡t'jI ~!:Ø PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date Sub From - To Hours Code Code Phase 1/16/2002 06:00 - 09:30 3,50 DRILL OTHR PROD 09:30 - 10:30 1.00 CASE SFTY PROD 10:30 - 21 :30 11,00 CASE RUNC PROD 21' ~:I) - ?J"iXI 1 ,:,~II C'; S E CIRC IPROD I I 23:00 - 00:00 I 1 00 C.~SE IRU~JC PROD ()(I'OO ' (11 '?,Il I 1, 51~ C~:;E RIJrJ(:' PR'')D 'J1:3( - Ü2.~' j I .?r~II~I! C,..\:;E CIRC I PR<:JD I I I I I 03. ~I) - (II~,. ~II~I i ,,>~,':II C':'SE ¡RUrJC ¡ F'R,:,¡Q I I I 06:00 - 22:00 16.001 CEMENTCIRC PROD I 22:00 - 00:00 2.00 CEMENT PUMP PROD 1 '1"':" ~OI~12 1/18/2002 00:00 - 08:30 8.50 CMPL TN OTHR CMPL TN 08:30 - 00:00 15.50 CMPL TN OTHR CMPL TN 1/19/2002 00:00 - 03:30 3.50 CMPL TN PULD CMPL TN 03:30 - 05:00 1.50 CMPL TN RURD CMPL TN 05:00 - 09:00 4,00 CMPL TN OTHR CMPL TN 09:00 - 10:00 1,00 CMPL TN OTHR CMPL TN 10:00 - 21 :00 11.00 CMPL TN RUNT CMPL TN 21 :00 - 22:00 1.00 CMPL TN SOHO CMPL TN 22:00 - 00:00 2.00 CMPL TN CIRC CMPL TN 1/20/2002 00:00 - 01 :30 1.50 CMPLTN CIRC CMPL TN 01 :30 - 02:00 0,50 CMPL TN OTHR CMPL TN 02:00 - 03:00 1.00 CMPL TN DEaT CMPL TN 03:00 - 03:30 0.50 CMPL TN OTHR CMPL TN 03:30 - 05:30 2.00 CMPL TN NUND CMPL TN 05:30 - 12:00 6.50 CMPL TN NUND CMPL TN Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Page 7 of 8 Spud Date: 12/26/2001 End: Group: Description of Operations Set test plug-Change lower rams to 5.5" & u pper rams to 3.5"-test same 250-3500. Rig up to run 3.5" X 5,5" csg-PJSM Running 18 its. 3,5" & 5.5" o:s9, C i ( c, C:1 ~,I .1 ': t '/ I:' Ie''" ':1 ' ' ( rJ '"I p i I I I u r' I ':' ,~, I ,~, ': ¡',ange bails, Running .:sg, Run ¡nil ':' Ie'.'." I~ ~ ':1 t (', ')'~ (I '~I ' , I [, I ,:.. "1~' .- I r,' - I 'j : In'] - S I" " ," r.-. t I J r r, ':, ,,~ 1 1:, P ill , ...'; [ [ lem~p'[ 't~ r~~ai~ full ç'lr".:, ~. ~- I R I.J n i n t" ,j I.;; ':. (,~, 9 . r ,1 :1 ~.-è u~' 1",.1 I', rJ .:. r ,~~ I J n oj ,: I a rn e - m a k e u pee men [ h t: :¡ Ij - b r e ,1 k G ire. @, l' 2 bpm while reciprocating-up W[, 150k down w t. 85k. Attempting to establish full circ. for cement job. Hold PJSM-Test lines 3500#- Batch mix & pu mp-40 bbls, cw 100-40 bbls. mudpush-follow ed wi 44 bbls. 15.8# class 'G' ceme,nt-wl 20 bbls. 10.8# brine-30 bbls. water & 204 bbls, mud-bump plug on calculated strokes-floats held-had 92% returns thru mud displaceme nt-Flow back on annulus-shut annular preve nter wI 190# on choke. Rig down csg. running equipment-rig up to I ay down dp out of derrick-load 3.5" tbg. in p ipe shed-drift & strap same. Lay down 4" dp out of derrick. Lay down 4" dp in mousehole. Rig down dp handling equipment & rig up to run 3.5" completion, Finish bleeding outer annulus. (bleed total of 44 bbls. volume). PJSM=Rig down landing jt.-pick up setting t 001 & set packoff-test to 5000# 10 mins. PJSM-Run completion as per program, Note ( While running completion-hot oil freeze pr otected 7 5/8" X 5.5" annulus @ 1500 hrs,-2 00# on annulus when started-broke down @ 1800#-final pressure 1200# @ 1,5 bpm. Pum ped total of 80 bbls. diesel,) Space out & make up hanger. Displace well to clean seawater @ 5 bpm. Displace well to seawater. Drain stack-land hanger & rilds, Test tbg. 1500# 15 mins,-test annulus 3000# 15 mins.-bleed tbg,-shear DCR valve @ 375 0 #, Lay down landing it. & install bpv. Nipple down bope. Load tree in cellar-nipple up tree-realig n tre e orientation per production engineer-test t hn h~nn r tn ¡;¡nnn t ~. TiTfI ~~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Page 8 of 8 PHilliPS ALASKA INC. Operations Summary Report 1 M-17 1 M-17 ROT - DRILLING NORDIC 3 n1433@ppco.com Nordic 3 Date From - To Hours Code Sub Phase Code 1/20/2002 12:00 - 14:00 2,00 CMPL TN FRZP CMPL TN 14:00 - 16:00 2.00 CMPL TN OTHR CMPL TN I I OTHR i CLIPL TrI 116.00-13.00 I 2,(IÜI cr.IPL Tr . . I 1 .3, ()'~I . I ,:r,1PL Tr I(r lPLTrJ I ! i 1 I I I I Start: 12/26/2001 Rig Release: 1/20/2002 Rig Number: 3 Spud Date: 12/26/2001 End: Group: Description of Operations Pull 2 way check & freeze protect well wI 10 0 bbls. diesel-equalize same. Rig down circ. hoses-set bpv-finish cleaning I pits-secure well-ready rig for move off well ;. P J S r.1 U'JV~ rig ùlt '.\'~II ,:" cl~an up ~Ictd, III') leleas e d fro m 1 r'.1 - 1 -; '3' 1 8 (I 0 h r s, I) 1 .2 (, ~ (I CI 2 ) Pnnred: 1/30/2002 1 :33' T 4 PM Date 02/16/02 03/20102 03/21/02 1 M-17 Event History Comment PERFORATED C SAND INTERVAL 10606' TO 10642' WI 2,5 HJ, 6 SPF, 2506 HYPERJET CHGS (TOTAL OF - 36 FT IN 2 RUNS) PUMPED BREAKDOWN AND DATAFRAC WITH E-LlNE IN THE WELL. PUMPED C SAND FRAC. SAW TSO - 25 MINUTES INTO JOB, HAD NWBSO Wig PPA ON PERFS. 90M# BEHIND PIPE, 53~lO OF DESIGN. LEFT 28M# IN WELLBORE. Page 1 of 1 3/26/2002 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 30-Jan-02 Re: Distribution of Survey Data for Well 1 M-17 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , MD (if applicable) 11,060.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RE~f"E ã\ IL:D ,~ .' ,\~ .--- ~ \J L,.. r -:-; r\ i '1("\n') a,Q~/~'d'36 - JEF NT VE Kuparuk River Unit North Slope, Alaska Kuparuk 1M, Slot 1M-17 1M-17 Job No. AKMM11217, Surveyed: 14 January, 2002 SURVEY REPORT 29 January, 2002 Your Ref: API 500292305800 Surface Coordinates: 5960383.58 H, 571907.35 E (70018' 07.3972" H, 149025' 03.2386" W) Kelly Bushing: 98.58ft above Mean Sea Level 5j..a=""-'Y-SUI1 DRILLING S&AVICeS A H8111burton Comp8ny Survey Ref: svy9755 Sperry-Sun Drilling Services . Survey Report for 1M-17 Your Ref: API 500292305800 Job No. AKMM11217, Surveyed: 14 January, 2002 North Slope, Alaska Iparuk River Unit Kuparuk 1 M easured Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs E.stlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -98.58 0.00 O.OON O.OOE 5960383.58 N 571907.35 E 0,00 MWD Magnetic 153.50 0.530 170.440 54.92 153.50 0.705 0.12 E 5960382.88 N 571907.47 E 0.345 0,56 245.52 0.970 167.380 146.93 245.51 1.885 0.36E 5960381.70 N 571907.73 E 0.480 1.53 334.05 1.660 191.040 235.44 334.02 3.875 0.28E 5960379.71 N 571907.66 E 0.976 2,81 424.37 2.280 159.870 325.71 424.29 6.845 O.64E 5960376.75 N 571908.06 E 1.345 5,08 513.34 3.590 117.690 414.57 513.15 9.805 3.72E 5960373.82 N 571911.16 E 2.742 935 602.50 4.260 113.270 503.52 602.10 12.405 9.23 E 5960371.27 N 571916.70 E 0.824 15,18 691.26 7.900 110.300 591.76 690.34 15.825 17.99 E 5960367.93 N 571925.49 E 4.115 23.95 782.55 10.990 118.320 681,81 780,39 22.135 31.54 E 5960361.75 N 571939.10 E 3.671 38.22 873.45 13.480 123.040 770.64 869,22 32.02 5 48.05 E 5960352.02 N 571955.70 E 2.950 57,08 962.05 15.660 126.320 856.39 954.97 44.73 S 66.34 E 5960339.48 N 571974.12 E 2.630 79,17 1057.13 18.400 127.830 947.29 1045.87 61.54 5 88.54 E 5960322.89 N 571996.47 E 2.919 106.90 .151.31 20.570 128.560 1036,07 1134.65 80.975 113.22 E 5960303.70 N 572021.34 E 2,319 13823 1250,53 22.310 130.220 1128.42 1227.00 104.005 141.23 E 5960280.94 N 572049.57 E 1.857 174,45 1344,69 24,580 130.330 1214.80 1313.38 128.22 5 169.81 E 5960256.99 N 572078.38 E 2.411 211 88 438.95 27. 100 129.150 1299.63 1398.21 154.46 5 201.41 E 5960231.05 N 572110.23 E 2.728 252,92 1533.24 30.700 127.960 1382.17 1480.75 182.84 5 237.05 E 5960203.02 N 572146.14 E 3.866 298,38 627,96 34.060 128.780 1462,15 1560.73 214.33 5 276.81 E 5960171.91 N 572186.20 E 3,577 348,98 1721.57 36,020 129.040 1538.79 1637.37 248.09 5 318.62 E 5960138.55 N 572228.33 E 2.100 402,63 :815.90 37.860 128.250 1614.18 1712.76 283.49 5 362.90 E 5960103.58 N 572272.95 E 2.014 459,20 912.56 39,910 128.900 1689.42 1788.00 321.335 410.33 E 5960066.20 N 572320.74 E 2,162 519.75 .007.51 42.430 128.980 1760.88 1859.46 360.61 5 458.95 E 5960027.38 N 572369.73 E 2.655 582, 14 102,30 45 420 130.630 1829.15 1927.73 402.725 509.44 E 5959985.76 N 572420,62 E 3.377 647,82 196,75 51 . 120 132.940 1892.00 1990,58 449.71 5 561.93 E 5959939.27 N 572473.55 E 6,304 71827 ,290.59 54,320 131.430 1948.83 2047.41 499.82 5 617.26 E 5959889.69 N 572529,36 E 3.642 792,92 385.59 56.170 131,740 2002.99 2101.57 551.63 5 675.63 E 5959838.44 N 572588.23 E 1.966 870,96 480.12 59,810 131.430 2053.09 2151.67 604.82 5 735.58 E 5959785.83 N 572648.69 E 3.861 951. 10 '574,23 62.310 131.960 2098.62 2197.20 659.60 5 797.07 E 5959731.64 N 572710.70 E 2.702 1033,45 368.65 61.810 131.450 2142.86 2241.44 715.09 S 859.34 E 5959676.74 N 572773.50 E 0.713 1116 86 764.56 63.190 132.630 2187.15 2285.73 772.06 5 922.52 E 5959620.38 N 572837.22 E 1.806 1201,92 "- - ---- 'lUary, 2002 - 15:50 -- -- ---- - .... --- Page 20f6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 1 M-17 Your Ref: API 500292305800 Job No. AKMM11217, Surveyed: 14 January, 2002 North Slope, Alaska )aruk River Unit Kuparuk 1 M 'asured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Jepth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment eft) eft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) ?858.83 64.430 132.100 2228.75 2327.33 829.06 S 985.02 E 5959563.98 N 572900.26 E 1.409 1286.51 ~953.69 64.160 132.900 2269,90 2368.48 886.81 S 1048.04 E 5959506.84 N 572963.83 E 0.811 1371 .98 048.22 63.410 132.340 2311.66 2410.24 944,23 S 1110.44 E 5959450.02 N 573026.78 E 0.955 1456,79 .142.82 62.780 133,220 2354,46 2453.04 1001.53 S 1172.36 E 5959393.32 N 573089.24 E 1.064 1 54 1. 1 5 237.41 63.610 133.490 2397.12 2495.70 1059.49 S 1233,75 E 5959335.95 N 573151,18 E 0.914 1625,56 332.13 64.770 133.460 2438.36 2536.94 1118.16 S 1295.62 E 5959277.88 N 573213.62 E 1.225 1710.81 426.74 64,310 133.270 2479.03 2577.61 1176.81 S 1357.72 E 5959219.82 N 573276,28 E 0.519 1796.22 521.50 63.760 133.890 2520.52 2619.10 1235.54 S 1419.44 E 5959161.68 N 573338.55 E 0.826 1881,39 316.12 62,370 133.570 2563.38 2661,96 1293.85 S 1480.39 E 5959103.96 N 573400,06 E 1.500 1965,72 710.25 62.370 136.460 2607.04 2705.62 1352.83 S 1539.34 E 5959045.55 N 573459.57 E 2.720 2049,01 ,804,97 63,490 134.730 2650.15 2748.73 1413.07 S 1598.36 E 5958985.87 N 573519.16 E 2,011 2133,21 300.08 64.770 135.710 2691.65 2790.23 1473.82 S 1658.63 E 5958925.70 N 573580.01 E 1.634 2218,67 395.21 64.090 135.770 2732.70 2831.28 1535.28 S 1718.52 E 5958864.82 N 573640.49 E 0.717 2304,33 J89.97 63.960 135.630 2774.21 2872,79 1596.24 S 1778.02 E 5958804.43 N 573700.56 E 0.191 2389,37 184.69 64.040 136.480 2815.73 2914.31 1657.54 S 1837.10 E 5958743.70 N 573760.23 E 0.811 2474.32 279,29 64.380 134.370 2856.89 2955.4 7 1718.21 S 1896.88 E 5958683.60 N 573820.58 E 2.040 2559,36 '374.28 64.030 131.950 2898.23 2996,81 1776.71 S 1959.25 E 5958625.71 N 573883.52 E 2323 2644,87 468.81 63.810 132.630 2939.79 3038.37 1833.84 S 2022.06 E 5958569.18 N 573946.87 E 0,687 2729,77 j56.69 63.340 132.850 2978.90 3077.48 1887.25 S 2079.86 E 5958516.32 N 574005.18 E 0.580 2808,47 j58.19 62.390 131.510 3025.19 3123,77 1947.90 S 2146.79 E 5958456.32 N 574072,69 E 1.502 2898,79 '53.05 60.290 132.610 3070,69 3169.27 2003.65 S 2208.59 E 5958401.16 N 574135.02 E 2.436 2982.02 47.67 61.260 134.380 3116.89 3215.47 2060.49 S 2268.49 E 5958344.90 N 574195.45 E 1.928 3064,58 '41.99 64,400 130.870 3159.96 3258.54 2117.27 S 2330,23 E 5958288.71 N 574257.74 E 4.694 3148,46 37.11 64, 130 130,810 3201.26 3299.84 2173.30 S 2395.06 E 5958233.30 N 574323.10 E 0.289 3234,12 31.49 64.800 131.260 3241,95 3340.53 2229.21 S 2459.29 E 5958178.01 N 574387.87 E 0.830 3319.26 .26.24 63.420 130.120 3283.32 3381.90 2284.79 S 2523.92 E 5958123.05 N 574453.02 E 1.815 3404.46 21.09 62.600 132.180 3326.37 3424.95 2340.39 S 2587.56 E 5958068.06 N 574517.19 E 2.120 3488.95 15.61 66.010 129,530 3367.35 3465.93 2396.07 S 2651.98 E 5958013.00 N 574582,14 E 4.404 3574,07 10.21 65.780 129.770 3405.99 3504.57 2451.17 S 2718.47 E 5957958.54 N 574649.16 E 0.336 3660,33 )5,11 65,280 128,390 3445.30 3543.88 2505.62 S 2785.52 E 5957904.73 N 574716.72 E 1.425 3746.57 -. .-. -~- -- ------ ~ .--------- uary, 2002 - 15:50 Page 3 of6 Dri/lQlJest 2.00,08.005 Sperry-Sun Drilling Services . Survey Report for 1M-17 Your Ref: API 500292305800 Job No. AKMM11217, Surveyed: 14 January, 2002 North Slope, Alaska )aruk River Unit Kuparuk 1 M ,asured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Jepth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) Cft) (ft) (ft) (°/1 OOft) 5699.70 64.030 127.920 3485.79 3584.37 2558.44 S 2852.74 E 5957852,56 N 574784.44 E 1.396 3831,83 794.51 61.650 131.050 3529.07 3627.65 2612.04 S 2917.84 E 5957799,58 N 574850.06 E 3.864 3916,06 5888.94 64.380 131,190 3571.92 3670.50 2667,38 S 2981,23 E 5957744.85 N 574913.97 E 2.894 4000 18 5983.43 63.640 131.610 3613.32 3711.90 2723.55 S 3044.94 E 5957689.30 N 574978.21 E 0.879 4085.10 077,95 64.670 132,320 3654.53 3753.11 2780.43 S 3108.18 E 5957633.03 N 575042.00 E 1.282 4170,17 ,172.41 63.380 132.600 3695.90 3794.48 2837.75 S 3170.83 E 5957576.30 N 575105.19 E 1.391 4255,08 '267.40 64,650 129.940 3737.52 3836.10 2894.06 S 3235.01 E 5957520.61 N 575169,91 E 2.850 4340,44 :361.56 64.400 131.010 3778.02 3876.60 2949.23 S 3299.67 E 5957466.06 N 575235.09 E 1.060 4425,40 456,56 64,320 132.070 3819.13 3917,71 3006.03 S 3363.77 E 5957409.88 N 575299.74 E 1 009 4511,°" '550.72 65,020 130.070 3859.42 3958.00 3061.93 S 3427.93 E 5957354.59 N 575364.43 E 2,059 4596,12 345,41 64,710 131.450 3899.64 3998.22 3117.90 S 3492.86 E 5957299.25 N 575429,89 E 1,359 4681 81 741.71 64.720 129.880 3940.77 4039,35 3174.64 S 3558.91 E 5957243.15 N 575496.48 E 1.474 4768,84 835.92 64,570 129.530 3981.12 4079.70 3229.03 S 3624.41 E 5957189.39 N 575562.49 E 0,372 485389 J30.34 64.990 132.070 4021.36 4119.94 3284.84 S 3689.06 E 5957134.20 N 575627.68 E 2.474 4939 27 024.51 64.730 129,500 4061.37 4159.95 3340.52 S 3753.60 E 5957079.14 N 575692.75 E 2.486 5024,48 119.00 64. 180 131.440 4102.12 4200.70 3395.85 S 3818.45 E 5957024.43 N 575758.13 E 1.942 5109,68 213.68 63.500 130.150 4143.86 4242.44 3451.37 S 3882.78 E 5956969.53 N 575822.99 E 1.418 5194.63 308.32 64.400 132.360 4185.43 4284.01 3507.44 S 3946.70 E 5956914.08 N 575887.43 E 2,303 5279,64 402.10 63.970 135,180 4226.27 4324.85 3565.82 S 4007.65 E 5956856.27 N 575948.94 E 2,745 5364.02 496.86 63.280 134.390 4268.37 4366.95 3625.63 S 4067.90 E 5956797.05 N 576009.77 E 1,043 5448 83 j92.06 63.630 135.160 4310,91 4409.49 3685.61 S 4128.36 E 5956737.65 N 576070.79 E 0.812 5533.92 386.79 63,700 139.470 4352.95 4451.53 3748.00 S 4185.90 E 5956675.81 N 576128.93 E 4.078 5618.46 '81.54 63,480 141.350 4395.10 4493.68 3813,39 S 4239.98 E 5956610.94 N 576183.63 E 1,792 5702,47 76,49 64. 11 0 136.980 4437,04 4535.62 3877.82 S 4295.67 E 595654 7.05 N 576239.94 E 4.182 5787,03 71.64 64.120 134.880 4478.59 4577.17 3939.32 S 4355.21 E 5956486.12 N 576300.06 E 1.986 5872.45 )31.19 63.910 134.750 4504.68 4603.26 3977.05 S 4393.18 E 5956448,76 N 576338.39 E 0,404 5925,93 26.61 63.870 134,560 4546.67 4645.25 4037,27 S 4454.13 E 5956389.12 N 576399.91 E 0,184 6011,54 .21.94 63.620 134.520 4588,84 4687.42 4097.24 S 4515.07 E 5956329.74 N 576461.42 E 0.265 6096.97 15.45 60.470 132.960 4632.67 4731.25 4154.35 S 4574.72 E 5956273.21 N 576521.62 E 3,677 6179 53 10,12 60,040 133.820 4679.64 4778.22 4210.81 S 4634.45 E 5956217.32 N 576581.89 E 0.910 6261 .7 1 -- --_.-_.-"- - --- - _n- -.. uary, 2002 - 15:50 Page 4 0'6 Drl/lQuest 2.00,08.005 4'''''., . " , Sperry-Sun Drilling Serviéès Survey Report for 1M-17 Your Ref: API 500292305800 Job No. AKMM11217, Surveyed: 14 January, 2002 North Slope, Alaska )aruk River Unit Kuparuk 1 M 'asured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Jepth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) .i504.32 59.740 133.000 4726.90 4825.48 4266.81 S 4693.65 E 5956161.89 N 576641.62 E 0.818 6343.19 J600.13 57.330 130.410 4776.91 4875.49 4321.19 S 4754.63 E 5956108.10 N 576703.12 E 3,412 6424,89 ;694.32 54 .050 128.950 4830.00 4928.58 4370.87 S 4814.49 E 5956058.99 N 576763.45 E 3.710 6502,59 3789.25 51.720 131.010 4887.28 4985.86 4419.48 S 4872.50 E 5956010.93 N 576821.92 E 3.003 6578,22 J884.68 49.980 133.080 4947.54 5046.12 4469.03 S 4927.46 E 5955961.92 N 576877.35 E 2.481 6652,21 ,979.87 48.470 130.980 5009.71 5108.29 4517,29 S 4980,99 E 5955914,16 N 576931.34 E 2.304 6724.29 '072.75 46.340 132.000 5072.56 5171.14 4562,58 S 5032.21 E 5955869,37 N 576982.99 E 2.432 6792.65 167.78 43.090 131.530 5140.09 5238.67 4607.11 S 5082.07 E 5955825,31 N 577033.28 E 3.438 6859.50 263.12 39,560 131,400 5211.67 5310.25 4648.80 S 5129.23 E 5955784.09 N 577080,84 E 3,704 6922 44 355.85 36.340 131.370 5284.79 5383.37 4686.49 S 5172.01 E 5955746.80 N 577123.98 E 3.473 ó979 45 452.20 33,730 131.390 5363.67 5462.25 4723.05 S 5213.51 E 5955710.64 N 577165,83 E 2.709 7034.75 546.33 31,060 132.750 5443.14 5541.72 4756.82 S 5250.96 E 5955677.23 N 577203.59 E 2.940 7085. 17 341.65 28.180 131.770 5526.00 5624.58 4788.51 S 5285.81 E 5955645.87 N 577238.74 E 3.064 7132,28 735.99 24.390 132.650 5610.57 5709.15 4816.56 S 5316.76 E 5955618.12 N 577269.96 E 4.038 7174,04 1830.66 20.420 131.000 5698.08 5796.66 4840.65 S 5343.61 E 5955594.29 N 577297.04 E 4.245 7210.12 J23.82 17.390 129.890 5786.20 5884.78 4860.24 S 5366.57 E 5955574.92 N 577320.1 B E 3.275 7240,28 J 17.98 15.430 131.930 5876.52 5975,10 4877.64 S 5386.68 E 5955557.72 N 577340.47 E 2.169 7266,87 J98.49 13.040 131.920 5954.56 6053,14 4890.87 S 5401.41 E 5955544.63 N 577355.32 E 2.969 7286 66 207.02 10.760 133.520 6060,75 6159.33 4906,02 S 5417.87 E 5955529.63 N 577371.92 E 2.122 7309,04 301.88 8.650 137.220 6154.24 6252.82 4917.36 S 5429.14 E 5955518.41 N 577383.30 E 2.318 7325,00 397.12 6.590 132.900 6248.64 6347.22 4926.34 S 5438.01 E 5955509.51 N 577392.25 E 2.244 7337.60 91,78 4,500 130.120 6342.85 6441.43 4932.43 S 5444.83 E 5955503.49 N 577399.13 E 2.225 7346.74 ;86.43 2.960 117.080 6437.30 6535.88 4935.93 S 5449.84 E 5955500.03 N 577404,18 E 1,847 7352,81 ;80,94 1,520 111 .260 6531.73 6630.31 4937.50 S 5453.18 E 5955498.50 N 577407.54 E 1.541 7356,34 73.44 1.480 84.960 6624.20 6722,78 4937,84 S 5455.52 E 5955498.18 N 577409.87 E 0.739 7358.29 70.04 1,720 87.440 6720.77 6819.35 4937.66 S 5458.21 E 5955498.38 N 577412.56 E 0.259 7360,17 '65.74 1.950 111.410 6816.42 6915.00 4938.19 S 5461.16 E 5955497.88 N 577415.52 E 0.830 7362.70 JO.88 2.210 112.380 6851.54 6950.12 4938.67 S 5462.34 E 5955497.41 N 577416.71 E 0,747 7363.90 '60,00 2,210 112,380 6910.61 7009.19 4939.54 S 5464.45 E 5955496,56 N 577418.82 E 0.000 736604 Projected Survey ------- _. - 'uary, 2002 - 15:50 Page 5 0'6 DrillQuesf 2.00.08,005 Spefry-Sun Drilling Services Survey Report for 1M-17 Your Ref: API 500292305800 Job No. AKMM11217, Surveyed: 14 January, 2002 . Kuparuk River Unit North Slope, Alaska Kuparuk 1 M All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to MSL. Northings and Eastings are relative to 618' FSL & 600' FWL. Magnetic Declination at Surface is 26.0600 (03-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 618' FSL & 600' FWL and calculated along an Azimuth of 132.3100 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11060.00ft., The Bottom Hole Displacement is 7366.09ft., in the Direction of 132.1120 (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11060.00 7009.19 4939,54 S 5464.45 E Projected SUlVey Survey tool program for 1M-17 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0,00 0,00 11060.00 7009,19 MWD Magnetic ---- -- -.'----- 29 January, 2002 - 15:50 Page 6 0'6 DrillQuest 2,00,08,005 OJ/07/02 Scblum~erger NO. 1878 Schlumberger Technology Corporation. by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1M-17 010/-;;)30 2N-309 Igq-~- 22098 22099 SCMT SCMT 02115/02 02121/02 SIGNEG("~~ L...!J..c;.t' f^' ) RECEIVED DATE: t.; ~;) 'j :- r:'ï10? 1,/'. \ , J L... - Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. AJaskaOO & Gas Cons. CommiSsion Anchorage Scblum~erge.. NO, 1874 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie 03/06/02 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Sepia 1 D-01 J1Q,ot¿9 PRODUCTION LOG WIDEFT 02118/02 1 1 1 D-01 DEFT LOG 02118/02 1 1 1 D-01 V GLS 02118/02 1 1 1D-119 Ig7-d~~ INJECTION PROFILE 02120/02 1 1 1M-17 dO I-d.~ TEMP LOG 02115/02 1 1 30-09 / '(\'8" -Co!.!, J PRODUCTION PROFILE 02125/02 1 1 1D-105A ~D)-~~ 22068 RST -SIGMA 01/17/02 1 1 ~ß - ()n- SIGNEC~ ~~^.. \ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color RECEIVED t.n!) r¡ ~ ')002 i 0' ':' I J L'IIII' Alaska Oil & Gas Cons. ComrnÎ8SÎOn Anchorage 02/27/02 Schlumberger NO. 1853 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Company: Alaska Oil & Gas Cons Comm AUn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1M-17 1 D-05 1 D-120 ,,~/:I}~.d 3D PRESSITEMP STATION LOGS I ,c.¡ - ò ~ S INJECTION PROFILE /0, Î' ~.~ \ INJECTION PROFILE 02116/02 02119/02 02120/02 1 1 1 Sl~~~ RECEIVED DATE: r.!..1.p C ~ "00") " \. . J L '- Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank yo8JaskaOiI&GasCons.Commission Anchorage PHilliPS Alaska, Inc. .:. ,3'Jt'ê"j'3r, ,:.1 FHILUFS Pt:TROLt:UI.1 C,:,r,1F:r" POBOX 100360 ANCHORAGE, ALASKA 99510-036û TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. DATE: AUGIJ.iT 7; 1ge7 ') Ù I - ì S (j AIRBILL:5131156 ,,7\ p\ AFT#: PBV02-02-05-01 :# ( 0 Ç) CHARGE CODE: 42366 OPERATOR: Phillips Alaska, Inc. SAMPLE TYPE: DRY NUMBER OF BOXES: 3 NAME: 1M-17 SAMPLES SENT: ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM THE RIG BOX #1 8070'-9090' BOX #2 9120'-10,680' BOX #3 10680'-11060' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COpy OF THIS TRANSMITTAL TO: lb:1 -\, I 1 RECEIVED BY: (')~ D. GOODMAN AT. 1464 J. REEDER ST. OF AK. Phillips Alaska Inc. BA YVIEW GEOLOGIC FACILITY P. o. BOX 100360 ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: r r:tbA û d À- J~( I k Lóf1 \ ~~]~~ :} !Æ ~!Æ~ ~~!Æ / ALASKA OIL AND GAS / CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W, ? AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279- 1 433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor Phillips Alaska, lnc, PO Box 100360 Anchorage AI< 99510 Re: Kuparuk River Unit IM-17 Phillips Alaska, Inc. Permit No: 201-230 Sur Loc: 618' FSL, 600' FWL, Sec. 17, TllN, RIlE, UM Btmhole Loc. 930' FSL, 759' FWL, Sec. 21, TIlN, RilE, UM Dear Mr. Mallary: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permining determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid FOmlation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on form 10-403 prior to the start of disposal operations. Because IM-17 will be the first development well from the 1M-Pad, induction/resistivity and porosity logs must be acquired from the base of the conductor to the total depth of the well. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, r. :J.h\~. OLvl~,) (. !:LL-./' Cammy ~chsli Taylor,j- Chair BY ORDER OF THE COl\fMISSION DATED this 13tb day of December, 2001 jjc/Enc1osures cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 1a. Type of work: Drill ø Rednll 0 Re-entry 0 Deepen 0 2. Name ot Operator Phillips Alaska, Inc. 3, Address P.O. Box 100360 Anchorage, AK 99510-0360 4, Location ot well at surtace 618' FSL, 600' FWL, See, 17, T11N, R11E, UM At top of productive interval 930' FSL, 759' FWL, See, 21, T1 1 N. R1 1 E, UM At total depth 930' FSL. 759' FWL, Sec. 21, T1 1 N. R1 1 E, UM 12. Distance to nearest property line 13. Distance to nearest well 759' @ TD feet MP 1 17-11-11 124' @ 1006' 16. To be completed for deviated wells Kickoff depth: 400 MD 18. Casing program size 20 MC 25.005 1b. Type of well, Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone ø 5, Datum elevation (OF or KB) RKB 31 feet o#Z~t:~::i~~~n 2293 7, Unit or property Name Kuparuk River Unit 8, Well number 1M-17 9. Approximate spud date December 21 , 2001 14. Number of acres in property 2560 Maximum hole angle Hole Casing Weight 'I 24" 16" 62.5# \'I'b ~ 7.625" 29,7# ~ 6,75" 5.5" 15.5# 6.75" 3.5" 9.3# Specifications Grade Coupling H-40 Weld L-80 BTC-Mod L-80 STCM L-80 EUE 8rd Length 129' 8021' 10371 ' 502' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical teet feet Effective Depth: measured true vertical feel feet Casing Conductor Surface Length Size Cemented Production Pertoration deplh: measured true vertical jMH t '2l14-/o ( !J.IV I"d- . 't"" A'" 1-. I \ Jq I:' I I' Development 011 ø Multiple Zone 0 10. Field and Pool Kuparuk River Field Kuparuk River Pool 11, Type Bond Isee 20 AAC 2502511 Statewide Number #5952 180 Amount $200,000 15. Proposed depth IMD and lVDI 10904' MD /6830 ' TVD 64° 17. Anticipated pressure (see 20 AAC 25.035 lel(21) Maximum surface 2576 psig At total depth (TVD) 3322 psig Setting Depth Commissioner by order of the commission Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 31' 31' 160' 160' Pre-Installed 31' 31' 8052' 4615' 590 sx AS Lite, 300 sx LiteCrete 31' 31' 10402' 6326' 200 sx Class G w/GasSlok 10402' 6326' 10904' 6830' included above Plugs (measuredl Junk Imeasured) Measured depth True Vertical depth RECEIVED NOV 2 9 2001 AlaBkaOII & Gas Coo!., Commission Anchorage 20. Altachments Filing tee ø roperty Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program ø Drilling lIuld progr~ ø Time vs depth ot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I. hereby ~.e~~h~Ore?~: :n./~rrecl to~eSI 01, my kn.OWledge OUesUons? Call I Oddl'IMU2:Vj/~5-697' Signed /" ¿.~11 ¿I'J/ -?'-~" ~ "/, !A..../l!.....' Title: DrIlling Eng/flee"ng SUf)Eof\'¡SO' Date /.-:- -¡ I L...' t C. Mal/ary .- ---- t- I Pr€?DM€?d bv Sh::lron AJ/SUD-nrak~ --.' Commission Use Onl~ Permit Number API number.., CI. - ,-Ç - I Approval date; ~ I t1 (J II See cover letter :;... 6 I - ¿ ~ 50- () tit.... --, 2"3 (:) ':::> 0 ex::::::, 0\. . '). tor other requirements Conditions ot approval Samples required 0 Yes 0 No Mud log required 0 Yes 0 No Hydrogen sulfide measures œ Yes 0 No Directional survey required ~ Yes 0 No ~ Required working pressure for BOPE D2M: 0 3M: 0 5M; 0 10M;D ~ ?~~, N\\~\.~~1'<\... ~\(~.;\: Other: Approved by Original Signed By C~mmy Oechsli Form 10-401 Rev. 12/1/85 . OR 'G ^A- Date /!À.l'3. 0 I Submit in triplicate Application for Permit to Drill, Well 1 M-17 Revision No.1 Saved: 28-Nov-01 Permit It" Kuparuk 1 M-17 Application for Permit to Drill Document MaximizE Well Value Table of Contents 1. Well Name.................................... .............. ....................................................... ........2 Requirements of 20 AAC 25,005 (f).................................... """,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.,,,,,,,,,,, .................2 \ 2. Location Sum mary ................................... .......... ............................... .......................2 Requirements of 20 AAC 25.005(c)(2) ......,....... ...................................................., .............. ..................2 Requirements of 20 AAC 25. 050(b)................................ .................,............ ..........................................2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) . ...... ....... ............... ............. ............... .............. ........................ ....3 4. Dri II i ng Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ....................................................................................,............. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) "",,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.,,,,,,,,,,,,.,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,..... 3 6. Casi ng and Cementi ng Program .............................................. ...............................4 Requirements of 20 AAC 25.005(c)(6) ..:................................................................................................ 4 7. Diverter System Information ............................ .............. ....... .................................. 4 Requirements of 20 AAC 25.005(c)(7) ........................ ........ ........... ........ ........................ .............. ......".. 4 8. Dri II i ng FI u id Program................................................................................ .......... ....4 Requirements of 20 AAC 25. 005(c)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ......................................................5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 1 o. Se ism i c An a I ys is............................................................... ....................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12. Evidence of Bondi ng ............................................................ ........................... ........ 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 01 G NA.. Permit It.doc Page 1 of 6 Printed: 28-Nov-01 Application for Permit to Drill. We1l1M-17 Revision NO.1 Saved: 28-Nov-01 13. Proposed Dri Iii ng Program............... ....................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ... .................,.................... ....., .........,.. .....,.................... '"'''''''' 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) '"'''''''''''' ...... ......... '" ..., ....,.. .......... .......................................... 6 15. Attachments..................................... ....................... ................... ..............................6 Attachment 1 Directional Plan................................ ...,.. "'" .........................................................,......,.,. 6 Attachment 3 Drilling Hazards Summary................ .,.... ....... """"'" .....,....... ..........................................6 Attachment 4 Cement Loads and CemCADE Summary. ...................................................................... 6 Attachment 7 Well Schematic. ................ ........... ......... ..... ....... """"""'" .,....... .., .........., ........... .............. 6 1. Well Name Requirements of 20 AAC 25.005 (f) Eactl well must tit? Identllìed h' â lIl/Ique n.jOlf' dé!...ï~/f}a!eJ b}' tile LJ,Ot:ldti)r ami J uflIi¡ut:! API f/lIlI1br:>r a~SI9f}ed bv tIlt:' l'(lflIlllI,';:;'I~}/Î uf1d~r 20 AAC.?),O'1{1(N. F(Jr.3 ~L't3// 1~'III} fIIulliplt'! I",'~I/ L rdn(hð~ ¿dell [;hmdl m(j...l..:;mll/ar~v De Id2f1(lfiëd b,L d lIflIqUr:> f/..lIne ,.'1f},j 4Pl numÖer bv addmy .3 súlli,~" tu the..' Odllk.' u(;"..''iI(Jf1ate..'d lor the..' We}/I bl/ the (!¡.1c..'ratur 3nu fel (he..' {/umbe'l (,/::'9(Jf1c..'U [,:.J tll¿' wc..'I/ LI.I' the ((111711715':;101 J. The well for which this Application is submitted will be designated as lM-17. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/.!cat/rJn ¡'or a Perrl7lt [(1 DI ti/ must ¿'C" 3CCm17pt7/71ei.1 bY' c.."'iKIJ or tile.""' iùllm~'m9 Item.:;" c..","',~ep{ I(]I an ¡f['1l} a/r23{lv (JII li/r~ Illth {he LÏ)nlnli,r;~ion and Idl?ntlfit;yj Iii t/lr!-" .31..~{J/lcatl()n: (.~) a pl.7t lr1r"fI"f}'l/l,~llhr. pri)¡,l(;vt¡. (md tile.' j.JM/kyty:;; ()¿¡'nf.'r,:; dlld ...::;110! ¡.'llIq {¡1)the (O~Jmlnatt"."; l.l{ th~ /.'(o{.'o.";r:>d /u(,.ìf¡on or t!it' !'It'// at tilt'! sud.::I..:c, at thr top 01 Ô-?{,/I Ub¡f'l /i'i-é' for,7!,:Jt¡'( IfI, .:ind dt !(.'/,-II depL/l. rcferel/C/3d to {JD~'t'rnmt'nlë-1/ sëcllOn lines, (8) the ('()ordllldtc'::; oft/Ie pruPt!5di l('rôtlOn uf tht3 n.'t!I/ dl tlte 5ur¡;-IC~, refe/t'flcr"J I,J lilt:! stJte;> plan':! coomin."l/e SI st2m /Î Jf illl:'-- o;tdtt' ,]0; fJ7amlôlfJco' bV tlk' Nd[¡OII.:fI Georj¿;'tlc Sun-e)' 117 Ihi.-' Natwna/ OCL'ðfli{ iJnd A!nJosp/Jcnc Adnnmstr¿;tI:.ìn: (C) the proposed dCptl7 d tlie H'c..'/I.lt the.." lop a/each ~J[)}cäll/L' formdtJOf! drld.it tot,]/ Je.'f..."1//]; Location at Surface NGS Coordinates Northings: 5,960,383.56 Eastings: 571,907.38 618.2' FSL, 599.91 FWL, See 17, Tl1N, RIlE, UM RKB Elevation 94.0' AMSL Pad Elevation 63.0' AMSL Location at Top of Productive Interval (Kuparuk "C4" Sand) NGS Coordinates Northings: 5,955,470.0 929.74' FSL, 758.71' FWL, See 21, TllN, RllE, UM Eastings: 577,410.0 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 10,582' 6,508' 6,415' Location at Total Depth NGS Coordinates Northings: 5,955,470.0 Eastings: 577,410.0 929.74' FSL, 758.71' FWL, See 21, Tl1N, RllE, UM Measured Depth, RKB: 10,904' Total Vertical Depth, RKB: 6,830' Total Vertical Depth, 55: 6,737' and (D) athcr IlIri."'ilT!h7[¡OI/ td7u,rCt7 t'.v 2tJ ,lV1C 25, OSO( [1),' Requirements of 20 AAC 25.050(b) j( ,'} lI'el/ I~>; M l>e ,n/ent..,)/ l,Jl/I,' .1,'[ ïdtr-'.J, rh:> a/v..,iit..-.J!:lon ,I;X a fe/mil: ft.) DOll (F~ '(rll U1 ";0 l) in,'}::,:/" OR,'G,AA- Permit It. doc Page 2 of 6 Printed: 28-NOI'''O 1 Application for Permit to Dnll, Weill M-17 Revision NO,1 Saved: 28-Nov-Ol ( 1) :oc.:'ude a p.'at, dra~..n to a 5u¡[òtlr': ~-~::Jic" 51,1':)1 ~'in9 tlh:? p,'!t/I :;f [lie IYC'.D~;sè'ä ,ré'iI'oorr:?, ..l1CIUOtl'g ail aL.~/acer. [ : ¡ 'é'li/)crr35 ¡¡,th'l ,i ..:?OtJ feet of an,v portion o( tlle proposed ~ré''''';' Please see Attachment 1: Directional Plan and (2) /'Or all ¡,'ellS ¡1-'lrhln 200 feé't of tile ,oroposerJ ~"'el/b(1re (A) list tne names of the operators of ["70Se 11'e'!s, to fl'e' extent [hat those ,7ame~ are knOll'f! or dIScc¡'eraû/e ,n ¡:'i.i!J/¡C r=C~1ids, anJ stlO!1' that eac¡' named opc?ratl}r has been furms/"led a cop." of thé' appl,c-atlL'n bv L-ertJfied mall: Dr ('8) state (hat tl7e app/Jcant 6 r/7e cniY a/fectc.'d OI...l7er, The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(e)(3) An applicatIOn tor a Permit to Onll must be cìcc;)mpaf/lr:?ä /.,}' eacll 0'- tIle fI'.'I'lo!".mg Item:.: except lor an Iré'tn dlready on tÌ/e I r¡"tlll!7e comm65ion and Identl/ìet1 in tht> app/ICo.'1tion: (J) a dIagram and dðl,ilpuon c)( tilt:! bJonout pr~vc'íI{lun e'IUI£}m~nt (BOPE,J as rt3(llJirt'd Öy 20 AAC.Ö,OJ5. /0 A4C /5,U36, t")/.;'0 AAC 25, 03.7, a~' {~llpl'Cdbk.~: Refer to documents on File 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (e}(4) An apfJ/Jcdfton tor a PéYnllt w Dnll must he (k~(-On~Darlied hi' each or" rha fol/C'l\'In~7 Items, r'"I((ept lor r"']nl{r"m .7/Ic.YiJV on rile t\.¡fh t/7r7 commiSsion and Identified m rilt? clppllcatlOn: (4) mk.11 (11< 7t1O/7 ù/7 dllilíng i1.-ìziJrd~, mäurimq (A) tilt? m,]ximum donn/7olr? pre.",-."ure tllat maJ' bl:! enCOUlllr2{r3t1, crltc;on::¡ (J,<:;ed ttì rJetr::'rmll"~ It, a1711 ma:I(/(I7/1rn l}clent~dl SU'-(,NP /V¡?,.:;::;ure based tNl rì melhane !1fddl:?f.1l: The reservoir pressure in the Kuparuk sands in the 1M-1? area is expected to be 3216 psi, 0.49 psi/ft. This pressure was extrapolated from offset wells. The maximum potential surface pressure (MPSP) based on the expected reservoir pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Kuparuk formation is 2576 psi, calculated thusly: MPSP =(6780 ft)*(0.49 - 0.11 psi/ft) =2576 psi (6) d'1la ¡)n pl)/t!rmjl gas ZOi]t',':"',' The well bore is not expected to penetrate any gas zones. a/7d (C) dat" COIXc.'/I7If/U ¡'.Il.Jlcf/tla/ CdUSc..':j' 0/ hLl/L' /-:1(t'{1/:,vrb ~':;Uäl as ~7bf/orr,'].:7¡/V r../eo-,¿1rcs.iurcd stratd, lo!:;."! (){culatiol7 .:'0flc...::;, anJ _',}!7r;s' tryat h.7~:? ,] pmpel79f}" ¡{lr Jlfiéru[1[¡al stickinq; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (e)(S) An 3pp/kè7{10n tor d P2/Tmt to Df/II must hi? d(~.-ornp.7nir?d i'V t'ðäl of lilt' l(:¡llollllflg Item:;: 2xcept ¡F,~v an 112m alrt'ddy DO IìIp ¡ wtll lOt? t",ìil1lm5jion and Idr?iltiíiet-i in ¡hé:' c-7ppl/~":a¡/~ìtI: (I,) a (/e::-u ~(}{¡()n ,.)i tile ¡)TOt 'edurr: lc..,Jr Cf. 'fldúctmg íOIl!7d{If.1f7 Inte~.mt}' tðl!:>~ :is It'lllJlreU under ,JU AAC /5, OJO(f),' A formation integrity test will be performed in accordance with the LOT / FIT procedure that Phillips Alaska has on file with the Commission. Application for Permit to Drill, Well 1 M-17 Revision NO.1 Saved: 28-Nov-01 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) Ail app/'-catltìn for a I-"'erm,t to Doll musr {:I¿> 3ccompanle.::i D~ ¿>.3L-''7 of r/1e rC//I..'1¡¡II/7qlterns, excc'pc for an item iJ/ri3ao}, on iìle ~~,,!h rhe cornn1l5~i'on and Identified In the a/Jphcatlon: (6) a compl¿>te propr.Jsed :asmg and æm¿>nl,ng pl°.;Jr3m as ,~cYluire,j Öy .?O AAC 25. O](J, and a dé?scnorion of an,\I s/ort¿>d 'If.ié?::, ¡..1re- Derfora!2d /¡f7¿>r. or screen to be iIIstal/é'd: Casing and Cementing Program Hole Top 8tm CsgfTbg Size Weight Length MDITVD MO/TVD 00 (in) (in) (Ibltt) Grade Connection (ft) (ft) (ft) Cement Program 16 24 62.5 H-40 Welded 129 31/31 160 / 160 Cemented from surface 7-5/8 9-7/8 29.7 L-80 STCM 8,021 31/31 8,052/ 4,615 See Attachment 5-1/2 X 6-3/4 15.5 & L-80 STCM & 10,371 31/31 10,402 / 6326 See 3-1/2 9.3 L-80 EUE 8RD 502 10,402 / 6326 10,904/ 6830 Attachment See also Attachment 3: Cement Loads and CemCADE Summary. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An ,:7,cpllcatton fÙI ;;1 Pcrnllt fa Dnll must he ':¡l~' -ornpar/ler! tJV c~al.--II fl( the m/lcWv'fn.] Items, l~)(Ct~vt for dn Itc~m alre,:¡Jv on rfle !~lltli tll(:, ',~ùmmr~5IDn and Id,'YINk.'d I{] tilt.:' app/lt~at/L)f1: ( i') r1 oiaqralfl dnd de50iptron 0"- tllr:; dfllcHl2( svçtem â,'; f:::'qUlre.:1 bJ -70 AAC }S.o.:),~: uoless 1111:; r£?t7Ulfë'fnent I."" w.~,'[.t.',i !}v lilt? C;)I T1fm~':;':òI;JI1 under ?O AAC .?S.03S(h J( l.}; Please refer to documents on file with the Commission for Nordic Rig 3. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An d¡'~D/I(dtl'i)n r¿'r.:J Perr!llt lti DoH musl (.Ie ,'lCl'Ompdmed by ¿:KI) ol/lle iÒI/cnrinp,tt>flb:. c:'\'O;;,p! (or im item dlrc:'aJ.~ on lì/e' ~'IIII tIlt! CDmr:!IS~lon and {(lL'nt¡{ic'd 1/7 t/7t"" dppllL~dttO{l: (8) J (jnlil/1() ¡/lIIJ pU){jr¿.mI, mcluä/l1~1 a dldyrc1fJ1 dnd J('~i..-rlpt/(){I '.Y the lit ;limy ilUld Sl'ster¡,~. (b 1t.'.¡UlreJ b~' /0 AAC ¿5.033: Drilling will be done with a bentonite slurry having the following properties over the listed intervals: Interval Density Funnel Yield Point Plastic 10 sec Gel Fluid (ppg) Viscosity (cP) Viscostiy Strength Loss (seconds) (lb/100 sf) (lb/100 sf) Surface Hole Surface to 500' 8.5 - 9.0 200- 300 50 -70 40 - 60 15 - 40 8 - 15 500' to Base of Permafrost 8.6 - 9.2 100-200 Final 9.4 60-150 25 - 50 15 - 35 15 - 30 4-6 Intermediate Hole Initial 8.5 - 8.8 35 - 45 8 -12 5 - 10 3-6 8 - 15 Final 9.8 45 - 55 18 - 25 14 - 24 6 -10 <5 Production Hole Final 9.8 45 - 55 18 - 25 14 - 24 4-7 <5 (Tau 0) Please refer to documents of file with the Commission for Nordic Rig 3. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. OR GNA- Permit It.,joc Page .¡. 'Jf 6 Printed: 28-NOI-O 1 I\pplicalion for Permit 10 Drill. Well 1 M-17 Revision NO.1 Saved: 28-Nov-01 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c){9) An a,DpliC¿;[iLìi7 lor a I-è'rm.[ [l.' Df/I/ must éC' accompanlea' D.~ eact] Lìf tor:: '(:'/./01\'1/79 /tern5,. t'.\ú::,ot f~)r an Item a/readY' on file ~"i."'7 [he commiSSion alìJ IcJent..fed If7 t/1e applIcation: ¡'9) fry 3n e.'<fJ'orat.?ry or str3tlQraph/c test n'eli~ a taDu/ation settm;J out t11C' oeDtll:=. aipreäicœo a/Jl7{..vmallv' geo'prr::sSI...'red :;[r3t.3 as reqUlrecf D,v 20 MC 25.0J3(l); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c){10) An appl'catlul] for a Pert/lit to On/! must bl3 accùmpòf/ll3d bv codei, of {II.:; ((}l/'7t1'l1lq ¡(ems, t')¡,'a:~pt fÒ( an ltr::1fJ alre.3~~v on FIC' !\'lrl¡li'7e ,-vmmISS"L1r1 .Jnd Identtlìed 1/1 tile app/,c¿.¡tlOn: (10) (or ilO C'xp/oldtLy}' or strdtlgrðpll/C tes[ ¡..ell, a Sel:iflllL' rc',fract,on 01 rdlectl(ln dn.7/y~'ls dS rcqUlrC'J O}/ 20 /lAC 25. 061'(a): Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An .ìJ~nIICJtlOn tOI a Pemll[ t(J Dnll mllst be dC!:ompanlt:d éV each of the rÒi/('~¡¡m,;.7 dems,. r'À'(ï..'pt for an Itc.YTJ al:t"ad.~ ()I] tile 1I,1t1! tilt;"' (':ùmml'.i.<;f(:¡n and 1dr..:'Ilflfir:'d IIJ rIle afJpll(~i1t/l..m: (II.! f..ìr.-J Hell ,'j"-,lled trOn! an ()f(~ho/(:> piatfarm, mob/I:? botton.' fÌJunr1õ2d::;tr(l(-wrf', /~ck '(If.' ng, or Ilodtmq dollmf,l L't:'5:>r:?1. an .:1l1â/I/SIS of :;:d'1I.)r;~ä ClY7(jttic)f]., as h>qU/ff'd hJ' .,")0 AAC }'>.()61(b): Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An dppl/(d!WI7 {()r.:J Pf'rrmt to DIIII mils! l)¿> dO..:O/llparlll:'(/ Öy ~.:J(h 0/ //it! fÒ/lmvirv I!rlll~: r.l(cr::'{..!/ (,;)r an itt'fII dlrerid~' Olllìi'r:! 11'1/17 tOe C(JfIlf'IlIS51011 dnd Ilk.'ntlfic.'U IIJ (17t' dpU/¡'::dt!(Jf]: (12) r:.'vlJC/lLt' Si70¡WIU tl7a[ the rcqulfr:.Ynents ({ 20 AAC 25. {),?S ¡' Bonú/{I~?,{lldL 't' l'r~'f...'17 ,mi.'!: Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) ,4n appli,-:l1fhìl1l,'Y a Pr:'flmt t(l 01111 muST llë' accompt7/J1r:."o tw Cr7(~h l.).f the ;0//.71 1'IJ](l Item..:;. eA(~(~Dt t,1r .711 Item ,'7Irt'adv (}l1lì/(~ wIth (he i.."tH7lim'i::llJl1 and Identified If1 tllr~ ,;~u{JllcatlOl7: The proposed drilling program is listed below. Please refer as well to Attachment 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 16" conductor. Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter and function test same. 3. Spud and directionally drill 9-7/8" hole to planned surface casing point (8,052' MD). Run MWD/LWD/PWP IO~J9i~g t90ls in drill string as req~ired for directional mO!1itori~g and form~tion data gathering. t}~/Çi:3/P4..'.J) ß-;rì.>;>/ht /L'(.3 rl-tlt.5f ¿¿/5.i.' b-. å.C¡"~,t./'/I-<-d. / Z £, .e-I /J:b J J t 4. Circulate and condition hole to run casing. POOH. 5. Run and cement 7-5/8" 29.7# L-80 BTCM casing string to surface. Displace cement with mud and perform stage job or top job if required. ".-----.-- 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test t6 5,000 p~,i. , ...../ ../ 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regû!ãfíons. Record results. O~. G. NA- Permit It.doc Page 5 ,)( 6 Printed: 28-NOl-O 1 <\pplicallon for Permit 10 Drill, Well 1 M-17 Revision No, 1 Saved: 28-Nov-01 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 9. Directionally drill 6-3/4" hole to total depth (10,904' MD). Run MWD/LWD/PWD logging tools in . drill string as required for directional monitoring and formation data gathering. ~~/;eES//Vt?U/þt5rJß.~ 10. Circulate and condition hole for casing. POOH. /JÞ 11. Run e-line logs or DPC logs as needed. 12. Run 5-1/2" 15.5# by 3.5" 9.3 # L-80 BTCM/EUE casing to surface and cement. 10. Run and land 3-1/2" tubing with gas lift completion. 11. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 12. Freeze protect well. Set BPV. Release rig and turn well over to production. 13. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/lcdtlon for a Pr.'rrmt to Dnll nlu::;tc be..' dC('O!T~D.7n.:c'd lJ,v e..'dd7 of tile..' /O/~O¡1'1/7~¡ ttäll:. except fur .Jl/ Itc.:m ,}!rCJuy (.If} rìJe ¡Vltll t/u." CUrT/misS/on Jfld IdentifIed in tile..' appllcatlun: (J 4} r7 f7r;""'neral dc::'5C/1ptIIJII ()f/JOL 1/ tih' c~o('rdto/ plans to d/5pc'5e of dn//m(J mud ;¡n,'1 o.1/tm{I..,.' ,7nd ,] :'it.}rr~mf.'nt ()t" n/iet/7LY th:: operator mtcnl1s to re'llucst aufllc'Jr/zat!rJl] undy :!O ,MC 25.080 kv an annll/ar dISfi()~c11 Llp("':!allo/7 In the ~L',~/!,,: Waste fluids generated during the drilling process will be disposed by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be either stored temporarily on site or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Phillips Alaska intends to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Cement Loads and CemCADE Summary. Attachment 4 Well Schematic. a~ G, NA- Permit It,doc Page 6 at 6 Printed: 28-NOI-O 1 ~ PHILL.PS Alaska, Inc. .m A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 c. R. Mallary Phone (907) 265-6434 Fax: (907) 265-1535 Email: jtranth@ppco.com November 29, 2001 Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West tn Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, Kuparuk Producer 1 M-17 Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well, Kuparuk well #1 M- 17. The well will be drilled and completed by Nordic 3. Please utilize documents on file for this rig. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be hauled to an approved Prudhoe or GKA Class II disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B} Geologic Data and Logs (20 AAC 25.071 ) Jeff Harrison, Geologist 265-6315 If you have any questions or require any further information, please contact Todd Mushovic at 265-6974. 7f~ I~ ¿;(; % #~/(a,« C. R. Mallary Drilling Engineering Supervisor RECEIVED NOV 2 9 2001 ORIGINAL Alaska 011 & Gas Cons. Commisslorl ,Anchorage _"I(-~l'IIIJ"~':.]~I~.]:II.:I:8.I.IIj'll"I~~..~:f,1~~~~~7.y~~~:~~~~[W,~f."":~~~!,,~~~¡S.~~~R~f~~~:'.7~,'':;~~~~~'r'~.~!":!"~~'~~~~~.~~~~~~~~~f~~~~t~!~~~~~. œ Phillips Alaska, Inc. :)"¡;(:~rH!: !?:~;!~[tJ.R%:~;r~(t)r\~/~~!f~~.J;~JJ;rr~~jf~~¡:~) P. O. Box 102776 ',', ' , ,', Repubh'B~nk.:$~èJbYVille:.~0Q.g¡ø):!.336" ',: , Anchorage, AK 99510-2776 ' Pay ONE HUNDRED DOLLARS AND 'NO CENTS 0101336 To the order of: STATE OF ALASKA AOGCC 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE AK 995013539 Date 11-29-01 **W********WTTIOO.OO* Amount V oid after 90 days (~ am fK-; Çlûu bu.- Two signatures required for amounls over $25,000.00 :' .1)1""" !I" ".row !Ii'.'t' ¡; c,'::"II!'O: 10 :"1 . ~ ~., I!I'" ~ J ; I ':' JJ~ ,,~~, ~..(, J ~" I !Io:' ~ ,.; ,.~~ ~ ~ ~~, I~t ---. wt;U-7;¡~'jÎ------ -.,---.-- - --.'-' --- - ._-- --. III 0 0 0 0 . 0 . :ì :I b III ~----...-.- -------.--- .~- --........--.. - ....-. - ~ -. -."--.- -¥. -- -. - -. ..- _._--~-_. - ---"-- - --._- - - .. -_.-- _. -""- -- -. 1:08 :1 gO L. 2 b 21: 0 g gOOOOu- - <::::) :::J::J --- ~ --- <: ::J::::=.. r--- '-".. ':'."'.!..... -.-. Kuparuk ~!v,rUnit North; Slope, Alaska !Ctiparuk-1M, Slot 1M-17 -. -plan:;':--1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 PROPOSAL REPORT 21 November, 2001 Surface Coordinates: 5960383.56 N, 571907.38 E (70018' 07.3970" N. 149025' 03.2377" W) Surface Coordinates relative to Project H Reference: 960383.56 N, 71907.38 E (Grid) Surface Coordinates relative to Structure: 959651.39 N, 81095.37 E (True) Kelly Bushing: 93.30ft above Mean Sea Level spe""''''''Y-5UI! g ~!b L LI"~-~---~~ R V LC e 5 A HalllÞunon Company Proposal Ref: pro9666 Sperry-Sun Drilling Services . Proposal Report for Plan: 1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 M -- Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dpgreg ~ Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings ' R'ite':..' Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft). (O/tOOft) '. - --. . l ~- . :' . . i..."'" 0.00 0.000 0.000 -93.30 0.00 O.OON 0.00 E 5960383.56 N ~-" 5~19Ö7 :38= ~ 0,00 SHL: X = 571907,38' E & Y = 5960383.56' N (618' FSL & 600' FWL, SEC. 17 - T11 N - R11 E) 100.00 0.000 0.000 6.70 100.00 0.00 N 0.00 E Q960383.56 N ~7,1907.38 E 0.000 0,00 200.00 0.000 0.000 106.70 200.00 0.00 N 0.00 E, 5960383:~ N 571907.38 E 0.000 0.00 300.00 0.000 0.000 206.70 300.00 O.OON 0.00 E.:,c~ :. ::69603.83.56 N 571907.38 E 0.000 0.00 400.00 0.000 0.000 306.70 400.00 O.OON 0.00 Ë . .'~ ~-, 6960083.56 N 571907.38 E 0.000 0,00 Begin Dir @ 2,5°/1000 (in 9-7/8" ... - ... Hole) : 400,OOft MD, 400,OQft TVD 500.00 2.500 115.548 406.67 499.97 0.945 .. - 1.97'E 5960382.64 N 571909.36 E 2.500 2.09 - 600.00 5.000 115.548 506.45 599.75 3.765 7.87 E 5960379.87 N 571915.28 E 2.500 8.35 ~ 700.00 7,500 115.548 605.84 699.14 8.465 17,69 E 5960375,27 N 571925.15 E 2.500 18.77 800.00 10.000 115.548 704.67 797.97 15.02,5 31.41 E 5960368.85 N 571938.94 E 2,500 33,34 Increase DL5 to 3.0/1 OOft : 800,0011 :::J:J MD, 797,97ft TVD 900.00 12,872 119.963 802.68 895.98. 24.33 5 48.90 E 5960359.70 N 571956.51 E 3,000 52.54 --- ~ 1000.00 15.790 122.778 899.56 992.86 37.26 S 69.99 E 5960346,97 N 571977.73 E 3.000 76.84 --- 1100.00 18,734 124.730 995.04 1088.34 53,785 94.64 E 5960330.69 N 572002.53 E 3.000 106.18 :æ: 1200.00 21.693 126.167 1088.87 - 1182.17 73.84 S 122.76 E 5960310.90 N 572030.84 E 3.000 140.49 ::t:::.. 1300.00 24.662 127.273 .1180.79 1274.09 97.38 5 154.29 E 5960287.66 N 572062,60 E 3,000 179.65 1400.00 27.636 128.155 1270.55 1363.85 124.355 189,14 E 5960261.02 N 572097.70 E 3,000 223,58 r-- 1500,00 30.616 128.877 1357.89 1451.19 154.67 5 227.21 E 5960231.07 N 572136.06 E 3.000 272.14 1600.00 33.599 129.482 1442.59 1535.89 188.25 S 268.40 E 5960197.88 N 572177,57 E 3.000 325,20 1700.00 36.584 130.000 1 524.41 1617.71 225.01 S 312.59 E 5960161.55 N 572222.11 E 3.000 382.63 1771.48 38.719 130,327 1 581.00 1674.30 253.175 345.96 E 5960133.71 N 572255.74 E 3.000 426 26 Base Permafrost 1800.00 39.571 130.449 1603,11 1696.41 264.84 S 359.67 E 5960122.18 N 572269.57 E 3.000 444,25 1900.00 42.560 130.845 1678.50 1771.80 307.63 S 409,50 E 5960079.86 N 572319,81 E 3.000 509,91 2000.00 45.550 1 31 . 1 98 1750.36 1843.66 353.27 S 461.95 E 5960034.73 N 572372,69 E 3.000 579,42 2100.00 48.541 131.517 1818.50 1911,80 401.63 5 516,88 E 5959986.90 N 572428.08 E 3.000 652,59 2200.00 51 .532 131.808 1882,72 1976.02 452.57 S 574.13 E 5959936.50 N 572485.81 E 3.000 729,22 2300.00 54.525 132.075 1942.85 2036,15 505.97 5 633.55 E 5959883.68 N 572545.74 E 3.000 809,10 2400.00 57.518 132,324 1998,74 2092,04 561.66 5 694,97 E 5959828.57 N 572607,69 E 3.000 892.02 2500.00 60.511 132.556 2050,21 2143.51 619.51 S 758.23 E 5959771 .33 N 572671.50 E 3,000 977.74 2600.00 63.505 132.775 2097.14 2190.44 679.35 5 823.15 E 5959712,12 N 572736.99 E 3.000 1066.03 2602.97 63.594 132.781 2098.47 2191.77 681.165 825.10 E 5959710.33 N 572738.96 E 3.000 1068,68 End Dir, 5tart Sail @ 63.59" : 2602.97ft MD. 2191.77ft TVD 2700.00 63.594 132.781 2141 .62 2234.92 740.18 S 888.88 E 5959651.92 N 572803.31 E 0.000 1155.59 21 November, 2001 - 5:48 Page 2 of 8 DrillQuest 2,00.09.006 Sperry-Sun Drilling Services . Proposal Report for Plan: 1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 M Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate, Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/1ooft) 2800.00 63.594 132,781 2186.09 2279.39 801.02 S 954.62 E 5959591.72 N - 57~869,62'E 0.000 1245.1 5 2900.00 63,594 132.781 2230.57 2323.87 861 ,85 S 1020,36 E 5959531 ,52 N - - 572935.94 E 0.000 1334.71 3000.00 63.594 132.781 2275.04 2368.34 922.68 S 1086.1 0 E 5959471.31 N - -. 573002.26 E 0.000 1424.28 3100.00 63.594 132.781 2319,51 2412.81 983,52 S 1151.83 E 5959411_.11 N 573068,57 E 0.000 1513.84 3200,00 63.594 132.781 2363.99 2457.29 1044,35 S 1217.57 E 5959350~91 N 573134.89 E 0.000 1603.40 12~:31 E :....- 5~59290.71 N 3300,00 63.594 132.781 2408.46 2501.76 1105.18 S 573201.21 E 0,000 1692,97 3400.00 63.594 132.781 2452.93 2546.23 1166,02 S - -1349:05 E., 5959230.51 N 573267,52 E 0.000 1782.53 3500.00 63.594 132.781 2497.41 2590.71 1226.85 S 1414.78-E- - 5959170.31 N 573333.84 E 0.000 1872.09 3600.00 63.594 132,781 2541.88 2635.18 1287.68 S -1480.52 E 5959110.10 N 573400.16 E 0.000 1961,66 3700.00 63.594 132,781 2586.35 2679.65 1348.52 S 1546.26 E 5959049.90 N 573466.47 E 0.000 2051 .22 C 3800.00 63.594 132.781 2630.83 2724.13 - 1A09.35 S 1611.99E 5958989.70 N 573532.79 E 0.000 2140.78 ::t::I 3900.00 63.594 132.781 2675.30 2768.60.- - 1470..18 S 1677,73 E 5958929.50 N 573599.11 E 0..000. 2230.35 4000..00 63.594 132.781 2719.78 2813.08 1531,02 S 1743.47 E 5958869.30 N 573665.42 E 0,000 2319,91 ........ 4100.00 63.594 132.781 2764.25 2857.55 1591.85 S 1 809.21 E 5958809,10 N 573731.74 E 0.000 2409.4 7 ~ 4200.00 63.594 132.781 2808.72 2902'-02 1652.68 S 1874.94 E 5958748.89 N 573798,05 E 0.000 2499.04 ........ ~ 4300.00 63.594 132.781 2853.20 2946.50 1713.52 S 1940,68 E 5958688,69 N 573864,37 E 0.000 2588.60 4400.00 63.594 132.781 2897.67 2990.97 1774,35 S 2006.42 E 5958628.49 N 573930.69 E 0.000 2678.16 4500.00 63.594 132.781 2942.14 3035.44 1835.19S 2072,16 E 5958568,29 N 573997.00 E 0.000 2767,73 ......... 4600.00 63.594 132.781 2986.62 3079.92 1896.02 S 2137.89 E 5958508.09 N 574063.32 E 0.000 2857.29 4700.00 63.594 132,781 3031.09 3124.39 1956.85 S 2203.63 E 5958447.89 N 574129.64 E 0.000 2946,85 4800,00 63.594 132,781 3075.56 3168,86 2017.69 S 2269.37 E 5958387.69 N 574195.95 E 0,000 3036.42 4900.00 63.594 --- 132.781 3120.04 3213.34 2078.52 S 2335.10 E 5958327.48 N 574262.27 E 0.000 3125.98 5000.00 - 63.594 132.781 3164.51 3257.81 2139.35 S 2400.84 E 5958267.28 N 574328.59 E 0.000 3215.54 5100.00 63.594 132.781 3208.98 3302.28 2200.19 S 2466.58 E 5958207.08 N 574394.90 E 0.000 3305.11 5200.00 63.594 132.781 3253.46 3346.76 2261.02 S 2532.32 E 5958146.88 N 574461,22 E 0.000 3394.67 5246.19 63.594 132.781 3274.00 3367.30 2289.12 S 2562.68 E 5958119.07 N 574491 .85 E 0.000 3436.04 Ugnu C 5300.00 63.594 132,781 3297.93 3391.23 2321 .85 S 2598.05 E 5958086.68 N 574527.54 E 0,000 3484,23 5400.00 63.594 132.781 3342.40 3435.70 2382.69 S 2663.79 E 5958026.48 N 574593.85 E 0.000 3573.79 5500,00 63.594 132.781 3386.88 3480.18 2443.52 S 2729,53 E 5957966.27 N 574660.17 E 0.000 3663.36 5600.00 63.594 132.781 3431.35 3524.65 2504.35 S 2795.27 E 5957906.07 N 574726.49 E 0.000 3752.92 21 November. 2001 - 5:48 Page 3 of 8 DrillQuest 2,00.09.006 Sperry-Sun Drilling Services . Proposal Report for Plan: 1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 M Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dog~ Vertfcal Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate- Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft).: . (ol100ft) J , 5700.00 63.594 132.781 3475.83 3569.13 2565.19 S 2861.00 E 5957845.87 N ".' 51A792.80 E 0.000 3842.48 5800.00 63.594 132,781 3520.30 3613.60 2626.02 S 2926.74 E 5957785.67 N '.. 57485~.12 E 0.000 3932.05 5900.00 63.594 132.781 3564.77 3658.07 2686.85 S 2992.48 E 59577.25.47 N --: 574925.43 E 0.000 4021.61 6000.00 63.594 132.781 3609.25 3702.55 2747.69 S 3058,21 E 595766527 N '574991.75 E 0.000 4111.17 6100.00 63.594 132,781 3653.72 3747.02 2808,52 S 3123.95 E 59?~605.0? N 575058.07 E 0.000 4200,74 ... 6200.00 63.594 132.781 3698.19 3791.49 2869.35 S ,3189.ß9 F. :' "'"'59.57544.86 N 575124,38 E 0.000 4290.30 6300.00 63.594 132.781 3742.67 3835.97 2930.19 S 3255.43 E. .5957484.66 N 575190.70 E 0.000 4379.86 6400.00 63.594 132.781 3787.14 3880.44 2991.02 S. 3321. fS.E 5957424.46 N 575257.02 E 0.000 4469.43 6500.00 63.594 132.781 3831.61 3924.91 3051.86 S .. 3386.90 E 595736426 N 575323.33 E 0,000 4558.99 C 6600.00 63,594 132,781 3876.09 3969.39 3112.69 S 3452.64 E 5957304.06 N 575389.65 E 0.000 4648.55 :J::J 6624.54 63.594 132.781 3887.00 3980.30 .3127.62 S 3468.77 E 5957289.28 N 575405,92 E 0.000 4670.53 Top West Sak --- 6700.00 63.594 132.781 3920.56 401 ~.86 . 3H3.52 S 3518.38 E 5957243.86 N 575455,97 E 0.000 4738.12 c-) 6800.00 63.594 132.781 3965.03 4058.33 3234.36 S 3584.11 E 5957183.65 N 575522.28 E 0.000 4827.68 --- 6900.00 63.594 132.781 4009.51 4102,81 3295.19 S 3649.85 E 5957123.45 N 575588.60 E 0.000 4917,24 ~ 7000.00 63.594 132.781 4053,98 4147.28 3356.02 S 3715.59 E 5957063.25 N 575654.92 E 0.000 5006,81 7100.00 63.594 132,781 4098.45 4191.75 3416,86 S 3781.33 E 5957003.05 N 575721 ,23 E 0.000 5096.37 r--- 7200.00 63.594 132.78.1 4142.93 4236.23 3477.69 S 3847.06 E 5956942.85 N 575787.55 E 0.000 5185.93 7300.00 63.594 132.781 . 4187.40 4280.70 3538.52 S 3912.80 E 5956882.65 N 575853.87 E 0.000 5275.50 7400.00 63.594 132.781 4231.87 4325,17 3599.36 S 3978.54 E 5956822.44 N 575920.18 E 0.000 5365.06 7500.00 63.594 132.781 4276.35 4369.65 3660.19 S 4044.27 E 5956762.24 N 575986.50 E 0.000 5454,62 7600.00 63.594 132.781 4320.82 4414,12 3721.02 S 4110.01 E 5956702.04 N 576052.82 E 0.000 5544.18 7602.65 63.594 132.781 4322.00 4415.30 3722.63 S 4111.75E 5956700.45 N 576054.57 E 0.000 5546.56 Base West Sak 7700.00 63.594 132.781 4365.30 4458.60 3781,86 S 4175.75 E 5956641.84 N 576119.13E 0.000 5633.75 7800.00 63.594 132.781 4409.77 4503.07 3842.69 S 4241.49 E 5956581.64 N 576185.45 E 0.000 5723.31 7900.00 63.594 132.781 4454.24 4547.54 3903.52 S 4307.22 E 5956521.44 N 576251.76 E 0.000 5812.87 8000.00 63.594 132.781 4498.72 4592.02 3964.36 S 4372.96 E 5956461.24 N 576318.08 E 0.000 5902.44 8052.35 63.594 132.781 4522.00 4615.30 3996.21 S 4407.38 E 5956429.72 N 576352.80 E 0.000 5949.33 7 -5/8" Casing Pt (200' TVD Below Base West Sak), Drill out 6-3/4" Hol 8052.35tt MD, 4615.300 TVD 7 -5/8" Casing 8100.00 63.594 132.781 4543.19 4636.49 4025.19 S 4438.70 E 5956401.03 N 576384.40 E 0.000 5992.00 8200.00 63,594 132.781 4587,66 4680.96 4086.02 S 4504.44 E 5956340.83 N 576450.71 E 0.000 6081,56 8300,00 63,594 132.781 4632,14 4725.44 4146.86 S 4570.17E 5956280 63 N 576517.03 E 0.000 6171.13 21 November. 2001 - 5:48 Page 4 of8 DrillQuest 2.00.09,006 Sperry-Sun Drilling Services . Proposal Report for Plan: 1 M-17 - 1 M- 1 7 (wp02) Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 M Measured Sub-Sea Vertical Local Coordinates Global Coordinates . ~1Itg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .(ft) (ol100ft) ~ 8400.00 63.594 132.781 4676.61 4769.91 4207.69 S 4635.91 E 5956220.43 N: 5165$3:35£ .0.000 6260.69 8462.51 63.594 132.781 4704.41 4797.71 4245.72 S 4677.00 E 5956182.80 N . 576624.80 E '0.000 6316.68 Begin Dir @ 3.0o/100ft: 8462.51ft MD. 4797.71ft TVD 8500.00 62.469 132.781 4721.41 4814.71 4268.41 S 4701.53 E 5956160.;34 N .576649.54 E 3.000 6350,09 8600.00 59.469 132.781 4769.93 4863.23 4327.79 S 4765.69 E . 595610f.pa N 57671427 E 3.000 6437.51 8700.00 56.469 132.781 4822.97 4916.27 4385.37 S 4827.91 E-.-;,5956044.60 N 576777 .03 E 3.000 6522.27 8800.00 53.469 132.781 4880,36 4973.66 4440.97 S --:-4888:00 E: , 5955989.57 N 576837.66 E 3.000 6604.15 8900.00 50.469 132.781 4941 .96 5035.26 4494.47 S 4945.80, E' 5955936.63 N 576895.97 E 3.000 6682.90 9000.00 47.469 132.781 5007.60 5100.90 4545.70 S ::' '.5OO1.1&E 5955885.93 N 576951.82 E 3.000 6758,33 9100.00 44.469 132.781 5077.10 51 70040 4594.52 S 5053.93 E 5955837.61 N 577005.05 E 3.000 6830,21 C 9200.00 41.469 132.781 5150.26 5243.56 4640.~1 S 5103.95 E 5955791.81 N 577055.51 E 3.000 6898.36 - . ::x:. 9300.00 38.469 132.781 5226.89 5320.19 4684.44 S 5151.09 E 5955748.63 N 577103.06 E 3.000 6962.59 .......... 9400.00 35,469 132.781 5306.78 54OQ.08.. .4725.28 S 5195.22 E 5955708.22 N 577147.59 E 3.000 7022.72 C') 9500.00 32.469 132.781 5389.71 ~83~01, 4763.23 S 5236.23 E 5955670.67 N 577188.95 E 3.000 7078.59 9600.00 29.469 132.781 5475.~ 5568~74 4798.17 S 5273.99 E 5955636.08 N 577227.05 E 3.000 7130,04 ---- 9700.00 26.469 132.781 5563.75 5657:05 4830.02 S 5308.4 1 E 5955604.56 N 577261.77 E 3.000 7176.93 ~ 9800,00 23.469 132.781 5654,39 5747.69 4858.69 S 5339.39 E 5955576.19 N 577293.02 E 3.000 7219.13 9900.00 20.469 132.781 5747.12 5840.42 4884.10 S 5366.84 E 5955551 .05 N 577320.72 E 3.000 7256.54 ......... 10000.00 17.469 132.781 5841 .68 5934.98 4906.1 7 S 5390.69 E 5955529.20 N 577344.78 E 3.000 7289.04 10100.00 14,469 _'32.781. 5937.81 6031.11 4924.85 S 5410.88 E 5955510.72 N 577365.15 E 3.000 7316.55 10200.00 11 .469 132.781 6035.25 6128.55 4940.10 S 5427.35 E 5955495.63 N 577381.76 E 3.000 7338,99 10300.00 8.469.. 132.781 6133.73 6227.03 4951.85 S 5440.06 E 5955484.00 N 577394.58 E 3.000 7356.30 10400,00. 5.469 132.781 6232,98 6326.28 4960.09 S 5448.96 E 5955475.84 N 577403.56 E 3.000 7368.43 10485.26 2,911 132.781 6318.00 6411.30 4964.32 S 5453.53 E 59554 71 .66 N 577408.17 E 3.000 7374.66 Lower KaJubtk 10500.00 2.469 132.781 6332.73 6426.03 4964.79 S 5454.04 E 5955471.19 N 577408.69 E 3.000 7375.35 10582,30 0.000 0,000 6415.00 6508.30 4966.00 S 5455,34 E 5955470,00 N 577410.00 E 3.000 7377.12 TARGET (C4) : 10582.30f1 MD, 6508.300 TVD C4 Targel - 1M-17 (C4), 250,00 Radiu!= Current Targe1 21 November, 2001 - 5:48 Page 5 of 8 Dril/Quest 2.00.09.006 Sperry-Sun Drilling Services . Proposal Report for Plan: 1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 North Slope, Alaska Kuparuk River Unit Kuparuk 1 M Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg, Vertical Depth lnel. Azim. Depth Depth Northings Eastings Northings Eastings Rate' Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) - (0/1ooft) 10600.00 0.000 0.000 6432.70 6526.00 4966.00 S 5455.34 E 59554 70.00 N 5114tO~OO-E ,0.000 7377.12 10601.30 0.000 0.000 6434.00 6527.30 4966.00 S 5455.34 E 5955470.00 N - 57741'0.00 E 0.000 7377.12 TARGET (C3): 10601.300 MD, 6527.3Oft TVD - - C3 10632.30 0.000 0.000 6465.00 6558.30 4966.00 S 5455.34 E 5955470.QP N 577410.00 E 0.000 7377.12 C2 10655.30 0.000 0,000 6488.00 6581.30 4966.00 S 5455.34 E -- 5955470.00 N 577410.00 E 0,000 7377,12 C1 10667.30 0.000 0.000 6500.00 6593.30 4966.00 S 5455:34 E -- -'5955470.00 N 577410.00 E 0.000 7377,12 UnitS ~ -- 10700,00 0.000 0.000 6532.70 6626.00 4966.00 S 5455.34 E - 5955470.00 N 577410.00 E 0.000 7377.12 <::) 10780.30 0.000 0.000 6613.00 6706.30 4966,00 S - 5455.34E 5955470.00 N 577410.00 E 0.000 7377,12 A6 10792.30 0.000 0.000 6625.00 6718.30 4966,00 S 5455.34 E 5955470.00 N 577410,00 E 0.000 7377.12 A5 ::t:J 10800.00 0.000 0.000 6632.70 6726.00 4966.00 S 5455.34 E 59554 70.00 N 577410.00 E 0.000 7377,12 ......... 10813.30 0.000 0.000 6646.00 6739.30 - -4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.000 7377.12 A4 c-) 10854.30 0.000 0.000 6687.00 6780.30 4966,00 S 5455.34 E 5955470.00 N 577410.00 E 0.000 7377.12 Miluveach ......... 10900.00 0.000 0.000 6732.70 6826.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.000 7377,12 ~ 10904.00 0.000 0.000 6736.70 6830.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.000 7377.12 Total Depth : 10904.00ft MD, 683O.ooft TVD r--- 5.1/2" x 3.1/2" Casing All data is in Feet (US) unless otherwisß_stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 93.3' MSL. Northings and Eastings are relative to 618 FSL & 600' FWL. Magnetic Declination at Surface is 26.127'" (19-Oct-0 1) The Dogleg Severity is inDegrees per 100 feet (US), Vertical Section is from 618" FSL & 600' FWL and calculated along an Azimuth of 132,311° (True). Based upon Minimum Curvature type calculations, at a Measured Deplh of 10904.00ft.. The Bottom Hole Displacement is 7377.1211.. in the Direction of 132.312'" (True). 21 November.. 2001 - 5:48 Page 6 of 8 DrillQuest 2.00,09.006 Sperry-Sun Drilling Services Proposal Report for Plan: IM-17 - IM-17 (wp02) Revised: 20 November, 2001 ~" 1~ Kuparuk River Unit North Slope, Alaska Kuparuk 1 M Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 0,00 400.00 800.00 2602.97 8052.35 SHL: X = 571907.38' E & Y = 5960383.56' N (618' FSL & 600' FWL, SEC. 17 - T11N - R11E) Begin Dir @ 2.5°/1OOft (in 9-7/8- Holef-:-400.00tt MD, 4OO.00tt TVD Increase OLS to3.0/100ff--:- ago.OOft MD, 797.97tt TVD End Dir, Start Sæl-_. 63.sget' :'2«)02:97h MD, 2191.77tt TVD 7-5/8Y Casing PI (200' TVD ~ Base West Sak), Drill out 6-314- Hole: 8052.35tt MO, 4615.300 TVO Begin Dir@ 3.00/100fl: 8462.51tt MO, 4797.71tt TVD TARGET -(C4) : 10582.3Ott MD, 6508,300 TVO TARGET (C3) : 10601.3Oft MO, 6527.300 TVO TotaJ Depth: 10904.00tt MD, 6830.000 TVD 8462.51 10582.30 10601.30 10904.00 0.00 O.OON O.OOE 400.00 O.OON O.ooE 797.97 15.02 S 31.41 E 2191.77 681.16 S 825.10 E 4615,30 3996.21 S 4407.38 E 4797.71 4245.72 S 4677.00 E 6508.30 4966,00 S 5455.34 E 6527.30 4966.00 S 5455.34 E 6830.00 4966.00 S 5455.34 E -- C ::t::J ---- ~ ---- Formation Tops ~ Formati on Plane Profile Penetration Point (Below Well Origin) Measured Vertical Sub-Sea r--- Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Ceg. (ft) (ft) (ft) (ft) (ft) 1581.00 0.000 - O.54ß 1 ì71.48 1674.30 1581.00 253.17 S 345.96 E Base Permafrost 3274.00 0.000 0.548 5246 19 3367,30 3274.00 2289.12 S 2562.68 E Ugnu C 3887.00 0.000 0.548 6624.54 3980.30 3887.00 3127.62 S 3468.77 E Top West SaI< 4322,00 0.000 0.548 7602.65 4415.30 4322.00 3722.63 S 4111.75E Base West Sak 6233.00 0.000 0,548 10400.02 6326.30 6233.00 4960.09 S 5448.96 E Base HRl 6318,00 0.000 0.548 10485,26 6411.30 6318.00 4964.32 S 5453.53 E Lower KaIubik 641 5.00 0.000 0.548 10582.30 6508.30 6415.00 4966.00 S 5455.34 E C4 6434.00 0.000 0,548 10601,30 6527.30 6434.00 4966.00 S 5455.34 E C3 6465.00 0.000 0.548 10632.30 6558.30 6465.00 4966.00 S 5455.34 E C2 6488.00 0.000 0.548 10655.30 6581.30 6488.00 4966.00 S 5455.34 E C1 6500.00 0,000 0,548 10667,30 6593.30 6500.00 4966,00 S 5455.34 E UnitB 6613.00 0.000 0.548 10780.30 6706.30 6613,00 4966.00 S 5455.34 E A6 6625.00 0.000 0.548 10792.30 6718.30 6625.00 4966.00 S 5455.34 E A5 6646.00 0.000 0.548 10813.30 6739.30 6646.00 4966.00 S 5-455,34 E A4 6687,00 0.000 0.548 10854,30 6ì80 30 6687,00 4966,00 S 5455.34 E Miluveach 21 November. 2001 - 5:48 Page 7018 DrillQuest 2.00.09.006 C ::x:J .......... c-) ---- ~ r--- Kuparuk River Unit Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> Targets associated with this wetlpath Target Name 1 M-17 (C3) 1M-17 (C4) 21 November, 2001 - 5:48 To Measured Vertical Depth Depth (ft) (ft) 8052.35 10904.00 4615.30 6830.00 Sperry-Sun Drilling Services Proposal Report for Plan: 1 M-17 - 1 M-17 (wp02) Revised: 20 November, 2001 Casing Detail 7-5/8" Casing 5-1/2" x 3.1/2" Casing Mean Sea LeveUGlobal Coordinates: Geographical Coordinates: Target Radius: Mean Sea LeveVGlobaJ Coordinates: Geographical Coordnates: Target Radius: Target Thickness: Page 8 at 8 .- - -- .'.'- . Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 6527.30 6434.00 250.00ft 6508.30 6415.00 250.00ft 19.00tt 4974.07 S 5463.27 E 5955462.00 N 577418.00 E 70° 17' 18.4531" N 149022' 24.0417" W 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 70° 17' 18.53268 N 1490 22' 24.2724" W (I North Slope, Alaska . Kuparuk 1 M Target Target Shape Type Circle Current Target Circle Current Target DrillQuest 2.00.09.006 Cè 3000 - ~ C~ ::x:. ~ .........~ CO C')~ .........~ 4000 --- ~ r--- 1000 - 2000 - -------- ~------ ---------- ~HI~UPS' ' ,TfTfi.! '~~.I Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 M-17 (wp02) - - - - - - . . I. - I':J --t- Reference is TRUE North Current Well Properties Wen' Horizontal Coordinates' Rei. Global Coordinates: 5960383.56 N, 571907 38 E Rei. Structure, 959651,39 N, 81095,37 E Rei Geographical Coordinates, 70' 18' 07,3970' N, 149" 25' 03,2377" W 618' FSL & 600' FWL, SEC 17 - T11N. R11E Plan 1M-17 RKB ElellallOn . North Relerence . Uni1s: 93 30ft above Mean Sea Level True North Feet (US) ---------- ----- - - ------- -- --- -- .------- --- ---- --- 7-5/S" Casing PI (200' TVD Below Base Wesl SakI, (\ / Dnll out 6-3/4" Hole' 80523511 MD 4615 30ft TVD --i~:;7' - - - 7S.~'C~ ~ 8052 4~ MCI 4&IS ~<t1 TVü -- ---------~~~--------------- 5000 - 6000 - , E'eqln [hr "" ~ ':' ': lOOn IIn ~3. 7'8 H,:o ",! -1000')11 t. [I, ~C~) (rOtI T\j() .~o . 1n.;r¿,iS'Õ DLS lG :3 (I' lùOtl 800 OOh MO 79-: 9-:11 TVO , , , - -- . I ,,', '2602 9ï" MD 2191 T7h TVO I , , - -----------=-~--~------ I '0. . ¡pP\) -- -------:---,----¡-'\Õ-;--- - ------ - ---- -- "__, r.I/.,'/;1- r " -/': ,rjJ,~r{J .. - 8tegln [lIr "~I :J (I 1 (1(¡t1 I.q~,,,: ",1 h /,1C, ,17'.1' ï 1 t1 T ',IE"' ~.';"I NII,',I' \ '- rrl./L I- (¡:"I'.3" 1\ l.' . . I 1000 Scale: 1inch = 100011 I 4000 5pE!"'I'~-5UIl pRI~J,_ING. seRv..I~r;e$ A Halliburton Company ~'H.I""" '1,'\ '¡5.'..!,/' I ,'1'111. ,','.If.I I ',L ,.', -,'I' 1'\ L 'ILl. ~I . / II \ .1<11/., ------------- /II<I.L! It ;', 2,;//' ii,,,I"/: 1.lfel, ': ("': '..'" I \ I I, .J'I~.J,I'I-'~,,~ ,Jid,.'- I. "I ~IIL 1"-'-" ,~ .,/ .\. -.. -, f"li I, ,ll., ."1 ../11 " . I~ I J r, -- -- --- ---- ---- - - - -- .--------- - - ---------. --- ----- ---~- ---~----- --- - - -ïï-:-- 7000 - Dr,IIQLI~1 2,OO,(}),OO6 I 2000 I 3000 -- --- I T,)F,I O~r,lr, 1'..1',:fI)~ (Inti I,.H:, 66,:11:' O(lh TIIC' !_~~). FSL ,~ ;'~":,, r'i\"- ~t\: :! 1 . 1!2~.J_~P~!_tJ-. ~__a_-r,__-. r .(j.Je. -A' s..1 2" II ']..':;'"Cs¡ '1)0;00).1('4, >.ID M)O 011 I VD I 5000 I 6000 I 7000 I 8000 I 9000 :J ;, - ------- -800 - -1600 - c ~ -2400 - ---- ~ -3200 - r--- -4000 - is -4800 - 0 co .c u ç; Q¡ ñi 0 <II DnllQuesl 2,OQ,09,Oùô 800 I Scale: 1 inch = 800" 1600 I Eastings 3200 I 4800 I 4000 I 2400 I . '. I)HI~LIPS" ¡fÐ . - . - . .~---- tEI~'n L.lr'~ :: 1 'h)úll ( n 8.;,8" Hijli:1 4CÚ fjljt¡ MÜ, .tljL' ()I~II TVD " Ir,,:rè,E'-" OL S I') j,C"1 ({'1I : eC~J Ounl,10 1'~7 'Jill TVO En.j [IlL SIøl1 S':tll iJ"' t"~:"~ 58 ::f~"'12 'dill Mu 21~~1 ì ìh T','G 5600 I 6400 I Phillips Alaska, Inc. North Slope, Alaska Kuparuk River Unit 1 M-17 (wp02) -n - -800 N -t' - -1600 Reference is TRUE North Current Well Properties Well, Honzontal Coordinates Ref GlQbal Coordinates Rei, Structure' ReI. Geographical Coordinales : RKB Elevation: Nor1h Reference Unils: ~~IJ.?' / 7.~18" Casing PI (200' NO Balo.'1 Base Wast SakI, Onll oUI6-3I4" Hole 805235" MO, 4615 30"-rVO 8-:'J'" [1'1 " ,:. (, ,1(',:'11 ' -:' ~.j;; cd" 1,1(', J ~'~~ i 11i :-1/[1 ~e~~~v:~~!l DRILLING SERVIC'ë-s A Halliburton Company ï 1:'1::11 Ü'7(ltrl lI}~(I,J I-,(ln f JIL' t ~ jl) ,-/':It"1 1,'1) ~~-~}':- .~- -~i':I. f: ,,'.' '--- ':.EI.', _~'~_1 f J_:.. I::' 11 E " I 800 I 1600 I 2400 I 3200 I 4000 I 4800 Plan, IM-17 596038356 N, 57190738 E 959651 39 N. 8109537 E 70' 18' 07 3970" N, 149 25' 03 2377' W 618' FSL & 600' FWl. SEe 17 - T11N - R11E 93,300 above Mean Sea Level - -2400 True NOl1h Feel (US) - -3200 1 \ I.', . L I 'f. .J, .:: ,';'1 /\"',"",' I. tll /, '.' II :"'.~ .III I \ I J'I/.,I.II"".\ 5h:; .'J' 1 "1 ~/lI., ,""I' ¡. \1 .\ -';'1' {III ~{... -" . TlI \ ' NIII , - -4000 I II(I'¡ I 'I I. ...'::,1 U",/'II J I, If I h'. '1:'.' - .1" / 'I'. I'/"J,," '..\ ; 11,' -'" I ..I ~lil I' ~ ~ I., L ,'. I,' I 1\ L 'L I. , ~ I 111\, I,' ilL, ----- ------- --------- -- - - \ \ ';'1'2". 3-'~' c,~ J loj';rt)J I~I ML> , ':.;..;{1 D'1 TwD - ,4800 -......-...._:- I 5600 I 6400 Scale. 1 Inch = 80011 Phillips Alaska, Inc. 1 M.17 (wp02) MD Inc Azim. SSTVD TVD NIS EIW V X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) (ft) i'J,lj() (,,1,)(1 Ú,I)[i -'J~.:3U O,uU 1,).'.)(,1 :'J :,~I.~:II) E ~1'J~~L).~;:3j.~=,Ó :"1 ::,¡,l':'li,.:j8 E 1,).')(.1 Û,lJL¡ :::;HL 400.00 0.00 0.00 306.70 400.00 0.00 N 0.00 E 5960383.56 N 571907.38 E 0.00 0.00 Begin Dlr (g! 2.5"/100ft (9.7/8" Hole) 800,00 10.00 115.55 704,67 797.97 15.02 S 31.41 E 5960368.85 N 571938.94 E 2,50 33.34 Increase DLS to 3,0/1 DOh 1771.49 38.72 130,33 1581,00 1674.30 253.18 S 345,96 E 5960133,71 N 572255.75 E 3,00 426.26 Base Permafrosl 2602.97 63.59 132,78 2098.47 2191.77 681. 16 S 825.10 E 5959710.33 N 572738.96 E 3.00 1068,69 End Dir, Start Sail 5246.19 63.59 132,78 3274.00 3367.30 2289.12 S 2562.68 E 5958119.07 N 574491.85 E 0.00 3436.04 Ugnu C C 6624,54 63.59 132.78 3887.00 3980.30 3127,62 S 3468,77 E 5957289,29 N 575405.92 E 0.00 4670.53 Top West Sak ::x:. 7602.65 63.59 132.78 4322.00 4415.30 3722.64 S 4111.75 E 5956700.45 N 576054.57 E 0.00 5546,56 Base West Sak 8052.36 63.59 132.78 4522.00 4615.30 3996,21 S 4407.38 E 5956429.72 N 576352.80 E 0.00 5949.33 7-518" Casing PI ---- 8462.51 63.59 132.78 ..¡ 704,41 4797.71 4245.72 S 46n.OO E 5956182.80 N 57662"¡,80 E 0.00 6316.68 Begin Dir ,:;r' 3,0:/10011 c-) 10485.26 2.91 132.78 6318.00 6411.30 4964,32 S 5453.53 E 5955471.66 N 577408.18 E 3.00 7374.66 Lower Kalubik ---- 10582.30 0.00 0.00 6415.00 6508.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 3,00 7377.12 TARGET (C4) ~ 10601.30 0.00 0.00 6434.00 6527.30 4966.00 S 5455.3-1- E 5955~70_00 N 577410.00 E 0.00 7377.12 TARGET (C3) 10632,30 0.00 0.00 6465.00 6558.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 C2 r--- 10655.30 0,00 0.00 6488.00 6581.30 4966,00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377,12 C1 10667.30 0.00 0,00 6500.00 6593.30 4966,00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 Unit B 10780.30 0.00 0.00 6613,00 6706,30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0,00 7377,12 A6 10792.30 0.00 0.00 6625.00 6718.30 4966.00 S 5455.34 E 5955470,00 N 577410,00 E 0.00 7377,12 A5 10813,30 0,00 0,00 6646.00 6739,30 4966,00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 A4 10854.30 0.00 0.00 6687.00 6780.30 4966.00 S 5455.34 E 5955470,00 N 577410.00 E 0.00 7377.12 Mlluveach 10904,00 0.00 0.00 6736.70 6830.00 49136,00 S 5455.34 E 595~¡"¡ 70.00 N 577410.00 E 0.00 7377,12 Total Depth Page 1 of 1 Company: Field: Reference Site: Reference WeD: Reference WeD path: Phillips Alaska Inc, Kuparuk River Unit Kuparuk 1 M Pad 1M-17 Plan Plan: 1M-17 Sperry-Sun Anticollision Report Date: 11/21/2001 Co-ordinate(N"E) Reference: Vertical (TVD) Reference: GLOBAL SCAN APPLIED: All \\ellpaths \\ithin 200'+ 100/1000 of reference Interpolation Method: MD loterval: 50.00 ft Depth Range: 30,30 to 10904.00 ft Ma.'\imwn Radius: 1287,37 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Denrrltin Wellpath Dale: 11/19/2001 Validated: No Planned From To Surve~' ft ft 30.30 700.00 30,30 10904.00 Planned: 1 M-17 (wp02) V1 Planned: 1M-17 (wp02) V1 Casing Points I\ID TVD ft ft 8051,68 4615.30 10904,00 6830.39 Diameter in 7.625 5.500 Hole Size in 9.875 6,750 Swnmar)' <---------------------- Offset \\'ellpath -------------..-..-..> Site WeD Wellpath Kuparuk 1 M Pad MP 1 17-11-11 Version: Toolcodc 4 CB-GYRO-SS MWD Time: 06:14:27 Page: Well: 1 M-17 Plan. True North 1 M-17 wi Nordic 3 93.3 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Tool Nume Camera based gyro single shots MW 0 - Standard --- ------------------------ ---- ------ Name 7 -5/8" 51/2" Reference Offset Ctr.Ctr No-Go Allowable MD 1\10 Distance Area Deviation ft It tt It It 1005.72 1000.00 124,29 20.15 104.15 MP 117-11-11 VO --------- ------ ._-~. ---- O~ G.N)~ Warning Pass: Major Risk - -- ------.-------þ-----.-- Phillips Alaska, Inc. 1 M-17 (wp02) MD Inc Azirn. SSTVD TVD NJS EIW Y X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) (ft) 0.00 0,00 000 -93.30 0.00 0.00 r\J 0.00 E 5960383,56 I\J 571907.38 E 0.00 0,00 SHL 100.00 0.00 0.00 6.70 100.00 0.00 N 0.00 E 5960383.56 N 571907.38 E 0.00 0.00 200.00 0.00 0.00 106.70 200.00 0.00 N 0.00 E 5960383.56 N 571907.38 E 0.00 0.00 300.00 0.00 0.00 206.70 300.00 0.00 N 0.00 E 5960383.56 N 571907.38 E 0.00 0.00 400.00 0.00 0,00 306.70 400,00 0.00 N 0.00 E 5960383.56 N 571907.38 E 0.00 0.00 Begin Dir @ 2.5°/10011 (9-7/8" Hole) 500.00 2.50 115.55 406.67 499.97 0.94 S 1.97 E 5960382.64 N 571909.36 E 2.50 2.09 600.00 5.00 115,55 506.45 599.75 3.76 S 7.87 E 5960379.87 N 571915.28 E 2.50 8.35 700.00 7.50 115.55 605.84 699.14 8.46 S 17.69 E 5960375.27 N 571925.15 E 2.50 18.77 800.00 10,00 115.55 704.67 797.97 15,02 S 31,41 E 5960368,85 N 571938,94 E 2,50 33.34 Increase DLS to 3.0/10011 900.00 12.87 119.96 802.68 895.98 24.33 S 48.90 E 5960359.70 N 571956.51 E 3.00 52.54 1000.00 15.79 122.78 899.56 992.86 37.26 S 70.00 E 5960346.97 N 571977.73 E 3.00 76.84 1100.00 18.73 124.73 995.04 1088.34 53.78 S 94.64 E 5960330.69 N 572002.53 E 3.00 106.19 1200.00 21.69 126.17 1088.88 1182.18 73.84 8 122.76 E 5960310.90 N 572030.84 E 3.00 140.49 1300.00 24.66 127.27 1180.79 1274.09 97.38 S 154.29 E 5960287.66 N 572062.60 E 3.00 179.65 1400.00 27.64 128.16 1270.55 1363.85 124.35 S 189,14 E 5960261.02 N 572097.70 E 3.00 223.58 1500.00 30.62 128.88 1357.90 1451.20 154.67 8 227.21 E 5960231.07 N 572136.06 E 3.00 272.14 1600.00 33.60 129.48 1442.59 1535.89 188.25 S 268.40 E 5960197.88 N 572177.57 E 3.00 325.21 C 1700.00 36.58 130.00 1524.41 1617.71 225.01 S 312.59 E 5960161.55 N 572222.11 E 3.00 382.63 :x: 1771.49 38.72 130.33 1581.00 1674.30 253.18 S 345.96 E 5960133.71 N 572255.75 E 3.00 426.26 Base Permafrost ........ 1800.00 39.57 130.45 1603.12 1696.42 264.84 8 359.67 E 5960122.18 N 572269.57 E 3.00 444.25 ~ 1900.00 42.56 130.85 1678.50 1771.80 307.63 S 409.50 E 5960079.86 N 572319.81 E 3.00 509.91 2000.00 45.55 131 .20 1750.36 1843.66 353.27 S 461.95 E 5960034.73 N 572372.69 E 3.00 579.42 ---- 48.54 131.52 1818.50 1911.80 401.63 S 516.88 E 5959986.90 N 572428.08 E 3.00 652.59 ::z: 2100.00 ~ 2200.00 51.53 131 .81 1882.72 1976.02 452.57 S 574.13 E 5959936.50 N 572485.81 E 3.00 729.22 2300.00 54.53 132.08 1942.86 2036.16 505.97 S 633.55 E 5959883.68 N 572545.74 E 3.00 809.1 O r-- 2400.00 57.52 132.32 1998.74 2092.04 561.67 S 694.97 E 5959828.57 N 572607.69 E 3.00 892.02 2500.00 60.51 132.56 2050.21 2143.51 619.51 S 758.23 E 5959771.33 N 572671.50 E 3.00 977.74 2600.00 63.51 132.78 2097.14 2190.44 679.35 S 823.15 E 5959712.12 N 572736.99 E 3.00 1066.03 2602.97 63.59 1 32.78 2098.4 7 2191.77 681 .1 6 S 825.10 E 5959710.33 hi 572738,96 E 3,00 1068.69 End Dlr; Start Sail 2700.00 63.59 132.78 2141.62 2234.92 740.18 S 888.88 E 5959651.92 N 572803.31 E 0.00 1155.59 2800.00 63.59 132.78 2186.09 2279.39 801.02 S 954.62 E 5959591.72 N 572869.62 E 0.00 1245.15 2900.00 63.59 132.78 2230.57 2323.87 861.85 8 1020.36 E 5959531.52 N 572935.94 E 0.00 1334.72 3000.00 63.59 132.78 2275.04 2368.34 922.68 S 1086.10 E 5959471.31 N 573002.26 E 0.00 1424.28 3100.00 63.59 132.78 2319.51 2412.81 983.52 S 1151 .83 E 5959411.11 N 573068.57 E 0.00 1513.84 3200.00 63.59 132.78 2363.99 2457.29 1044.35 S 1217.57 E 5959350.91 N 573134.89 E 0.00 1603.41 3300.00 63.59 132.78 2408.46 2501.76 1105.188 1283.31 E 5959290.71 N 573201.21 E 0.00 1692.97 3400.00 63.59 132.78 2452.93 2546.23 1166.02 8 1349.05 E 5959230.51 N 573267.52 E 0.00 1782.53 3500.00 63.59 132.78 2497.41 2590.71 1226.85 8 1414.78 E 5959170.31 N 573333.84 E 0.00 1872.09 3600.00 63.59 132.78 2541 .88 2635.18 1287.68 8 1480.52 E 5959110.10 N 573400.16 E 0.00 1961.66 3700.00 63.59 132.78 2586.36 2679.66 1348.52 S 1546.26 E 5959049.90 N 573466.4 7 E 0.00 2051 .22 3800.00 63.59 132.78 2630.83 2724.13 1409.35 S 1611.99 E 5958989.70 N 573532.79 E 0.00 2140.78 3900.00 63.59 132.78 2675.30 2768.60 1470.18 S 1677.73 E 5958929.50 N 573599.11 E 0.00 2230.35 4000.00 63.59 132.78 2719.78 2813.08 1531.02 S 1743.47 E 5958869.30 N 573665.42 E 0.00 2319.91 Page 1 of 3 Phillips Alaska, Inc. 1 M-17 (wp02) MD Inc Azim. SSTVD TVD N/S EIW V X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) COJ10OO) (ft) 4100,00 63.59 132.78 2764.25 2857.55 1591.85 S 1809.21 E 5958809.10 N 573731.74 E 0.00 2409.47 4200.00 63.59 132.78 2808.72 2902.02 1652.69 S 1874.94 E 5958748.90 N 573798.06 E 0,00 2499.04 4300.00 63.59 132.78 2853.20 2946.50 1713.52 S 1940.68 E 5958688.69 N 573864.37 E 0.00 2588.60 4400.00 63.59 132.78 2897.67 2990.97 1774.35 S 2006.42 E 5958628.49 N 573930.69 E 0.00 2678.16 4500.00 63.59 132.78 2942.14 3035.44 1835.19 S 2072.16 E 5958568.29 N 573997.00 E 0.00 2767.73 4600.00 63.59 132.78 2986.62 3079.92 1896.02 S 2137.89 E 5958508.09 N 574063.32 E 0.00 2857.29 4700.00 63.59 132.78 3031.09 3124.39 1956.85 S 2203.63 E 5958447.89 N 574129.64 E 0.00 2946.85 4800.00 63.59 132.78 3075.56 3168.86 2017.69 S 2269.37 E 5958387.69 N 574195.95 E 0.00 3036.42 4900.00 63.59 132.78 3120.04 3213.34 2078.52 S 2335.11 E 5958327.48 N 574262.27 E 0.00 3125.98 5000.00 63.59 132.78 3164,51 3257.81 2139.35 S 2400.84 E 5958267.28 N 574328.59 E 0.00 3215.54 5100.00 63.59 132.78 3208.98 3302.28 2200.19 S 2466.58 E 5958207.08 N 574394.90 E 0.00 3305.11 5200.00 63.59 132.78 3253.46 3346.76 2261.02 S 2532.32 E 5958146.88 N 574461.22 E 0.00 3394.67 5246.19 63.59 132.78 32ì ..LOa 3367.30 2289.12 S 2562.68 E 5958119.07 N 574491.85 E 0.00 3436.04 Ugnu C 5300.00 63.59 132.78 3297.93 3391 .23 2321.85 S 2598.05 E 5958086.68 N 574527.54 E 0.00 3484.23 5400.00 63.59 132.78 3342.40 3435.70 2382.69 S 2663.79 E 5958026.48 N 574593.85 E 0.00 3573.80 5500.00 63.59 132.78 3386.88 3480.18 2443.52 S 2729.53 E 5957966.28 N 574660.17 E 0.00 3663.36 5600.00 63.59 132.78 3431.35 3524.65 2504.35 S 2795.27 E 5957906.07 N 574726.49 E 0.00 3752.92 C) 5700.00 63.59 132.78 3475.83 3569.13 2565.19 S 2861.00 E 5957845.87 N 574792.80 E 0.00 3842.48 5800.00 63.59 132.78 3520.30 3613.60 2626.02 S 2926.74 E 5957785.67 N 574859.12 E 0.00 3932.05 ::0 5900.00 63.59 132.78 3564.77 3658.07 2686.85 S 2992.48 E 5957725.47 N 574925.44 E 0.00 4021.61 ---- 6000.00 63.59 132.78 3609,25 3702.55 2747.69 S 3058.22 E 5957665.27 N 574991.75 E 0.00 4111.17 C) 6100.00 63.59 132.78 3653.72 3747.02 2808.52 S 3123.95 E 5957605.07 N 575058.07 E 0.00 4200.74 --- 6200.00 63.59 132.78 3698.19 3791.49 2869.36 S 3189.69 E 5957544.86 N 575124.38 E 0.00 4290.30 :c:: 6300.00 63.59 132,78 3742.67 3835.97 2930.19 S 3255.43 E 5957484.66 N 575190.70 E 0.00 4379.86 ~ 6400.00 63.59 132.78 3787.14 3880.44 2991.02 S 3321 .16 E 5957424.46 N 575257.02 E 0.00 4469.43 r--- 6500.00 63.59 132.78 3831.61 3924.91 3051.86 S 3386.90 E 5957364.26 N 575323.33 E 0.00 4558,99 6600.00 63.59 132.78 3876.09 3969.39 3112.69 S 3452.64 E 5957304.06 N 575389.65 E 0.00 4648.55 6624.54 63.59 1 32.78 3887.00 3980.30 3127.62 S 3468.77 E 5957289.29 N 575405,92 E 0.00 4670.53 Top West Sak 6700.00 63.59 132.78 3920.56 4013.86 3173.52 S 3518.38 E 5957243.86 N 575455.97 E 0.00 4738.12 6800.00 63.59 132.78 3965.03 4058.33 3234.36 S 3584.11 E 5957183.65 N 575522.28 E 0.00 4827.68 6900.00 63.59 132.78 4009.51 4102.81 3295.19 S 3649.85 E 5957123.45 N 575588.60 E 0.00 4917.24 7000.00 63.59 132.78 4053.98 4147.28 3356.02 S 3715.59 E 5957063.25 N 575654.92 E 0.00 5006.81 7100.00 63.59 132.78 4098.45 4191.75 3416.86 S 3781,33 E 5957003.05 N 575721.23 E 0.00 5096.37 7200.00 63.59 132.78 4142.93 4236.23 3477.69 S 3847.06 E 5956942.85 N 575787.55 E 0.00 5185.93 7300.00 63.59 132.78 4187.40 4280.70 3538.52 S 3912.80 E 5956882.65 N 575853.87 E 0.00 5275.50 7400.00 63.59 132.78 4231.88 4325.18 3599.36 S 3978.54 E 5956822.45 N 575920.18 E 0.00 5365.06 7500.00 63.59 132.78 4276.35 4369.65 3660.19 S 4044.27 E 5956762.24 N 575986.50 E 0.00 5454.62 7600.00 63.59 132.78 4320.82 4414.12 3721.02 S 4110.01 E 5956702.04 N 576052.82 E 0.00 5544.19 7602.65 63.59 1 32,78 4322.00 4415.30 3722.64 S 4111.75E 5956700.45 N 576054.57 E 0.00 5546.56 Base West Sak 7700.00 63.59 132.78 4365.30 4458.60 3781.86 S 4175.75 E 5956641.84 N 576119.13 E 0.00 5633.75 7800.00 63.59 132.78 4409.77 4503.07 3842.69 S 4241.49 E 5956581.64 N 576185.45 E 0.00 5723.31 7900.00 63.59 132.78 4454.24 4547.54 3903.52 S 4307.22 E 5956521.44 N 576251.77 E 0.00 5812.87 8000.00 63.59 132.78 4498.72 4592.02 3964.36 S 4372.96 E 5956461.24 N 576318.08 E 0.00 5902.44 Page 2 of 3 Phillips Alaska, Inc. 1 M-17 (wp02) MD Inc Azim. SSTVD TVD N/S EIW Y X DLS v.s. Comment (ft) (Deg) (Deg) (ft) (ft) (ft) (ft) (ft) (ft) (°/1000) (ft) 8052.36 63.59 132.78 4522.00 4615.30 3996.21 S 4407.38 E 5956429.72 N 576352.80 E 0.00 5949.33 7-5/8" Casing pt 8100.00 63.59 132.78 4543.19 4636.49 4025.19 S 4438.70 E 5956401.03 N 576384.40 E 0.00 5992.00 8200.00 63.59 132.78 4587.66 4680.96 4086.02 S 4504.44 E 5956340.83 N 576450.71 E 0.00 6081 .56 8300.00 63.59 132.78 4632.14 4725.44 4146.86 S 4570.17 E 5956280.63 N 576517.03 E 0.00 6171.13 8400.00 63.59 132.78 4676.61 4769.91 4207.69 S 4635.91 E 5956220.43 N 576583.35 E 0.00 6260.69 8462,51 63.59 132.78 4704.41 4797.71 4245.72 S 4677.00 E 5956182.80 N 576624.80 E 0.00 6316,68 Begin Dlr @ 3,oo/100ft 8500.00 62.47 132.78 4721.41 4814.71 4268.41 S 4701.53 E 5956160.34 N 576649.54 E 3.00 6350.09 8600.00 59.47 132.78 4769.94 4863.24 4327.79 S 4765.69 E 5956101.58 N 576714.27 E 3.00 6437.51 8700.00 56.47 132.78 4822.97 4916.27 4385.37 S 4827.91 E 5956044.60 N 576777.04 E 3.00 6522.27 8800.00 53.47 132.78 4880.36 4973.66 4440.98 S 4888.00 E 5955989.57 N 576837.66 E 3.00 6604.15 8900.00 50.47 132.78 4941.96 5035.26 4494.47 S 4945.80 E 5955936.63 N 576895.97 E 3.00 6682.90 9000.00 47.47 132.78 5007.60 5100.90 4545.70 S 5001.16 E 5955885.93 N 576951.82 E 3.00 6758.33 9100.00 44.4 7 132.78 5077.10 5170.40 4594.52 S 5053.93 E 5955837.61 N 577005.05 E 3.00 6830.21 9200.00 41.47 132.78 5150.26 5243.56 4640.81 S 5103.95 E 5955791.81 N 577055.51 E 3.00 6898.36 9300.00 38.4 7 132.78 5226.90 5320,20 4684.44 S 5151.09E 5955748.63 N 577103.06 E 3.00 6962,59 9400.00 35.47 132.78 5306.78 5400.08 4725.28 S 5195.22 E 5955708.22 N 577147.59 E 3.00 7022,72 C 9500.00 32.47 132.78 5389.71 5483.01 4763.23 S 5236.23 E 5955670.67 N 577188.95 E 3.00 7078.59 9600.00 29.47 132.78 5475.44 5568.74 4798.17 S 5273.99 E 5955636.08 N 577227.05 E 3.00 7130.04 ::t:J 9700.00 26.47 132.78 5563.75 5657.05 4830.02 S 5308.41 E 5955604.56 N 577261.77 E 3.00 7176.93 ---- 9800.00 23.47 132.78 5654.39 5747.69 4858.69 S 5339.39 E 5955576.19 N 577293.02 E 3.00 7219.13 C"':) 9900.00 20.47 132.78 5747.12 5840.42 4884.10 S 5366.84 E 5955551.05 N 577320.72 E 3.00 7256.54 ---- 10000.00 17.47 132.78 5841.68 5934.98 4906.17 S 5390.69 E 5955529.21 N 577344.78 E 3.00 7289.04 ~ 10100.00 14.47 132.78 5937.81 6031.11 4924.86 S 5410.88 E 5955510.72 N 577365.15 E 3.00 7316.55 10200.00 11.47 132.78 6035.25 6128.55 4940.10 S 5427.35 E 5955495.63 N 577381.76 E 3.00 7338.99 ~~ 10300.00 8.47 132.78 6133.73 6227.03 4951.85 S 5440.06 E 5955484.00 N 577394.58 E 3.00 7356.30 ~--- 10400.00 5.47 132.78 6232.98 6326.28 4960.09 S 5448.96 E 5955475.84 N 577403.56 E 3.00 7368.43 10485.26 2.91 132.78 6318.00 6411.30 4964.32 S 5453.53 E 5955471.66 N 57ì408.18 E 3.00 7374.66 Lower Kalubik 10500.00 2.47 132.78 6332.73 6426.03 4964.79 S 5454.04 E 5955471.19 N 577408.69 E 3.00 7375.35 10582.30 0.00 0.00 6415.00 6508.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 3.00 7377,12 TARGET (C4) 10600.00 0.00 0.00 6432.70 6526.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 10601.30 0.00 0.00 6434.00 6527.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 TARGET (C3) 10632.30 0.00 0.00 6465.00 6558.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 C2 10655.30 0.00 0.00 6488.00 6581 .30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377,12 C1 10667.30 0.00 0.00 6500.00 6593.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 Unit B 10700.00 0.00 0.00 6532.70 6626.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 10780,30 0.00 0.00 6613.00 6706.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 A6 10792.30 0.00 0.00 6625.00 6718.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 A5 10800.00 0.00 0.00 6632.70 6726.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 10813.30 0.00 0.00 6646.00 6739.30 4966,00 S 5455,34 E 5955470.00 N 577410.00 E 0.00 7377.12 A4 10854.30 0.00 0.00 6687,00 6780.30 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377,12 Mlluveaeh 10900.00 0.00 0.00 6732.70 6826.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 10904.00 0.00 0.00 6736.70 6830.00 4966.00 S 5455.34 E 5955470.00 N 577410.00 E 0.00 7377.12 Tolal Deptrl Page 3 of 3 i Sperry-Sun Drilling Services Proposal Data - Plan: 1M-17 - 1M-17 (wp02) I 1 : 2 I 3 4 5 6T I 7' I 8' MD Delta Inclin. (ft) MD (ft) (°) 0,00 0.000 400.00 4OO.pQ' 0.000 800,00 :,4()O.OO 10.000 2602.97 1802.97 63.594 8462.51 5859.54.63.594 10582.30 2119.79 0.000 10601.30, - 19.0.0' a.cool . 10904.00' '- ~2:~~_- .. _0~~1 21 November, 2001 - 5:46 Azimuth (°) 0.000 0.000 115.548 , 132.781 132.781 0.000 0.000 0.000 TVD Northings Eastings! Dogleg' T ooIf ace (ft) (ft) (It): (0/10att): e) 0.00 0.00 0.00: \. -.-...--.. ._-~ 400:00 -: 0.00, 0.001 o.OOo:'-õ.OOO "Z97!d7-' ,15.02 S' . 31,41 E --==2.500! 115.5~ 2191.77 '~'1.~6 S' ~.10 E 300û 19.124., '4797.71, 42~.12 S' ~,oo E 0.000 0.000 6508.30 4966.00 S 5455,34 E 3.000 180.000 6527.30l 4966.00 S ; 5455.34 E 0.000!,_~j:..~9Q . 6830.00 ¡.. 4~6.<>9 s . _~455.34 E I 0,000 0.000 0 . I , I ^ I J' . .:f,i/~1- 1..-1- Dri/lOuest ! 1 i 2 : 3 4 5 6T I 7' [ 8' MD (ft) 0.00 400.00 800.00 2602.97 8462.51 10582.30 10601.30 10904.00 t , Sperry-Sun Drilling Services Proposal Data - Plan: 1 M-17 - 1 M-17 (wp02) Delta Inelin., Azimuth MD (ft) (°) , (°) : 0,00011 0.000 400.00 '0.000, 0.000 '400.00 .1O.000! 115.000 1802.~7 ~.594 ,132233 5859.54. 63.594 132.233 2119.79 0,000 0.000 19.00 0.0001 0,000 ..30~?g - . .O_'~¡ ~-~Q()O 21 November, 2001 - 5:47 lVD Northings (ft) (ft) -93.30 5960383.56 N 306.70 596å383.56 N 704.671 5960368.85 N 2098.47 5959710.33 N 4704.41 5956182.80 N 6415.00 5955470.00 N 6434.00 ¡ 5955470.00 N I 6736.70i ~95~70.~.N- o~,'aNAL Eastings Dogleg TooIfaee l (ft) e /1 00ft) (°) 571907.38 E' I -~~~~~~ 571907.38 E 0.000: 0.000 -- - 571938.94 E 2.500 I 115.000' 572738.96 E 3.000 19.124: 576624.80 E 0.000 0.000: 577410.00 E 3-=.000 _180-=-09.~j 577410.00 EI__-9.00ql----~~~~I¡ 577410.00 E¡ 0.000' 0.000 - 1 - DrillQuest 1 M-17 Drillina Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 9-7/SI1 Hole /7-5/S' CasinQ Interval Event Conductor Broach G ravel and sand sloughing Shaker Overflow Shoe Fracture/Lost Returns during cement job Hole cleaning in long, high angle tangent Risk Level Low Low Moderate High High I M itiCiation StrateCiY Monitor cellar continuously during interval. Elevated mud viscosity from spud, and High density sweeps Controlled ROP, and use of solids control van Reduced pump rates, and lightweight tail cement Good drilling practices 6-3/4' Hole /5-1/2 & 3-1/2' CasinQ Interval Event Shale stability in HRZ High ECD and swabbing if higher MW is required Shale stability across K- 1 interval I Risk Level Moderate High Moderate :: G. AlJ.. I M itiCiation StrateCiY Control with higher MW and proper drilling practices. Pumping and rotating out on all trips to reduce swab and barite sag potential. Control with higher MW and proper drilling practices. 1M-17 Drilling Hazards Summary. doc prepared by Shane Cloninger 11/5'01 Page 1 of 1 Rig: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 11/21/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com < TOCat Surface -I II I ~evious Csg I < 16", 62.6# casing I, at 120' tvÐ I' I I 'I \ I / I ) ~ ,::--~ ,~ i ',- ::1 :~'] < Base of Permafrost at 1,772' tvÐ (1.674'lVD) < Top of Tail at 5.825' tvÐ < Top of West Sak at 6.625' tvÐ ,-!': .:,;: tJ :l J < 75/8",29.7# casing in 9 7/8" OH ill at 8,052' tvÐ (4,615'lVD) Mark of Schlumberger Schlumberger ~~mCADE Preliminary Job Desigrl 7 5/8" Surface PrEoI,m,nary Job De£,gn t-:Eed on Iorr"tEod ,nput d.:ota For €-51,male purposes only, Volume Calculations and Cement Systems Volumes are based on 250~'ó excess in the permafrost and 45~,~ excess below the permafrost. The top of the tail slurry is designed to be 800' above the West Sak formation. Lead Slurrv Minimum pump time: 260 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg, Class G + 50%0124, 9%(BWOW)D44, 0.6°/0046, 30%053, 1.5~/oS1, 1.5%079, 0.5%065 - 4.44 ft3/sk 0.9513 fe/ft x (120') x 1.00 (no excess) = 0.2148 fe/ft x (1772' - 120') x 3.50 (250% excess) = 0.2148 fe/ft x (5825' - 1772') x 1.45 (45% excess) = 114.2 fe + 1242 fe+ 1262.3 fe = 2618.5 fe / 4.44 fe/sk = Round up to 590 sks 114.2 fe 1242fe 1262.3 ft3 2618.5 fe 589.8 sks Have 170 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 180 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.40 ft3/sk 0.2148 ft3/ft x (8052' - 5825') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 693.6 ft3 + 20.6 fe = 714.2 ft3/ 2.4 ft3/sk = Round up to 300 sks 693.6 fe 20.6 fe 714.2 fe 297.6 sks BHST = 101°F, Estimated BHCT = 91°F. (BHST calculated using a gradient of 2.4°F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW 100 6 50 8.3 8.3 Drop Bottom Plug 3.0 11.3 MudPUSH XL 6 50 8.3 19.6 Lead Slurry 6 467 77.8 97.4 Tail Slurry 6 128 21.3 118.7 Drop Top Plug 3.0 121.7 Displacement 6 346 57.7 179.4 Slow Rate 3 20 6.7 186.1 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH" XL, Pv == 17-21, Ty:::: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. J:, ~,'AÁL RIg: Nordic 3 Location: Kuparuk Client: Phillips Alaska, Inc. Revision Date: 11/21/01 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com If, 1 ~I Ii II ~ A"eVi~US Csg. .1..< 75/8 .29,7#, at 8.052 ft. M) < 51/2", 15.5#, L-80 grade in 6 3/4" OH ] ;::\.ì /,1 :/",( ~'~:-l \:,:;:' :~~/':: < Top of Tail at 9,902 ft. M) < X-over at 10,402 ft. M) . ~~~;~ : < Top of C4 Target at 10,582 ft. M) - ,'. \ I < 31/2".9,3#, L-80 grade BJE, 8rd rvbdified in 6 3/4" OH IDat 10,904ft. M) (6,830 ft. TVD) .Mark of Schlumberger Schlumberger L,~mCADE Preliminary Job Desigrl 5 1/2" x 3 1/2" Production Pro?l,m,nary Joe Doõ's'gn easo?d on Ilm,red ,npul data Fer est,mate purposes Only Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurrv (minimum thickening time 145 min.) GasBLOK wi Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing @ 15.8 ppg, 1.2 fe/sk 0.0835 fe/ft x 500' x 1.75 (75~'~ excess) = 0.1817 felft x (10904' - 10402') x 1.75 (75% excess) = 0.0488 fe/ft x 80' (Shoe Joint) = 73.1 fe + 159.6 ft3 + 3.9 fe = 236.6 fel 1.2 fe/sk = Round up to 200 sks 73.1 ft3 159.6 fe 3.9 fe 236.6 fe 197.2 sks BHST = 156°F, Estimated BHCT = 125°F. (BHST calculated using a gradient of 2.4 °F/1 00 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 50 8.3 18.0 Tail Slurry 6 43 7.2 25.2 Drop Top Plug 3.0 28.2 Displacement 6 231 38.5 66.7 Bump Plug 3 20 6.7 73.4 MUD REMOVAL Recommended Mud Properties: 10.4 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv == 19-22, T y == 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. O.G . ,!~1~! , I L I~..." £I,~ '- I - -", 1 M - 17 Produl ..:r Proposed Completion Schematic Slimhole Base Case - 3-1/211 Completion String tPiiiûiPS\ P~ILLlPS Alaska, Inc. æ A Subsidiary of PHilLIPS PETROLEUM COMPANY 16" 62.6# @ +1- 120' MD Surface csg. 7-5/8" 29,7# L-80 BTCM +/- 8,052' MD / 4,615' TVD Production csg. X-over pt. 5-1/2" 15.5# L-80 BTCM +1- 10,402' MD I 6,326' TVD Future Perforations Production csg 3-1/2" 9,3# L-80 EUE8RD 10,904' MD I 6,830' TVD ~ J- ¡ ¡ I ~ ~ ~ ~ AIIÍ I ¡ I ¡\;;~ i I $ f. ~ ~ - ~ ~ ~ r ~ 1¡';:;lÞ I L ~ . . f ¡ I I;;;~l~ I ~ ~ ~ ~ ¡¡ .t t ~ ¡',:' ! ¡ ¡ ~ ~ ~ I::=JI ~ ~ ~ ~ ~ ¡-~-!.- '" ;;;J /" 1~~;;:':~ ¡~ .... ~ 3-1/2" FMC Gen 5 Tubing Hanger. 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Cameo 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple (4) 3-1/2" x 1" Cameo 'KBG-2-9' mandrel WI dummy valve (Max. 004,725", 102.90") 3-1/2" x 1" Cameo 'KBG-2-9' mandrel wi DCK-3 shear valve and latch (Max. 00 4.725", ID 2.90"), pinned for 3000 psi shear (casing to tubing differential) 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Cameo 'DS' nipple wi 2.812" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke. 3-1/2" L-80 EUE8RD box up, 3-1/2" x 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle. 80-40. 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" 00 x 4" 10 17' Seal Bore Extension CSR set at +1- 180' above top perforation 0 --I - !~,,'~, JIG U ~I ,,1 ! ~.. ~...::.r." SDC, 11/5/01 TRANS1\lIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BEINCLUDEDINTRANSNDTTALLETTER \VELL NAME \L-'Q,Ù \ \-\ - \ \ CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) / DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORA TION ANNULAR DISPOSAL <--J NO INJECTION \VELL ANNULAR DISPOSAL ~s INJECTION WELL REDRILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well -' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the apprond application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. {Company Name) will assume the liability of any protest to the spacing exception that may occur. /<eLl WELL PERMIT CHECKLIST COMPANY ß, / /I;~ WELL NAME //)1-1 -7 PROGRAM: exp - dev ;/ redrll- serv - wellbore seg _ann. disposal para req- 'FIELD & POOL t/9tJ/Dn INIT CLASS ~V' ;'D/(. GEOl AREA 757(1 UNIT# all /¿'6 ON/OFF SHORE CJ/J ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . , . c.£-1 1'- - ~ c/.. ' '. '~' 2. Lease number appropriate.'*'". . . . . . . . . . . . . . . . . . ,N ,,;¿ 5u..""-r~ ~c-Q. ~ IA...- .A þL 0 2 e z '1-'3)' --fl"'V ~dL,'<- -h ~ ~'-"~/ a--~. 3. Unique well name and number. .. . . . . . . . . . . . , IN .,. "'þ. H\.. r{ D L c~2¥-<1. 61:> 4. Well located in a defi~ed pool.. . . :: . . : . . . . . . . . . ,N hr~-f ~OPfMCfjt:. LV4/~..... f(¡j!1' í~ ~ -;-~ K :;:¡;C~ rule:; ¿ê,2..(/:S.:d.,I ~~br'1-h."01 5. Well located proper distance from dnlhng Unit boundary. . . . ..)N tl.-e.j¡ l...A.:< &nlILd 1r-r:>r.... -tjt/~ ¡-:>a.!d! '-'Y'L I 9l:J , ,^<- 2.B.:: <-(3 #" / u..;(! 7/ 6. Welll?catedproperdi~tance.fro~?ther~ells.. . . . . . . . . Y N ~ ,n~<~~lf:d~~~,~/eY. /V~ /nt-<dlc:-? tV)!1 k':!jjul;~ ~,"- ~/ll-17. 7. Suffi~ent a~eage avadabl~ In dnlhng Unit.. . . . . . . . . . . / N ~1'\. -U...¿. -Bl.'4J::{ ~/ I.JJ¿II¡ ÞIL t:L-1vd-50';-liC-.. k::.iS . ,:UtI r-.' rV~ '.rHn"A- /02 /D 8. If deviated, IS wellböre plat Included.. . . . . . . . . . . . . . ' N -"'/7t..X> I ,nt>, ;;>1'-:/CAf~/,cDC- /.-J> ¿¡...¿.,-¿ ?,-,;:/-bW -I-r~ , Z 7,?"ç' A -r; j/ T7t.r:?-rL 9. Operator only affect~ party.. '. . . . . . . . . . . . . . . . . , N /.; 0- JJ 0'; o...iJ~'-1-o,J" ~?:i)C' VIJ. -It.. '~t.. ¡-.fa..c.L /LO/¿ ~ fr-rl"l\ 2 ßZc.¡.3::# I. 10. Oper~tor has ~ppropna!e bond In force.. . . . . . . . . . . . . N A Cc?~/t.-k .5'-~/''¡'''¿ 0,) t<X-/( ~5s iV 11./ bL r-24'v ;& ~.,'--' / /71- /7. 11. Permit can be Issued without conservatIon order. . . . . . . . ) N ' V / (, - ). (, . ",7 r... AP,fR DATE 12. Permit can be issued without administrative approval.. . . . . (y,¿4.- ..1-1."5fr~ I~,. ¿J6:.v . .~!...> )"b /2. S.O( 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y IN ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 15. Surface casing proteds all known USDWs. . . . . . . . . . . N ~~ '-J~\:)~ ~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N ~ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y @ ~,,~~\u, \J'~'\)~~<:l\ \J\~\tVa\<c. ,'\, Ç>\C1""~~ 18. CMT will cover all known productive horizons. . . . . . . . . . ~ N 19. Casing designs adequate for C, T, 8 & permafrost. . . . . . . N . - 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . Y N C<...~"-:>~"'-~ "~ \ ~ ~ c:.e..~.\{. ~* ' 21. If a re-drill, has a 10-403 for abandonment been approved. . . ¥-bI- ~~ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N ~C\ c\a~c<.... C) Ç>~~Gc "- 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling fluid program schematic & equip list adequate. . . . . N 25. 80PEs, do they meet regulation. . . . . . . . . . . . . . . . N , . , 26. BOPE press rating appropriate; test to .~ psig. N~~\' ~~\-~dS""1~';, ?K~ \~\"\ ~ ~\- ~ SrJ:'CID'" 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N , , 28. Work will occur without operation shutdown. . . . . . . . . . . )l ~ ( 29. Is presence of H28 gas probable.. . . . . . . . . . . . . . . . Y <J':V \\=>S,<-:.~ \\'-LIé..\'( ~~~~\. ~ç, ~t¿Cy'-.J'\~~E:.cJ ~ ~t'-~c.\Q~\,^-~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . . Y @) Ill.. 5 I~' I-;:;>r-.¿~~.;¡j- lA~ Ie -PCt&:/ ¿.../ 6 - ./Jd ¿¿,dÏs1 /c<=-¿y kc! 3- nt-.. ~, .;:.. ¿u-ë..5 é'. 31. Data presented on potential overpressure zones . . . . . . . ~ 4~pa-r.(...(L .¡-r!.~.-IJy-vð,r F~lf.'--'-'--€-I ,¿xr?~ /r:; /.c.. 3;2.,DOpS.. (.D.o{t:¡ r:.-</f¿ 32 S" I' f h II ~ N J~,<-!,, 1; )b4.S'~ <'-7'- OJ""-r-->c- ~UUI d4~- Ov~- ;:)""~:;;.5.:...(~ -ô?ltLS . elsmlc ana YSls 0 s a ow gas zones. . . . . . . . . . . .. A l. I.J ' ¡ ') APeR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . " ¡J Y N c<--r-¿ ~ -è-""t:::><t£."fli!. ,.Á /) :5Þ I ¿. 5", DI 34. Contact name/phone for weekly progress reports [exp~ only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. " to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOlJ2; ENGINEERING: UIC/Annular COMMISSION: . R~0r0 ~ 1JJ6i, IL/7/D WM ~ 8~ I' s .AØ'. +~l\h91JV1 \Jt"). JM~/:~t ~1-"tJ61 ,,/? : ~ fY!; f GEOLOGY APPR DATE c 0 Z 0 -I ~ :::0 -I m y N ~U.S\-rc. -\ D Clos '::» ~ ~~\ \... Y N T~\ ~ ~\ \ N\Cl'i ~\\\M..Q\f\" \¡)c( rt\l"\.\ \-\-~ ~f ~\). Z -I :I: en » ::0 m » Com mentsllnstructions: '~¥-f Nt4"'.f- & c1.dLd -k. :t'f"~b.~j/dh- o/¿Ú!J':] ",.!duo!. ¡';d ('~ f> ~;!J cv-vd ('L' '^':' -> / & /oJ!.S /}(¿, 5 f .Þ- t¿I..[,u ," fY..~,-- e.ð7ldu~ I-o-r fv T, þ-~ /¿~ c:\msoffice\wordian\diana\checklist (rev. 11/01/100) Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readabiltty of the Wen History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~¡:'.::-(r,'-::url ['rllllrl'~ ~,,=:r':l''::t;: LI3 .3c,:'In '-'tll.l.cJ' SPé"lsi,:;.r,: :, S L1SL1t, ~P."=:':l.slC,f¡: ..¡ ~ ¡'¡'~,n ,:..,¡:,( (is H: I)..j: ..j';. .>:":'::' F.-=",l H-2:'1,j",r S.::-("1':-2 n:'lrTI,,=:.........,., ,LISIFE C' at", . . . . . . . , , . . . . . . . . . . , . I)::' I) -I (, 2 ,~, ( 1 ',;¡ 1 n , . , . , . . . . . . , , . , . . . .3 To: P -2 "" 1 ! j a rTlE: . . . . , . , . . , . . . . . , U I! I:' I! ':,W] '~,:,n C i nua C 1 ',:,n UurrJ:.,,,,, r. . . , , ,1~ll f'r","1CU':; P,,,,,,,=:1 [larTIE:,..,.,. IJIJFlk'\'J!i ':,,:,riUnE:nt::.. . . , . . , . . . . . . . , . . STS LIS 1:'1p-2 H-2acJ-2!: .302[':.1.C¿- nam.:,.,.....,..,. LI ST b'E. C,:õ1 t -=, . . . . , , , , , . . , . , . , . . . ,0:2 (i -I I:' 2: ':' r 1 q 1 n, . . . . , . , , , . , . . , . , . . .:; T .3 T.:q:,¿. II :õ1IT1¿.. . , . , . , , , . . , , . . . i.itl~'Ji':'\'HJ ': ':' r, t 1 rJ u a C .1. ':' r, I I '..I ITJ::, -2 r , . . , . J' 1 Fr,,=:""1':'1lS', TapE: Ij:õ1rT1e,..,.. .1.11j¡:[j'~'i'Jli C ,:,ITúTl¿' n t:3 , , . , . . , . . . . . , . . . . S 1 S LIS H,,:: 1 ,:,:Ü E'~'F ': ':' iTúl',-: f¡ t Fe,: ':' r d 1.:', b'E HLè,C,E.P fup:õ1 r ul: [Iil C' ['J.:'.[o 10::"::':, # t'JELL [i.c..11£: .1...PI [ii.i[IEE.F,: ,:,PEF;',T':,F: L':":;':;I[lG ':':'I.JP.:',[j'L: 1.:', b' E. 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': h r,1 ': :'11 .:'.:: r "1 ': ¿. .:. 3C.l.¿.f¡t.l.I1C r.::chnical S-2r~lCE:S i?r.111.1.p.: ,:".lð.: f:,:'I, In,.:. ~p.::(r~' '.:'In (I .j - ,:., F ¡;: - (I ::: 1 ¡¡je, f Uti ;:'Y-llll-ll:: 1 -, .J. ':,,:",':1-" ¡:" E".::,¡nE l~ llli llE 6l? ~:,I) I~I .1:11:, ~,I~I . :. :' t.:..:-. ';;'1..1 I Iii C, ¡;: IJ [I ,:",F'.-[J[l-ll:::l- J. S;'.I: fP F. t ,Xi I E ':'~ Ell H'ÆE ':::.:'.SIW:; [,P I LL£FS EIT ::I':E 'ILi' ::,I'::E II[i, ['EE1H 1FT I ':, :, -, 1:', ':, :.., 1:', tS. - ~,I:' I:.. ...,:, I) 1 ,S . (I ('I) 1;;' . (":":' L,'). C' 1'::' '~I . I:' ': I:' ~, 1 . ':' :~ I) ~ 1.1:1 ,:'.LL [oU1Ho:, ,:.F,[ lJE,:,~T)FEC' ['EFTH3 ,[IC', ¡..,LiLE'.::: ,,::,rHEFlJI3E - . ~~, ~ ~, -, .;, ":' I:, aOI-a3ó 10/01 W,TH,. [,¡¡.JC. 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':,I'~'(I '~':'fTl!T¡-=- fl t F 0;:'':' ..:' t j FI LE HE;'.DEF FILE IJU¡, EEF,: [C' I TEe' i , E F.r:; EC' !J\'m DEpth ~h1ftEd 3nd C'EPTH I W:F [[-IEìJT: « [I LE SI.11,][.!.:"F.ï fEU T'>:'L ':::'='['E FEF C'FW' P.H':'E P.P:': F P:: F. PI.! F.PC' F E,1 '3P, rl I: H I fC:IJT !I':::I!T P..::'F C'1' C'T.=.H .3'= F_:', ,:lll='p-=-d ':Ul"':e.õ; all bit run.::. m'Õr':;1o;:,j. . :' t) I:' (I ET~F.T DEFTH 129.0 1:9.0 1:9.0 E3.S 1 ¿,;, . :' E;.::, 1 ':';: , 5, 1>:.:3 . :. 1 ~ 1. ::. 1 ~::' , (I 1 -:':' , I) 1~5.0 22~.1) ~951). :1 ¿':1¿0.~ ~')6CI.5 STOF DEFTH 11:1 9 ¿.8 . =. 1 (I 'j t,,~ . ':' 1'~1 ';' í:, ':: , ::. 111):'(1,:, 11'~1: I~I . 5, 1 1 (I ? I~I . :. 1 1'~':' ':' . :. 111:':' I~I . S 11 (I 1 :;, . 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