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208-133
Kat 3r--(ve i I f 33o Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com> Sent: Tuesday, September 10, 2019 6:16 AM ���cp/�O�L' To: Regg, James B (CED) 1 Cc: Valentine, Doug K; NSK Prod Engr Specialist Subject: 3K-1081-1 Defeated LPP/SSV (PTD# 208-1330) returned to service Mr. Regg, l The low pressure pilot (LPP) on injection well 3K -108L1 (PTD# 208-1330) was returned to service at approximately 1400 hrs on Monday September 8, 2019. At that point we had increased the injection rate to 600 BWPD and the injection pressure rose to 340 psig and was rising. Thanks, If ZIIM/ Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 From: CPF3 Prod Engrs Sent: Sunday, September 08, 2019 5:19 PM To: jim.regg@alaska.gov Cc: Valentine, Doug K <Doug.K.Valentine@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com> Subject: 3K-1081-1 Defeated LPP/SSV (PTD# 208-1330) per CO 4068.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K -108L1 (PTD# 208-1330 ) is defeated today, Sunday September 8, 2019. 3K -108L1 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Sak injectors at DS 3K. 3K-3081-1 is currently at wellhead injection pressure of 260 psig (decreasing) and injection rate of 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log' , where this well is referred to as 3K -308B. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 40613.001". K✓Ut 3V-1obI i P16 2-06133C Regg, James B (CED) From: CPF3 Prod Engrs <n1223@conocophillips.com�,>'�' q Sent: Sunday, September 8, 2019 5:19 PM �t l(l tq To: Regg, James B (CED) ( l ` Cc: Valentine, Doug K; NSK Prod Engr Specialist Subject: 3K-1081-1 Defeated LPP/SSV (PTD# 208-1330) per CO 4066.001 Mr. Regg, The low pressure pilot (LPP) on injection well 3K -108L1 (PTD# 208-1330 ) is defeated today, Sunday September 8, 2019. 3K -108L1 had been shut in since July 4, 2019 due to the CPF3 Seawater Tank preventing SW injection. We are ramping up injection slowly to the West Salk injectors at DS 3K. 3K-1081.1 is currently at wellhead injection pressure of 260 psig (decreasing) and injection rate of 300 bbls of water per day. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log" , where this well is referred to as 3K -108B. The AOGCC will be notified when the injection pressure has increased to above 250 psi and is stable, and the LPP/SSV function is returned to normal operation, in accordance with "Administrative Approval No. CO 40613.001". Please let me know if you have any concerns or questions, Thanks, Kenneth Lloyd Martin/Kaelin Ellis PERA/CPF3 Production Engineers Ph: (907) 659-7871 Pager: (907) 659-7000 pp# 328 DATA SUBMITTAL COMPLIANCE REPORT 312/2010 Permit to Drill 2081330 Well Name/No. KUPARUK RIV U WSAK 3K-108L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23395-60-00 MD 13189 TVD 3630 Completion Date 12/27/2008 Completion Status 1 WINJ Current Status 1 WINJ UIC-, Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T~pe Med/Frmt Number Name Scale Media No Start Stop CH Received Comments y I'.Rpt LIS Verification 3031 13189 Open 2/20/2009 LIS Veri, GR, FET, RPD, D C Lis 17604 , IT nduction/Resistivity 3031 13189 Open 2/20/2009 RPS, RPM, RPX, ROP LIS Veri, GR, FET, RPD, RPS, RPM, RPX, ROP Log Induction/Resistivity 25 Col 120 13189 Open 2/20/2009 MD ROP, EWR, DGR 8- Dec-2008 i Log Induction/Resistivity 25 Col 120 3629 Open 2/20/2009 TVD EWR, DGR 8-Dec- 2008 ~D C 17605~nduction/Resistivity 120 13189 Open 2/20/2009 EWR logs in PDS, EMF I and CGM graphics Well CoreslSamples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~ N Chips Received? i`f1~" Formation Tops L'J N Analysis -~FYI~- Received? it !I DATA SUBMITTAL COMPLIANCE REPORT 3/2/2010 Permit to Drill 2081330 Well Name/No. KUPARUK RIV U WSAK 3K-108L1 Operator CONOCOPHILLIPS ALASKA INC MD 13189 ND 3630 Completion Date 12/27/2008 Completion Status 1WINJ Current Status 1WINJ Comments: Compliance Reviewed By: API No. 50-029-23395-60-00 UIC Y Date: ~~ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 3K-108+L1 February 4, 2009 AK-MW-6005292 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 3K-108+L1 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23395-00,60 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23395-00,60 Digital Log Images 2 CD Rom 50-029-23395-00 50-029-23395-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 ~~- ,e,~.. ~. r Bry~J1,8131~ 'a~,'1~4n.COm Date: ~~~ ~r~c~ 1~(~,03 vac a~ ~~3 1~ ~ ~~ P, Signed: ~ WELL L®G TRANS1dIITTAL To: State of Alaska January 9, 2009 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 3K-108 L1 AK-MW-6005292 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23395-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bryan. Burinda@halliburton. com ;~ -, ~ ~z ; ,~~ ~ ~ ~ ~ L.~- ~~,, ~ ~.,_ w_ ~, ~'~~~ Date: g ` - ; . s~- Signed: US C d o°fs- ! 33 /~~~ T Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 13, 2009 3:38 PM To: 'Eggemeyer, Jerome C.'; Hartwig, Dennis D Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -AGAIN Jerome, Thanks for the additional information. Tom Page 1 of 3 From: Eggemeyer, Jerome C. [mailto:]erome.C.Eggemeyer@conocophillips.com] Sent: Friday, February 13, 2009 3:33 PM To: Hartwig, Dennis D; Maunder, Thomas E (DOA) Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Tam, Definitely some complex completions and a hero's effort on getting them in the ground. To add one point to what dennis already said; we usually flow the mud out of the well through the slotted liner (no problem with damage or plugging since there is a lot of area). when running the resinject it is impassible to flow the mud back because it will certainly plug the tiny nozzles and therefore we have to circulate the well to a fluid that does not have to be flowed back. Lots of fluids to clean things ups as dennis mentions and the ultimate issue is that we can not flow the mud back prior to starting injection into these completions. thanks, Jerome From: Hartwig, Dennis D Sent: Friday, February 13, 2009 11:28 AM To: 'Maunder, Thomas E (DOA)' Cc: Alvord, Chip; Eggemeyer, Jerome C. Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Tom, As far as the 13-3/8 hangup issues, the initial. attempt to get the 13-3f8 down. was unsuccessful so after a cleanout, w=e went back. in with a different shoe. The new shoe, a silver bullet aluminum shoe, offers a profile which is more conducive to overcoming ledges etc. After drilling the intermediate hole we spent several days getting the BHA hung up shallow inside of the 13-3/8" pipe. ~?Ve finally got the BHA out of the hole and. made a cleanout run to bottom with a reverse circulation junk basket and recovered several large pieces of aluminum which is the likely cause of our problems. Alpine runs smaller sizes of the silver bullet as a matter of course and has never had any issues_ Our issue may have resulted from drilling out v*~th a rock. bit. as apposed to a PDC as well. as setting the 13- 3/8 slightly off bottom. The caustic and acid washes were a preface to running the ResInject screens. Integral to the screens are very small nozzles (2.Smm diameter) which we were very worried. about plugging. The caustic and acid were performed to remove any easing.. scale which might plug off the nozzles. during liner installation. ~n ~zi~nn9 Page 2 of 3 The dual completions were the first in the world to employ this particular level s junction. I would be happy to stop over sometime and describe in more detail the basis of design and detailed completion construction. Thanks...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - ATO-1592 Office :907-265-6862 Cell :907-575-7109 Fax :907-265-].535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 13, 2009 10:51 AM To: Hartwig, Dennis D Cc: Alvord, Chip; Eggemeyer, Jerome C. Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) -- AGAIN Dennis, et al, Further to my earlier message, a couple of comments/observations. WOW, you certainly got practice tripping lots of different tubulars!! Any determination what was the hold-up in the 13-3/8"? Alignment appeared to be the issue with the tubing. I note that a comment is included that the 9-5/8" casing/cementing job was planned with slips. I think this is a good move due to the uncertainty of successfully landing a mandrel hanger when the focus is improving the cement job as much as possible with pipe movement. One of my pet peeves is when I see "emergency slips". Slips are slips and their purpose is to allow the pipe to be properly set in tension regardless of where it is ultimately "set". I think that the focus can sometimes be too much on landing the hanger and not on promoting the best cement job possible. After the OSD, caustic and acid washes of the 9-5/8° casing are performed. What was the purpose here? I have seen such operations in other wells, but usually in advance of gravel packs and such. Thanks in advance, Tom From: Maunder, Thomas E (DOA) Sent: Friday, February 13, 2009 10:33 AM To: 'Hartwig, Dennis D'; Allsup-Drake, Sharon K Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) Not a problem. I will make the change. From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Friday, February 13, 2009 10:32 AM To: Maunder, Thomas E (DOA); Allsup-Drake, Sharon K Subject: RE: 3K-108 (208-130) and 3K-108L1 (208-133) Tom, You are correct, on the 407, block 23 should be checked to OPEN, since the screen intervals are open to injection. I apologize for the oversight. Regards...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhiltips Alaska - ATO-1592 Offiee :907-265-6862 Cell :907-575-7 (09 Fax :907-265-1535 Page 3 of 3 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, February 13, 2009 9:27 AM To: Hartwig, Dennis D; Allsup-Drake, Sharon K Subject: 3K-108 (208-130) and 3K-108L1 (208-133) Sharon and Dennis, I am reviewing the 407s submitted for these wells. On the 407, block 23 (perforation section), it is checked that these intervals are NOT open to production or injection. I don't believe that this is correct. The well may not be in operation, however the intervals are open. Am I missing something here? I think for "not open" to apply that some sort of plug needs to be in place. I look forward to your reply. Tom Maunder, PE AOGCC 2/13/~(l09 • ~' E~ I+.I;C:?ANIC AL INTEGRITY R=.PORT " BUD D._:I : - ~ ~'"~ _- OPER ~ FIELD ~.~;~.~ ~~Zy ~~ ~~.- ~04sL1 ~ ~ ~~0~ ;: LLL NtJME ER ~j ~-- \ ~~ - \.b 2S L~-~- ._=G rS~I~~I. ~ W~i.l`4~sa~c VS ~ ~n ~ LL DAT ~_ TD : '~~1~iSl~ .?~.. 3C~5~ TVD ; ?BTD : `31~ ? ID ~S \ TVD Casing ~~~~ Shoe. ~~~ MD ~~S ~~ LV. ~1~- ?~ ~~ =4"i ~_:,e_ : SC~222~11 Shoe: '~ ~~ _ ~ o ~ ~ 3~ ~~ P acicer ~a0 ~ '.-D _o1e S_te ~ ~ and ~".~'C"r'._A?~=C~`?, INTEGi~1TY - PART # rnru~ ~s ?ress Test: Cor~ents : T'J7i ~e~ at $CRC.~r~SA~~ l~ v~- r : . ; Perfs 'l~y~_ to ~~\S~ '~a c~4s ~~~~3 ? 15 min ~ 0 min i , '.~'CHP?~T1C< i , 1NTEGR?'T~ - PART # 2 ~--~rc~1'1 ~b\ Cement Voles :• ~.mt. Llner Cs? 5~~s~ !7V ~l~ tsoo' ~ 3D~~xS `~~ ~b~ S Cmt -rol to cover oers _ :eoretical TOC ~ 3O2a1cS ""SO ~~~Ccrc's To C 30~~ ~~~h~~L ~ ~t30~ ~.s~~~c ~. ~~c~~ Cement Bond Log (Yes or No) l~°3 In AOGCC File ~~_ CBL Evaluation, tone above perfs ~~p ~ ~c-~`~Cr SC-~~h~ Rrc~~' l Production Log: Tppe CON~LJSIONS: ?arL Y 1 ?art t2: M`~ ~S ~~ ~C~ Evaluation Maunder, Thomas E (DOA) From: CPF3 Prod Engrs [n1223@conocophillips.com] Sent: Thursday, February 05, 2009 3:35 PM Yage 1 of 3 To: Maunder, Thomas E (DOA); CPF3 DS Lead Techs Cc: CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Pr Subject: RE: "NE West Sak Injector 3K-108 (208-130)". ~ ®~_,~~ o~-~~`~ ~,, Tom, ~ Sorry for any confusion. It was indeed the pilots for both strings; 3K-108 LPP and HPP & 3K-108L1 LPP and HPP that were taken out and then put back into service. You are correct that both the 3k103 and 3k-108 are dual tubing string injectors. Therefore, each string has a HPP and LPP. We will try to be more specific and use the nomenclature as you have described below. Please calf or message if you have any questions or need more information. Thank you G~SC~ ~~~- \ r ~ .Iohn ~onctfo f Tim Nelson ~~~ 1 1, Co CanocoPhillips Alaska; Inc. CPF3 Production Engineers Email: N1223@conocophiliips.com Ph. (907) 659-7811 Fax. (907) 659-7806 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 05, 2009 12:00 PM To: CPF3 DS Lead Techs Cc: CPF3 Prod Engrs; CPF3 Prod Supt; Regg, James B (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I have had a chance to review the files. It appears that there are two individual tubing strings here, one for 3K- 108 and the other for 3K-108L1. Were the low pressure pilots defeated for both strings? If that is the case, the messages should have included the information for both strings/valves. This could have also been the case for 3K-103 and 3K-103L1. If you or one of the engineers could provide the information for the pilots that were defeated and then placed back in service for each string, it will be appreciated. Just reply to this message. Equipping these wells with dual strings makes the reporting a bit more complicated when the pilots are defeated. It seems appropriate where dual strings are involved to make sure that the specific string with the defeated pilot is clearly identified (-108 or 108L1) or send separate messages for each string. Call or message with any questions. I look forward to your reply. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, February 03, 2009 4:58 PM 2/13/2009 Page 2 of 3 To: 'CPF3 DS Lead Techs' Cc: CPF3 Prod Engrs; CPF3 Prod Supt Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Wayne, et al, I will have to check the files tomorrow. It appears I have messages regarding both 3K-108 and 3K-103. Tom Maunder, PE AOGCC From: CPF3 DS Lead Techs [mailto:n1105@conocophillips.com] Sent: Tuesday, February 03, 2009 4:41 PM To: Maunder, Thomas E (DOA) Cc: CPF3 Prod Engrs; CPF3 Prod Supt; CPF3 DS Lead Techs Subject: RE: "NE West Sak Injector 3K-108 (208-130)". Tom, 1 hope I am sending this to the correct person. As we don't currently have one of our P.E.'s on the slope, 3K-108 LPP's where satisfied and put back in service 2/03!09 a~ 16:30 If I need to do something else please iet me know. Thank you very much. Wayne Griebei CPF3 DS Lead From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 03, 2009 3:02 PM To: CPF3 Prod Engrs; Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: RE: Tim, When you send a message such as this, please include a title. Specifically for a well with a defeated safety valve the title should in this case read "NE West Sak ]njector 3K-108 (208-130}". Thanks in advance. Call or message with any questions. Tom Maunder, PE From: CPF3 Prod Engrs [mailto:nl223@conocophillips.com] Sent: Monday, February 02, 2009 6:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Prod Engr Specialist; Targac, Gary; CPF3 Prod Supt; Allsup-Drake, Sharon K; CPF3 DS Lead Techs; NSK Problem Well Supv Subject: Tom /Jim, This email is to notify the AOGCC that the North East West Sak (NEWS) Injector 3K-108 Low Pressure Pilots (LPP) are defeated as of 2/2/2009. This is in accordance with "Administrative Approval No. CO 4066.001" The LPP and SSV (Surface Safety Valve) have been tagged and recorded on the "Facility Defeated Safety Device ~~ og. The 3K-108 was brought on injection today, 2/02/2009. It is anticipated that injection pressure will increase above 250 psi within a few days. Current injection rate is 640 BWPD at 200 psi injection pressure in the B lateral and 430 BWPD at 235 psi injection pressure in the D lateral. 2/13/2009 Page 3 of 3 The AOGCC will be notified when the injection pressure has increased above 250 psi and the LPP functions are returned to normal. Tim Nelson /John Condio ConocoPhillips Alaska, Inc. CPF3 Production Engineers Email: N1223@conocophillips.com Ph. (907) 659-7871 Fax. (907) 659-7806 2/13/2009 3K-103 - Doyon 15 -Current ~us • Page 1 of 4 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 05, 2009 11:50 AM To: 'Sale, Julie J' Cc: 'Wharton, Paul K'; 'Downey, Allison'; 'Spenceley, Neil'; Dennis Hartwig Subject: RE: 3K-103 (208-115), 3K-103L1 (208-116), 3K-108 (208-130) and 3k-108L1 (208-133) Julie, et al, I was checking files over here regarding these wells. It appears that 3K-108 and -10~L1 are also equipped with individual tubing strings. If this is correct, separate volumes should be reported for each string similar to 3K-103 and -103L1. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC From: Maunder, Thomas E (DOA) Sent: Tuesday, January 27, 2009 1:37 PM To: Sale, Julie J Ce: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria; Davies, Stephen F (DOA); Roby, David S (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) and 3K-103L1 (208-116) Yes, Julie that is correct. Call or message with any questions. Tom Maunder, PE AOGCC From: Sale, Julie) [mailto:Julie.J.Sale@conocophillips.com] Sent: Tuesday, January 27, 2009 1:26 PM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Spenceley, Neil; Machal, Gloria Subject: RE: 3K-103 (208-115) Thomas, Does this give you the information you are needing from ConocoPhillips? Proposed Reporting Method On the AOGCC Monthly Injection Report (10-406), we typically report well level injection for multi-laterals because all injection goes through one meter at the surface. In this case we will have separate surface injection meters for each string so we have the ability to report at the wellbore/string level. Julie J. Sale ConocaPhillips Supervisor Revenue and Regulatory Upstream Accounting Alaska 930 G POB 0 Bartlesville, OK 74004 918-bbl-3523 (w} /918-914-3b69 (c} 918-bbl-1702 (tax) b20-778-490b (personal-cell} julie.j.sale@conocophillips.com 2/13/2009 3K-103 - Doyon 15 -Current ~us • Page 2 of 4 From: Spenceley, Neil Sent: Tuesday, January 27, 2009 11:31 AM To: Maunder, Thomas E (DOA) Cc: Wharton, Paul K; Downey, Allison; Sale, Julie J Subject: RE: 3K-103 (208-115) Tom, As per our conversation we will report the 3K injection volumes as follows; The well will be split in two {3K-103 and 3K-103L1) to e reported as separate rate streams injecting into the West Sak oil pool. Please let me know if you would like to see it reported differently. Thanks. Neil From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 27, 2009 8:14 AM To: Spenceley, Neil Subject: FW: 3K-103 (208-115) Here is that message trail. From: Downey, Allison [mailto:Allison.Downey@ConocoPhillips.com] Sent: Tuesday, January 13, 2009 8:47 AM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA); Hartwig, Dennis D; Sale, Julie J Subject: RE: 3K-103 (208-115) Torn. I am working the 3K-103 reporting issue with the Revenue Accounting group. vVe will have an answer for you soon on haw the dual string injection will be reported. The well is not in service yet but is expected to start injection this week. Allison Allison Downey C31S Technical Data Management ConocoPhillips Alaska, inc. 907-263-4299 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 3:00 PM To: Hartwig, Dennis D; Downey, Allison 2/13/2009 3K-103 - Doyon 15 -Current status ~ Page 3 of 4 Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Dennis, Thanks. We will look forward to Allison's contact. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12, 2009 2:56 PM To: Maunder, Thomas E (DOA) Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Tam., I have forwarded on your questions to Allison Downey (~Ilison._cloi~°n~:~ ~u~:co~aocopilaps.con~,). Allison .... has been tasked with setting up A"I'DB to store the lateral specific injection data separately as opposed to commingled. I left a phone message for Allison and will continue to follow up until. your questions are answered. Regards...Denniis Dennis Hartwig :Drilling Engineer Ureater Kuparuk Area Cc.~nocoPl~illips Alaska - A"i'0-1592 Office :907-265-6862 Cell :907-575-7109 1~'ax :907-26.5-1535 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, January 12, 2009 1:40 PM To: Hartwig, Dennis D Cc: Roby, David S (DOA); Davies, Stephen F (DOA); McMains, Stephen E (DOA) Subject: RE: 3K-103 (208-115) Thanks Dennis. Aiso, do you know if the well has been placed in operation? As we have looked into the particulars for this well several questions regarding the injection reporting have come up. To our knowledge, this is the first dual tubing, multi-lateral well into the WS and likely on the slope. I believe there are a few other dual tubing single penetration WS wells. In mast cases, neither production nor injection is "credited" to laterals since everything is commingled in the wellbore. That is not the case here where the separate volumes in each string can be determined. I am not sure who would be the one to comment on how the injeotion volumes would be reported, however it appears that is a question that should be asked. I'd appreciate if you could forward this portion of the message on for comment. Cali or message with any questions. Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conocophillips.com] Sent: Monday, January 12, 2009 12:42 PM 2/13/2009 3K-103 - Doyon 15 -Current s ~ Page 4 of 4 To: Maunder, Thomas E (DOA) Subject: RE: 3K-103 (208-115) Tom, I will look into these issues and get back to you A~AP...Dennis Dennis Hartwig Drilling Engineer Greater Kuparuk Area ConocoPhillips Alaska - A1'0-1592 Office :907-265-6862 Cell :907-575-7109 Fax. :907-26~-1~.i5 2/13/2009 ~~ RE~EI~Ep STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~lAN 2 6 2009 WELL COMPLETION OR RECOMPLETION REPO~~st~~~_ ,. 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ~ / WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: >'~ChOf • Development ^~ ~~'oratory ^ Service ~ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: December 27, 2008 12. Permit to Drill Number: 208-133 / ' 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 4, 2008 r 13. API Number: 50-029-23395-60 4a. Location of Well (Governmental Section): Surface: 1472' FSL, 319' FWL, Sec. 35, T13N, R9E, UM 7. Date TD Reached: December 7, 2008 14. Well Name and Number: 3K-108L1 • Top of Productive Horizon: 301' FNL, 782' FEL, Sec. 35, T13N, R9E, UM 8. KB (ft above MSL): 74.1' RKB Ground (ft MSL): 33.4' AMSL 15. Field/Pool(s): Kuparuk River Field ' Total Depth: 1070' FNL, 238' FEL, Sec. 36, T13N, R9E, UM 9. Plug Back Depth (MD + ND): 11471' MD / 3559' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 • y- 6008466 Zone- 4 10. Total Depth (MD + ND): 13189' MD / 3630' TVD 16. Property Designation: ALK 25519 TPI: x- 533467 y- 6011990 Zone- 4 Total Depth: x- 539295 ~ y- 6011250. .Zone- 4 11. SSSV Depth (MD + ND): nipple @ 538' MD / 537' ND 17. Land Use Permit: 2555 18. Directional Survey: Yes ^~ No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): approx. 1654' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): top of window @ 7280' • /-'{p GR/RES, USIT .3'~$3~7'vd t•2t•~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 154# 43' 160' 43' 160' 42" 436 sx AS I 13.375" 68# L-80 43' 3070' 43' 2223' 16" 702 sx AS Lite, 225 sx AS II 9.625" 40# L-80 40' 7280' 40' 3483' 12.25" 540 sx DeepCRETE 3.5" 9.2# L-80 7268' 11473' 3481' 3560' 6.75" screens /blank 23. Open to production or injection? Yes No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 3.5" 7315' 7201' 7401'-7432' MD 3501'-3504' ND 7894'-7925' MD 3526'-3526' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8544'-8576' MD 3520'- 3521' ND DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9195'-9226' MD 3527'-3527' ND na 9689'-9720' MD 3541'-3543' ND 10620'-10651' MD 3555'-3556' TV 11303'-11334' MD 3554'-3557' TV 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting to be brought on-line Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes ^ No ~ • If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. .. ~_,.:4.x. NONE • f2 Z'7 a$8 + ,i r°Ei) s ~i Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ,~~ /• 2(e •~ ~a~i3 '~• f'~c~~ 28. GEOLOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ^.r No . If yes, list intervals and formations tested, Permafrost -Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1891' (est) 1654' (est) needed, and submit detailed test information per 20 AAC 25.071. West Sak D 7280' 3483' Ugnu C 4600' 2731' Ugnu B 5878' 3136' Ugnu A 6226' 3259' N sand 6760' 3400' K-13 6882' - 3422' N/A Formation at total depth: West Sak D ` 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 /-Zt-Zook Printed Name hi C o Alvord Title: Alaska Drillino Manager ~ ~ Z3 ~ 01 //~~ / 1 ~ Signature /wL t. Wl~ Phone ~~~ `~ Z' Date INSTRUCTIONS Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~~ KUP ~ 3K-108L1 ®ncxnPll~l=~p5 { \,i WeII Attributes _ _ __ _ 4Max Mgle & MD ITD Wellbore APUU WI Field Name Well Status Protl/Inj Type Inc! (°) IMD (ftK6) Act Btm (ftK6) ~'i`->+cn'Ire' ~ 500292339560 (WEST SAK INJ SWI 193.58 8,16086 13,106.0 _ (ppm) (Date Annotation IEnd Date KB-Grd (H) C ent H2S "' I 12/27/2008 SS otat,onPPLE IDe _ I. (Last WO' I 0.34 iRig R I e Date Wall COnfg MULTIPLEL ST~RAL$'c 3AK~a81L1. L3 /uu8 O4q:~S, - - - - -- L A pth (ftKB) IEnd Date (Annotation End Date I Last Tag: Rev Reason: NEW WELL 12/31/2005 RANGER. ,3 ICasin Strin s - -- rCasing Description String 0... (String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd L D Lateral tie hack & 3 1/2 ~' 2992 7.268.4 7,351.6 3.498.4 9.20 L-80 IBT HANGER, 2s - RAM hanger I > Casing Description',String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) _. String Wt... String ... String Top Thrd '~D-SAND LINER ~ 3 1/2 2.992 7,370.7 11,473.0 3,559] 9.20 _ L 80._ SLHT Tubing Strings - - - (Tubing Description String 0... String ID .Top (ftK6) Set Depth (f... Set Depth (ND) ... I Str ng Wt... Btrmg String Top Thrd D-SAND TUBING 3 1/2 2.920 13.2 7,290.9 3 485.0 9.20 ~ L-80 IBTM Coin letion Details Top Depth ' (ND) ToP Inc! Top (kK8) I (ftK6) (°) Item Description Comment ID (in) coNDUCroR, _ _ 13.21 13.2 -90.82 HANGER Vetco Gray Dual 13-3/S" x 3-1/2" x 3-1/2" w/ 3.725" MCA Top Connection 3.500 az-1sz -- 514.7 514.7 -79.02 NIPPLE 3-1/2" Camco "DS" Nipple w/ 2.875" Profile (EUE 8rd) (4.5" O.D.) 2.875 NIPPLE, 515- - -- 2,4595 -555.1 -32.54 SLEEVE Baker 3-1 /2" CMD Slitling Sleeve w/ 2.813" Profle (TC-II BxP) (4.29" OD) 2.813 7,176.3 3,461.2 77.76 Packer -Dual (Baker "GT" Dual Packer Mandrel (3-1/2" NU tOrd Box z Pin) 2.920 7,177.4 3,461.5 77.78 Packer -Dual ;Baker 9-6l8" x 3-112" "GT" Retrievable Dual Packer (40K Shear Release) 2.920 wPPLE, 526 ---- 7.181.0 3,462.4 77.87 Packer -Dual 116aker "GT" Dual Packer Mandrel (3-1/2" NU 10rtl Boz z Pin) 2.920 7,207.1 3 468.6 78 48 NIPPLE 3-112" Camco "D" Nipple w/2.75" No-Go Profile (EUE Srd Box x Pin) 2.750 (~ 7,215.5 3,470.5 78.68 Extension Jt Baker 3.38" "DSM" Extension Jt (3.220" SSDS Boz z Pln) 2.720 7,245.4 3,476.8 79.39, Dual Seal Baker 3.38" "DSM" Extension Jt Mandrel (3.220" SSDS Box x Pin) 2.700 I - _ __ 7.246.8 3 477.1 79 421, Dual Seal Baker 7" x 9-518" Ram Dual Seal Module (Below collet) 2.700 7,279.1 3,48301 80.18~SEAL ASSY Baker Shroutled Seal Assembly ~ 3.000 SLEEVE, 2,489 -..... '~'^-"^'°-- - Pertorations '. -. snot _.... ._. - - __... Top (TVD) Btm (fVD) Dens GAS LIFT, Top (ftK6) Btm (ftK6) (ftK6) (ftK6) ', Zone Date (sh-. Type COmmerd 2.506 - 7 400J 7,432.0 3,501.0 3,504.4 WS D, 3K-1O8L1 12/13/2008 99.0 Screen Resinject Reslink Screen 7,893.8 7,925.2 3,525.5 3,526.3 WS D, 3K-108L7 12/13/2008 99 0 Screen Resinject Reslink Screen 8,544.2 8,575.6 3,520.0 3,520.5 WS D, 3K-108L7 12/13/2008 99.0 Screen Resinject Reslink Screen 9,195.0 9,226.4 3,526.8 3,527.2 WS D, 3K-108L1 12/13/2008 99.0 Screen Resinject Reslink Screen suRFACE, 9,688-9 9 720.3 3 540.5 3,542.7 WS D, 3K-108L1 12!1312008 99.OIScreen Resinject Reslink Screen 43-3.070 j 10,619.6', 10,650 9 3,555.0 3,556.3 WS D, 3K-108L1 12/132008 99 OScreen Resinject Reslink Screen _.- -. 11,302.61 11,334.0 3,554.2 3,556.6 WS D, 3K-108L1 12/13/2008 99.OIScreen Resinject Reslink Screen w` - - Fearer Dval Notes• Gene 7 176 Annotation Patlcer Dual I ~ -- Packer o~ai ~ lv3vzoose ral 8 Safety ~' ~NOIE MULTI-LA FERAL WELL wIDUAL TUBING STRINGS ' ' 7161 \ q.. 12/31/2008 (NOTE View schematic w/Alaska Schematic9.0 Packer Dual - - - - 7186 rx r' Packer Dual - ],189 Parker - Duai, 7,192 \ NIPPLE. 7.207 - NIPPLE, ],2141 - EX[ension Jt, 7,216 Dual Seal, I 7.245 Dual seal, I _ _ 7.253 ~I Dual Seal, _ 7,247 Oual Seal, 7.258 SEAL ASSY,_ 7.279 Seal Bore Divener,- - ~_ 7,273-].379 may' D Lateral ee back & RAM hanger 7,268-7.382 Sheen, 7,40SCreen2 7,894~7,925- NTERMEDIATE._ _ - 40-8,016 jMandrel Details - - - - (TVD) Inc! OD Valve Latch Size TRO R n 1 2,505 9 Top Depth Top I P A _-__ Stn To ftK6 (ftK6) (°) Make Model (in) Serv Type Type I Gn) (ps) Run Dat C mm... 2,037.0 65.78 CAMCO KBG-2-9 i Gas Llft DMY DCK-3 0 0.0' 12/22/2008 scre 8,544-8,576 Screen. 9,195-9,226 Screen, 9.689-9,720 Scree 10,620-10,651 Sheen. _- 11,303-11,334 D-SAND LINER, 7,371-11,473 TD (3K-108L I ), 13,106 ,r, CanacvP~illips 539'MD-2.875"DS Nipple 2008 West Sak Dual Injector System 540'MD-2.875"DSNipple with Level 5 Rotating self-Aligning Multilateral (RAMTM) System 2513' MD- CMD Slitling Sleeve. 3~N' x T.813" BX Prof le `~ West Sak ~` 2518' MD- GLM, Camco, 3 Y"x 1" KBG2.9 13-318" Casing Shoe - ~°,-. 3K~'' O$ 3070' MD, 2223' TVD ~ Y~''c (70.5 deg) 7198' MD-Antl-Rotation Clamp v Dual Tubing Strings 7222' MD- Tubing Swivel Sub 3-'/:" 9.3# IBTM wISCC L-80, 2.992" Iq 2.867" Drat /0®, ~, /7231' MD- 2.750" D Nipple 7270 MD 3 /. x 3 /: z 9 SIB Dual Seal Module for RAM Hanger 7268' MD~ 7" X 9-5/B" F2AM Hanger Eauiament Specifications 7" X 9.518" RAM Junction Malnbore Drift: 3.68" Lateral Drift'. 5.80" RAM Hanger/Seal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 3-%" x 3'/" 9.518" Dual Seal Module O5M OD: 7.62" Lateral Seal Assembly OD: 3.75" Lateral lD' 2.69" Malnbore Seal Stinger OD: 3.08" Malnbore ID: 2.69" 79' MD- 5-'/." Bowen Overshot 5.75" OD 7743' MD~ MLHR Production Anchor MD- Seal Assembly a.7s'• seal oD 3.875" ID ^.'i~ ~~~ Baker Oil ToDls As Completed TD 13189' MD, 3630' ND Liner Shoe 11473 MD, 3560' ND (90 deg) 'B' Sand Lateral 3~/:" 9.3M Liner with Hydril 563 antl SLHT connections 9-518" Casing Shoe, 40.0#, L80 BTC 8016' MD, 3575' ND (88 deg) TD 13180' MD, 3684' ND i (87 deg) 13150' MD, 3682' TVD ~, 7201' MD- 3-'/:" z 9.5/8" GT Dual Packer 7226' MD- 2.813" DS Nlppla 7273' MD- 4 `/:" X 9-SIB" RAM Seal Bore Diverter (BBD) for Dual Seal Module 4 Y" 12.611 IBTM &Hydril 521 Tut D-Sand Casing Exit 7280' MD, 3483' ND (6o deg) 'D' Sand Lateral 3~h" 9.371 Liner wnh SLHT oonnecuons 7335' M D- 7" % 9.518" MI: Liner Hanger Packer 7382' MD~ Sealbore 4.75" ID ,~ I1 u • ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3K Pad 3K-108 L1 Permit to Drill: 208-1330 API: 50-029-23395-60 ~, to w ?• r~..,-. z~ ~ ..> 91. . . Definitive Survey Report 12 January, 2009 ~.~ :rA'~cn: ~~'J ~. ,.: Sperry Drilling Servia~es ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3K Pad Wel I: 3K-108 Wellbore: 3K-108 L1 Design: 3K-108 L1 Local Co-ordinate Reference: We113K-108 TVD Reference: 3K-108 @ 74.14ft (Doyon 15) MD Reference: 3K-108 @ 74.14ft (Doyon 15) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDM Alaska Prod v16 roject Kuparuk River Unit lap System: US State Plane 1927 (F~cact solution) System Datum: Mean Sea Level eo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point lap Zone: Alaska Zone 04 Using geodetic scale factor tell 3K-108 tell Position +N/-S 0.00 ft Northing: 6,008,466.47ft Latitude: 70° 26' 3.152 +E/-W 0.00 ft Easting: 529,306.29 ft Longitude: 149° 45' 39.922 \ osition Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.40ft -- - W®Abore 3K-108 L1 - - - -- I Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 12/20/2008 22.43 80.90 57.653 Design 3K-108L1 - ~ ~~ Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 7,271.04 Vertical Secti on: Depth From (TVD) +W-S +E/-W Direction (ft) (ft) (ft) (°) 40.74 0.00 0.00 50.00 Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 90.00 461.00 3K-108 Gyro (3K-108) CB-GYRU-SS Camera based gyro single shot 9/5/2008 12: 498.34 7,271.04 3K-108 MWD+SAG+CA+IIFR+MS (3K-1 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/5/2008 12: 7,280.00 13,106.97 3K-108L1 MWD (3K-108 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/4/2008 1; Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ftj (ft) (°1100') (ft) Survey Tool Name 40.74 O.GO 0.00 40.74 -33.40 0.00 0.00 6,008,466.47 529,306.29 0.00 0.00 UNDEFINED 90.00 0.50 69.28 90.00 15.86 0.08 0.20 6,008,466.55 529,306.49 1.02 0.20 CB-GYRO-SS (1) 120.00 0.49 56.48 120.00 45.86 0.19 0.43 6,008,466.67 529,306.72 0.37 0.43 CB-GYRO-SS (1) 135.00 0.51 58.10 135.00 60.86 0.26 0.54 6,008,466.74 529,306.83 0.16 0.54 CB-GYRO-SS (1) 180.00 0.67 65.00 180.00 105.86 0.48 0.95 6,008,466.96 529,307.23 0.39 0.95 CB-GYRO-SS (1) 225.00 0.81 81.39 224.99 150.85 0.64 1.50 6,008,467.12 529,307.79 0.56 1.50 CB-GYRO-SS (1) 241.00 0.86 69.38 240.99 166.85 0.70 1.73 6,008,467.18 529,308.01 1.14 1.73 CB-GYRO-SS (1) 286.00 1.05 76.74 285.98 211.84 0.91 2.44 6,008,467.40 529,308.73 0.50 2.44 CB-GYRO-SS (1) 331.00 1:54 58.82 330.97 256.83 1.32 3.36 6,008,467.81 529,309.64 1.40 3.36 CB-GYRO-SS (1) 365.00 2.47 64.71 364.95 290.81 1.87 4.42 6,008,468.36 529,310.70 2.80 4.42 CB-GYRO-SS (1) ~ 376.00 2.30 64.70 375.94 301.80 2.07 4.83 6,008,468.56 529,311.11 1.55 4.83 CB-GYRO-SS (1) 421.00 3.09 63.02 420.89 346.75 3.00 6.73 6,008,469.50 529,313.00 1.76 6.73 CB-GYRO-SS (1) 1/12/2009 1:59:56PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 3K Pad We I I: 3K-108 Wellbore: 3K-108 L1 Design: 3K-108 L1 Survey MD Inc Azi ND NDSS +NI-S (ft) (°) (°1 lftl Ift) Ift) 461.00 4.40 63.55 460.61 386.67 4.17 498.34 5.03 59.43 498.02 423.88 5.64 543.40 5.81 58.45 542.88 468.74 7.84 594.48 6.48 55.84 593.66 519.52 10.81 618.07 5.99 53.00 617.11 542.97 12.30 690.23 7.28 50.12 688.79 614.65 17.50 785.50 11.15 46.87 782.81 708.67 27.67 879.52 15.82 45.83 874.22 800.08 42.82 974.27 20.38 46.15 1,069.98 24.05 47.98 1,165.56 25.82 45.79 1,260.77 29.71 44.29 1,355.84 34.12 45.07 1,451.46 38.20 44.94 1,545.48 37.94 44.14 1,641.99 42.58 45.12 1,737.16 45.50 41.90 1,831.90 48.60 40.30 1,926.57 48.19 40.70 2,021.64 52.75 39.75 2,116.77 52.37 38.37 2,212.61 55.88 38.23 2,307.20 59.36 39.76 2,402.58 63.82 2,497.60 68.41 2,546.64 70.63 2,593.00 72.43 2,687.05 71.81 2,782.60 70.41 2,878.24 68.62 2,973.33 71.61 3,040.17 70.46 3,083.70 69.11 3,178.37 68.62 3,274.37 69.68 3,368.98 72.74 3,464.61 70.97 3,559.43 69.80 3,654.27 69.64 3,749.28 68.83 41.21 42.31 41.85 42.00 40.58 964.25 1,052.84 1,139.51 1,223.75 1,304.43 1,381.61 1,455.63 1,529.26 1,597.67 1,662.22 1,725.08 1,785.57 1,843.41 1,899.56 1,950.21 1,995.58 2,034.05 2,051.21 2,065.89 2,094.77 40.22 2,125.70 39.67 2,159.17 39.26 2,191.51 39.95 2,213.23 40.36 2,228.28 41.05 2,262.41 39.57 2,296.58 40.78 2,327.05 41.32 2,356.83 41.08 2,388.66 40.63 2,427.53 42.38 2,455.22 890.11 63.26 978.70 87.87 1,065.37 115.43 1,149.61 146.79 1,230.29 182.50 1,307.47 222.38 1,381.49 263.70 1,455.12 308.06 1,523.53 356.06 1,588.08 408.32 1,650.94 462.15 1,711.43 518.13 1,769.27 576.78 1,825.42 637.71 1,876.07 699.77 1,921.44 1,959.91 1,977.07 1,991.75 2,020.63 2,051.56 2,085.03 2,117.37 2,139.09 2,154.14 2,188.27 2,222.44 2,252.91 2,282.69 2,314.52 763.55 828.33 862.42 895.14 962.39 1,031.23 1,099.91 1,168.94 1,217.64 1,248.86 1,315.80 1,384.21 1,452.63 1,521.16 1,588.37 2,347.39 2,381.08 1,655.65 1,722.18 "Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +EI-W Northing Ift) (ft) 9.06 6,008,470.68 11.75 6,008,472.16 15.40 6,008,474.38 19.99 6,008,477.36 22.07 6,008,478.86 28.59 6,008,484.08 39.95 6,008,494.30 55.78 6,008,509.51 76.95 6,008,530.03 103.47 6,008,554.74 132.86 6,008,582.41 164.21 6,008,613.89 199.56 6,008,649.74 239.44 6,008,689.77 280.11 6,008,731.25 323.93 6,008,775.77 369.43 6,008,823.94 414.99 6,008,876.38 460.96 6,008,930.38 508.28 6,008,986.54 555.88 6,009,045.37 604.00 6,009,106.49 654.27 6,009,168.74 708.74 6,009,232.72 766.60 6,009,297.72 797.38 6,009,331.94 826.76 6,009,364.76 885.83 6,009,432.24 944.42 6,009,501.30 1,001.94 6,009,570.20 1,058.77 6,009,639.45 1,099.06 6,009,688.30 1,125.40 6,009,719.62 1,182.99 6,009,786.78 1,241.02 6,009,855.41 1,298.80 6,009,924.05 1,358.48 6,009,992.81 1,417.31 6,010,060.24 1,475.50 6,010,127.75 1,534.37 6,010,194.50 • We113K-108 3K-108 @ 74.14ft (Doyon 15) 3K-108 @ 74.14ft (Doyon 15) True Minimum Curvature EDM Alaska Prod v16 - 1 Map Vertical Fasting DLS Section (ft) (°/100') (ft) Survey Tool Name 525,315.33 3.28 5.06 C8-GYRO-SS t1) 529,318.02 1.91 11.75 MWD+IFR-AK-CAZ-SC (2) 529,321.65 1.74 15.40 MWD+IFR-AK-CAZ-SC (2) 529,326.23 1.42 19.99 MWD+IFR-AK-CAZ-SC (2) 529,328.31 2.45 22.07 MWD+IFR-AK-CAZ-SC (2) 529,334.80 1.85 28.59 MWD+IFR-AK-CAZ-SC (2) 529,346.12 4.10 39.95 MWD+IFR-AK-CAZ-SC (2) 529,361.89 4.97 55.78 MWD+IFR-AK-CAZ-SC (2) ', 529,382.98 4.81 76.95 MWD+IFR-AK-CAZ-SC (2) 529,409.40 3.90 103.47 MWD+IFR-AK-CAZ-SC (2) 529,438.68 2.09 132.86 MWD+IFR-AK-CAZ-SC (2) 529,469.90 4.15 164.21 MWD+IFR-AK-CAZ-SC (2) 529,505.11 4.66 199.56 MWD+IFR-AK-CAZ-SC (2) 529,544.83 4.27 239.44 MWD+IFR-AK-CAZ-SC (2) 529,585.33 0.59 280.11 MWD+IFR-AK-CAZ-SC (2) 529,628.97 4.85 323.93 MWD+IFR-AK-CAZ-SC (2) 529,674.28 3.87 369.43 MWD+IFR-AK-CAZ-SC (2) 529,719.62 3.50 414.99 MWD+IFR-AK-CAZ-SC (2) 529,765.38 0.54 460.96 MWD+IFR-AK-CAZ-SC (2) 529,812.48 4.86 508.28 MWD+IFR-AK-CAZ-SC (2) 529,859.84 1.22 555.88 MWD+IFR-AK-CAZ-SC (2) 529,907.72 3.66 604.00 MWD+IFR-AK-CAZ-SC (2) 529,957.74 3.92 654.27 MWD+IFR-AK-CAZ-SC (2) 530,011.95 4.86 708.74 MWD+IFR-AK-CAZ-SC (2) 530,069.55 4.95 766.60 MWD+IFR-AK-CAZ-SC (2) 530,100.20 4.61 797.38 MWD+IFR-AK-CAZ-SC (2) 530,129.45 3.89 826.76 MWD+IFR-AK-CAZ-SC (2) 530,188.24 1.58 885.83 MWD+IFR-AK-CAZ-SC (2) 530,246.55 1.51 944.42 MWD+IFR-AK-CAZ-SC (2) 530,303.80 1.95 1,001.94 MWD+IFR-AK-CAZ-SC (2) 530,360.35 3.17 1,058.77 MWD+IFR-AK-CAZ-SC (2) 530,400.45 1.98 1,099.06 MWD+IFR-AK-CAZ-SC (2) 530,426.66 3.22 1,125.40 MWD+IFR-AK-CAZ-SC (2) 530,483.98 0.85 1,182.99 MWD+IFR-AK-CAZ-SC (2) 530,541.74 1.82 1,241.02 MWD+IFR-AK-CAZ-SC (2) 530,599.24 3.45 1,298.80 MWD+IFR-AK-CAZ-SC (2) 530,658.64 1.93 1,358.48 MWD+IFR-AK-CAZ-SC (2) 530,717.20 1.26 1,417.31 MWD+IFR-AK-CAZ-SC (2) 530,775.13 0.48 1,475.50 MWD+IFR-AK-CAZ-SC (2) 530,833.73 1.92 1,534.37 MWD+IFR-AK-CAZ-SC (2) 1/12/2009 1:59:56PM Page 3 COMPASS 2003. i6 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. .Project: Kuparuk River Unit Site: Kuparuk 3K Pad We I I: 3K-108 W®Ilbore: 3K-108 L1 Design: 3K-108 L1 Survey MD Inc Azi TVD TVDSS (ftl (°) 1°) (ft) (ft) 3,844.67 70.66 41.37 2,488.24 2,414.10 3,940.48 70.13 40.79 2,520.39 2,446.25 4,035.22 71.35 41.25 2,557.64 2,477.50 4,130.76 68.18 41.43 2,584.68 2,510.54 4,225.08 70.65 41.15 2,617.84 2,543.70 4,318.70 71.23 41.69 2,648.41 2,574.27 4,414.77 73.62 41.78 2,677.42 2,603.28 4,510.83 73.38 42.03 2,704.70 2,630.56 4,606.43 72.46 42.01 2,732.78 2,658.64 4,701.58 73.16 41.45 2,760.90 2,686.76 4,796.48 72.50 41.70 2,788.92 2,714.78 4,891.14 71.91 41.54 2,817.85 2,743.71 4,987.45 71.39 41.42 2,848.17 2,774.03 5,082.48 72.87 40.69 2,877.33 2,803.19 5,177.41 72.22 40.48 2,905.80 2,831.66 5,272.11 72.09 40.67 2,934.82 2,860.68 5,369.10 71.70 40.31 2,964.96 2,890.82 5,464.31 70.85 40.74 2,995.53 2,921.39 5,557.39 69.69 43.29 3,026.95 2,952.81 5,652.28 69.71 46.54 3,059.88 2,985.74 5,747.59 70.59 49.02 3,092.25 3,018.11 5,842.39 70.23 50.47 3,124.04 3,049.90 5,937.39 69.55 54.40 3,156.71 3,082.57 6,032.89 67.84 56.94 3,191.41 3,117.27 6,127.77 69.13 60.75 3,226.22 3,152.08 6,200.70 70.87 64.51 3,251.17 3,177.03 6,250.37 71.97 67.30 3,267.00 3,192.86 6,286.30 71.83 68.92 3,278.16 3,204.02 6,317.78 72.17 69.18 3,287.89 3,213.75 6,411.71 72.30 72.17 3,316.56 3,242.42 6,509.38 73.76 75.02 3,345.07 3,270.93 6,602.58 76.41 79.32 3,369.06 3,294.92 6,651.82 78.02 81.44 3,379.96 3,305.82 6,698.75 78.74 82.76 3,389.42 3,315.28 6,795.20 80.40 85.32 3,406.88 3,332.74 6,890.30 79.92 88.37 3,423.13 3,348.99 6,985.68 81.58 92.03 3,438.47 3,364.33 7,081.09 81.59 91.54 3,452.43 3,378.29 7,176.21 81.34 93.83 3,466.55 3,392.41 7,271.04 80.31 92.03 3,481.67 3,407.53 +N/-S (ft) 1, 788.82 1,856.85 1,924.33 1,991.62 2,057.96 2,124.32 2,192.66 2,261.21 2,329.10 2,396.93 2,464.76 2,532.14 2,600.63 2,668.83 2,737.60 2,806.07 2,876.18 2,944.72 3,009.81 3,072.83 3,133.06 3,190.77 3,245.15 3,295.33 3,340.97 3,372.46 3,391.67 3,404.41 3,415.11 3,444.71 3,471.08 3,491.05 3,499.07 3,505.39 3,515.23 3,520.39 3,520.05 3,517.11 3,512.71 3,507.92 Local Co-ordinate Reference: We113K-108 TVD Reference: 3K-108 @ 74.14ft (Doyon 15) Mi? Refere nce: 3K-1 08 @ 74.14ft (Doyon 15) North Reference: True Survey Cal culation Meth od: Minimum Curvature Database: EDM Alaska Prod v16 Map Map Vertical +EI-W Northing Easting DLS Section (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,594.10 6,010,261.36 530,893.19 2.16 1,594.10 MWD+IFR-Ah-GAZ-SC (2) 1,653.41 6,010,329.62 530,952.22 0.79 1,653.41 MWD+IFR-AK-CAZ-SC (2) 1,712.10 6,010,397.32 531,010.65 1.37 1,712.10 MWD+IFR-AK-CAZ-SC (2) 1,771.31 6,010,464.84 531,069.58 3.32 1,771.31 MWD+IFR-AK-CAZ-SC (2) 1,829.57 6,010,531.41 531,127.57 2.63 1,829.57 MWD+IFR-AK-CAZ-SC (2) 1,888.11 6,010,597.98 531,185.85 0.83 1,888.11 MWD+IFR-AK-CAZ-SC (2) 1,949.07 6,010,666.55 531,246.54 2.49 1,949.07 MWD+IFR-AK-CAZ-SC (2) 2,010.59 6,010,735.34 531,307.78 0.35 2,010.59 MWD+IFR-AK-CAZ-SC (2) 2,071.76 6,010,803.46 531,368.67 0.96 2,071.76 MWD+IFR-AK-CAZ-SC (2) 2,132.26 6,010,871.53 531,428.90 0.93 2,132.26 MWD+IFR-AK-CAZ-SC (2) 2,192.43 6,010,939.59 531,488.80 0.74 2,192.43 MWD+IFR-AK-CAZ-SC (2) 2,252.29 6,011,007.19 531,548.39 0.64 2,252.29 MWD+IFR-AK-CAZ-SC (2) 2,312.84 6,011,075.91 531,608.67 0.55 2,312.84 MWD+IFR-AK-CAZ-SC (2) 2,372.24 6,011,144.34 531,667.79 1.72 2,372.24 MWD+IFR-AK-CAZ-SC (2) 2,431.16 6,011,213.33 531,726.43 0.72 2,431.16 MWD+IFR-AK-CAZ-SC (2) 2,489.79 6,011,282.03 531,784.79 0.24 2,489.79 MWD+IFR-AK-CAZ-SC (2) 2,549.65 6,011,352.36 531,844.36 0.53 2,549.65 MWD+IFR-AK-CAZ-SC (2) 2,608.24 6,011,421.13 531,902.68 0.99 2,608.24 MWD+IFR-AK-CAZ-SC (2) 2,666.87 6,011,486.44 531,961.05 2.86 2,666.87 MWD+IFR-AK-CAZ-SC (2) 2,729.70 6,011,549.70 532,023.62 3.21 2,729.70 MWD+IFR-AK-CAZ-SC (2) 2,796.08 6,011,610.18 532,089.76 2.62 2,796.08 MWD+IFR-AK-CAZ-SC (2) 2,864.24 6,011,668.15 532,157.69 1.49 2,864.24 MWD+IFR-AK-CAZ-SC (2) 2,934.93 6,011,722.80 532,228.16 3.95 2,934.93 MWD+IFR-AK-CAZ-SC (2) 3,008.39 6,011,773.27 532,301.41 3.06 3,008.39 MWD+IFR-AK-CAZ-SC (2) 3,083.91 6,011,819.20 532,376.75 3.98 3,083.91 MWD+IFR-AK-CAZ-SC (2) 3,144.76 6,011,850.93 532,437.47 5.40 3,144.76 MWD+IFR-AK-CAZ-SC (2) 3,187.74 6,011,870.31 532,480.36 5.77 3,187.74 MWD+IFR-AK-CAZ-SC (2) 3,219.43 6,011,883.16 532,512.00 4.30 3,219.43 MWD+IFR-AK-CAZ-SC (2) 3,247.39 6,011,893.98 532,539.91 1.34 3,247.39 MWD+IFR-AK-CAZ-SC (2) 3,331.79 6,011,923.90 532,624.19 3.03 3,331.79 MWD+IFR-AK-CAZ-SC (2) 3,421.39 6,011,950.62 532,713.68 3.17 3,421.39 MWD+IFR-AK-CAZ-SC (2) 3,509.17 6,011,970.94 532,801.37 5.29 3,509.17 MWD+IFR-AK-CAZ-SC (2) 3,556.51 6,011,979.14 532,848.68 5.32 3,556.51 MWD+IFR-AK-CAZ-SC (2) 3,602.05 6,011,985.64 532,894.18 3.15 3,602.05 MWD+IFR-AK-CAZ-SC (2) 3,696.38 6,011,995.85 532,988.46 3.13 3,696.38 MWD+IFR-AK-CAZ-SC (2) 3,789.92 6,012,001.38 533,081.98 3.20 3,789.92 MWD+IFR-AK-CAZ-SC (2) 3,884.04 6,012,001.41 533,176.09 4.17 3,884.04 MWD+IFR-AK-CAZ-SC (2) 3,978.38 6,011,998.84 533,270.43 0.51 3,978.38 MWD+IFR-AK-CAZ-SC (2) 4,072.34 6,011,994.80 533,364.39 2.40 4,072.34 MWD+IFR-AK-CAZ-SC (2) 4,165.83 6,011,990.38 533,457.89 2.17 4,165.83 MWD+IFR-AK-CAZ-SC (2) 1/122009 1:59:56PM Page 4 COMPASS 2003.16 Burld 42F ~~ ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. ...Local Co-ordinate Reference: We113K-108 Project: Kupa ruk River Unit ND Reference: 3K-108 @ 74.14ft (Doyon 15) Site: Kupa ruk 3K Pad MD Reference: 3K-108 @ 74.14ft (Doyon 15) Well: 3K-108 North Reference: True Wellbore: 3K-108 L1 Survey Ca lculation Met hod: Minimum Curvature Design: 3K-108 L1 Database: EDM Alaska Prod v16 survey Map Map Vertical MD Inc Azi ND NDSS +N/-S +E/-W Northing Easting D LS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,2H0.00 80.20 5[.05 3,483.19. 3,409.05 3,507.61 4,114.65 6,011,950.11 533,466.71 1.25 4,174.65 MWD+IFR-AK-CAZ-SC (3) 7,303.37 80.75 91.87 3,487.06 3,412.92 3,506.82 4,197.69 6,011,989.41 533,489.75 2.47 4,197.69 MWD+IFR-AK-CAZ-SC (3) 7,399.21 82.68 91.12 3,500.87 3,426.73 3,504.34 4,292.49 6,011,987.31 533,584.55 2.16 4,292.49 MWD+IFR-AK-CAZ-SC (3) 7,494.73 85.86 90.39 3,510.40 3,436.26 3,503.09 4,387.51 6,011,986.43 533,679.57 3.41 4,387.51 MWD+IFR-AK-CAZ-SC (3) 7,589.74 86.66 89.66 3,516.60 3,442.46 3,503.05 4,482.32 6,011,986.76 533,774.36 1.14 4,482.32 MWD+IFR-AK-CAZ-SC (3) 7,684.70 87.71 90.97 3,521.26 3,447.12 3,502.53 4,577.16 6,011,986.61 533,869.19 1.77 4,577.16 MWD+IFR-AK-CAZ-SC (3) 7,778.84 88.70 92.28 3,524.21 3,450.07 3,499.86 4,671.21 6,011,984.31 533,963.25 1.74 4,671.21 MWD+IFR-AK-CAZ-SC (3) 7,874.40 88.95 92.17 3,526.17 3,452.03 3,496.15 4,766.68 6,011,980.98 534,058.72 0.29 4,766.68 MWD+IFR-AK-CAZ-SC (3) 7,969.95 91.17 91.84 3,526.07 3,451.93 3,492.81 4,862.16 6,011,978.01 534,154.21 2.35 4,862.16 MWD+IFR-AK-CAZ-SC (3) 8,065.37 93.15 90.89 3,522.48 3,448.34 3,490.54 4,957.48 6,011,976.12 534,249.53 2.30 4,957.48 MWD+IFR-AK-CAZ-SC (3) 8,160.86 93.58 90.41 3,516.87 3,442.73 3,489.46 5,052.80 6,011,975.41 534,344.84 0.67 5,052.80 MWD+IFR-AK-CAZ-SC (3) 8,255.68 90.93 90.43 3,513.14 3,439.00 3,488.76 5,147.54 6,011,975.09 534,439.57 2.79 5,147.54 MWD+IFR-AK-CAZ-SC (3) 8,350.12 88.08 90.10 3,513.96 3,439.82 3,488.33 5,241.96 6,011,975.02 534,533.98 3.04 5,241.96 MWD+IFR-AK-CAZ-SC (3) 8,444.82 88.27 91.03 3,516.97 3,442.83 3,487.39 5,336.61 6,011,974.46 534,628.62 1.00 5,336.61 MWD+IFR-AK-CAZ-SC (3) 8,541.53 88.21 90.82 3,519.94 3,445.80 3,485.83 5,433.26 6,011,973.28 534,725.27 0.23 5,433.26 MWD+IFR-AK-CAZ-SC (3) 8,636.87 90.37 91.41 3,521.12 3,446.98 3,483.98 5,528.57 6,011,971.80 534,820.58 2.35 5,528.57 MWD+IFR-AK-CAZ-SC (3) 8,731.47 88.76 91.78 3,521.84 3,447.70 3,481.34 5,623.13 6,011,969.54 534,915.14 1.75 5,623.13 MWD+IFR-AK-CAZ-SC (3) 8,826.50 88.21 91.43 3,524.35 3,450.21 3,478.68 5,718.08 6,011,967.25 535,010.09 0.69 5,718.08 MWD+IFR-AK-CAZ-SC (3) 8,922.61 89.44 91.82 3,526.33 3,452.19 3,475.96 5,814.13 6,011,964.90 535,106.14 1.34 5,814.13 MWD+IFR-AK-CAZ-SC (3) 9,015.18 89.69 92.63 3,527.03 3,452.89 3,472.36 5,906.63 6,011,961.67 535,198.65 0.92 5,906.63 MWD+IFR-AK-CAZ-SC (3) 9,111.27 90.87 94.05 3,526.56 3,452.42 3,466.77 6,002.55 6,011,956.45 535,294.58 1.92 6,002.55 MWD+IFR-AK-CAZ-SC (3) 9,206.58 88.58 93.26 3,527.02 3,452.88 3,460.69 6,097.66 6,011,950.75 535,389.70 2.54 6,097.66 MWD+IFR-AK-CAZ-SC (3) I 9,301.43 89.20 92.28 3,528.85 3,454.71 3,456.11 6,192.38 6,011,946.54 535,484.43 1.22 6,192.38 MWD+IFR-AK-CAZ-SC (3) 9,397.79 89.82 93.15 3,529.68 3,455.54 3,451.54 6,288.63 6,011,942.36 535,580.68 .1.11 6,288.63 MWD+IFR-AK-CAZ-SC (3) 9,492.33 89.14 92.30 3,530.54 3,456.40 3,447.05 6,383.05 6,011,938.23 535,675.12 1.15 6,383.05 MWD+IFR-AK-CAZ-SC (3) 9,587.25 86.79 92.38 3,533.91 3,459.77 3,443.18 6,477.83 6,011,934.73 535,769.90 2.48 6,477.83 MWD+IFR-AK-CAZ-SC (3) 9,682.53 85.80 93.10 3,540.06 3,465.92 3,438.63 6,572.80 6,011,930.56 535,864.88 1.28 6,572.80 MWD+IFR-AK-CAZ-SC (3) 9,777.35 86.42 93.59 3,546.50 3,472.36 3,433.11 6,667.24 6,011,925.41 535,959.33 0.83 6,667.24 MWD+IFR-AK-CAZ-SC (3) 9,873.09 86.85 93.04 3,552.12 3,477.98 3,427.59 6,762.65 6,011,920.26 536,054.75 0.73 6,762.65 MWD+IFR-AK-CAZ-SC (3) 9,967.96 89.94 94.62 3,554.77 3,480.63 3,421.25 6,857.26 6,011,914.30 536,149.37 3.66 6,857.26 MWD+IFR-AK-CAZ-SC (3) 10,062.98 89.57 96.14 3,555.18 3,481.04 3,412.34 6,951.86 6,011,905.76 536,244.00 1.65 6,951.86 MWD+IFR-AK-CAZ-SC (3) 10,158.18 89.26 97.32 3,556.15 3,482.01 3,401.19 7,046.39 6,011,894.98 536,338.57 1.28 7,046.39 MWD+IFR-AK-CAZ-SC (3) 10,253.98 90.43 100.07 3,556.41 3,482.27 3,386.71 7,141.08 6,011,880.87 536,433.30 3.12 7,141.08 MWD+IFR-AK-CAZ-SC (3) 10,348.18 90.19 100.15 3,555.90 3,481.76 3,370.17 7,233.82 6,011,864.70 536,526.09 0.27 7,233.82 MWD+IFR-AK-CAZ-SC (3) 10,444.36 91.05 100.48 3,554.86 3,480.72 3,352.95 7,328.44 6,011,847.86 536,620.77 0.96 7,328.44 MWD+IFR-AK-CAZ-SC (3) 10,539.11 90.19 100.60 3,553.83 3,479.69 3,335.62 7,421.58 6,011,830.89 536,713.97 0.92 7,421.58 MWD+IFR-AK-CAZ-SC (3) 10,633.99 87.65 99.61 3,555.62 3,481.48 3,318.98 7,514.96 6,011,814.62 536,807.41 2.87 7,514.96 MWD+IFR-AK-CAZ-SC (3) ~ 10,729.17 88.82 99.21 3,558.55 3,484.41 3,303.42 7,608.82 6,011,799.44 536,901.31 1.30 7,608.82 MWD+IFR-AK-CAZ-SC (3) 10,824.11 89.57 101.23 3,559.89 3,485.75 3,286.58 7,702.24 6,011,782.96 536,994.79 2.27 7,702.24 MWD+IFR-AK-CAZ-SC (3) 10,918.09 90.62 101.17 3,559.73 3,485.59 3,268.33 7,794.43 6,011,765.07 537,087.04 1.12 7,794.43 MWD+IFR-AK-CAZ-SC (3) 1/12/2009 1:59:56PM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips or its affiliates Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 3K Pad Wel I: 3K-108 Wellbore: 3K-108 L1 Design: 3K-108 L1 Survey MD Inc Iftl 1°) 11,074.06 90.0(1 11,109.15 91.67 11,203.55 90.06 11,299.36 88.83 11,394.09 88.77 11,489.11 90.74 11,584.83 91.23 11,679.42 91.48 11,774.22 90.62 11,869.77 87.84 11,964.96 85.62 12,061.23 86.79 12,155.37 88.89 12,250.15 88.58 12,347.43 89.44 12,440.30 88.71 12,536.22 88.33 12,630.39 86.29 12,725.19 85.36 12,820.93 84.61 12,915.69 83.00 13,011.33 83.18 13,106.97 88.03 Az i (°) 101.11 102.14 102.85 103.21 104.42 104.87 103.44 102.81 102.34 101.25 102.11 102.30 101.88 102.39 103.04 103.81 103.85 105.34 ND Ift) O,SSS.16 3,557.73 3,556.30 3,557.23 3,559.21 3,559.62 3,557.97 3,555.74 3,554.00 3,555.28 3,560.71 3,567.09 3,570.63 NDSS (ft) 3,485.02 3,483.59 3,482.16 3,483.09 3,485.07 3,485.48 3,483.83 3,481.60 Local Co-ordinate Reference ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ~~ Well 3K-108 3K-108 @ 74.14ft (Doyon 15) 3K-108 (a3 74.14ft (Doyon 15) True Minimum Curvature EDM Alaska Prod v16 Map Map Vertical +N/-S +E!-W Northing Easting DLS Section (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,249.78 7,888.58 6,011,746.50 537,181.26 0.59 7,bbS.58 MWD+IFR-AF-GAZ-SC (3) 3,230.63 7,981.71 6,011,728.11 537,274.45 2.01 7,981.71 MWD+IFR-AK-CAZ-SC (3) 3,210.21 8,073.86 6,011,708.06 537,366.67 1.86 8,073.86 MWD+IFR-AK-CAZ-SC (3) 3,188.61 8,167.20 6,011,686.82 537,460.08 1.34 8,167.20 MWD+IFR-AK-CAZ-SC (3) 3,165.99 8,259.16 6,011,664.57 537,552.13 1.28 8,259.16 MWD+IFR-AK-CAZ-SC (3) 3,141.97 8,351.09 6,011,640.91 537,644.14 2.13 8,351.09 MWD+IFR-AK-CAZ-SC (3) 3,118.56 8,443.89 6,011,617.88 537,737.02 1.58 8,443.89 MWD+IFR-AK-CAZ-SC (3) 3,097.09 8,535.98 6,011,596.77 537,829.19 0.72 8,535.98 MWD+IFR-AK-CAZ-SC (3) 3,076.46 8,628.49 6,011,576.50 537,921.77 1.03 8,628.49 MWD+IFR-AK-CAZ-SC (3) 3,056.93 8,722.00 6,011,557.34 538,015.35 3.13 8,722.00 MWD+IFR-AK-CAZ-SC (3) 3,037.69 8,815.06 6,011,538.47 538,108.48 2.50 8,815.06 MWD+IFR-AK-CAZ-SC (3) 3,017.38 8,908.95 6,011,518.53 538,202.43 1.23 8,908.95 MWD+IFR-AK-CAZ-SC (3) 2,997.68 9,000.93 6,011,499.20 538,294.48 2.27 9,000.93 MWD+IFR-AK-CAZ-SC (3) 2,977.76 9,093.57 6,011,479.64 538,387.19 0.63 9,093.57 MWD+IFR-AK-CAZ-SC (3) 2,956.35 9,188.45 6,011,458.61 538,482.14 1.11 9,188.45 MWD+IFR-AK-CAZ-SC (3) 2,934.79 9,278.77 6,011,437.41 538,572.54 1.14 9,278.77 MWD+IFR-AK-CAZ-SC (3) 2,911.87 9,371.88 6,011,414.86 538,665.72 0.40 9,371.88 MWD+IFR-AK-CAZ-SC (3) 2,888.17 9,462.90 6,011,391.52 538,756.83 2.68 9,462.90 MWD+IFR-AK-CAZ-SC (3) 2,863.30 9,554.12 6,011,367.00 538,848.14 1.00 9,554.12 MWD+IFR-AK-CAZ-SC (3) 2,838.75 9,646.28 6,011,342.82 538,940.38 0.95 9,646.28 MWD+IFR-AK-CAZ-SC (3) 2,814.05 9,737.18 6,011,318.48 539,031.38 2.04 9,737.18 MWD+IFR-AK-CAZ-SC (3) 2,787.97 9,828.47 6,011,292.76 539,122.76 0.47 9,828.47 MWD+IFR-AK-CAZ-SC (3) 2,763.45 9,920.59 6,011,268.60 539,214.96 5.69 9,920.59 MWD+IFR-AK-CAZ-SC (3) 2,744.07 10,000.25 6,011,249.54. 539,294.69 0.00 10,000.25 PROJECTED to TD 13,189.00 88.03 3,572.73 3,574.41 3,575.91 3,578.38 3,582.80 3,479.86 3,481.14 3,486.57 3,492.95 3,496.49 3,498.59 3,500.27 3,501.77 3,504.24 3,508.66 105.17 3,589.71 3,515.57 104.66 3,598.07 3,523.93 105.74 3,608.30 3,534.16 106.15 3,619.81 3,545.67 103.67 3,627.13 3,552.99 103.67 3,629.95 .3,555.81 1/12/2009 1:59:56PM Page 6 COMPASS 2003.16 Burld 42F ~~ Time Logs Date From To Dur S. De th E De th Phase Code Subcode__ T Comment _ _ 15:30 17:15 1.75 0 0 COMPZ RPCOM PULD P Rig up tools for handling slim hole directional assembly. Pick up slim hole assembly and torque up connections. 17:15 17:45 0.50 0 0 COMPZ RPCOM RURD P Rig up 3-1 /2" handling tools. 17:45 18:00 0.25 0 0 COMPZ RPCOM SFTY ~ P PJSM -running liner. 18:00 00:00 6.00 0 5,709 COMPZ RPCOM RCST P Running 3-1/2" B sand lateral liner with screens and swell ackers. 12/01 /2008 Run and set liner with MLZXP hanger packer. Pull out of hole and pickup whipstock and milling assembly. Make u and run in hole with whi stock and mills. 00:00 00:30 0.50 5,709 5,709 COMPZ RPCOM SFTY P PJSM in pipeshed -picking up han er acker assembl 00:30 02:15 1.75 5,709 5,914 COMPZ RPCOM RCST P Pickup and RIH with seal bore recepticle, extension joint, MLZXP hanger packer and 1 stand of drill pipe. PU wt 110k SO wt 100k, rotating wt 108k, rotating torque @ 30 r m 2.5k ftlbs. 02:15 02:45. 0.50 5,914 5,914 COMPZ RPCOM DHEQ P Shallow pulse test MWD pumping 95 m, 510 si. ood test. 02:45 03:15 0.50 5,914 6,390 COMPZ RPCOM RCST P TIH with liner on 5"drill pipe. 03:15 04:15 1.00. 6,390 6,390 COMPZ RIGMNT RGRP T Replace hose on iron roughneck. Sim ops -inspect and service drawworks. 04:15 10:15 6.00 6,390 13,150 COMPZ RPCOM RCST P TIH with liner on drill pipe recording weights every 10 stands, monitoring displacement via trip tank. Rotated thru tight spots then continued in on elevators. Rotated last 4 stands down. Tagged bottom at 13188' MD and picked up to setting depth. PU wt 190k, SO wt 125k, rotating wt 150k, rotating torque at 35 rpm 10k ft lbs. 10:15 10:45 0.50 13,150 13,150 COMPZ RPCOM CIRC P Orient hanger 22L pumping 110 gpm, 650 si. 10:45 12:15 1.50 13,150 7,334 COMPZ RPCOM CIRC P Break connection and drop ball. Pump down at 107 gpm, 630 psi. Ball on seat at 744 strokes. Set fianger packer and release running tool. Pickup and confirm released. Close pipe rams and test packer to 2500 psi for 5 minutes. Pressure held. 12:15 12:30 0.25 7,334 7,245 COMPZ RPCOM TRIP P POOH on elevators. 12:30 13:30 1..00 7,245 7,245 COMPZ RIGMNT SVRG P Inspect and service blocks, top drive and drawworks. 13:30 15:45 2.25 7,245 60 COMPZ RPCOM TRIP P POOH on elevators with liner running tools. 15:45 17:15 1.50 60 0 COMPZ RPCOM PULD P Lay down liner running tools and slim hole MWD. 17:15 18:00 0.75 0 0 PROD2 STK PULD P Pick up whipstock subs and handling e ui ment. Y ~:i ~~:; .5 ~$ C;F ": r: `~ Tirne Lis ------ rorli To Dur S,De~th E De th Phase CodE Subcode T :Ce:nment Date F _ 18:00 18:30 0.50 0 0 PROD2 STK PULD P Pick up and rack back MWD and millin assembl . 18:30 21:15 2.75 0 66 PROD2 STK PULD P Make up whipstock, subs and anchor. Orient whipstock and .anchor. 21:15 22:15 1.00 66 66 PROD2 STK WPST P Make. up milling assembly/MWD to whipstock and orient MWD to whi stock. 22:15 00:00 1.75 66 2,916 PROD2 STK WPST P TIH with whipstock and milling - assembly on 5'' drill pipe. Monitoring dis lacement via tri tank. 12/02/2008 Continue to run in hole with whipstock and 8=1/2"mills, MAD pass 6249' to 6298' (GR 6120' to 6169'), continue RIH to 7347', set whipstock (MLZXP collet depth 7347.67'), pull test 20k over, shear with 50k down, Top of whipstock @ 7280', circulate bottom's up, displace to OBM, mill window (TOW 7280', BOW 7297'), then 33' of 8-1/2" open hole to 7330', work window with mills, circulate a sweep to clean hole, monitor well- static, perform a 13 ppg FIT, rig down equipment, trip out to 5775', pump a dry job, continue ulling out of the hole to 185', la down bha to 84', download MWD, continue to la down millin assembl ,flush BOP stack. 00:00 02:15 2.25 2,916 6,249 , PROD2 STK WPST P TIH with whipstock and milling assembly on 5"drill pipe. Monitoring dis lacement via tri tank. 02:15 02:45 0.50 6,249 6,298 PROD2 EVALFN OTHR P MAD pass 6249' to 6298' (GR depth 6120' to 8169'). Pumping 650 gpm w/ 1900 si-- 52% flow out. 02:45 03:30 0.75 6,298 7,200 PROD2 STK WPST P Continue trip in with whipstock assembl . 03:30 04:00 0.50 7,200 7,347 PROD2 STK WPST P Make top drive connection, circulate 650 gpm w/ 1980 psi-52% flow out,. and orient whipstock to 25R. Pu wt 175k, SO wt 135k. 04:00 04:15 0.25 7,347 7,280 PROD2 STK WPST P Set whipstock (collet @ 7347.67') (pulled tested 20k), set down 50k and shear off. PU wt 168k, SO wt 130k, Rot wt 150k. Rot 30 rpm w/ ~'T'1 l~ ~"1: v ~ 6-7k ft Ibs of torque. Pumping 650 gpmw/ 2040 psi--52% flow out. Tag to of whi stock 7280'. 04:15 05:30 1.25 7,280 7,280 PROD2 STK CIRC P Circulate bottoms up with brine and displace well to OBM. Pumping 630 gpm w/ 2900 psi-53% flow out. Circulate 564 bbls. 05:30 13:30 8.00 7,280 7,297 PROD2 STK WPST P Mill window in the 9-5/8" 40 ppf L-80 casing. Pumping 630 gpm w/ 2900 psi--53% flow out. Rotate 70 to 120 .. ~ ~ ~ rpm w/ 7-9k ft Ibs of torque. Weight on mills 0 to 6k. Top of window 7280', bottom of window 7297'. Pump a 30 bbl swee 9.2 / 150 vis . 13:30 15:30 2.00 7,297 7,330 PROD2 STK . WPST P Continue to mill 33' of 8-1/2" open hole below bottom of window. Pumping 630 gpm w/ 2900 psi--53% flow out. Rotate 70 to 120 rpm w/ 7-9k ft Ibs of torque. Weight on mills 8 to 4k. f~age 3~ cs4~ ~~ Time Logs _ - I _ - Frorli Date To Dur S De t~h E. Depth Phase Code _Subc_od~_ T Comm_ ent _ _ __ _ 15:30 17:30 2.00 7,330 7,330 PROD2 5TK CIRC P Rotate and reciprocate from 7330' to 7279' to cleanup window. Pump a 35 bbl 9.2 ppg 150 vis sweep. Pumping 625 gpm w/ 2700 psi--52% flow out. PU wt 168k, SO wt 130k, Rot wt 150k. Rotate 120 rpm w/ 7k ft Ibs of for ue. 17:30 18:00 0.50 7,330 7,255 PROD2 STK OTHR P Monitor well-static. Rig up for FIT. 18:00 18:45 0.75 7,255 7,255 PROD2 STK CIRC P Perform a 13 ppg Formation integrity test. Pumping down drill pipe and annulus with the ri test um . 18:45 19:15 0.50 7,255 7,255 PROD2 STK TRIP P Rig down testing equipment. Blow down lines. 19:15 20:00 0.75 7,255 5,775 PROD2 STK TRIP P Trip out with milling assembly. Monitor well on the tri tank. 20:00 20:15 0.25 .5,775 5,775 PROD2 STK CIRC P Pump a dry job. Blow down the top drive. 20:15 21:45 1.50 5,775 185 PROD2 STK TRIP P Continue to pull out of the hole with the milling assembly. Monitor well on the tri tank. 21:45 22:00 0.25. 185 84 PROD2 STK PULD P Lay down BHA 22:00 22:30 0.50 84 84 PROD2 STK OTHR P Download Sperry Sun MWD. 22:30 23:30 1.00 84 0 PROD2 STK PULD P Continue to laydown BHA. 23:30 00:00 0.50 0 0 PROD2 STK OTHR P Flush BOP stack: Pumping 850 gpm w/,30Q psi-61 % flow. out. Rotate 30 r m. Clean and clear ri floor. 12/03/2008 Continue to flush BOP stack after milling, blow down choke line and top drive, rig up/test BOPE to 250 psi low and 3000 p si high.(Witness of test by AOGCC inspector John Crisp). Rig down 3-1/2" test joint, PJSM, change elemen t on annular. Test annular with 5", 3-1/2" and 4"test joint, blow down lines, set Vetco/Gray wear bushing, change out lower IB OP and saver sub on the top drive. Rig up/test 1BOP, rig down testing e ui ment, clear floor, service ri icku and make u drillin assembl for drillin "D" lateral. 00:00 00:30 0:50 0 0 PROD2 STK - OTHR P Continue to flush BOP stack. Pumping 850 gpm w/ 300 psi--61 flow out. Rotate 30 rpm. Clean and clear ri floor. 00:30 01:00 0.50 0 0 PROD2 STK. OTHR P Blow down choke) line and top drive. 01:00 02:15 1.25 0 0 PROD2 WELCTL OTHR P Rig up to test BOPE. ~~. 3 Time L~s _ _ - Date _ __ From _ _ _ To -_ Dur S Depth E. Depth_ Phase Code Subcod_e T Comment __ _ _ 02:15 10:15 8.00 0 0 PROD2 WELCTL BOPE P Test B.OPE. Witness of test by AOGCC inspector John Crisp. Tested to 250 psi low and 3000 psi high.- Chart all tests. Hold each test for 5 minutes. Tested with 3-1l2" and 5" test joint on upper (3-1 /2" x 6" variable bore rams), lower (2-7/8" x 5" variable bore rams), and the annular. Tested all valves in the choke manifold, tested kill line valves, choke line valves and kill line. Tested two 4" floor safety valves, one 4" 16OP, 5" floor safety valve and 5" IBOP valve. Note: Lower pipe rams had to be cycled to hold, valve #17 in the choke manifold was serviced with 'grease to hold. Lower IBOP on the top drive failede Annular failed with 3-1 /2" test 'oint. 10:15 10:45 0.50 0 0 PROD2 WELCTL OTHR T Hydril not able to hold pressure. Lay down 3 1/2" test joint and rig down test a ui ment. 10:45 11:00 0.25 0 0 PROD2 WELCTL SFTY T PJSM on changing Hydril element 11:00 12:45 1.75 0 0 PROD2 WELCTL EQRP T Change out Hydril Element 12:45 13:45 1.00 0 0 PROD2 WELCTL OTHR T Pick up 5" test joint and rig up test equipment. Break-in new element by functioning 2 times each with 450 psi, 600 psi & 800 psi of closing ressure. 13:45 18:00 4.25 0 0 PROD2 WELCTL BOPE P Resume testing BOPE. Tested to 250 psi low and 3000 psi high. Chart all tests. Hold each test for 5 minutes. Tested with 3-1/2", 4" and 5" test joint with the annular. Tested with 4" test joint. on upper (3-1/2" x 6" variable bore rams), lower (2-7/8" x 5".variable bore rams). Install Vetco/Gray wear bushing 13-7/16" OD x 9" ID x 38" lon 18:00 19:00 1.00 0 0 PROD2 WELCTL OTHR P Blow down choke manifold, choke and kill lines. 19:00 20:30 1.50 0 0 PROD2 WELCTL EQRP T Change out lower IBOP on the top drive. Chan a saver sub as well. 20:30 21:00 0.50 0 0 PROD2 WELCTL OTHR P Rig up to test lower IBOP. 21:00 22:00 1.00 0 0 PROD2 WELCTL BOPE P Test lower IBOP to 250 psi low and 3000 psi high. Hold each test 5 minutes. OK. Chart test 22:00 22:30 0.50 0 0 PROD2 WELCTL OTHR P Rig down testing equipment. 22:30 23:00 0.50 0 0 PROD2 RIGMNT SVRG P Clean and clear rig floor. Service top drive. 23:00 00:00 1.00 0 96 PROD2 DRILL PULD P Pickup/make up drilling assembly for drilling "D" lateral (motor with 1.22 deg bend). Monitor well on the trip tank. _ ;- r ............_._____..._____. . Time Logs _ _ _ Date _ From To _ Dur S- Depth E- Depth Phase -Code __Subcode T_ -Comment _ __ 12/04/2008 24 hr Summary Continue to pickup and make up 6-3/4" drilling assembly for drilling "D" lateral, shallow test MWD @ 96', continue with BHA to 370', trip in the hole with 4" drill pipe to 5840', change elevators, install circulating sub and crossover to 5"drill pipe, continue trip in with 5"drill pipe to 7186'. Slip and cut 145' of drilling line, adjust brakes, service rig. Continue trip to 7330 (Top of window @ 7280'), directional drill the "D" lateral to 8424', circualte 1073 bbls prior to pulling out to install two more stands of 4"drill pipe and check torque on service break of circ sub, monitor well-static, trip out to 5840', check torque on sub, install two more stands of 4", chan a elevators to 5", clean floor. 00:00 01:00 1.00 96 96 PROD2 DRILL OTHR P Upload Sperry Sun MWD 01:00 01:15 0.25 96 96 PROD2 DRILL CIRC P Shallow pulse test MWD tools. Pumping 260 gpm w/ 1490 psi--35% flow out. 01:15 01:45 0.50 96 370 PROD2 DRILL PULD P Continue to pickup/makeup drilling assembly for drilling "D" lateral (motor with 1.22 deg bend). Monitor well on the tri tank. 01:45 03:30 1.75 370 5,840 PROD2 DRILL TRIP P Trip in the hole with 4" drill pipe. Monitor displacement on the trip tank. Fill i e eve 25 stands. 03:30 03:45 0.25 5,840 5,945 PROD2 DRILL TRIP P Change elevators to 5". Make up Downhole devices PBL sub and XT 39 to 4-1/2" IF crossover. 03:45 04:30 0.75 5,945 7,186 PROD2 DRILL TRIP P Continue trip in the hole with 5"drill i e. 04:30 06:00 1.50 7,186 .7,186 PROD2 RIGMNT SVRG P Slip and cut 145' of 1-3/8"drilling - line. Adjust brakes. Aquire SPR's. Grease crown. 06:00 06:30 0.50 7,186 7,330 PROD2 DRILL . TRIP P Continue trip in the hole with 5"drill pipe. Note: Top of window 7280', bottom of window 7297'. No problems going throu h window. 06:30 12:00 5.50 7,330 7,810 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 617 units. 12:00 18:00 6.00 7,810 8,346 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1083 units. 18:00 19:00 1.00 8,346 8,424 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 551 units. 19:00 21:30 2.50 8,424 8,424 PROD2 DRILL CIRC P Circulate prior to short trip to install two stands of 4"drill pipe and check torque on service break of circulating sub.Circulate a total of1073 bbls. Pumping 320 gpm w/ 3100 psi--33% flow out. Rotate 110 rpm w/ 5k ft Ibs of for ue. 21:30 21:45 0.25 8,424 8,424 PROD2 DRILL OWFF P Monitor well- static. Blow down the to drive. 21:45 23:15 1.50 8,424 5,840 PROD2 DRILL TRIP P Trip out of the hole to the circualting sub. Pulled through window good. Monitor well on the tri tank. 23:15 23:30 0.25 5,840 5,840 PROD2 DRILL OTHR P Break the circulating sub, check and clean connections, redope, torque service break to 19200 ft Ibs of torque. Change handling equipment to 4". - - -- _ _, Time Logs Date From To Dur S Depth- E. Depth Phase Code- Subcude T Comment 23:30 23:45 0.25 5,840 6,037 PROD2 DRILL TRIP P Trip in the hole with two more stands of 4" drill pipe (Total of 60 stands of 4"drill i e . 23:45 00:00 0.25 6,037 6,037 PROD2 DRILL OTHR P Change elevators to 5". Clean and clear ri floor. 12/05/2008 Trip in the hole to 8424', acquire a replacement generator for the SWACO solids control van from ASRC, wire enerator/ check rotation, continue to directional drill the "D" lateral from 8424' to 10611'. 00:00 01:45 1.75 6,037 8,424 PROD2 DRILL TRIP P TIH with 5" DP. Monitor dis lacement on tri tank 01:45 06:00 4.25 8,424 8,924 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1741 units 06:00 06:45 0.75 8,924 9,050 PROD2 DRILL DDRL P Directional drill 6-3/4""D" lateral.. Max as observed 617 units. 06:45 09:30 2.75 9,050 9,050 PROD2 DRILL CIRC T Recip and circulate while waiting on replacement generator for MI solids control van 09:30 12:00 2.50 9,050 9,358 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 2021units. 12:00 .18:00 6.00 9,358 9,959 PROD2 DRILL DDRL P Directional drill 6-3/4° "D" lateral. Max as observed 1022 units. 18:00 00:00 6.00 9,959 10,611 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1347 units. 12/06/2008 Continue to directional drill the 6-3/4" "D" lateral from 10611' to 12975'. 00:00 06:00 6.00 10,611 11,181 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 674 units. 06:00 12:00 6.00 11,181 11,846 PROD2 DRILL DDRL P Directional drill 6-3/4""D" lateral. Max as observed 1551 units. 12:00 18:00 6.00 11,846 12,512 PROD2 DRILL DDRL P . Directional drill 6-3/4" "D" -ateral. Max as observed 885 units. 18:00 00:00 6.00 12,512 12,975 PROD2 DRILL DDRL P Directional drill 6-3/4" "D" lateral. Max as observed 1350 units. 12/07/2008 Continue to directional drill the 6-3/4" "D" lateral from 12975' to 13189', circulate and reciprocate from 13189' to 13124', pump a 25 bbl sweep (9.4 ppg/ 200 vis), continue to circulate, monitor well- fluid falling slowly, short trip to 11686' and back to bottom @ 131.89', circulate, pull two singles to place downhole devices circulating sub above the window, pump 1-/2" ball to open circ sub, after open- circulate at 500 gpm for a bottom's up+ then 800 gpm for 4 more bottom's up, pickup asingle- drop two 1-3/8" steel balls to close tool,. acquire slow pump rates-verify tool shut, monitor well, pull out of the hole to 11754', pump a 27 bbl dry job, continue to ull out of the hole to 9947' midni ht. 00:00 03:15 3.25 12,975 13,189 PROD2 DRILL DDRL P Directional drill 6-3/4" "D"lateral. Max as observed 1350 units. 03:15 10:00 6.75 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 320 to 296 gpm w/ 3570 to 3020 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 188k, SO wt while rotating 145k, rotating and recip.from 13189' to 13,124'. Max as observed 838 units. 10:00 11:45 1.75 13,189 .13,189 PROD2 DRILL CIRC P Pump 25 BBL, 9.4 ppg, 200 vis swee 11:45 12:30 0.75 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 320 to 296 gpm w/ 3570 to 3020 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 188k, SO wt while rotating 145k. rotating and recip.from 13189' to 13,124'. Max gas observed 278 units. Circulated over 5 Bottom's u _- g: ~- ... Time Logs- - -- _ - - _ -- _ _ -_ _ -j 'Date _ From To Dur S Depth E. Depth PhaseCodE Sub_ccde T_ .Comment 12:3© 13:00 0.50 13,189 13,189 PROD2 DRILL OWFF P Monitored well -fluid level falling slowl ,Install air sli s 13:00 14:30 1.50 13,189 11,686 PROD2 DRILL TRIP P POOH on elevators from 13,189' to 11,686' monitoring fill on TT. PU wt 185k, SO wt 110k. Record PU and SO wt's eve 5 stands. 14:30 14:45 0.25 11,686 11,686 PROD2 DRILL OWFF P Monitored well -fluid level falling slowl 14:45 15:30 0.75 11,686 13,189 PROD2 DRILL TRIP P TIH on elevators from 11,686' to 13189' monitoring fill on TT. Record PU and SO wt's every 5 stands. PU wt 190k, SO wt 100k. 15:30 17:30 2.00 13,189 13,189 PROD2 DRILL CIRC P Circulate, pumping 285 gpm w/ 2970 psi, rotate 120 rpm w/ 10k ft lbs. PU wt 190k, SO wt while rotating 145ke Rotating and recip.from 13189' to 13,124'. Pum ed a Bottom's u +. 17:30 18:00 0.50 13,189 13,112 PROD2 DRILL PULD P - Pull out of hole to place the Downhole devices PBL circulating sub above the top of the window 7280'). La down two sin les. 18:00 18:30 0.50 13,112 13,112 PROD2 DRILL CIRC P Drop 1-1/2" activating ball to open sub, pump ball down at 5 bpm w/ 1740 psi - 27% flow out, for 740 strokes, then slow down to 1.5 bpm w/ 300 psi -11 % flow out, till ball on seat (1030 strokes). Pressure dropped from 500 psi to 380 psi indicatin orts o ened. 18:30 20:30 2.00 13,112 13,112 PROD2 DRILL CIRC. P Circulate through the downhole devices PBL sub. Reciprocate from 13112; to 13050' (work PBL sub 7270' to 7208'). Pumped 500 gpm w/ 1350 psi- 45% flow out for 5500 strokes, then increased flow to 600 gpm w/ 1730 psi- 50 % flow out, 700 gpm w/ 2250 psi- 54% flow out, and finally 800 gpm w/ 2780 psi- 58% flow out. Pumped a total of 2085 bbls 5.5 BU . 20:30 21:00 0.50 13,112 13,112 PROD2 DRILL TRIP P Pickup a single. Drop two 1-3/8" steel balls to close circulating sub. Pump balls down @ 5 bpm w/ 330 psi- 26% flow out for 500 strokes, then slow to 1.5 bpm w/ 220 psi- 9% flow out till balls on seat after 680 strokes. Pressuredup to 3410 psi to blow ball seat and close tool. 21:00 21:30 0.50 13,112 13,112 PROD2 DRILL CIRC P With circulation sub closed, obtain slow pump rates: # 1 mp 20 spm 480 psi, 30 spm 830 psi. #2 mp 20 spm 490 psi, 30 spm 810 psi. Verify tool is closed. 21:30 21:45 0.25 13,112 13,112 PROD2 DRILL OWFF P Monitor well- static. Blow down the to drive. ~,~ Tirne Logs _ _ __ _ _ __ _ Dur S Depth E. Depth Phase CodE _ Subcode T Ccm_ment _ _ To From Date ____ _ _ 21:45 22:45 1.00 13,112 11,754 PROD2 DRILL TRIP P Pull out of the hole on elevators. Monitor displacement on the trip tank. Obtain PU and SO wt's every 5 stands. 22:45 23:00 0.25 11,754 11,754 PROD2 DRILL CIRC P Pump a 27 bbl dry job (11.2 /71vis .Blow down the to drive. 23:00 00:00 1.00 11,754 9,947 PROD2 DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's eve 5 stands. 12/08/2008 Continue to pull out of the hole from 9947' to 6039', change handling tools to 4", break circ sub (retrieve 2 steel balss, 1 torlon ball), retorque sub/LD same, continue to pull out with drilling assembly, lay down BHA, download, continue to lay down bha. Clear and clean floor. PJSM, PU/MU/RIH with hole opener/cleanout assembly to 1900'. Conduct table top Rig evacuation drill. Continue to trip in to 5894', change handling tools to 5", Install string magnet on top of first single of 5", continue trip in to 9522' (obstruction), work hole to 9616', continue to 12049' (obstruction), work hole to 12089', continue to 12592', work hole to 12659'. Continue trip to TD @ 13189'. Rotate and reciprocate to clean hole prior to displacement to 9.5 ppg VersOut breaker brine. 00:00 02:15 2.25 9,947 6,039 COMPZ DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's every 5 stands in open hole, every 10 stands in casin . 02:15 02:30 0.25 6,039 5,842 COMPZ DRILL TRIP P C/O from 5" handling tools to 4" and continue POOH 02:30 02:45 0.25 5,842 5,842 COMPZ DRILL RURD P Break connection on PBL Sub, Removed two steel balls and one Trolon ball 02:45 05:00 2.25 5,842 370 COMPZ DRILL TRIP P Continue to pull out of the hole on elevators. Monitor displacement on the trip tank. Record PU and SO wt's eve 10 stands. 05:00 07:30 2.50 370 0 PROD2 DRILL PULD P Continue POOH laying down BHA and downloading MWD. Monitor dis lacement on the tri tank. 07:30 07:45- 0.25 0 COMPZ WELLPF RURD P Clear floor and RU for BHA #12. 07:45 -08:30 0.75 296 COMPZ WELLPF PULD P PJSM, MU BHA#12 to 296' 08:30 09:15 0.75 296 1,900 COMPZ WELLPF TRIP P TIH on elevators W/BHA#12 on 4" DP. Monitoring displacement on trip tank. Recording PUW & SOW every 10 stands. 09:15 09:45 0.50 1,900 1,900 COMPZ WELLPF SFTY P Table top Rig evacuation drill 09:45 11:15 1.50 1,900 5,894 COMPZ WELLPF TRIP P TIH on elevators W/BHA#12 on 4" DP. Monitoring displacement on trip tank. Recording PUW & SOW every 10 stands. 11:15 11:45 0.50 5,894 5,894 COMPZ WELLPF PULD P C/O to 5" handling equipment. PU ma net on to of first 'oint of 5" DP 11:45 13:00 1.25 5,894 9,522 COMPZ WELLPF TRIP P TIH on elevators W/BHA #12 on 5" DP. Monitoring displacement on trip tank. Recording PU wt & SO wt eve 10 stands. 13:00 14:15 1.25 9,522 9,616 COMPZ WELLP F UREM P Circ and rotate through obstruction. Pumping 7 bpm w/ 1410 psi-32% flow out. Date Logs-From To Dur S Deptf~ E_ DG th Phase Code_ Subcode T Comment _ _____ _ _J 14:15 15:15 1.00 9,616 12,049 COMPZ WELLPFTRIP P TIH on elevators W/BHA #12 on 5" DP. Monitoring displacement on trip tank. 15:15 16:00 0.75 12,049 12,089 COMPZ WELLPF UREM P Circ and rotate through obstruction. Pumping 5 bpm w/ 1050 psi- 26% flow out. Rotate 60 rpm w/ 9-10k ft Ibs of for ue. 16:00 16:30 0.50 12,089 12,592 COMPZ WELLPF TRIP P TIH on elevators W/BHA #12 on 5" DP. Monitoring displacement on trip tank. 16:30 16:45 0.25 12,592 12,659 COMPZ WELLPF UREM P Circ and rotate through obstruction. Pumping 5 bpm w/ 1050 psi- 26% flow out. Rotate 60 rpm w/ 9-10k ft Ibs of for ue. 16:45 17:15 0.50 12,659 13,189 COMPZ WELLPF TRIP P TIH on elevators VV/BHA #12 on 5" DP to TD. Monitoring displacement on tri tank. Obtain aramiters. 17:15 23:45 6.50 13,189 13,189 COMPZ WELLPF CIRC P Rotate and reciprocate from 13,129' . to 13,189' (magnet depth 7,259' to 7,199') CBU @ 320 GPM, 2050 PSI- 32% flow out. Rotate 120 RPM, 10K tq. Max gas observed 215 uhits. Circulated 2907 bbls (5+ BU). Note: While circulating: Held pre job safety meeting with truck drivers and derrick hand. Cleaned trip tank, blow down line to stack. Blow down secondary kill line. Held pre job safety meeting with rig crew after VersOut breakerwas mixed into one truck and truck was s otted. 23:45 00:00 0.25 13,189 13,189 COMPZ WELLPF OTHR P Flush both mud pumps with 9.2 ppg brine. Flush kill line with 9.2 ppg brine. 12/09/2008 Displace from 9.2 OBM to 9.5 ppg VersOut breaker brine, monitor well, pull out of the hole with hole opener/cleanout assembly to 6924' (window @ 7280'), pre job safety meeting, displace vis brine out of hole to 9.2 ppg brine @ 6924', displace to 9.2 ppg brine, monitor well, continue to pull out of the hole, lay down hole opener assembly. Clean floor, make up Baker whipstock retrieval assembly, run in the hole, clean slot, pull free, set back a stand, circulate bottom's up, obtain slow pump rates, monitor well, drop a 2,38" rabbit in the drill i e, ull out of the hole with the whi stock to 4795' midni ht. - - - -- - - • Tirne Low __ - _ - _-_'. _- Date From To Dur . De~th S E D~h_ Phase Code _ Subcode T Comment _ --- _ 00:00 03:15 _ 3.25 _ 13,189 13,189 COMPZ WELLPF CIRG P Displace 9.2 OBM from well, change over to Versa out Breaker in the open hole. Work pipe from 13189 to 1129', rotate 50 rpm w/initial 10k ft Ibs/ final was 14k ft Ibs. PU wt prior 185k and 193k after, SO wt before 128k and after 118k, Rotating weight prior 153k and 153k after. Torque 10k before and 14k after. Pumping 5 bpm. Pump 25 bbls of LVT (6.8 ppg), 75 bbls Transition spacer (9.7 ppg); 408 bbls vis brine (9.2 ppg)w/ 1.75 % safe tube, 285 bbls VersOut Breaker (9.5 ppg), follow with 110 bbls of brine w/ 1.75% safe lube.(9.2 ppg). Initial circulating pressure 1040 psi, final 910 psi. Flush hoses back to the trucks after um in . 03:15 03:30 0.25 13,189 13,189 COMPZ WELLPF OWFF P Monitorwell-taking alittle.-Blow down the to drive. 03:30 08:00 4.50 13,189 6,924 COMPZ WELLPF TRIP P Pull out of the hole on elevators. Record PU and SO wt's every 5 stands in open hole, every 10 stands in the casing. Hole taking 12 bph over calculated displacment. Monitor well on the tri tank. 08:00 08:30 0.50 6,924 6,924 COMPZ WELLPF SFTY P Pre job safety meeting on displacement from vis brine (9.2 ppg) to brine 9.2 08:30 09:00 0.50 6,924 6,924 COMPZ WELLPF PULD P Bring tools to the floor for next BHA. Work logistics to get trucks lined up for dis lacement. 09:00 10:15 1.25 6,924 6,924 COMPZ WELLPF CIRC P Displace from vis brine to brine (9.2 ppg) w/ .6% safe tube. Pumping 5 bpm w/ 390 psi-27% flow. out, 6 bpm w/ ??? psi, 7.5 bpm w/ 810 psi-35% flow out. Reciprocate from 6924' to 6844'. Rotate 50 rpm w/ 5-6k ft Ibs of torque, final of 4k ft Ibse PU wt 150k, SO wt 125k, Rot wt 148k.. 10:15 10:45 0.50 6,924 6,924 COMPZ WELLPF OWFF P Monitor well- slight losses, calculated @ 6 bph. Blow down top drive. 10:45 11:15 0.50 6,924 5,897 COMPZ WELLPF TRIP P Pull out of the hole. Monitor well on the tri tank. 6 b hover calculated. 11:15 11:30 0.25 5,897 5,897 COMPZ WELLPF OTHR P Change elevators from 5" to 4". 11:30 13:15 1.75 5,897 299 COMPZ WELLPF TRIP P Continue to pull out of the. hole. Monitor well on the trip tank with 6 b h losses. 13:15 14:30 1.25 299 0 COMPZ WELLP F PULD P Lay down hole opener BHA. Monitor well on the trip tank. Hole took 67 bbls over calculated for tri . 14:30 14:45 0.25 0 0 COMPZ WELLP F OTHR P Clear and clean rig floor. Monitor well on the tri tank w/ 7 b h losses. - ,~,c . . c' .~, • Time Logs _ _ -- - -- _ - From To Dur S D~th E Depth Phase Code Subcode T Comment Date _ 14:45 15:30 0.75 0 159 COMPZ FISH PULD P Pickup/ make up whipstock retrieval BHA. Monitor well on the trip tank w/ 7 b h losses. 15:30 18:30 3.00 159 7,199 COMPZ FISH TRIP P Trip ih the hole with retieving hook assembly with a string magnet to pull whipstock. Monitor well on the tri tank. 4-6 b hover calculated. 18:30 20:15 1.75 7,199 7,286 COMPZ FISH FISH P PU wt w/o pumps 170k, SO wt with pumps 175k. SO wt 122k w/o pumps, SO wt with pumps 132k. Work hook to find slot of whipstock. After locating slot, rotate pipe 180 deg, then wash from 7291' to 7281' (Slot of whipstock @ 7286') pumping 67 spm w/ 720 psi-32% flow out. Max gas observed 446 units. Pulled whipstock assembly free with 205k. Fluid in the hole dropped confirming "B" lat open to wellbore. Pumping 50 spm w/ 640 psi- 23% flow out (loss of 6% on flow meter). Approx 40 bbl er hour losses. 20:15 20:30 0.25 7,286 7,268 COMPZ FISH TRIP P Pulled whipstock assembly free with 205k on weight indicator (30K over). Fluid in the hole dropped confirming "B" lat open to wellbore. Pull a stand and set back (bottom of anchor @ 7268' . 20:30 22:00 1.50 7,268 7,268 COMPZ FISH CIRC P Circulate at 30 spm w/ 160 psi- 13% flow out, increase pump rate to 50 spm w/ 410 psi-23% flow out after 80 bbls pumped. Pumped a total of 527 bbls (BU 375 bbls). Losses of 47 b h. Max as 20 units. 22:00 22:15 0.25 7,268 7,268 COMPZ FISH CIRC P Acquire slow pump rates. Mud pump #1, 20 spm/30 spm= 90/160 psi. Mud pump #2; 20spm/30 s m=80/150 si. 22:15 22:30 0.25 7,268 7,268 COMPZ FISH OTHR P Monitor well. 40 bph losses. Drop a 2.38" hollow rabbit with 120' of wire to rabbit drill i e. 22:30 00:00 1.50 7,268 4,795 COMPZ FISH TRIP P Pull out of the hole with whipstock. Monitor well on the tri tank. 12/10/2008 Continue to pull out of the hole with the whipstock from 4795' to whipstock retrieval BHA, lay down BHA (retrieved rabbit at the jars). Lay down whipstock assembly (mills appeared to walk off slide to the right, anchor to whipstock orientation appears that whipstock face is right of anchor 7 degrees). Clean magnets, lay down Baker tools from rig floor. Clean and clear rig floor. PU casing tools to run Seal Bore Diverter. Pickup and make up Seal Bore Diverter, orient face of Seal Bore Diverter 17 deg right of MLHR Anchor, run in the hole on 5"drill pipe to latch collet into the "B" lateral MLZXP @ 7347.67' (bottom of seals 7379.42', profile for RAM hanger will be 7275.89'). Set down ,pull test, set down10k, pressure test to 2500 psi (IBP, Seals). Release from Seal Bore Diverter. Pull out of the hole with running tools. Lay down tools, break and lay down whipstock assembly. Rig up to run liner for "D" lateral, pre job safety meeting, run 3-1 /2" 9.2 ppf L-80 SLHT screen & blank liner to 5824' midni ht, chan a elevators to 5". • Time o s 9 - - - - - - T Comment _ - - E DE th_PhaSZ-Code __Subc,~ e De th Dur S Date From To d ~ _ - _ -- P Pull out of the hole with whipstock. . COMPZ FISH TRIP 00:00 02:15 2.25 4,795 228 Monitor well on the trip tank. Retrieved the 2-3/8" rabbit with wire- landed on the jars. Lost 101 bbls over calculated displacment. Losses are 28 to 23 bbl per hour from midni ht to 2 am. 02:15 03:00 0.75 228 69 COMPZ FISH PULD P Lay down BHA (retrieved 2-3/8" rabbit at the'ars . 03:00 05:00 2.00 69 0 COMPZ FISH PULD P Lay down whipstock assembly (mills appeared to walk off slide to the right, anchor to whipstock orientation appears that whipstock face is right of anchor 7 de rees . 05:00 05:15 0.25 0 0 COMPZ FISH PULD P Clean magnets, lay down Baker tools from rig floor. Clean and clear ri floor. 05:15 05:45 0.50 0 0 COMPZ CASING RURD P PU casing tools to run Seal Bore Diverter. 05:45 06:00 0.25 0 0 COMPZ CASING SFTY P Pre job safety meeting on picking up Seal Bore Diverter 06:00 06:45 0.75 0 115 COMPZ CASING RUNL P Pickup and make up Seal Bore Diverter. Note: fluid loss: From midnight to 0600 hrs = 150 bbls. 06:45 07:00 0.25 115 115 COMPZ CASING OTHR P Orient MLHR Anchor to Seal Bore Diverter (Face opening oriented 17 de rees ri ht of anchor). 07:00 07:30 0.50 115 288 COMPZ CASING RUNL P Make up Seal Bore Diverter running assembl BHA. 07:30 11:15 3.75 288 7,379 COMPZ CASING RUNL P Run 4-1 /2" Seal Bore assembly in the hole on 5"drill i e. 11:15 11:30 0.25 7,379 7,379 COMPZ CASING RUNL P Engage Seal Bore MLHR anchor into "B" lateral MLZXP packer, seals isolating holes in the Casing Seal Bore receptacle of "B" lateral, slacked off to engage MLHR Production Anchor. Set down 22k, pull tested to 255k (75k overpull). Set down 10k, then test seals & IBP to 2500 psi for 5 min. Test good. Bleed pressure down to 1000 psi, pickup to release running tool, bleed pressure to zero. PU wt 179K, SO wt 135k, Block wt 75k. Note: Fluid losseswre 25 bph prior to sealing off the "B" lateral. Fluid losses to the "B" lateral are now isolated. Well now takin 6 b h 11:30 13:45 2.25 7,379 181. COMPZ CASING RUNL P Pull out of the hole with Seal Bore Diverter running tools. Monitor losses on the trip tank. Losses are 5 to 6 b h. 13:45 14:45 1.00 181 0 COMPZ CASING OTHR P Lay down running tools for the Seal Bore dverter. Clean ma nets. 14:45 15:45 1.00 0 0 COMPZ FISH PULD P Pickup whipstock BHA from pipe shed and break connection. Lay down same. n • ', Tirne Logs -- - _- -- - - - -- - - - - Date_ _ From To Dur S. Depth E, Depth Phase Code _ Subcode T _Comment _ _- -_ - 0 0 COMPZ CASING KURD P Rig up to run 3-1 /2" 9.2 ppf L-80 15:45 16:30 0.75 SLHT Screen/Blank liner for the "D" lateral. 16:30 17:00 0.50 0 0 COMPZ CASING SFTY P Pre job safety meeting on running l iner. 17:00 18:00 1.00 0 604 COMPZ CASING RUNL P Run 3-1/2" 9.2 ppf L-80 SLHT liner with Reslink screens and TAM freecaps (water activated swell packer). Note: Fluid losses from 0600 to 1800 hrs = 219 bbls. 18:00 23:45 5.75 604 5,824 COMPZ CASING RUNL P Continue to run 3-1 /2" 92 ppf L-80 SLHT liner with Reslink screens and . TAM freecaps (water activated swell packer). Monitor well on the trip tank with 5 to 6 bph losses. PU wt 110k, SO wt 102k 23:45 00:00 0.25 5,824 5,824 COMPZ CASING OTHR P Change outhandling equipment to 5" 12/11 /2008 Continue to run 3-1 /2" 9.2 ppf L-80 SLHT screen & blank liner from 5824' to 5878', Rig down GBR tools, MU BHA for running liner, run in the hole on 5" drill pipe, exit Seal Bore Diverter ramp @ 7285.32' (no problems), Continue to run in the hole to 11516', rotating through tight spots @ 9900' and 10904'-11504', worked through obstruction @ 11504' to 11516'. Attempt to go deeper with no progress. Pull out of the hole from 11516' to 11474' (tight). With the top of the liner @ 11477', drop a 29/32" ball to release liner, pull running tools from 5660' to 5619'. Noticed overpull, worked free, continue pulling out with running tools to 5082'. Slip and cut drilling line. Service the rig. Continue pulling out, lay down the Baker running tool- Junk ring slide downbecause thread ring had unscrewed- thread ring was deformed. Change out the HRD-E liner running tool. Make u remainin BHA, tri in to 3981' with assembl . to embl h 00:00 00:45 0.75 5,824 5,878 COMPZ CASING RUNL P y anger ass MU Baker RAM 5878'. 00:45 01:15 0.50 5,878 5,878 COMPZ CASING RURD P Rig down GBR tongs. Bring completion tools to floor, then to pipe shed. Clear and clean ri floor. 01:15 01:30 0.25 5,878 6,052 COMPZ CASING RUNL P MU running BHA. Magnets, boot baskets, HWDP to 6052'. PU wt 118k, SO wt 110k. Rot wt 112k w/ 30 r m-for ue 3500 ft lbs. 01:30 03:00 1.50 6,052 7,384 COMPZ CASING RUNL P Run in hole with 5"drill pipe. Exit seal Bore diverter ramp @7285.32', No indication of any problems. Parameters @ 7000' were: PU wt 132k, SO wt 120k, Rot wt 125k w/ 30 m - 4k ft Ibs of for ue. 03:00 09:30 6.50 7,384 11,516 COMPZ CASING RUNL P Running liner in open -hole from 7385'. to 11,516' MD. Rotating through tight spots at 9,900' MD, and 10,904' to 11504' MD. Worked through obstruction at 11,504' to 11, 516' MD. 09:30 10:45 1.25 11,516 11,516 COMPZ CASING RUNL T Attempt towork through obstruction at 11,516' MD 45 RPM, 13.5K TO, PU 182K, ROT 142K - no ro ress --- • ~ Tirne Logs- -- - __ - -- _ _ _ - _ - Date From To Dur S Depth E De~th_Phasz-Code- Subcode T Con.ment 10:45 12:00 1.25 11,516 11,516 COMPZ CASING RUNL T Attempt to POOH from 11,516' MD hung up at 11,474' worked pipe with 40 to 45 RPM, 13.5K TO, max pull 310K. No progress. PU wt 182k, Rot wt 142k, no down wt. Fluid losses 9.5 b h. 12:00 14:30 2.50 11,516 11,477 COMPZ CASING RUNL T Continue to work "D" lateral liner.from 11500' to 11474', mate 40 rpm w/ 13500 ft Ibs of torque. Maximum pull to 310k on weight indicator. Monitor well on the trip tank. 14:30 15:30 1.00 11,477 11,477 COMPZ CASING CIRC T With liner shoe @ 11477' and top of liner 5605.76'. Drop a 29/32" ball to release from liner. Pump ball down @ 3 bpm w/ 180 psi- 17% flow out. Ball on seat after 680 strokes. Pressure to 3500 psi. Pickup 7.5', then pressure up to 4500 psi to blow ' ball seat. Blow down the to drive. 15:30 16:30 1.00 5,660 5,619 COMPZ CASING RUNL T Pull running tools from 5660' to 5619'. Noticed overpull while pulling running tools out of the RAM Hanger. Work free. Pulled 50k over. Monitor well on the tri tank. 16:30 16:45 0.25 5,619 5,082 COMPZ CASING RUNL T Continue to pull out of the hole with runnin tools to 5082'. 16:45 17:45 1.00 5,082 5,082 COMPZ RIGMN7 SVRG T Slip and cut 150' of 1-3/8"drilling line. Monitor well on the trip tank with 10 b h losses. 17:45 18:45 1.00 5,082 5,082 COMPZ RIGMNT SVRG T Service rig, crown sheaves, top drive and drawworks. 18:45 20:00 1.25 5,082 0 COMPZ CASING RUNL T Continue to pull out of the hole with running tools from 5082' to surface. Monitor well on trip tank w/ 30 bbls over calculated fro the tri . 20:00 22:15 2.25 0 0 COMPZ CASING OTHR T Lay down Baker liner running tool to the pipe shed. Junk cover had slid down the assembly because threaded ring had unscrewed. Threaded ring deformed. Remove Junk rin and thread form assembl . 22:15 22:45 0.50 0 45 COMPZ FISH PULD T Change out the HRD-E liner running tool. Drift assembl to 2.45". 22:45 23:00 0.25 45 174 COMPZ FISH PULD T Make up remaining BHA to 174.20' 23:00 00:00 1.00 174 3,981 COMPZ FISH TRIP T Trip;in the hole to 3981' with assembly to engage RAM liner han er f/ the "D" lateral. r, lTi3=.~ ~ ~ Time Logs - - _ _ - - - _ -- - Date From To D_ur S_-.Depth E. Depth Pha_sE_ Code Subcode T- Co_m_ment _ - 12/12/2008 2a hr Summary Finish making up Liner retrieval BHA (HRD-E), trip in f/ 3981' with assembly to 5591' engage fish with top of RAM hanger @ 5605.76', work pipe to try and make hydraform centralizers at the bottom of the joints of liner (able to work pipe 14' f/11485' to 11471'), break off single. Rig up Schlumberger WL, run in the hole with wireline (unable to get to planned cut depth of 7371.44'), attempt to pump down @ 5 bpm w/ 190 psi, no good. Cut liner on jt # 149, estimated 2' down from box (estimated 6570'). Pull out of the hole with wireline, rig Rig up GBR, lay down RAM hanger and 31 joints of Pull out of the hole with fish li i b w . ne. re erger w n Schlum do 3-1/2" liner (29 jts + 2 Reslink screens= 31 joints+ cutoff 3.4' of jt # 149 , 29 hydraforms centralizers, 2 TAM freecaps (swell packers), rig down GBR, strap and rabbit joints layed down. Total length of fish from top of Ram Liner hanger = 969.73', bring Baker fishing tools to the floor, MU BHA to 28'. Note: To of RAM Han er 5601.76' + 969.73' = To offish 3-1/2" liner 6571.49'. 00:00 01:00 1.00 3,981 5,591 COMPZ FISH TRIP T Continue to trip in the hole to 5591' with assembly to engage RAM liner han er f/ the "D" lateral.. 01:00 05:15 4.25 5,591 11,473 COMPZ FISH TRIP T PU single"(31.79') and a 15.23' pup jnt. Obtain parameters prior to tagging up. UP 175K, DN 130K, ROT 140K, RPM 30 w/ 6k ft Ibs of torque. Tagged up at 5606' (top of Liner Hanger), SO and latch up with retreiving tool. Shoe at 11477. Worked pipe to shift Hydroforms to pin end of liner Jnts. Park string with shoe at 11473' (estimated 15k overpull), top of RAM hanger @ 5601.76'. 05:15 09:30 4.25 11,473 11,473 COMPZ FISH ELNE T With string sitting in slips. RU Schlumberger Wire line to cut liner w/ 2-3/8" chemical cutter. 09:30 12:15 2.75 11,473 6,570 COMPZ FISH ELNE T Schlumberger wire line run in the hole. Attempt to pump down @ 5 bpm w/ 190 psi- 25% flow out. Could not get as deep as planned 7371' cut depth. Cut liner @ estimated 6570' with 2-3/8" chemical cutter. Cut liner 't # 149 a rox 2' below to of box. 12:15 13:30 1.25 6,570 6,570 COMPZ FISH ELNE T Pull out of the hole with Schlumber er wireline. 13:30 15:00 1.50 6,570 6,570 COMPZ FISH ELNE T RD Schlumberger wire line unit.. 15:00 17:00 2.00 6,570 977 COMPZ FISH TRIP T POOH wifh 5"drill pipe from estimated 6570' to Baker liner running tool with RAM hanger. Did not notice any overpull. PU wt 158k. Fluid losses a rox 11 b h. 17:00 18:00 1.00 977 977 COMPZ FISH RURD T Rig up GBR to break and Tay down liner. 18:00 21:45 3.75 974 0 COMPZ FISH PULD T Lay down Baker liner runhing tool with Ram Hanger. Then lay down a total of 31 jts + cut off (3.4' of jt # 149): 29 joints of 3-1l2" 9.2 ppf L-80 SLHT liner, (2) Reslink screens, (29) 6-1/8" Hydraforms, (2) TAM freecap swell packers (freecaps were still in original position on the joints). Total length of fish from top of RAM hanger is 969.73' la ed down. 21:45 22:15 0.50 0 0 COMPZ FISH RURD T Rig down GBR tools. • Tirne Logs _ ~ S. D~t(~_ E D~h_Phase Code Subcode_. T_Comrr~ent - To Dur Date rom _ __ 22:15 22:45 0.50 28 COMPZ FISH OTHR T Clean and clear floor. Bring tools to floor for overshot run. Measure cutoff to be 3.40". Strap and rabbit joints layed down. Will not rabbit to 2.867" as originally. Attempt to rabbit to 2.85", all will not rabbit. Some would not rabbit to 2.76". 22:45 00:00 1.25 0 28 COMPZ FISH PULD T Make up Baker Fishing BHA: Overshot w/ 3-U2" mill control packoff and grapple, crossover, 7-3/4" Bowen Lub Bumper Sub, 7-3/4" Bowen Oil Jar, crossover to 28'. 12/13/2008 Finish making up Fishing BHA from 28' to 119', run in the hole to 6494' with overshot, space outwith drill pipe, rotate over liner, pickup 13k over, set in slips, pre job safety meeting, rig up Schlumberger WL, run in the hole pump down wireline (5 bpm w/ 1410 psi) to 7479'. Pickup wireline to cut with 2-3/8" chemical cutter to 6828' , roximate 2' below box of joint # 124 (approx 7371.4'). Pull out with wireline, rig down Schlumberger a pp wireline. Pickup, lay down spaceout pups, lay down two singles of 5' drill pipe to 7199'. Finish rigging down Schlumberger wireline. Pull out of hole with fishing BHA and fish, lay down BHA, lay down fish 799.22' :(cuttoff jt with overshot, 24 jts+ 1 Reslink screen + 1.27' cutoff on jt #124, 24 hydraform centralizers, two freecaps). Note: Top offish (3-1/2" liner) @ 6571.49' + 799.22' = 7370.71' =top of jt # 124 left in the hole. Clean floor, pickup tools to the floor, make up dummy overshot assembly, run in the hole to 7245', PU wt 175k, SO wt 132k, Rot wt 150k w/8k ft Ibs of torque- 20 rpm. Obtain pump parameters: 20 spm w/ 70 psi, 30 s m = 70 si, 40 s m = 100 si, 50 s m = 160 si. Tri in hole slow and to to of 3-1/2" liner 7373.13'. 00:00 00:15 0.25 28 119 COMPZ FISH PULD T Finish making up BHA to fish 3-1/2" liner. 00:15 03:00 2.75 119 6,494 COMPZ FISH TRIP T Trip in the hole with 5" drill pipe to 6494' with overshot. PU wt 165k, SO wt 135k. 03:00 04:00 1.00 6,494 6,572 COMPZ FISH PULD T Pickup two singles, 31.79' then 31.85', follow with a 15.23' pup and a 5.01. Tag liner top @ 6574.78' swallow to 6577.11'. Set down 15k, icku to 178k on wt indicator. 04:00 04:15 0.25 6,572 6,572 COMPZ FISH SFTY T Pre job safety meeting. 04:15 07:15 .3.00 6,572 6,572 COMPZ FISH RURD T Rig up Schlumberger wireline. 07:15 09:30 2.25 6,572 6,572 COMPZ FISH ELNE T Run in the hole with wireline and 2-3/8" chemical cutter to 6828', pumped down @ 5 bpm w/ 1410 psi to .7479'. Pulled back up and cut liner at ~ 7371.4'. Cut liner jt # 124 a rox 2' below to of box. 09:30 15:15 5.75 7,371 0 COMPZ FISH TRIP T POOH with 5"drill pipe from estimated 7371" to Baker Overshot: Did not notice any overpull. PU wt 170k. Fluid losses a rox 8 b h. 15:15 15:45 0:50 0 0 COMPZ FISH TRIP T LD BHA and rig up GBR -. ~ c ... ', Tirne Lis - -_ --- _ - -- _ ---- - -- - -_ _ __ - - _ - ~ i Date From To Dur S,D~th E. DEpth Phase Code -_ Subcode_- T Comrl~ent _ __ _ 15:45 18:00 _ 2.25 0 0 COMPZ FISH TRIP T POOH with 25 jnts of liner and one Resinject Reslink screen. Lay down fish 799.22' :(cuttoff jt #149 with overshot 27.84', 24 jts+ 1 Reslink screen + 1.27' cutoff on jt #124 (left 29.96' in the hole) , 24 hydraform centralizers, two freecaps). Note: Top of fish (3-1/2" liner) was. @ 6571.49' + 799.22' = 7370.71' =top of jt # 124 left in the hole. Note: fluid losses from 0600 to 1800 hrs = 181 bbls of brine. 18:00 18:30 0.50 0 0 COMPZ FISH OTHR T Clean and clear rig floor. 18:30 19:00 0.50 0 0 COMPZ CASING RUNL T Pick tools to the rig floor. 19:00 19:30 0.50 0 0 COMPZ CASING SFTY T Pre job safety meeting 19:30 21:00 • 1.50 0 331 COMPZ CASING RUNL T Pickup BHA:-Make up the overshot assembl dumm run. 21:00 23:15 2.25 331 7,245 COMPZ CASING RUNL T Run overshot dummy assembly in the hole on 5"drill i e. 23:15 23:30 0.25 7,245 7,245 COMPZ CASING RUNL T Obtain parameters: PU wt 175k, SO wt 132k, Rot wt 150k w/ 8k ft Ibs of torque- 20 rpm. Pump 2 bpm w/ 70 psi-14% flowout, 3 bpm w/ 70 psi-16% flow out, 4 bpm w/ 110 psi-22% flow out, 5 bpm w/ 160 psi 27% flow out. 23:30 00:00 0.50 7,245 7,373 COMPZ CASING RUNL T Work down slow and tag top of 3-1/2" liner with cutlip guide of overshot 7373.13' with 4k. 12/14/2008 Pick up above top of 3-1/2" " D" lat liner, rotate down slow to 7373' w/ 20 rpm and 8k ft Ibs of torque. Rotating wt 150k. slack of to 7396' (should have no-go out at 7385.58'), saw a little bit of flicker on wt indicator @ 7382', but continued to 7396' along side of liner, pumped 20 spm with 50 psi-10% flow out, 30 spm w/ 80 psi-17% flow out. (not over liner). Picked up above top of liner, went down slow to 7386' w/ 8k setting down on no-go (Did not even see top of liner). Pumped 20 spm w/ 290 psi- 8% flow out,. confirming over liner. Picked up above liner again, tagged top @ 7313.13', picked up above top, rotated to 7313', slacked off and no-go again at 7386'. -Note: Did not see anything at the top of the SealBore Diverter, also did not see anything at the ramp going into open hole. Note: Cutlip guide to no go = 12.45' measured, packoff up .95' from cutlip guide (packoff to no go 11.49'). Monitor well, POOH, UD BHA, redress overshot with 3-1/2"grapple and mill control packoff, clean & clear floor, MU/RIH with tie in D lat liner assembly, RIH on 5" drill pipe to 7334', PU 175k, SO wt 130k, Rot wt 152k, work over linertop @ 7373 ;slack off to 7377, pull test to 10k over (185k, verify over liner), continue down to latch in RAM hanger w/ 40k (no indication of snap in), pull to 30k over, set down 55k on collet. Drop 29/32" ball to release RAM Hanger, pump down @ 3bpm, pressure to 2750 psi to ,release. Pull out of the hole laying down 5" drill pipe to 173', Lay down BHA and liner running tool. Remove Baker tools from floor. Pre job safety meeting on laying down 11 stands of 5"drill pipe and 62 stands of 4"drill pipe from the derrick. Lay down all 5", chap a elevators to la down 62 stands of 4" drill i e Time Loss Date From To Dur S D~th E. Depth Phase Code Subcode T Com,r~~ent-__ _ _ __- _ _ _ 00:00 00:45 0.75 7,373 7,386 COMPZ CASING RUNL T Pick up above top of 3-1/2" "D" lat liner, rotate down slow to 7373' w/ 20 rpm and 8k ft Ibs of torque. Rotating wt 150k. stack of to 7396' (should have no-go out at 7385.58'), saw a little bit of flicker on wt indicator @ 7382', but continued to 7396' along side of liner, pumped 20 spm with 50 psi-10% flow out, 30 spm w/ 80 psi-17% flow out (not over liner). Picked up above top of liner, went down slow to 7386' w/ 8k setting down on no-go (Did not even see top of liner). Pumped 20 spm. w/ 290 psi- 8%flow out, confirming over liner. Picked up above liner again, tagged top @ 7313.13', picked up above top, rotated to 7313', slacked off and no-go again at 7386'. Note: Did not see anything at the top of the SealBore Diverter, also did not see anything at the ramp going into open hole. Note: Cutlip guide to no go = 12.45' measured, packoff up .95' from cutli uide ackoff to no 0 11.49' . 00:45 03:30 2.75 7,386 331 COMPZ CASING RUNL T Pickup above top of liner, monitor well- losses of 9 bph. Pull out of the h ole on elevators. Monitor well on the trip tank. hole took 33 bbls over calculated for tri . 03:30 05:00 1.50 331 0 COMPZ CASING RUNL T Lay down BHA (Dummy tie into u er lateral . 05:00 05:45 0.75 0 0 COMPZ CASING OTHR T Inspect overshot. Saw signs of setting on liner top. Obtain pictures. Break and dress overshot with a 3-1 /2"grapple and mill control ackoff. Tor ue connections. 05:45 06:30 0.75 0 0 COMPZ CASING OTHR T Lay down Baker jars and Bumper sub. Pickup a Bumper sub for tie back run. Clean and clear ri floor. 06:30 08:15 1.75 0 294 COMPZ CASING RUNL T Make up liner tie in BHA, clean ma nets. 08:15 11:30 3.25 294 5,600 COMPZ CASING RUNL T Run in the hole with Liner tie in assembl from 294' to 5600'. - r ~5 _- n I Tirne L~ _ _ - - - - _ - Date From To Dur S Depth E_ Depth Phase Code Subcode T Comment _ _ __ " 11:30 13:15 1.75 5,600 11,473 COMPZ CASING RUNL P Continue to run in the hole with "D lateral tie in assembly f/ 5600' to 7334', obtained parameters: Up 175K/ Dn 130K, Rot wt 152k w/ 7k ft Ibs of torque. Pumping 3 bpm w/ 160 psi- 16% flow out. Continue RIH to 7373' tagging liner top with 4K. Rotate down with overshot to 737T. Pulled up with 185K to verify overshot engaged liner. Continued down to 7381 to latch RAM hanger into Seal Bore Diverter. Set down 40k on RAM Hanger, no noticeable latch in. Pull 30k over ,then set down 55k on collet.. 13:15 14:15 1.00 11,473 7,620 COMPZ CASING CIRC P Drop 29/32" ball to release Liner running tool, pumping @ 3 bpm with 160 psi-16% flow out. Ball landed and seated after 1050 strokes, pressured up to 2750 releasing liner running tool Note: Fluid losses from 0600 hrs to 1800 hrs: 86 bbls. 14:15 19:45 5.50 7,620 173 COMPZ CASING RUNL P POOH LD 5" DP from 7620'#0 173' 19:45 20:45 1.00 173 0 COMPZ DRILL PULD P LD liner running BHA. Total fluid lost on tri was 55 bbls over calculated. 20:45 22:00 1.25 0 0 COMPZ DRILL PULD P Lay down Baker tools from rig floor. Clear and clean floor. 22:00 22:15 0.25 0 0 COMPZ DRILL SFTY P Pre Job safety meeting on laying down drill i e from the derrick. 22:15 22:45 0.50 0 0 COMPZ DRILL PULD P Pickup mousehole, install in rotary table. Monitoring well on the trip tank. 22:45 23:45 1.00 0 0 COMPZ DRILL PULD P Lay down 11 stands of 5" drill pipe from derrick, usin the mouse hole. 23:45 00:00 0.25 0 0 COMPZ DRILL OTHR P Change elevators to 4". Then planning to lay down 62 stands of 4" dp from the derrick. Monitoring well on the tri tank. 12/15/2008 Lay down 62 stands of 4"drill pipe from the derrick, change handling tools, pre job safety meeting. Pickup/Make up/run in the hole with 33 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, pull out of the hole (change seal rings) stand back on the driller's side for the "D"lateral completion. Pickup/make up/ run in the hole with 143 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, service rig, continue to run in the hole with tubing a total of 231 joints (77 stands). Pull out of the hole 8 stands and stand back on the off driller's side for the mainbore completion. Shut down for weather- Phase III for entire Kuparuk field. Note: The wind died down after midnight thirty, Roads and pads was contacted as to the status and when the could clear the road to 3K ad. Will check back after 3 or 4 am. 00:00 05:15 5.25 0 0 COMPZ DRILL PULD P Lay down 62 stands of 4" dp from the derrick. Monitoring well on the trip tank. 05:15 05:45 0.50 0 0 COMPZ DRILL OTHR P Clean and clear rig floor. 05:45 07:00 1.25 0 0 COMPZ RPCOM RURD P Change out handling equipment to icku 3-1/2" tubin . Ri u GBR. 07:00 07:15 0.25 0 COMPZ RPCOM SFTY P Pre job safety meeting on picking up tubin . .~ Time Logs _ _ ~~ _- - _ _ _ S Depth E. Depth _Phase Code Subcode T_ Comment_ _ Date From To Dur _ 07:15 08:00 0.75 0 1,020 COMPZ RPCOM PULD P Pickup 33 joints of 3-1/2" 9.2 ppf L-80 IBT-m tubing, run in the hole. All tubing was drifted to 2.91 ". Monitor 6 b h losses on the tri tank. 08:00 08:45 0.75 1,020 0 COMPZ RPCOM TRIP P Pull out of the hole with 3-1 /2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on driller's side of derrick for L1 D lateral com letion. 08:45 13:15 4.50 0 4,428 COMPZ RPCOM PULD P Pickup/MU/RIH with 231, joints of 9.2 ppf L-80 IBT-m tubing for mainbore. All tubing was drifted to 2.91". Monitor 6 bph losses on the trip tank. 143 'ts icked u 13:15 14:45 1.50 4,428 4,428 COMPZ RIGMNT SVRG P Service rig. 14:45 16:00 1.25 4,428 7,168 COMPZ RPCOM PULD P Continue to pickup/MU/RIH with 231 joints of 9.2 ppf L-80 IBT-m tubing for mainbore. All tubing was drifted to 2.91". Monitor 6 bph losses on the tri tank. 16:00 16:30 0.50 7,168 6,417 COMPZ RPCOM TRIP P Pull oiat of the hole with 3-1 /2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on off driller's side of derrick for mainbore completion. 8 stands out of the hole. 16:30 00:00 7.50 6,417 6,417 COMPZ RPCOM WOW T Phase III weather in the entire Kuparuk field. Shut down operations on ri waitin on weather. 12/16/2008 Shut down for weather- Phase III for entire Kuparuk field. Road to 3K cleared and resumed work at 05:00 hours. Pull out of the hole with 3-1/2" tubing for mainbore and stand back on off driller's side of derrick. Total of 77 stands on the off driller's side to use on the main bore lateral. Single in hole with 261 joints of 3-1/2" tubing for D-Lateral completion. Pulled out of hole with tubing and racked back on driller's side. Shut down 2 hours for investigation and review of smashed finger incident. Chan ed out rams in BOP stack for dual com letion strip 00:00 04:45 4.75 6,417 6,_417 COMPZ RPCOM WOW T Shut down for weather- Phase III for entire Kuparuk field. Note: The wind died down after midnight thirty, checked back after 3 am. Roads and Pads are working the main roads; hoping to get to Phase II by shift change. Security says it is still bad from 1 Q back to the base camp. Security called 0437 hrs. Main roads are phase II, trying to get to phase I by 5 am. Roads and pads has already made a pass to 3K pad. Tourpusher called Roads & pads. Our road is good. Pre job safety meeting, then work will start 0500 hrs. ;~ ~ Time Los - - __ _ __ j ~ - - - -- -- - __ _ ~I Date From To Dur S Depth E._ Depth Phase Code Subcode T _ CommEnt _ 04:45 05:00 0.25 6,417 6,417 COMPZ RPCOM SFTY P Pre job safety meeting on trip out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, standing back on the off driller's side for the main bore. Chan a out seal rin s. 05:00 08:00 3.00 6,417 0 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on off driller's side of derrick for mainbore completion. Will be a total of 77 stands on the off driller's side to use on the main bore lateral. 08:00 14:00 6.00 0 7,068 COMPZ RPCOM TRIP P Pickup/MU/RIH with 231 joints of 9.2 ppf L-80 IBT-m tubing for D-Lateral. All tubing was drifted to 2.91". Monitor 5-7 bph losses on the trip tank. 14:00 16:45 2.75 7,068 270 COMPZ RPCOM TRIP P Pull out of the hole with 3-1/2" 9.2 ppf L-80 IBT-m tubing, change seal rings, stand back on driller's side of derrick for D-Lateral completion. Total of 87 stands on the driller's side to use on the D-Lateral. 16:45 18:45 2.00 270 270 COMPZ RPCOM SFTY T Shut down operatiors after crew members hand was pinched between elevators and stump. Man was taken to the medic for evaluation. Initial investigation by Doyon Safety, Tool usher and Com an Man. 18:45 19:15 0.50 270 0 COMPZ RPCOM TRIP P Resume POOH with D-lateral com letion strin . 19:15 19:30 0.25 0 0 COMPZ RPCOM RURD P Rig down handling equipment. 19:30 20:30 1.00. 0 0 COMPZ WELCTL BOPE P Pull wear ring, run test plug on 5" drill pipe and kelly up with top drive to hold test plug while changing rams. 20:30 23:00 2.50 0 0 COMPZ WELCTL ROPE P Change out upper and lower rams. Pull variables and install dual string rams. Crew change. Crew that was delayed b weather on 12/15 arrived at ri . 23:00 23:15 0.25 0 0 COMPZ WELCTL SFTY P PJSM -finish changing rams. 23:15 00:00 0.75 0 0 COMPZ WELCTL BOPE P Tighten rams doors. 12/17/2008 Test BOPE. Witness waived by AOGCC Lou Grimaldi. Run in hole with dual seal module and packer. Begin runnin dual tubin strip . 00:00 00:30 0.50 0 0 COMPZ WELCTL SFTY P PJSM -rigging up test equipment and test BOPE. 00:30 01:45 .1.25 0 0 COMPZ WELCTL BOPE P Pull 5"test joint leaving test plug ih hole. Fill stack with water and RIH with dual string test joint. Rig up test e ui ment Tirne L~ - - _ -_ - - -- _ _ Date From To - Dur S - -_ ~th D E. Depth Phase Code Subcude T C_or~iment _ _ - - 01;45 05:30 3.75 _ 0 0 C OMPZ WELCTt B OPE P Test BOPE. Tested upper and lower d ual rams, two floor safety values, choke manifold, blind rams, upper and lower IBOP. Total of 34 components tested. Hydril not t ested. Accumulator drawdown test starting pressure 3000 psi, after f unctioning values pressure 1500 psi, 55 seconds for 200 psi increase and 3 minutes, 18 seconds to full charge, 3050 psi. 5 bottle average pressure 2400 psi. Sim ops, brings tubing pups to rig floor. Witness waived by AOGCC Lou Grimaldi. -05:30 06:15 0.75 0 0 COMPZ WELCTL BOPE P Pull test plug, rig down test e ui ment and blow down lines. 06:15 06:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM -Rigging up long bails and 3-1/2"dual string handleing e ui ment. 06:30 08:15 1.75 0 0 COMPZ RPCOM RURD P Rig up long bails and 3-1/2" dual strin handlein a ui ment. 08:15 09:00 0.75 0 0 COMPZ RPCOM RURD P Clear and clean rig floor in preparation for tubing run. Grease upper and lower IBOP. Make up floor valves. 09:00 09:30 0.50 0 0 COMPZ RPCOM SFTY P Crew change, PJSM -running dual tubin strip . 09:30 13:00 3.50 0 110 COMPZ RPCOM RCST P Pick up and make up dual seal module and dual strip acker. 13:00 14:00 1.00 110 110 COMPZ RPCOM RURD P Move service loop in derrick for elevators due to hi h winds. 14:00 18:00 4.00 110 2,072 COMPZ RPCOM RCST P Run 3-1 /2"dual tubing string from derrick. Record weights and balance strip wei ht eve 5 stands. 18:00 00:00 6.00 2,072 4,900 COMPZ RPCOM RCST P Continue to Run 3-1/2"dual tubing string from derrick. Record weights and balance string weight every 5 stands. 12/18/2008 Run and land dual completion string. Attemp to set packer and could not build pressure in main bore. Begin trouble shooting, attempting to find leak path. Rig up slickline for trouble shooting. After midnight: Ran slickline to 6600' MD, pressured up to 1000 psi and held for 5 minutes. Pressure held. Pressured u several times to work i e, max ressure 1300 si. bin l t 1/2"d 00:00 05:30 5.50 4,900 7,288 COMPZ RPCOM RCST P g ua u Continue to Run 3- string from derrick. Record weights and balance string weight every 5 stands. PU wt 155k, So wt 112k 05:30 05:45 0,25 7,288 7,288 COMPZ RPCOM RCST P Snapped Dual Seal Module into collet and set down 10k. Snapped out of collet with 175k 05:45 06:30 0.75 7,288 7,238 COMPZ RPCOM RCST P POOH and stand back one stand from each tubing string. Rig up to um corrosion inhibited brine. hibited i i 06:30 09:00 2.50 7,238 7,238 COMPZ RPCOM CIRC P on n Pump 290 bbls corros brine from vac truck and displaced from tubing with 63 bbls from pits. Pum ed at 3 b m, 190 si. --- --- - _. _- . .~ Time Log -- - _ __ - I - - --- - _ From To Dur S. Depth _E__ Depth Phase Code Subcode T Comment_ _ _ _ ---- Date _ 09:00 .10:00 1.00 7,238 7,238 COMPZ RPCOM HOSO P Blow down lines, space out tubing string. Pups installed under 1st stand of tubin . 10:00 10:15 0.25 7,238 7,238 COMPZ RPCOM SFTY P PJSM -making up hanger and l andin 'oints. 10:15 12:00 1.75 7,238 7,238 COMPZ RPCOM RCST P Make up hanger and landing joints. Rig down slips and tongs, drain stack. 12:00 12:45 0.75 7,238 7,288 COMPZ RPCOM RCST P RIH with tubing hanger. Observed collect snap in. Set down 10k and picked up to 165k. Continue slacking off to shear Dual String Module, 38k down, continue slacking off to shear seal shroud, 16k down. Land han er. 12:45 14:30 1.75 0 0 COMPZ RPCOM RCST P Run in lock down screws and test hanger, good test. Lay down landing joints and installtwo-way check valves. Test to of han er, ood test. 14:30 15:00 0.50 0 0 COMPZ RPCOM PACK P Pull two-way check valve from main bore, close blind rams and pressure up to set packer.. Would not build pressure. Getting returns from annulus. 15:00 16:30 1.50 0 0 COMPZ RPCOM PACK T Install landing joint in main bore and pump down mainbore, still not building pressure. Pull two-way check from D-lateral and installed landing joint. Pumped down D-Lateral takin returns from annulus. 16:30 19:00 2.50 0 0 COMPZ RPCOM CIRC T Circulate dye marker down main bore to estimate location of leak path. Pumping 3 bpm, 280 psi. Stopped after 3252 strokes corrosion inhibited brine at surface and no dye to surface. Conference call with down to discuss options. Plan forward rig. up slickline, replace shear out valve in gas lift mandrel and run oor bo hole finder. 19:00 19:30 0.50 0 0 COMPZ RPCOM SFTY T PJSM -working around CI brine on rig floor. Review MSDS with mud en ineer. 19:30 20:00 0.50 0 0 COMPZ RPCOM CIRC T Rig up and pump down D-lateral tubing to obtain rates and pressures to compare with hanger/overshot run. 2 bpm / 340 psi, 3 bpm / 800 psi, 3.5 bpm / 1100 psi. Pumped total of 187 strokes. 20:00 21:15 1.25 0 0 COMPZ RPCOM SLKL T Spotting slickline unit, bring sheaves and wire to ri floor. 21:15 22:45 1.50 0 0 COMPZ RPCOM CIRC T Resume pumping down main bore looking for dye marker while rigging up slick line. Pumping 3 bpm / 280 .psi. Observed dye marker at shakers at 4700 strokes (calculated surface to surface 4420 strokes, with losses 5100 strokes . ---- - Tirne LocJs _ - Date From To_ Dur S Depth. E. De tp h Phase Code Subcode_ T Comment_ 22:45 00:00 1.25 0 0 COMPZ RPCOM SLKL T Rig up slickline tools and BOPE. 12/19/2008 Unable to pressure up on main bore, continue trouble shooting. Rig up slickline and run hole finder to 6600' MD. No leaks found. Make drift run with slickline to 7289' MD. Unland tubing strings and stroke pipe in attem t to seat main bore stin er in seals. No success. Be in ullin dual tubin strin . 00:00 01:15 1.25 0 0 COMPZ RPCOM SLKL T Rig up slickline tools and BOPE. 01:15 01:30 0.25 0 0 COMPZ RPCOM SLKL T slickline tools stacking out at tubing han er. 01:30 01:45 0.25 0 0 COMPZ RPCOM SLKL T PJSM -rigging down slickline BOP and tools, ullin landin 'oint. 01:45 02:45 1.00 0 0 COMPZ RPCOM SLKL T Rig down slickline BOP, pull main bore landing joint. ID=2.25", too small for any slickline tools. Pull Lateral landing joint. ID=2.98". Swap landin 'oints. 02:45 03:30 0.75 0 0 COMPZ RPCOM SLKL T Rig up slickline BOP and tools. 03:30 04:30 1.00 0 6,600 COMPZ RPCOM SLKL T Run hole finder to max depth and still be able to shear pin and activiate tool 04:30 05:15 0.75 6,600 6,600 COMPZ RPCOM SLKL T Pressure up to 1000 psi and hold for 5 minutes. Pressure held, no leaks from 0' to 6600' MD. Pressure up several times to try and elongate tubin . 05:15 06:00 0.75 6,600 0 COMPZ RPCOM SLKL T POOH with slickline. Stop on the way out of hole to pressure up on mainbore tubing; pumping past hole finder tool string. Pumped 3 bpm, 280 psi, not building pressure, getting returns up annulus. Pull slickline tools to surface. 06:00 08:45 2.75 0 0 COMPZ RPCOM SLKL T Waiting on Proactive Service Diagnostic Tools (PSD) caliper coming from Deadhorse. E-line on location. Discussing options with town. 08:45 12:00 3.25 0 0 COMPZ RPCOM SLKL T Make a drift run for caliper on slickline to 7289' MD. POOH and rig down slickline tools. 12:00 17:15 5.25 0 0 COMPZ RPCOM RCST T Rig up dual string handleing equipment and lines to pump down main bore. Back out lock down screws on tubing hanger and hobble one mud pump. Stroke tubing string 12' pumping while slacking off the first 6'. Reland hanger, run in lock down screws, test hanger and pump down main bore. Still not building pressure. Repeat process stroking 16', 1 T & 20'. No success. 17:15 18:00 0.75 0 0 COMPZ RPCOM RCST T Pick up on tubing string and unsnap Dual Seal Module. Reland DSM and han er. Retest. No success. 18:00 18:15 0.25 0 0 COMPZ RPCOM RURD T Rig down lines and prepare to pull tubin strin s. Time Logs _ _ I _-- - From To Dur S_ Depth EDepth Phase Code_Subcode T Comment __ _ Date _ 18:15 18:30 0.25 7,240 7,200 COMPZ RPCOM PULD T Pull tubing hanger to rig floor. No overpull observed when unsnapping Dual Seal Module. PU wt 155k, So wt 112k. 18:30 19:00 0.50 7,200. 7,200 COMPZ RPCOM SFTY T PJSM -laying down dual tubing han er 19:00 20:45 1.75 7,200 7,200 COMPZ RPCOM PULD T Lay down hanger and landing joints. 20:45 21:15 0.50 7,200. 7,200 COMPZ RPCOM PULD T Clear and clean rig floor. 21:15 21:45 0.50 7,200 7,200 COMPZ RPCOM SFTY T PJSM -pulling dual tubing string. 21:45 00:00 2.25 7,200 6,754 COMPZ RPCOM PULD T Pull 4 stands and 9 space out pups. PU wt 150k, SO wt 112k. 12/20/2008 Pull out of hole with dual completion string, racking tubing in derrick. Lay down dual packer and dual seal assembly. Change rams and test. Service rig. Rig up to run in hole with single tubing string with slick, dumm run. 00:00 00:30 0.50 6,754 6,754 COMPZ RPCOM SFTY T Stop and tliscuss job. What is going well, what can we do better. 00:30 06:00 5.50 6,754 4,200 COMPZ RPCOM PULD T POOH with dual tubing string, pups and jewelry. PU wt 125k, SO wt 110k. 06:00 12:00 6.00 4,200 150 COMPZ RPCOM PULD T POOH with dual tubing string to dual acker assembl . 12:00 12:45 0.75 150 150 COMPZ RPCOM PULD T Change out handleing equipment, clear and clean rig floor, rig up to lay down Baker DSM and Packer. 12:45 16:15 3.50 0 0 COMPZ RPCOM PULD T POOH with dual string packer, extension joints and dual seal module. Lay down tools and send to Deadhorse for servicing. Clear and clean ri floor. 16:15 17:00 0.75 0 0 COMPZ WELCTI EQRP T Change out one set of dual rams. Put sin le variables into ram cavi 17:00 18:30 1.50 0 0 COMPZ RIGMN7 SVRG P Slip and cut drilling line. 18:30 20:00 1.50 0 0 COMPZ RIGMN7 SVRG P Service topdrive, blocks and crown. Unhan blocks. 20:00 21:00 1.00 0 0 COMPZ WELCTL ROPE. T Rig up for BOP test, fill stack with water. 21:00 21:30 0.50 0 0 COMPZ WELCTL SFTY T PJSM -testing BOPE. Reviewed COP /Rowan 67 lockdown screw incident. 21:30 22:00 0.50 0 0 COMPZ WELCTL BOPE T Test variable rams and annular reventor. Good test. 22:00 22:45 0.75 0 0 COMPZ WELCTL BOPE T Pull test plug and set wear ring. 22:45 23:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM =rigging up 3-1/2" handling e ui ment with GBR. 23:00 23:45 0.75 0 0 COMPZ RPCOM RURD T Rig up handleing tools. 23:45 00:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM -making up slick stinger and tripping in hole from derrick. Reviewed DDI rocedures. 12/21 /2008 Run in hole with single tubing string with slick stinger and attempt to stab into mainbore seals in seal bore diverter with no success. Washed over seal bore diverter and made repeated attempts to stab into seals. Discussed options with town and decision made to run caliper tools to determine orientation of ram hanger. First cali er run was inconclusive. ~LL- _ - r' ,~~r ci; '~ i _... _. i Time Logs -- - -- _ ur S. Depth E Depth Phase Code Subcode _ T _Comment __ _ _ - D To Date Fror7i _ _ _ 00:00 00:15 0.25. 0 0 COMPZ RPCOM RURD T Cut and dress mule shoe on end of slick stin er for dumm run. 00:15 01:00 0.75 0 50 COMPZ RPCOM RCST T Pick up and run slick stinger, extension joint and "DS" nipple. Ad'ust bails. 01:00 05:30 4.50 50 7,312 COMPZ RPCOM RCST T RIH with 3-1/2" mainbore tubing string from off driller side. Attempt to stab stinger into seal bore diverter with no success. PU wt 112k, SO wt 98k 05:30 06:30 1.00 7,312 .7,312 COMPZ RPCOM CIRC T Wash over seal bore diverter slide, rotate pipe 1/4 turns, attempting to stab into seals. Pumped 5 bpm, 460 si. No success. 06:30 07:30 1.00 7,312 7,315 COMPZ RPCOM CIRC T Pickup single, RIH until tagged up in D-Lateral and set down 3k. Broke off single. Pumped 2 bpm / 110 psi, 3 bpm / 230 psi, 4 bpm / 410 psi, 5 b m / 710 si. 07:30 08:15 0.75 7,315 7,295 COMPZ RPCOM RCST T Work pipe attempting to stab into mainbore seals. Rotate pipe 1/8 turns. No success. 08:15 10:00 1.75 7,295 7,270 COMPZ RPCOM CIRC T Wash over seal bore diverter slide, Pumped 7 bpm / 830 psi, 10 bpm / 1540 psi. Conference call to discuss o tions 10:00 11:00 1.00 7,270 7,295. COMPZ RPCOM RCST T Attempt to Stab into mainbore seals, no success. 11:00 12:00 1:00 7,295 7,268 COMPZ RPCOM RCST T Rack back 1 stand, pick up 3 - 6' pups and single. Park in slips at top of ram han er. 12:00 12:15 0.25 7,268 7,268 COMPZ RPCOM SFTY T PJSM -rigging up slickline 12:15 15:00 2.75 7,268 7,268 COMPZ RPCOM SLKL T Rig up and RIH with slickline 2.824" swedge. Located DS nipple at 7235' WLM. Pumped swedge down from 6800' WLM. POOH with wireline tools. 15:00 15:45 0.75 7,268 7,268 COMPZ RPCOM SLKL T Pick up wireline memory caliper tools. 15:45 18:30 2.75 7,268 7,268 COMPZ RPCOM SLKL T RIH with caliper tools. Pumped: down from 6775' WLM. Wait for tool to activiate and caliper upper ram hanger. Observed 900# overpull when POOH with activiated Cali er. 18:30 19:15 0:75 7,268 7,268 COMPZ RPCOM SLKL T Lay down slickline tools. Download - data and send to Houston for evaluation. ' 19:15 23:45 4.50 7,268 7,268 COMPZ RPCOM WOOR T Waiting on caliper log evaluation. Discuss options with town. Crew workin on PMs and cleanin ri . 23:45 00:00 0.25 7,268 7,268 COMPZ RPCOM SLKL T Caliper log inconclusive. Bad data when tools hung up down hole. Decision made to make another attempt to log upper ram hanger helix. Tirne LocJs ,' ! Date From To Dur __ _S Depth E._Depth Phase Code SubcodeT _Gomrnent _ __ 12/22/2008 z4 hr Summary Make 2 slickline runs and record four caliper logs of ram hanger helix. Discuss options for plan fornrard with town. Ri u and be in ullin dumm tubin strin with slick stin er. 00:00 02:45 2.75 7,268 7,268 COMPZ RPCOM SLKL T Finish rigging up slickline caliper tools and RIH, pumping down at 4 bpm from 6600' WLM. Set tool on depth and POOH across hanger to check for hangups. One of three. passes hung up. Set tool on depth, 7298' WLM, and wait for caliper to activiate. Sim ops: crew cleaning rig, BOP stack, pits and pipe shed. Continue workin on PMs: 02:45 03:45 1.00 7,268 7,268 COMPZ RPCOM SLKL T POOH with slickline logging upper ram hanger. Tools hung up and pulled 450# over. Determined later that overpull was the result of the upper centralizer entering to tubing tail. 03:45 04:15 0.50 7,268 7,268 COMPZ RPCOM SLKL T Breakout slickline tools. Download data and sent to Houston. 04:15 05:45 1.50 7,268 7,268 COMPZ RPCOM WOOR T Waiting on caliper log evaluation. Caliper log better than first run but not good enough to see helix. Discuss options with town. Decision made to make another slickline run. Tool will be programmed to make multiple passes without coming out of hole. Sim ops: crew cleaning rig, working PMs and ins ectin au er bearin s. 05:45 06:15 0.50 7,268 7,258 COMPZ RPCOM SLKL T Pick tubing string up so that tubing tail is 10' above ram hanger top. This will make room for the calliper and centralizers to exit the hanger top before enterin the tubin tail. 06:15 07:30 1.25 7,258 7,258 COMPZ RPCOM SLKL T Make up slickline tool string. slickline crew than ed out. 07:30 11:00 3.50 7,258 7,258 COMPZ RPCOM SLKL T RIH with caliper tool pumping down from 6200' WLM. Wait for tool to activiate and made three logging asses before POOH. 11:00 12:00 1.00 7,258 7,258 COMPZ RPCOM SLKL T Breakout slickline tools, download- data and send to Houston. 12:00 16:15 4.25 7,258 7,258 COMPZ RPCOM WOOR T Waiting on caliperlog evaluation. Caliper log shows hanger properly oriented. Sim ops: loading pipe shed with 5" drill i e and ri u to ull tubin . 16:15 16:45 0.50 7,258 7,258 COMPZ RPCOM SFTY T PJSIVI -rigging down slickline, BOPE, sheaves and sending tools down beaver slide. 16:45 17:45 1.00 7,258 7,258 COMPZ RPCOM SLKL T Rig down slickline. __ - g:. ; 3 • Tirne Low E. De th Phase Code__Subcode _T _ Cori~ment_ 'Date From To Dur S Depth _ 17:45 18:00 0.25 7,258 7,258 COMPZ RIGMNT SFTY T PJSM -replacing camera in derrick 18:00 19:00 1.00 7,258 7,258 COMPZ RIGMNT RGRP T Install new camera in derrick. 19:00 21:00 2.00 7,258 7,258 COMPZ RPCOM WOOR T Inspect and service drawworks and to drive. Clear and clean ri floor. 21:00 21:45 0.75 7,258 7,258 COMPZ RPCOM RURD T Rig down long bails, rig up and ad'ust short bails for ullin tubin . 21:45 22:00 0.25 7,258 7,258 COMPZ RPCOM SFTY T PJSM -pulling tubing and racking back in derrick. 22:00 00:00 2.00 7,258 4,749 COMPZ RPCOM PULD T POOH with 3-172"tubing with slick stin er. 12/23/2008 Pulled out of hole with slick stinger racking back tubing. Sent stinger extension joint to Deadhorse to be bent. Ran in hole with slick stinger, extension joint and MWD. Stabbed into seals and pressure tested good. Pulled out of hole. 00:00 02:45 2.75 4,749 0 COMPZ RPCOM PULD T POOH with 3-1 /2" tubing with slick stinger. Break out slick stinger extension joint and hot shot to Baker Production to be bent. 02:45 09:15 6.50 0 0 COMPZ RPCOM WOEQ T Extension joint being bent. Crew _ servicing rig, change oil in top drive and iron rough neck, inspect-saver sub and powerwash top drive. Work on PMs 09:15 09:45. 0.50 0 0 COMPZ RPCOM SFTY T PJSM -picking up and making up slim hole MWD strin . 09:45 11:45 2.00 0 175 COMPZ RPCOM PULD T Pick up stinger, bent extension joint and MWD. 11:45 12:45 1.00 175 175 COMPZ RPCOM CIRC T Rig up and circulate for shallow pulse test of MWD. Pump 110 gpm, 230 si. Good test. 12:45 17:00 4.25 175 7,283 COMPZ RPCOM RCST T TIH with 3-1 /2" tubing from derrick. PU wt 110k. SO wt 98k. 17:00 17:45 0.75 7,283 7,283 COMPZ RPCOM RURD T Rig up to circulate and orient bent 'oint for stabbin seal bore diverter. 17:45 19:30: 1.75 7,283 7,300 COMPZ RPCOM CIRC T String at 135L, rotate to 152R and attempt to stab stinger into seals. No joy. Rotate tubing to 175R, slacked off and stabbed into seals on depth. Continue slacking off until began stacking weight. Tested seals with 2500 psi. Good test. Pick up and stab stinger second time to confirm de ths. All ood. 19:30 20:15 0.75 7,300 7,300 COMPZ RPCOM RURD T Rig down and blow down lines. Rig u 3-1 /2" handlin tools. 20:15 20:30 0.25 7,300 7,300 COMPZ RPCOM SFTY T PJSM -POOH with slick stringer, bent'oint and slim hole MWD. 20:30 00:00 3.50 7,300 100 COMPZ RPCOM PULD T POOH with 3-1 /2" tubing racking back in derrick. 12/24/2008 Layed down MWD, bent extension joint and slick stinger. Changed rams and tested with dual tubing test 'oint. Ri u and run Dual Seal Module, Extension Joints and Dual Packer followed b 69 stands of tubin . 00:00 00:15 0.25 100 100 COMPZ RPCOM SFTY T PJSM -laying down MWD, extension 'oint and slick stin er .00:15 02:00 1.75 ' .100 0 COMPZ RPCOM PULD T Lay down BHA, handling tools and clear ri floor. ., ,. ~ , . t ... ~ "- - _ _ Time-L~s_ _ __ _ _ _ -- - Dur S Depth E, nth Phase Coue SubcodE T _ Comment _ __ _ From To D ate _ _ _ _ _ _ 02:00 02:30 0.50 0 0 COMPZ WELCTL OTHR T Pull wear bushing and set test plug. 02:30 02:4fi 0.25 0 0 COMPZ WELCTL SFTY T PJSM -changing upper pipe rams 02:45 03:45 1.00 0 0 COMPZ WELCTL OTHR T Change upper pipe rams to dual 3-1 /2" 03:45 04:15 0.50 0 0 COMPZ WELCTL BOPE T Rig up BOPE test equipment, run 3-1 /2"dual strip test'oint. 04:15 05:45 1.50 0 0 COMPZ WELCTL BOPE T Test upper pipe rams with dual string test joint. Troubleshoot leaking test lu . 05:45 07:15 1.50 0 0 COMPZ WELCTL OTHR T Rig down test equipment, pick up stack washer and wash stack. 07:15 08:00 0.75 0 0 COMPZ WELCTL OTHR T Grease upper and lower IBOPs, rease drawworks. 08:00 09:00 1.00 0 0 COMPZ WELCTL BOPE T Install test plug and run dual string test 'oint. 09:00 09:30 0.50 0 0 COMPZ WELCTL BOPE T Test top rams, 250 psi low, 3000 psi hi h 09:30 10:15 0.75 0 0 COMPZ WELCTL BOPE T Rig down test equipment and blow . down lines 10:15 10:30 0.25 0 0 COMPZ RIGMNT SFTY T PJSM -working on camera in derrick 10:30 11:00 0.50 0 0 COMPZ RIGMNT RGRP T Troubleshoot camera in derrick, no success 11:00 11:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM -rigging up long bails and dual strip handlin a ui ment 11:15 13:00 1.75 0 0 COMPZ RPCOM RURD T Rig down short bails and rig up long bails. Rig up dual string handling tools. 13:00 13:30 0.50 0 0 COMPZ RPCOM SFTY T PJSM -running Dual Seal Module, Extension Joints and Dual Packer. 13:30 18:00 4.50 0 115 COMPZ RPCOM RCST T Pick. up and run Dual Seal Module, Extension Joints and Dual Packer. 18:00 18:15 0.25 115 115 COMPZ RPCOM SFTY T PJSM - TIH with dual tubing string from derrick. 18:15 00:00 5.75 415 2,400 COMPZ RPCOM RCST T TIH withdual tubing string. 12/25/2008 Ran dual tubing string to TD. Spaced out, spotted corrosion inhibited brine and landed tubing strings. Made quick pressure test of mainbore seals, pressure held, seals engaged! Ate Christmas Dinner. Attempted to seal dual packer with no success. Troubleshooting packer setting, discuss options with town. (Packer set and tested at 02:00, 12/26 00:00 06:00 6.00 2,400 6,829 COMPZ RPCOM RCST T Trip in hole with dual production tubing, up weight 145k, down weight 112k, balance string weights every 5 dual stands 06:00 08:30 2.50 6,829 7,236 COMPZ RPCOM RURD T Trip in hole with dual production tubing, up weight 155k, down weight 110k, balance string last time before sna in into collet 08:30 09:45 1.25 7,236 7,281 COMPZ RPCOM HOSO T Snap in to RAM Hanger Collett at 7281 ft with 8k Ibs down, 150k Ibs over ull to 170k to sna out 09:45 11:00 1.25 7,281 7,251 COMPZ RPCOM HOSO T Pull from 7281ft to 7143 ft, add in 4 pups (22.95' in B Main String) and 5 pups (22.46' D Lateral) below one stand on both strip s i • ~~ Time Logs - --- --- - -- -- -- ~ I From To Dur S Depth_E. Depth Phase Code Subcode T Comment - __ ~~ Da te _ _ 11:00 12:15 1.25 7,251 7,251 COMPZ RPCOM OTHR T Rig to pump corrosion inhibited brine down main tubin and u annulus 12:15 14:15 2.00 7,251 7,251 COMPZ RPCOM CIRC T Pump 290 bbls corrosion inhibited brine @ 3 bpm displaced with 63bbls brine down main tubing, 240psi, 31 bbls lost ast 6 hours 14:.15 14:30 0.25 7,251 7,251 COMPZ RPCOM OTHR T Rig down circulating head and blow down lines. 14:30 14:45. 0.25 7,251 7,251 COMPZ RPCOM SFTY T PJSM -picking up and making up dual tubin han er 14:45 16:15 1.50 7,251 7,251 COMPZ RPCOM RCST T Pick up and make up dual string han er. 16:15 16:45 0.50 7,251 7,288 COMPZ RPCOM HOSO T Snap DSM into Ram Hanger 17 ft in, set down 8k, pull to 163k (8k over up weight to confirm latch), slack off to shear DSM (28k), slack off 1T and observed lateral shroud shear. Set down last 3' and landed han er. 16:45 17:15 0.50 7,288 7,288 COMPZ RPCOM DHEQ T Run in 4 Lock Down screws, rig up and test main bore tubing seals to 500psi, 15 minutes, pressure held, charted test. 17:15 18:00 0.75 7,288 7,288 COMPZ RPCOM DHEQ T Run in all lock down screws, test hanger body seals to 5000 si/10minutes, ood test. 18:00. 18:15 0.25 0 0 COMPZ RPCOM SFTY T PJSM -pulling landing joints and settin two wa check valves. 18:15 20:00 1.75 0 0 COMPZ RPCOM DHEQ T Pull landing joihts, install Vetco two way check valves, rig down tubing handlin a ui ment, clean mud its 20:00 20:45 0.75 0 0 COMPZ RPCOM RURD T Rig up to test tubing hanger metal seals. 20:45 21:15 0.50 0 0 COMPZ RPCOM DHEQ T Close blind rams and pressure test tubing hanger to 5000psi/10 minutes. ood test. 21:15 21:30 0.25 0 0 COMPZ RPCOM DHEQ T Pull two way check valve from mainbore tubin . 21:30 21:45 0.25 0 0 COMPZ RPCOM DHEQ T Close blind rams and pressure up on mainbore tubing to 1000 psi and hold for 5 minutes. Pressure held, good test. 21:45 00:00 2.25 0 0 COMPZ RPCOM PACK T Continue pressuring up to 3000 psi and hold for 15 minutes to set packer. Bleed tubing pressure to 1500 psi and pump down annulus. Not building pressure in annulus, packer not set. Pressure mainbore tubing to 4000 psi and hold 15 minutes. Bleed down to 1500 psi and pump down annulus. Packer not set. Pressure up on tubing to 4000 psi and pump down annulus, not building pressure. Discuss options with town. Recheck surface equipment. Continue troubleshootin . 12/26/2008 Set dual string packer, then two way check valves. Change upper and lower pipe rams, reorient BOP stack and set on stum . Ni le u and test tree. ~___. _ ~. 1_~ ~. ~ n ~ P • Time Logs - ---- - From To Dur S Depth E- Depth Phase Code Subcode - T _ Con~n~ent _ ~~ Date _ 00:00 02:00 2.00 0 0 COMPZ RPCOM PACK T Packer not setting, continue troubleshooting. Checking surface equipment. Discuss options with town. Surge pumps to 3600 psi and bleed off rapidly. Restest annulus, holding pressure. Test annulus to 2500 psi with 1500 psi on mainbore tubiri .Good test. 02:00 02:15 0.25 0 0 COMPZ RPCOM PACK P Rig down test equipment and blow down lines. 02:15 02:45 0.50 0 0 COMPZ RPCOM SFTY P PJSM -setting two way check valve in mainbore and ri in down lines. 02:45 03:00 0.25 0 0 COMPZ RPCOM RCST P Set two-way check in mainbore tubing hanger. Offset two-way check in D-Lateral to check for ressure. 03:00 03:15 0.25 0 0 COMPZ WELCTL SFTY P PJSM -changing upper & lower pipe rams. 03:15 06:30 .3.25 0 0 COMPZ WELCTL OTHR P Change out upper and lower pipe rams. 06:30 07:00 0.50 0 0 COMPZ WELCTL SFTY P PJSM -nipple down stack, rotating mud cross. 07:00 09:30 2.50 0 0 COMPZ WELCTL NUND P Nipple down riser, flow line, bell nipple and turnbuckles. Break bolt on mud cross., Cleanin rockwasher. 09:30 10:00 0.50 0 0 COMPZ WELCTL SFTY P PJSM -picking up stack and rotating mud cross. 10:00 11:30 1.50 0 0 COMPZ WELCTL NUND P Pick up stack and rotate mud cross. 11:30 12:00 0.50 0 0 COMPZ WELCTL OTHR T Clean up diesel spilled inside rig from heater tank vent line. 12:00 15:30 3.50 0 0 COMPZ WELCTL NUND P Tighten breaks on mud cross, pick u stack and rack back on stum . 15:30 16:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM -picking up and nippling up tree 16:00 17:30 1.50 0 0 COMPZ RPCOM NUND P Pick up and nipple up tree. 17:30 19:15 1.75 0 0 COMPZ RPCOM DHEQ P Rig up and test seal between wellhead and tree, 250 psi low / 5000 high. Hold each for 10 minutes. Good tests. 19:15 19:45 0.50 0 0 COMPZ RPCOM RURD P Rig up to test tree. 19:45 20:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM -flooding and. testing tree. 20:00 20:30 0.50 0 0 COMPZ RPCOM DHEQ P Flood D-Lateral side of tree with diesel from Little. Red Services. Test to 250 psi. Rig up and flood B-Lateral (mainbore). Actuator valve leaking. Stop operation. Vetco calling su ervisor. 20:30 21:45 1.25 0 0 COMPZ RPCOM NUND T Rig down and lay down D-Lat actuator, make up flange to tree. Flood D-Lat side of tree. 21:45 22:30 0.75 0 0 COMPZ RPCOM DHEQ P Test B-Lat tree to 5000 psi, good test. Test D-Lat to 250 psi 15000 psi. Tree cap leaked on 5000 psi test. 22:30 23:00. 0.50 0 0 COMPZ RPCOM DHEQ T Change out O-ring in tree cap. • Time LocJs __ - - Date From To Dur S Depth E. D~h_Phase Code Subcode T CommEnt _ _ _ __ 23:00 23:45 0.75 0 0 COMPZ RPCOM DHEQ P Test B-Lat, mainbore, side of tree 250 si / 5000 si. Good test. 23:45 00:00 0.25 0 0 COMPZ RPCOM NUND T Changed out short stud between tree and wellhead. Retest void 250 psi / 5000 si. Good test. 12/27/2008 Test tree, freeze protect well, set back pressure valves and move off well RIG RELEASED AT 13:00 00:00 02:30 2.50 0 0 COMPZ RPCOM FRZP P Nipple up lubricator and pull two-way check valve from mainbore. Turn tree cap flange to line up tree cap with D-Lateral tubing. Nipple up lubricator and ull twi-wa check from D-Lat. 02:30 03:00 0.50 0 0 COMPZ RPCOM FRZP P Rig up for freeze protecting well.. 03:00 03:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM -shearing out gas lift mandrel and freeze rotectin well. 03:15 06:30 3.25 0 0 COMPZ RPCOM FRZP P Sheared out valve at 1600 psi and pumped 163 bbls @ 1 bpm down the annulus taking returns up the mainbore tubing. Circulated until diesel seen at surface. Rig down from mainbore and rig up on D-Lat tubing. Bullheaded 25 bbls of diesel down D-Lat tubing at 1 bpm. Sim ops: rig up and begin laying down tubin from derrick. 06:30 07:00 0.50 0 0 COMPZ RPCOM FRZP P Rig dowh from freeze protect and blow down lines. Sim ops; cleaning its. 07:00 11:00 4.00 0 0 COMPZ RPCOM NUND P Rig up lubricator and set Back Pressure Valve in D-Lat tubing. Rotate tree cap and install BPV in mainbore tubin . 11:00 12:00 1.00 0 0 COMPZ RPCOM SFEQ P Test tree cap 250 psi / 5000 psi, ood test. 12:00 13:00 1.00 0 0 COMPZ RPCOM RURD P Re-install gauges on tree, clean cellar box and record final pressures (mainbore tubing O psi, D-Lateral tubing 200 psi, (9-5/8' x tubing annulus 0 psi, 12-1/4" x 9-5/8" annulus 120 psi). RIG RELEASE 13:00 -- _ SARAH PAL/N, GOVERNOR Chip Alvord Drilling Team Leader ConocoPhillps Alaska, Inc. PO Box 100360 Anchorage, Alaska 99510 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 3K-108L1 ConocoPhillps Alaska, Inc. Permit No: 208-133 Surface Location: 1473' FSL, 319' FWL, Sec. 35, T13N, R9E, UM Bottomhole Location: 994' FNL, 238' FEL, Sec. 36, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. The permit is approved subject to full compliance with 20 AAC 25.055 and CO 406B. Approval to drill the well to the intended Bottomhole location and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. ConocoPhillips assumes the liability of any protest to the spacing exception that may occur. The permit is for a new wellbore segment of existing well KRU 3K-108 permit No 208-133, API 50-029- 2339500-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt yott from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, ~r~ Daniel T. Seamount, Jr. T1 Chair DATED this r ~ day of August, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS ~~ PERMIT TO DRILL 20 AAC 25.005 f I Pn 1a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Multiple Zone^ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: / Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 3K-108L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 13114' ND: 3629' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1473' FSL, 319' FWL, Sec. 35, T13N, R9E, UM 7. Property Designation: ADL 25519 West Sak Oil Pool Top of Productive Horizon: 303' FNL, 910' FEL, Sec. 35, T13N, R9E, UM 8. Land Use Permit: ALK 2555 13. Approximate Spud Date: 8/23/2008 Total Depth: 994' FNL, 238' FEL, Sec. 36, T13N, R9E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 238' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 529306 y- 6008466 Zone- 4 10. KB Elevation (Height above GL>: 40' AMSL feet 15. Distance to Nearest Well within Pool: 3K-102L1 , 1179' @ 1393<. 16. Deviated wells: Kickoff depth: 7094 ft. Maximum Hole Angle: 94° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1764 psig Surface: 1360 psig 18. Casing Program ifi ti S Setting Depth Quantity of Cement Size ons pec ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 40" 20" x 34" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCRETE 16" 13.375" 68# L-80 BTC 3500' 40' 40' 3500' 2287' 700 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 7688' 40' 40' 8400' 3944' 590 sx DeepCRETE 6.75" 3.5" 9.3# L-80 SLHT 6021' 7093' 3459' 13114' 3629' screens, no cement 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ^ BOP Sketch Drilling Program Q Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Winfree @ 265-6820 Printed Name Chip Alvord Title Drilling Team Leader Signature ~~ ~~ ~~ ~+ ~• . Q I~,~ Phone Z G ~ .G y 0 cf Date ~.~~ Zl ~ P Y-~+ /1 h n All k Commission Use Only Permit to Drill p Number: ~a(/ IJ.~~ API Number: 50-~aq~,~~95 ~Od Permit A proval Date: ~ • ~ • og See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: Samples req'd: Yes ^ No L~K-Ir Mud log req'd: Yes ^ No Other: ~~ V ~ ~` ~ ~~7 ~5~ H2S measures: Yes ^ No [/~ Dire ionwy req'd: Yes ~ No ^ V `~Z o~ti~ ~~CU.~~Ov~.~+nQCCb~ L At©~~ , ] ~ ~ APPROVED BY THE COMMISSION LI DA ,COMMISSIONER Form 10-401 Revised 12/2005 ~ 6 ~ ~~~ (~ ~',~ # ~ s •p Supmit in Duplicate Appli~r Permit to Drill, Well 3K-108L1 Revision No.0 Saved: 12-Aug-08 Permit It -West Sak Well #3K-108L1 r.w wt Application for Permit to Drill Document ~--~ ~ ~I ~m a 1Noll Vafuo Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (f) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ...................................................................................3 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing 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. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 5 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10. Seismic Analysis ..................................................................................................... 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 Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 `*,~+' ~ '~' ~ Oat Y ~..+. 3K-108L1 PERMIT IT.doc Page 1 of 6 Printed: 12-Aug-08 Applic~for Permit to Drill, Well 3K-108L1 Revision No.O Saved: 12-Aug-O8 13. Proposed Drilling 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 .................................................................................................................. Attachment 2 Drilling Hazards Summary ................................................................................................. Attachment 3 Doyon 15 West Sak 3ksi BOP Configuration ........................................................ Attachment 4 Well Schematic ................................................................................................................. Attachment 5 Quarter mile radius Injector effects ..................................................................... 1. Well Name Requirements of 20 AAC 25.005 (i) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(6). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 3K-108L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the. commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at total depth; Location at Surface 1473' FSL 319' FWL, Section 35 T13N, R09E ASP Zone 4 NAD 27 Coordinates RKB Elevation 74.3' AMSL Northings 6,008,466' Eastings: 529,306' Pad Elevation 34.3' AMSL Location at Top of Productive Interval 303' FNL, 910' FEL, Section 35, T13N, R09E West Sak "D" Sand ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 7,091' Northings: 6,011,988' Eastings: 533,339' Total Vertical De th RKB: 3 459' Total Vertical De th, SS: 3,384' Location at Total De th 994' FNL, 238' FEL Section 36, T13N R09E ASP Zone 4 NAD 27 Coordinates Measured De th RKB: 13 114' Northings: 6,011,326' Eastings: 539,294' Total Vertical De th, RKB: 3,629' Total Vertical De th, SS: 3,555' and (D) other information required by 20 AAC 25.050(6); 3K-108L1 PERMIT IT.doc Page 2 of 6 Printed: 12-Aug-08 • Applic~for Permit to Drill, Well 3K-108L1 Revision No.0 Saved: 12-Aug-08 3K-108L1 will require a spacing exception as the toe of the lateral is planned 238' from the Milne Point lease line. A formal request for this spacing exception has been subimtted separately from this drilling permit application. Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-40i) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan 3K-108L1 and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 3K-108L1. For all drilling, casing and liner operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 9-5/8" rams in the lowermost cavity. For the dual 3-1/2" completion operations the stack will be equipped with dual 3-1/2" rams in the uppermost ram cavity, blind rams in the middle cavity, and dual 3-1/2" rams in the lowermost cavity. The additional set of dual 3-1/2" rams is required since the Annular preventer will be ineffective while running dual 3- 1/2" strings simultaneously. See attached diagram entitled "Doyon IS West Sak 3ksi BOP Configuration" Upon initial nipple up and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 9-5/8" OD. Prior to running the dual 3-1/2" completion, a test plug will be installed below the lower most rams, the upper and lower ram cavities will be equipped with dual 3-1/2" rams and tested to 3,000 psi. Please see information on the Doyon Rig 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 3K area are 0.48 psi/ft, or 9.0 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "B" sand formation is 1,360 psi: 3K-108L1 PERMIT IT.doc Page 3 of 6 ("'ti (`~ ~ ~ ~ J~ Printed: 12-Aug-08 MPSP = (3,675 ft TVD)(0.48 - 0.11 psi/ft) = 1,360 psi (e) data on potential gas zones; The well bore is not expected to penetrate any gas zones. Appli~for Permit to Drill, Well 3K-108L1 Revision No.O Saved: 12-Aug-08 and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 3K-108L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f); The parent wellbore 3K-108 will be completed with a 9-5/8" intermediate casing landed in the West Sak B sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. No formation integrity test will be performed in the drilling of the 3K-108L1 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summa Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (Ib/ft) Grade Connection ft (ft) (ft Cement Pro ram 3-1/2 blank With ResInjeCt 6-3/4" D Sand Lateral (3K-108 Ll) 9.3 L-80 SLHT 6,021' 7,093/ 3,459 13,114'/ 3,629' Screens - no cement screens 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); No diverter system will be used during 3K-108L1 operations. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the D lateral interval: 3K-108L1 PERMITIT.doc Page 4 of 6 Printed: 12-Aug-OS ~~~~~~~ ~'' 4..E ~; ~., Appli~for Permit to Drill, Well 3K-108L1 Revision No.0 Saved: 12-Aug-O8 Lateral Mud Program (MI VersaPro Mineral Oil Base) B 8~ D sand laterals Value _ Densit ( ) 9.0 - 9.3 Plastic Viscostiy 15 - 25 (Ib/100 std Yield Point 15 - 20 (cP) HTHP Fluid loss (ml/30 min @ <4.0 200 si & 150° Oil /Water Ratio 70 / 20 Electrical 650 - 900 Stabili Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 15. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 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 application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematic. ~~t~"~~~~~~~ 3K-108L1 PERMITIT.doc Page 5 of 6 Printed: 12-Aug-08 Applir~or Permit to Drill, Well 3K-108L1 Revision No.O Saved: 12-Aug-08 Note: Previous operations are covered under the 3K-108 Application for Permit to Drill. Run and set Baker Gent WindowMaster whipstock system, at window point of +/- 7,094' MD / 3,459' TVD, the top of the D sand. 2. Mill 8-1/2" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD, MWD, PWD and rotary steerable tool. RIH. 4. Drill to TD of D sand lateral at +/- 13,114 MD / 3,629' TVD, as per directional plan. 5. Circulate 4 bottoms up with reciprocation and rotation. Open up PBL circulation sub and circulate 9-5/8" casing clean at increased flowrates for 4 bottoms. Close circ sub & displace to clear weighted brine. Pump out of Hole if necessary. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. RIH and set Baker Seal Bore diverter 8. PU and run 3-1/2" blank liner, ResInject screens and TAM swell packers with Baker Oil Tools RAM Hangar system. 9. Land Baker RAM hanger in Baker seal bore diverter. Release hanger running tool. POOH laying down drill pipe as required. 10. PU 3-1/2" Baker dual seal module, dual GT packer and dual 3-1/2" injection completion and RIH to depth. Land tubing. Set BPV 11. Nipple down BOPE, nipple up tree and test. Pull BPV. 12. Freeze protect well with diesel by pumping into 3-1/2" x 9-5/8"annulus, taking returns from tubing and allowing to equalize. (If the schedule and equipment availability allows, the Wells Group will freeze protect the well post rig). 13. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 3K Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 3K Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future 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 Doyon 15 West Sak 3ksi BOP Configuration Attachment 4 Well Schematic Attachment 5 Quarter mile radius Injector effects 3K-108L1 PERMIT IT.doc Page 6 of 6 ~.,.~~ ~ ` ~ ~ ~ Printed: 12-Aug-OS • • ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-108 (E12) -Slot 3K-108* Staked 3K-108 L1 Plan: 3K-108 L1 (wp09) Standard Proposal Report 27 June, 2008 .~,-<,., 1~4,AL.t,.i E3lJ E'3Tf~ N Sperry G~tliing ~ervicos Sryarry Orirlrng 8orviass 750 100D 1250 1500 1750 c 2000 0 '"' 2250 L Q N ~ 2500 m U 1= ~ 2750 m H 3000 3500 Project: Kuparuk River Unit WELL DETAILS: Plan 3K-108 (El2) NAU 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 3K Pad Grou nd Level: 34 .30 Well: Plan 3K-108 (E12) +N/-S +E/-W Northing Fasting latiltude Longitude Slot Wellbore: 3K-108 L1 0.00 0.00 6008466.45 529306.39 70° 26' 3.151 N 149° 45' 39.919 W 3K-108* Stakes Design: 3K-108 L1 (wp09) FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 1586.01 1511.71 1773.90 T3 1655.15 1580.85 1892.83 PFrost 1804.20 1729.90 2195.13 K15 2414.21 2339.91 3843.36 T3+g00 2811.41 2737.11 4917.81 Ugnu C 3061.64 2987.34 5594.71 Ugnu B 3213.79 3139.49 6031.79 Ugnu A 3323.89 3249.59 6409.51 N 3458.99 3384.69 7091.87 WSak D CASING DETAILS TVD TbDSS MD Size Natue 2414.22 2339.92 3843.38 13-3/8 13 3/8" 3459.31 3385.01 7093.71 9-5/8 9 5/8" TOW 3629.30 3555.00 13114.05 3-1/2 31/2" 9 5/8" TOW @ 7094' MD, 3459' ND: 303' FNL, 910' FEL - Sec35-T13N-R09E BHL @ 13114' MD, 3629' ND: 994' FNL, 238' FEL - Sec36-T13N-R09E Ugnu A ,N ,~ -o- -------------- ----------- -_~-0-_0--~--------------- O -_---0_-__--d--__ ~ --- ~ -_--D-_-__-o--_-_ -_--Q-Y\~-__----_---____ -_ -~-.Q - ~_/---------- ---- - ~ _-_~ -~-- _ -- ~ - O_ - -O 0 .N- - ~ l~ O c~- -~_ ~ ~ _ _ _ - - - _ ~- _ _ - ~ - - _ _ _ ~ - - - _ _ fl ~ _ ' o0 3K 108 L1 (wp09) WSak D ~ 3750 4000 9 5/8° TO 4500 4750 o i i i i I ~ i i i 3K-E12 L1 CP1 (03/04/07) 3K-E12 L1 CP2 (03/04/08) i i ~ ,, ~ i I I i 3K-E12 L1 CP3 (03/04/08) I I i it 3K-E12 L1 CP4 (9111/07) ' 3K-108 (wp09) 1 i iI 3K-108 L1 Toe 5000 -Illlllliliiilliiiii iiiiiiiiii ii~i~~~~~~~~~~~~l~~~l~l~~l~~ 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6i50 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 9500 9750 10000 10250 10500 10750 Vertical Section at 90.00° (750 ft/in) ~'r ConocoPhillips Alaska ~"~J~{.,~~~~A~{~~ ®pr•ry OrNIMip 8r•vlna 5000 4750 4500 3 3250 3000 O `-' 2750 t O 2500 z 2250 O 2000 1750 1500 1250 1000 750 9 5/8" TOW (~ 7094' bID, 3459' TVD: 303' FNL, 910' FEL - Sec35-T13N-R09E / I ~ I ~ I I 9 5/8" TOW i i I i 3K-E12 LI CP1 (03/04/U7) Project: Kuparuk River Unit WELL DETAILS: Plan 3K-108 (El2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Ground Level: 34.30 Wellbore: 3K-108 L1 +N/-s +E/_w Nortninb Fasting Latittuae Longitude sent ` ' ° ' 39.919 W 3K-108 Staked 45 3.151 N 149 0.00 0.00 6008466.45 529306.39 70° 26 Plan: 3K-108 L1 (wp09) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 3K-108 (E12) -Slot 3K-108` Staked, True Nodh Vertical (TVD) Reference: 74.3' (34.3'+40) @ 74.30tt Measured Depth Reference: 74.3' (34.3'+40) @ 74.300 Calculation Method: Minimum Curvature CASING DETAILS TVD TVDSS MD Size Narne 2414.22 2339.92 3843.38 13-3/8 13 3/8" 3459.31 3385A1 7093.71 9-5/8 95/8"TOW 3629.30 3555A0 13114.05 3-I/2 31/2" I i I i it i 3K-E12 LI CP2 (03/04/08) c I it i i t i i 3K-E 12 LI CP3 ((13/04/03) BHL (-il 131 14' MD, 3629' TVD: 994' FNL, 238' FEL - Sec36-T13N-R09E o \\ \\ ° ~ o° ~ i 3 1/2" I I ~ ~ ~ , ~ ~ 3K-108 Ll (wp09) i i i 3K-E 12 L I CP4 (9/ I I /07) i i i i i 3K-108 LI Toe T M Azimuths to True North Magnetic North: 23.08° Magnetic Field Strength: 57623.3snT Dip Angle: 80.88° Date: 10/16/2007 Model: BGGM2007 3500 3750 4000 4250 4500 4750 5000 5250 5500 5750 6000 6250 6500 6750 7000 7250 7500 7750 8000 8250 8500 8750 9000 9250 9500 9750 IOOOn lrn5n tnsnn ln7m West(-)/East(+) (750 ft/in) ~ ConocoPhillips ~~ ~.~~ ~ _ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Weltbore: 3K-108 L1 Design: 3K-108 L1 (wp09) Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108' Staked TVD Reference:. 74.3' (34.3'+40) @ 74.30ft MD Reference: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method:. Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3K Pad Site Position: Northing: 6,008,428.74ft Latitude: 70° 26' 2.780 N From: Map Easting: 529,306.18ft Longitude: 149° 45' 39.930 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.23 ° - Well Plan 3K-108 (E12) -Slot 3K-10si` Staked -- Well Position +N/S 0.00 ft Northing: 6,008,466.45 ft Latitude: 70° 26' 3.151 N +E/-W 0.00 ft Easting: 529,306.39 ft Longitude: 149° 45' 39.919 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 34.30ft Wellbore 3K-108 L1 Magnetics Mod el Name Sample Date L bggm2007 10/16/2007 Design 3K-108 L1 (wp09 ) __ Audit Notes: Version: 8 Phase: Vertical Section: Depth From (TVD) (ft) j 40.00 Plan Sections Measured Vertical TVD Depth Inc lination Azimuth Depth System i (ft) (°) (°) (ft) ft 7,093.71 80.00 90.43 3,459.31 3,385.01 7,110.21 82.24 90.43 3,461.86 3,387.56 7,140.21 82.24 90.43 3,465.91 3,391.61 7,379.17 94.07 92.15 3,473.58 3,399.28 7,398.94 94.07 92.15 3,472.18 3,397.88 7,489.98 90.05 90.01 3,468.91 3,394.61 8,189.98 90.05 90.01 3,468.30 3,394.00 8,322.50 88.72 90.03 3,469.72 3,395.42 9,337.36 88.72 90.03 3,492.30 3,418.00 9,723.10 88.47 101.60 3,501.79 3,427.49 11,086.09 88.47 101.60 3,538.30 3,464.00 11,129.39 88.20 100.33 3,539.56 3,465.26 12,076.10 88.20 100.33 3,569.30 3,495.00 12,127.85 86.65 100.34 3,571.63 3,497.33 13,114.05 86.65 100.34 3,629.30 3,555.00 Declination Dip Angle Field Strength 23.08 80.88 57,623 PLAN Tie O n Depth: 7,093.71 +N/-S +E/-W Directio n (ft) (ft) (°) 0.00 0.00 90.00 Dogleg Build Turn +N/-S +E/-W Rate Rate Rate Tool Face (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 3,506.02 4,046.89 0.00 0.00 0.00 0.00 3,505.90 4,063.19 13.60 13.60 0.00 0.00 3,505.68 4,092.92 0.00 0.00 0.00 0.00 3,500.30 4,331.26 5.00 4.95 0.72 8.32 3,499.56 4,350.96 0.00 0.00 0.00 0.00 3,497.84 4,441.90 5.00 -4.41 -2.35 -151.92 3,497.72 5,141.90 0.00 0.00 0.00 0.00 3,497.68 5,274.41 1.00 -1.00 0.01 179.30 3,497.21 6,289.02 0.00 0.00 .0.00 0.00 3,458.23 6,672.01 3.00 -0.07 3.00 91.42 3,184.29 8,006.69 0.00 0.00 0.00 0.00 3,176.06 8,049.18 3.00 -0.61 -2.94 -101.80 3,006.43 8,980.09 0.00 0.00 0.00 0.00 2,997.15 9,030.95 3.00 -3.00 0.03 179.40 2,820.39 9,999.47 0.00 0.00 0.00 0.00 6/27/2008 10:28:38AM a e 2 COMPASS 2003.16 Build 42F Halliburton -Sperry Standard Proposal Report Database: EDM 2003.1 6 Single User Db Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108"` Staked Company: ConocoPhilli ps (Alask a) Inc. -Kup2 ND Reference: 74.3' (34.3'+40) @ 74.30ft Project: Kuparuk River Unit MD Reference: 74.3' (34.3'+40) @ 74.30ft Site: Kuparuk 3K Pad North R eference: True Well: Plan 3K-108 (E12) Survey Calculation Method: M inimum Curvature Wellbore: 3K-108 L1 Design: 3K-108 L1 (wp09) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth NDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,385.01 7,093.71 80.00 90.43 3,459.31 3,385.01 3,506.02 4,046.89 6,011,988.00 533,339.07 0.00 4,046.89 9 518" TOW @ 7094' MD, 3459' ND: 303' FNL, 910' FE L - Sec35-T1 3N-R09E - 9 5/8" TOW 7,100.00 80.86 90.43 3,460.36 3,386.06 3,505.98 4,053.09 6,011,987.98 533,345.27 13.60 4,053.09 7,110.21 82.24 90.43 3,461.86 3,387.56 3,505.90 4,063.19 6,011,987.94 533,355.37 13.60 4,063.19 7,140.21 82.24 90.43 3,465.91 3,391.61 3,505.68 4,092.92 6,011,987.83 533,385.09 0.00 4,092.92 7,200.00 85.20 90.86 3,472.44 3,398.14 3,505.01 4,152.34 6,011,987.40 533,444.51 5.00 4,152.34 7,300.00 90.15 91.58 3,476.50 3,402.20 3,502.87 4,252.20 6,011,985.65 533,544.37 5.00 4,252.20 7,379.17 94.07 92.15 3,473.58 3,399.28 3,500.30 4,331.26 6,011,983.39 533,623.43 5.00 4,331.26 7,398.94 94.07 92.15 3,472.18 3,397.88 3,499.56 4,350.96 6,011,982.73 533,643.14 0.00 4,350.96 7,400.00 94.02 92.13 3,472.11 3,397.81 3,499.52 4,352.02 6,011,982.69 533,644.20 5.00 4,352.02 7,489.98 90.05 90.01 3,468.91 3,394.61 3,497.84 4,441.90 6,011,981.37 533,734.07 5.00 4,441.90 7,500.00 90.05 90.01 3,468.90 3,394.60 3,497.84 4,451.93 6,011,981.41 533,744.10 0.00 4,451.93 7,600.00 90.05 90.01 3,468.81 3,394.51 3,497.82 4,551.93 6,011,981.78 533,844.09 0.00 4,551.93 7,700.00 90.05 90.01 3,468.73 3,394.43 3,497.81 4,651.93 6,011,982.16 533,944.07 0.00 4,651.93 7,800.00 90.05 90.01 3,468.64 3,394.34 3,497.79 4,751.93 6,011,982.54 534,044.06 0.00 4,751.93 7,900.00 90.05 90.01 3,468.55 3,394.25 3,497.77 4,851.93 6,011,982.91 534,144.05 0.00 4,851.93 8,000.00 90.05 90.01 3,468.47 3,394.17 3,497.75 4,951.93 6,011,983.29 534,244.04 0.00 4,951.93. 8,100.00 90.05 90.01 3,468.38 3,394.08 3,497.74 5,051.93 6,011,983.66 534,344.03 0.00 5,051.93 8,189.98 90.05 90.01 3,468.30 3,394.00 3,497.72 5,141.90 6,011,984.00 534,434.00 0.00 5,141.90 3K-E12 L 1 CP1 (03/04107) 8,200.00 89.95 90.01 3,468.30 3,394.00 3,497.72 5,151.93 6,011,984.04 534,444.02 1.00 5,151.93 8,300.00 88.95 90.02 3,469.26 3,394.96 3,497.69 5,251.92 6,011,984.40 534,544.01 1.00 5,251.92 8,322.50 88.72 90.03 3,469.72 3,395.42 3,497.68 5,274.41 6,011,984.48 534,566.49 1.00 5,274.41 8,400.00 88.72 90.03 3,471.44 3,397.14 3,497.64 5,351.90 6,011,984.75 534,643.97 0.00 5,351.90 8,500.00 88.72 90.03 3,473.67 3,399.37 3,497.60 5,451.87 6,011,985.09 534,743.94 0.00 5,451.87 8,600.00 88.72 90.03 3,475.89 3,401.59 3,497.55 5,551.85 6,011,985.44 534,843.90 0.00 5,551.85 8,700.00 88.72 90.03 3,478.12 3,403.82 3,497.51 5,651.82 6,011,985.79 534,943.87 0.00 5,651.82 8,800.00 88.72 90.03 3,480.34 3,406.04 3,497.46 5,751.80 6,011,986.13 535,043.83 0.00 5,751.80 8,900.00 88.72 90.03 3,482.57 3,408.27 3,497.42 5,851.77 6,011,986.48 535,143.79 0.00 5,851.77 9,000.00 88.72 90.03 3,484.79 3,410.49 3,497.37 5,951.75 6,011,986.83 535,243.76 0.00 5,951.75 9,100.00 88.72 90.03 3,487.02 3,412.72 3,497.32 6,051.72 6,011,987.18 535,343.72 0.00 6,051.72 9,200.00 88.72 90.03 3,489.24 3,414.94 3,497.28 6,151.70 6,011,987.52 535,443.69 0.00 6,151.70 9,300.00 88.72 90.03 3,491.47 3,417.17 3,497.23 6,251.67 6,011,987.87 535,543.65 0.00 6,251.67 9,337.36 88.72 90.03 3,492.30 3,418.00 3,497.21 6,289.02 6,011,988.00 535,581.00 0.00 6,289.02 3K-E12 L1 CP2 (03/04/08) 9,400.00 88.68 91.91 3,493.72 3,419.42 3,496.16 6,351.64 6,01.1,987.99 535,643.61 3.00 6,351.64 9,500.00 88.61 94.91 3,496.09 3,421.79 3,490.22 6,451.42 6,011,981.65 535,743.41 3.00 6,451.42 9,600.00 88.54 97.91 3,498.57 3,424.27 3,479.07 6,550.75 6,011,970.89 535,842.77 3.00 6,550.75 9,700.00 88.48 100.91 3,501.17 3,426.87 3,462.74 6,649.36 6,011,954.94 535,941.44 3.00 6,649.36 9,723.10 88.47 101.60 3,501.79 3,427.49 3,458.23 6,672.01 6,011,950.52 535,964.10 3.00 6,672.0.1 9,800.00 88.47 101.60 3,503.85 3,429.55 3,442.77 6,747.31 6,011,935.36 536,039.46 0.00 6,747.31 9,900.00 88.47 101.60 3,506.53 3,432.23 3,422.67 6,845.24 6,011,915.65 536,137.45 0.00 6,845.24 10,000.00 88.47 101.60 3,509.21 3,434.91 3,402.58 6,943.16 6,011,895.94 536,235.44 0.00 6,943.16 10,100.00 88.47 101.60 3,511.89 3,437.59 3,382.48 7,041.08 6,011,876.23 536,333.43 0.00 7,041.08 10,200.00 88.47 101.60 3,514.56 3,440.26 3,362.38 7,139.01 6,011,856:52 536,431.42 0.00 7,139.01 6/27/2008 10:28:38AM Page 3 COMPASS 2003.16 Burld 42F ~ j ~ ~ ~ ~ i ~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 L1 Design: 3K-108 L1 (wp09) Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108' Staked TVD Reference: 74.3' (34.3'+40) @ 74.30ft MD Reference: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature ~~ Planned Survey Measured Vertical Map Map ', Depth Incl ination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section ~~ (ft) (~) (~) (ft) ft (ft) (fit) (ft) (ft) 3,442.94 10,300.00 88.47 101.60 3,517.24 3,442.94 3,342.28 7,236.93 6,011,836.80 536,529.41 0.00 7,236.93 10,400.00 88.47 101.60 3,519.92 3,445.62 3,322.18 7,334.85 6,011,817.09 536,627.40 0.00 7,334.85 10,500.00 88.47 101.60 3,522.60 3,448.30 3,302.08 7,432.77 6,011,797.38 536,725.40 0.00 7,432.77 10,600.00 88.47 101.60 3,525.28 3,450.98 3,281.98 7,530.70 6,011,777.67 536,823.39 0.00 7,530.70 10,700.00 88.47 101.60 3,527.96 3,453.66 3,261.88 7,628.62 6,011,757.96 536,921.38 0.00 7,628.62 10,800.00 88.47 101.60 3,530.64 3,456.34 3,241.79 7,726.54 6,011,738.25 537,019.37 0.00 7,726.54 10,900.00 88.47 101.60 3,533.32 3,459.02 3,221.69 7,824.47 6,011,718.53 537,117.36 0.00 7,824.47 11,000.00 88.47 101.60 3,535.99 3,461.69 3,201.59 7,922.39 6,011,698.82 537,215.35 0.00 7,922.39 11,086.09 88.47 101.60 3,538.30 3,464.00 3,184.29 8,006.69 6,011,681.85 537,299.71 0.00 8,006.69 3K-E12 L1 CP3 (03!0 4/08) 11,100.00 88.38 101.19 3,538.68 3,464.38 3,181.54 8,020.32 6,011,679.16 537,313.35 3.00 8,020.32 11,129.39 88.20 100.33 3,539.56 3,465.26 3,176.06 8,049.18 6,011,673.79 537,342.23 3.00 8,049.18 11,200.00 88.20 100.33 3,541.78 3,467.48 3,163.40 8,118.61 6,011,661.41 537,411.71 0.00 8,118.61 11,300.00 88.20 100.33 3,544.92 3,470.62 3,145.49 8,216.94 6,011,643.88 537,510.10 0.00 8,216.94 11,400.00 88.20 100.33 3,548.06 3,473.76 3,127.57 8,315.28 6,011,626.35 537,608.49 0.00 8,315.28 11,500.00 88.20 100.33 3,551.20 3,476.90 3,109.65 8,413.61 6,011,608.82 537,706.88 0.00 8,413.61 11,600.00 88.20 100.33 3,554.34 3,480.04 3,091.73 8,511.94 6,011,591.29 537,805.27 0.00 8,511.94 11,700.00 88.20 .100.33 3,557.49 3,483.19 3,073.81 8,610.27 6,011,573.76 537,903.66 0.00 8,610.27 11,800.00 88.20 100.33 3,560.63 3,486.33 3,055.90 8,708.60 6,011,556.23 538,002.05 0.00 8,708.60 11,900.00 88.20 100.33 3,563.77 3,489.47 3,037.98 8,806.93 6,011,538.71 538,100.45 0.00 8,806.93 12,000.00 88.20 100.33 3,566.91 3,492.61 3,020.06 8,905.26 6,011,521.18 538,198.84 0.00 8,905.26 12,076.10 88.20 100.33 3,569.30 3,495.00 3,006.43 8,980.09 6,011,507.84 538,273.71 0.00 8,980.09 3K-E12 L1 CP4 (9/11 107) 12,100.00 87.48 100.33 3,570.20 3,495.90 3,002.14 9,003.59 6,011,503.65 538,297.22 3.00 9,003.59 12,127.85 86.65 100.34 3,571.63 3,497.33 2,997.15 9,030.95 6,011,498.76 538,324.60 3.00 9,030.95 12,200.00 86.65 100.34 3,575.85 3,501.55 2,984.22 9,101.81 6,011,486.11 538,395.50 0.00 9,101.81 12,300.00 86.65 100.34 3,581.69 3,507.39 2,966.30 9,200.01 6,011,468.57 538,493.77 0.00 9,200.01 12,400.00 86.65 100.34 3,587.54 3,513.24 2,948.37 9,298.22 6,011,451.04 538,592.03 0.00 9,298.22 12,500.00 86.65 100.34 3,593.39 3,519.09 2,930.45 9,396.43 6,011,433.50 538,690.30 0.00 9,396.43 12,600.00 86.65 100.34 3,599.24 3,524.94 2,912.52 9,494.63 6,011,415.97 538,788.57 0.00 9,494.63 12,700.00 86.65 100.34 3,605.09 3,530.79 2,894.60 9,592.84 6,011,398.43 538,886.83 0.00 9,592.84 12,800.00 86.65 100.34 3,610.93 3,536.63 2,876.68 9,691.05 6,011,380.89 538,985.10 0.00 9,691.05 12,900.00 86.65 100.34 3,616.78 3,542.48 2,858.75 9,789.25 6,011,363.36 539,083.37 0.00 9,789.25 13,000.00 86.65 100.34 3,622.63 3,548.33 2,840.83 9,887.46 6,011,345.82 539,181.63 0.00 9,887.46 13,100.00 86.65 100.34 3,628.48 3,554.18 2,822.90 9,985.67 6,011,328.28 539,279.90 0.00 9,985.67 13,114.05 86.65 100.34 3,629.30 3,555.00 2,820.39 9,999.46 6,011,325.82 539,293.70 0.00 9,999.46 BHL @ 13114' MD, 3 629' TVD: 994' FNL,'°238' FEL - Sec36-T13N-1209E - 3 112" - 3K-108 L1 Toe 6/27/2008 10:28:38AM Page 4 COMPASS 2003.16 Build 42F "" ~*¢; ~~~-~~ ~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 L1 Design: 3K-108 L1 (wp09) Targets Target Name - hit/miss target Dip A -Shape (° 3K-E12 L1 CP2 (03/04/08) - plan hits target - Polygon Point 1 Point 2 3K-E12 L1 CP1 (03104/07) - plan hits target - Polygon Point 1 Point 2 3K-108 L1 Toe - plan hits target - Point 3K-E12 L1 CP3 (03/04108) - plan hits target - Polygon Point 1 Point 2 3K-E12 L1 CP4 (9/11/07) - plan hits target - Point Casing Points Measured Vertical Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108` Staked TVD Reference: 74.3' (34.3'+40) @ 74.30ft MD Reference: 74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature Halliburton -Sperry Standard Proposal Report ngle Dip Dir. ND +N/-S +E/-W (°) (ft) lft) (ft) 1.51 90.02 3,492.30 3,497.21 6,289.02 3,492.30 3,497.21 6,289.02 3,537.58 3,184.40 8,006.77 1.20 90.01 3,468.30 3,497.72 5,141.90 3,468.30 3,497.72 5,141.90 3,492.32 3,497.17 6,288.49 0.00 0.26 3,629.30 2,820.39 9,999.47 0.56 101.59 3,538.30 3,184.29 8,006.69 3,538.30 3,184.29 8,006.69 3,547.97 3,006.50 8,980.11 0.00 0.00 3,569.30 3,006.43 8,980.09 Depth Depth (ft) (ft) 3,843.38 2,414.22 13 3/8" 7,093.71 3,459.31 9 5/8" TOW 13,114.05 3,629.30 3 1 /2" Formations Measured Vertical Vertical Depth Depth Depth SS (ft) (ft) ft 1,892.83 1,655.15 PFrost 2,195.13 1,804.20 K15 6,409.51 3,323.89 N 1,773.90 1,586.01 T3 5,594.71 3,061.64 Ugnu B 4,917.81 2,811.41 Ugnu C 3,843.36 2,414.21 T3+800 7,091.87 3,458.99 WSak D 6,031.79 3,213.79 Ugnu A Northing Easting (ft) (ft) 6,011,988.00 535,581.00 6,011,988.00 535,581.00 6,011,681.96 537,299.79 6,011,984.00 534,434.00 6,011,984.00 534,434.00 6,011,987.95 535,580.47 6,011,325.82 539,293.71 6,011,681.85 537,299.71 6,011,681.85 537,299.71 6,011,507.91 538,273.72 6,011,507.84 538,273.71 Casing Hole Diameter Diameter Name (~~) (~~ 13-3/8 16 9-5/8 12-1/4 3-1/2 6-3/4 Name Lithology Dip pip Direction (°) (°) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6/27/2008 10:28:38AM Page 5 COMPASS 2003.16 Build 42F ~~x~~~~R~~ ~`~ e ~~~ Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: .Plan 3K-108 (E12) Wellbore: 3K-108 L1 Design: 3K-108 L1 (vrp09) ___ Pian Annota ____ tions Halliburton -Sperry Standard Proposal Report Local Co-ordinate Reference: Well Plan 3K-108 (E12) -Slot 3K-108"` Staked ND Reference: 74.3' (34.3'+40) @ 74.30ft MD Reference: .74.3' (34.3'+40) @ 74.30ft North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 7,093.71 3,459.31 3,506.02 4,046.89 9 5/8" TOW @ 7094' MD, 3459' TVD: 303' FNL, 910' FEL - Sec35-T13N-R09 13,114.05 3,629.30 2,820.39 9,999.47 BHL @ 13114' MD, 3629' TVD: 994' FNL, 238' FEL - Sec36-T13N-R09E 6/27/2008 10:28:38AM Page 6 ~~~~ COMPASS 2003.16 Build 42F ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3K Pad Plan 3K-108 (E12) 3K-108 L1 3K-108 L1 (wp09) Clearance Summary Anticollision Report 27 June, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-108 (E12) - 3K-108 L1 - 3K-108 L1 (wp09) Well Coordinates: 6,008,218.39 N, 1,669,337.76E (70° 26' 02.11" N, 149° 45' 51.20" W) Datum Height: 74.3' (34.3'+40) @ 74.30ft Scan Range: 7,093.71 to 13,114.13 ft. Measured Depth. Scan Radius is 1,507.41 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 MA6.N..BUTC,Rt 8psrry Drtlting ~i®rvicss i ~^~~ ~J J SURVEY PROGRAM Date: 2008-OS12T00:00:00 Validated: Yes Version: 8 Depth From Depth To Survey/Ylan Tool 40.00 600.00 31h 108 (wp09) (3K 108) CIYG]'RO-SS 600.00 7093.71 3K-108 (wp09) (3K-108) NIWD+IFR-AK-CAG-SC 7093.71 13114.10 3K-108 L1(wp09)(3K-108 Ll) MWD D vo 180 ConocoPhillips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based so Travelling Cylinder Aaimuth (TFO+AZI) ~°J vs Centre to Centre Separation X200 ft/inf Details: Plan 3K-108 (E12) North American Datum 1983 Alaska Zone 4 Ground Level: 34.30 +NI-S +EI-W Northing Easting Latittude Longitude Slot 0.00 0.00 6008218.39 1669337.76 70° 26' 2.106 N 149° 45' 51.202 W REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 3K-108 (E12), True North Vertical (ND) Reference: 74.3' (34.3'+40) ~ 74.30ft Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 74.3' (34.3'+40) @ 74.30tt Calculation Method: Minimum Curvature From Colour To MD 0 262 262 512 512 762 762 1012 1012 1262 1262 1512 1512 - . _.,__,._. _ 1762 1762 - -- 2012 2012 2262 2262 2512 2512 2762 2762 -------- - 3012 3012 4012 4012 5012 5012 6012 6012 7012 7012 8012 8012 9012 9012 10012 10012 11012 11012 12012 12012 --~-~ ~ 13012 13012 14012 14012 ..._....,__ _. 15012 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 50.00 Depth Range From: 7093.71 To 13114.13 Centre Distance: 1507.41 Reference: Plan: 3K-108 L1 (wp09) (Plan 3K-108 (E12)/3K-108 L 180 90 Travelling Cylinder Azimuth (1'FO+AZI) ~°( vs Centre to Centre Separafiou (50 ft/inJ SECTION DETAILS Sec MD Inc Azi ND +N/-S +E/-W DLeg TFace VSec Target 1 7093.71 80.00 90.43 3459.30 3506.38 4046.54 0.00 0.00 4046.54 2 7110.21 82.24 90.43 3461.85 3506.26 4062.84 13.60 0.00 4062.84 3 7140.21 82.24 90.43 3465.89 3506.03 4092.56 0.00 0.00 4092.56 4 7377.56 93.99 92.11 3473.67 3500.77 4329.30 5.00 8.17 4329.30 5 7400.73 93.99 92.11 3472.06 3499.92 4352.40 0.00 0.00 4352.40 6 7490.05 90.05 90.01 3468.91 3498.27 4441.63 5.00 -151.94 4441.63 7 8190.05 90.05 90.01 3468.30 3498.15 5141.63 0.00 0.00 5141.63 3K-108 L1 CP1 8 6322.56 88.72 90.02 3469.72 3498.11 5274.13 1.00 179.48 5274.13 9 9337.43 88.72 90.02 3492.30 3497.73 6288.75 0.00 0 00 6288.75 3K-108 Lt CP2 10 9723.19 88.47 101.60 3501.79 3458.77 6671.76 3.00 91.42 6671.76 11 11086.17 88.47 101.60 3538.30 3184.91 8006.44 0.00 0.00 8006.44 3K-108 L1 CP3 72 11129.46 88.20 100.32 3539.56 3176.68 8048.93 3.00 -101.80 8048.93 13 12076.17 88.20 100.32 3569.30 3007.12 8979.85 0.00 0.00 8979.85 3K-108 L1 CP4 14 12127.92 86.65 100.34 3571.83 2997.85 9030.71 3.00 179.40 9030.71 1 S 13114.13 86.65 100.34 3629.30 2821.15 9999.24 0.00 0.00 9999.24 3K-108 L7 Toe ConocoPhillips (Alaska) Inc. -Kup2 ~~~~ ~'C~N Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 L1 (wp09) Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 3K Pad -Plan 3K-108 (E12) - 3K-108 L1 - 3K-108 L1 (wp09) Scan Range: 7,093.71 to 13,114.13 ft. Measured Depth. Scan Radius is 1,507.41 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Site Name Comparison Well Name - Wellbore Name -Design Kuparuk 3K Pad 3K-102 - 3K-102 - 3K-102 3K-102 - 3K-102L1 - 3K-102L1 3K-102 - 3K-102L1 P61 - 3K-102L1 P61 3K-102 - 3K-102L1 PB1 - 3K-102L1 PB1 3K-19 - 3K-19 - Gyro(861) +IFR Projection 3K-19 - 3K-19 - 3K-19 3K-20 - 3K-20 - 3K-20 3K-20 - 3K-20 - 3K-20 Plan 3K-108 (E12) - 3K-108 - 3K-108 (wp09) $UI'V@V tOO/ pl'OgCal11 Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Depth Distance Depth Separation Depth Factor Minimum Separation Warning (ft) (ft) (ft) (ft) ft 13,020.59 1,175.43 13,020.59 673.07 14,084.00 2.340 Clearance Factor Pass -Major Risk 13,014.89 1,169.67 13,014.89 699.42 14,081.00 2.487 Clearance Factor Pass -Major Risk 8,512.44 1,223.19 8,512.44 996.39 9,800.00 5.393 Centre Distance Pass -Major Risk 11,393.06 1,228.61 11,393.06 847.44 12,456.00 3.223 Clearance Factor Pass -Major Risk 7,097.42 1,153.36 7,097.42 1,048.31 7,650.00 10.979 Clearance Factor Pass -Major Risk 7,093.71 1,148.75 7,093.71 1,045.29 7,650.00 11.103 Clearance Factor Pass -Major Risk 9,003.10 1,310.16 9,003.10 1,099.78 8,225.00 6.228 Clearance Factor Pass -Major Risk 9,023.62 1,309.98 9.023.62 1,100.02 8,250.00 6.239 Centre Distance Pass -Major Risk ~I!! 7,100.00 0.05 7,100.00 . From To Survey/Plan (ft) (ft) 40.00 600.00 600.00 7,093.71 7,093.71 13,114.10 3K-108 L1 (wp09) Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey Tool CB-GYRO-SS MWD+IFR-AK-CAZ-SC MWD • 27 June, 2008 - 15:41 Page 2 of 4 COMPASS HALLIBUFtTON Anticollision Report for Plan 3K-108 (E12) - 3K-108 L1 (wp09) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to 74.3' (34.3'+40) @ 74.30ft. Northing and Easting are relative to Plan 3K-108 (E12). Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surtace is: 0.22 °. Ladder Plot O .....~. 135C O L[7 b- 3 K- 3 K• 3K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3 K• 3K 3K 3K 3K 3K 3K 3K P la P la .: 1 D. -~f- P la -~ 3 K 3 K- ---------- ---------- ---------- ---------- ---------- ~ -------- ~ ~ ~ i ~ i i i ~ i ` ~ L- . ~ i t:> i i i ~ i m}t a ~ . 1•..•, ' ~ ~ ~ ` E ~ i ~ i ~ i I i c t . ~ ...~ i ~ i -----~----- -----~----- -----~----- ~ -----~----- ~ -----~----- ~ -----E--- ~ i i i i i i i i ~ i i i i i i i i ~ i ~ i ~ i ~ i ~ i ~ ~ ,.,>: ., . i i i i i i i i ~ i i ~ ~ ~ i i i i i ~ i i i i ~ ~ ~ i i ~ ~ ~ i i i ~ i ~ i ~ ~ ~ i i i I i ' i ~ i ---- ---! ~ ---! ~ ---! ~ i i ~ i ~ ~ i ~. y n ~~ nn ~n nn 7~ M... n0 10000 12500 .. Measured Depth X2500 ftfin) -.~- P la -{~- P la ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit iJ•124, Plan iJ-124, 1J-124 (wp05)V4 1,3K•01,3K•01 V1 2, 3 K•OZ, 3K-02 V1 3, 3K•03, 3K-03 V1 4, 3K•04, 3K•04 V1 5, 3K•05, 3K-05 Vi 8, 3K-06, 3K-08 V1 7,3K-07,3K•07 V1 8, 3 K-0$, 3K•08 V1 9, 3K-09, 3K-09 V4 9, 3K•09A, 3K-09A Vt 02, 3K•102, 3 K-102 VO 02,3K•102L1,3K-102L1 VO 02,3K•102L1P81,3K-102L1PB1 VO 9, 3 K•19, 3K-19 V6 9. 3K•19, Gyro (861)+ IFR Projection V1 0, 3K•30, 3K-20 V14 2, 3 K•22, 3K-22 V3 2, 3 K•22A, 3K-22A Vi 3, 3K-23, 3K•23 V2 4, 3 K-24, 3K•34 V13 5, 3K-25, 3K•25 Vi 6, 3 K-26, 3K•28 V1 7, 3K-27, 3K-27 V2 3K-1DB (E12),3K-1D8,3K-108 (wp09)V14 3K-D8,3K-D8,3K-D8 WpD1 V4 3K-E1D,3K-E10,3K-E1DwpD1 V5 3K-E8, 3K-E8, 3K-E8 wp02 V8 C C7 .~_ [~ 900 Q 47 (f) C U 0 45C U7 L N U • 27 June, 2008 - 15:41 Page 3 of 4 COMPASS HALLIE3URTON ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for Plan 3K-108 (E12) - 3K-108 L1 (wp09) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor IUDG- 8;5- 75G- 0 ~n 625 - 0 U m c SDG - 0 .~ cB n U} 3~5- 2aU - 125- GDG U 1250 2500 ~, _ b ~ # ~_~ i . e: ,_ i i _1- ~_,_-, d ~-L. ~ _ .. ~ _..,. - ~ L., _-1 S j _ _ a-d- t ~ j I ~ _, ~ , +1 ...... .,..z. f : „ _..»,. .. ._. o- e.. .. _ .l . ~ ... .. ~ 1 ~ - y ~ ~ _ ~ I ~ ~ ~ { } ~ .~ ...,._ _. ..~~ T... _ _. _,., p s~ `- a~, - - 3 C ~' ' a ~i ~ l~ _ ~ _ i. .,. ~ ~ _ ~ ~-- t--,. ~ ~,~ -t_-d- .. ,~ I f ~ } ~ k ` .: '_ .. ~ - d ,t._ _~ f .. ~_ t ~-- .1- .i.ap- f -s __ ~__~_ ~ _~ ~ >. i .. j ~~ , , _ n _ ~- ~ ,< r ,I _ .~ _~ , 4 _.•. i ~f . ~._ ~~ ~ ~ ~ I s, •- .. , , , ~ -~ a-~F ~ ~m~- t ~ ~ , .._ ~ ~-#-x ~ .1. r ~_ ~ _.. e M i r ~ t I ,~ , 3750 SGUU 625E 75Q0 $7a-0 IGGGU 1125E 125GG 1375E ISU Measured Depth (2500 ft/ln) -~- 118, 1D•118, Plan IY1 V1 ~ 1J•124, Plan 1J•124, 1J•124(wp05)V4 D1, 3K-01,3K•01 V1 OT, 3K-02, 3K-02 Vt 03, 3 K-03. 3 K•03 Vt D4, 3K-04, 3K•04 V1 D5, 3K•05,3K-05 Vt D8, 3K•09,3K-08 Vt D7, 3K-07, 3K-07 Vt O8, 3K•D8,3K-08 V1 09, 3K-09, 3K-09 V4 09, 3K-09R 3K•09AV1 102, 3K-102, 3K•102 VO 102, 3K-102 Lt, 3K-102 Lt ~ 102,3K-102L1PB1,3K•102L1PB1 W 19, 3K-19, 3K•19 V8 19, 3K•19, Gyro(~341)+ IFR Projection V1 20, 3K-20,3K-30 V14 22, 3K-22, 3K•22 V3 23, 3K•22R 3K22AVI 23, 3 K-23, 3 K•23 V2 24, 3K-24, 3K•24 V12 25, 3K•25,3K-25 V1 38, 3K•26,3K-28 V1 27, 3K-T7, 3K-27 V2 n 3K-108 (E12), 3K-108, 3K-108 (wp09) V14 n 3K-D8, 3K•D8, 3K-D8 wp01 1ta n 3K-E10, 3K-E10, 3K-E10 wp01 V5 n 3K-~, 3K-EB, 3K-E8 wp02 Ii9 :Iim:3K-30, 3K-38, 3K-38 (wp01) VD • u 27 June, 2008 - 15:41 Page 4 of 4 COMPASS 3K-108Ll~rillin~ Hazards ~inmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 3-1/2" Liner Interval Hazard Risk Level Miti anon Strate Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud weight. Pressure Stuck Pipe Low Good hole cleaning aided by circulation sub and cuttings bed impellers, PWD tools monitoring and analysis, decreased mud weight Lost Circulation Moderate Reduced pump rates, mud rheology, LCM program, additional fluid stored on location during completion run. Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out or backreaming ~, ~ ~~ 3K-108 Drilling Hazards Summary.doc ~ ~ ~, ; ? "'~ ~ j 8/11/20081:39:08 PM Drill String Valves To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Annular To be tested to 250 psi and 1,500 psi at initial installation and every 14 days thereafter. 13-5 Double Ram Upper Rams: 3 '/" to 6" variables To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. For Dual 3-'/z" completion operations, 3-'/2" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run Lower Rams: Blind To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. Choke and Kill Line Valves - To be tested to 250 psi and 3,000 psi at initial installation and every 14 days thereafter. 13-5 Single Ram Rams to fit Intermediate Casing: 7-5/8" or 9-5/8" To be tested to 250 psi and 3,000 psi only before running casing. For Dual 3-'/z" completion operations, 3-'/2" dual rams to be installed and tested to 250 psi and 3,000 psi prior to completion run Wellhead Valves tested to 3,000 psi upon assembly -' 13-5 BOP 3K diagram. vsd ConocoPhillips Doyon 15 West Sak 3 ksi Sheet 1 of 1 BOP Configuration prepared byDenni7~ ~i~ Alaska Insulated Conductor: 20" 94# K-55 x 34" 0.312 WT+f- 80' ConocoPhillips 2876"DS Nipple 2008 West Sak Dual Injector System 2.876"DSNipple with Level 5 Rotating self-Aligning Multilateral (RAMTM) System GLM, Camco, }'/." x t" KBG2.9 GLM, Camco, 3-%.' x 1" KBG2-9 West Sa k 13-318" Casing Shoe 3K-108 3300'MD, 2213'TVD As Planned Dual Tubing Strings Rotational Alignment Sub 3-'/:" 9.3#, L-80, 2.992" ID, 2.867" Drift ®® 2.812" DB Nipple }'/." x 9-618" GT Dual Packer }'/," x 3•'/." x 3618" Dual Soal j Motlule for RAM Hanger / 7" X 3618" RAM Hanger Eauiament Specifications 7" X 9-5I8" RAM Junction Mainbore Drift: 3.68" Lateral Drift: 5.80" RAM Hanger/Seal Bore Diverter OD: 8.375" Overall Length of RAM Junction: 38.3 ft Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HR0.E 3-%" x 3-%" 9-518" Dual Seal Module DSM OD: 7.62" Lateral Seal Assembly OD: 3.75" Lateral lD: 2.69" Mainbore Seal Stinyer OD: 3.08" Mainbore 10: 2.69" Sealbore Receptacle 0.76" 10 MLHR Produe[IOn Anchor 1 Seal Assembly 4.76" Seal OD 3.876" 10 9-518" Casing Shoe, 7688' MD, 3533' TVD Lateral Lengths D-Sand 6021' B Sand 5430' Total Drilled Footage 19139' Casing Shoe 13114' MD, 3629' TVD 'B' Sand Lateral 3-%" 9.3# Liner with SLHT connectlans L-80 BTC ~~~i~ BAKER HUGHES l3aker Oil'fDOls Casing Shoe 13117' MD, 3675' TVD D•Sand Casing Exit 7093' MD, 3459' TVD (80 deg) 'D' Sand Lateral 3-'/." 9.3# Liner with SLHT wnneetlons 4'/:" x 9-618" RAM Seal Bore Diverter (SBD( for Dual Seal Module }%^ t26# IBTM Tubing / 7" X 9-618" MLZXP Liner Hanger Packer ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 3K Pad 4 ;:~.,~ :~ Plan: 3K-108 (wp09) '" 1/4 Mile Pool Scan Sperry Drilling Services July s, Zoos HALLIBURTON Grilling and Formation Evaluation • • Closest in POOL ~~ ~~~ t ';~~ Closest A roach: Reference Well: 3K-108 w 09 Plan Offset Well: 3K-20 Coords. - Coords. - ASP ASP 3-D ctr-ctr ': Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. TVD E + /W - 90° Comments De th Incl. Angle TRUE Azi. ND E + /W - 90° Comments POOL Min Distance POOL Min Distance (1578.08 ft) in POOL (1578.08 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-20 (3365 - (wp09) Plan (3365 - 1578.08 "':€i:~ i ~i 7650 90.05 90.01 3394.49 6011734.3 1673926 4601.58 3575 NDss) 6597.37 63.05 68.16 3584.99 6010167.8 1673919 4588.86 3575 NDss) Closest A roach: Reference Well: 3K-108 L1 w 09 Plan Offset Well: 3K-102L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. ._. Depth Incl. An le TRUE Azi. ND E + /W - 90° Comments Depth Incl. An le TRUE Azi. ND E + - 90° Comments POOL Min Distance POOL Min Distance (1175.29 ft) in POOL (1175.29 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-102L1 (wp09) Plan (3365 - 1175.29 13000 86.65 100.34 3548.271 6011097.9 1679214 9887.147 (3365 - 3575 TVDss) 14081 89.19 97.42 3422.034 6009944.5 1679026 9695.162 3575 NDss) Closest A roach: Reference Well: 3K-10 8 w 09 Plan Offset Well: 3K-102 Coords. - Coords. - ASP ASP 3-D ctr-ctr Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS Distance. De th Incl. An le TRUE Azi. ND E + /W - 90° Comments De th Incl. An le TRUE Azi. ND E + /W - 90° Comments POOL Min Distance POOL Min Distance (1179.35 ft) in POOL (1179.35 ft) in POOL (7093.71 - 13114.13 (7093.71 - 13114.13 MD) to 3K-108 L1 MD) to 3K-102 (3365 (wp09) Plan (3365 - 1179.35 12875 86.65 100.34 3540.97 6011119.8 1679091 9764.39 3575 NDss) 13939.23 86.88 98.8 3575.91 6009959.5 1678883 9555.1 3575 NDss) POOL Summary Template1.xls 7/8!2008 1:32 PM Project: Kuparuk River Unit Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Plan: 3K-108 (wp09) 6171 5143 4800 4457 4114 3771 3086 ~ 2743 '2400 ~l• 2057 0 ~Z^, 1714 ~ 1371 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 3K-108 (E12), True NoRh Vertical (ND) Reference: Mean Sea Level Measured Depth Reference: 74.3' (34.3'+40) @ 74.30ft Calculation Method: Minimum Curvature WELL DETAILS: Plan 3K-103 (F.12) Grom~d Level: 34.30 +N/-S +E/-W Northing Basting Lalitlude Longitude 0.00 0.00 (i0082I8.39 1669337.76 70° 2G' 2.106 N49° 45' 51.202 W 343 0 -343 -1371 -1714 Slut T M Azimuths to True North Magnetic North: 23.08° Magnetic Field Strength: 67623.3snT Dip Angle: 80.88° Dale: 10/16/2007 Model: BGGM2007 .I....I... I ~ I I i i i -(i8(, -343 -0 343 686 1029 1371 1714 2057 2400 2743 3080 3429 3771 4114 4457 4800 5143 5486 5829 6171 6514 6857 7200 7543 7886 8229 8571 8914 9257 9600 9943 10280, 10629 10971 11314 West(-)/East(+) (1200 tUin) ~" ConocoPhillips Project: Kuparuk River Unit • Site: Kuparuk 3K Pad Well: Plan 3K-108 (E12) Wellbore: 3K-108 Design: 3K-108 (wp09) C b-..... ............. _ ... .. "° ' ....... .. b.... - 3 ,.~ _ _ - - 3K-108 (wp09) 3K-10 ;.- /' Alaska Department of Natural~ources Land Administration System Page 1 of~~ ~~: ~; . ~ . ~. ~ ~ 1;,; = ~ ; ; : i~r's Search State Cabins a3#tl ~D~11'GES ,. ..>,... r , ., . , , CSI r ~~~ File Type ADL File Number: 25519 ~ - Printable Case File_Summary. See Township, Range, Section and Acreage? Yes ~ No New Searchy L,4S Men~~ I Case Abstract I Case Detail I Land Abstract M~~ File: :DUI: 2~~19 ~'^''~ Search for Status Plat Updates A of 08`1 Si'~OOS Customer: ©U0106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Type: 78~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DN OIL AND GAS Case Status: 35 ISSUED Status Date: 01 /25/1965 Total Acres: 2560.000 Date Initiated: 11/02/1964 Office ofPrimafyResEonsibility : DOG DIV OIL AND GAS Last Transaction Date: 12/07/2005 Case Snbh~e : NORTH SLOPE Last Transaction: DR DOCUMENT RECORDED 19~ri~lirur: U 7~u~ct~.rliil~: Ol 3N I~arl~~e: 1109E ~~'c~clion~ ~~ .Sc°c~liurr ages: 640 Search Pla#s ~lleridian: U 7'otii~n~hrh: (11 _'>N Range: 00~>L: Sectaufr.~ ?6 S'cclinil Acres: 640 1leridian: U Tu~,~n.,~lrr1~: Ol ;N Range: 009E Section: ~~ .~'~-clio~t.d~~res: 640 alc~ri~li~m: U %ui~j~.,~hi~?: O1 :N Range: 009E S'c~c~~~on: (i ,ti`cctiun acres: 640 Legal Description 11-02-196;1 * * * SALE NOTICE L EGAL DESCRIPTION * * ~` U-3-1-1 < ALL ,SEC: TION 25, T13N, R9E, UM 640 ALL SECTION 2<, " " " 640 ALL SECTION 35, " " " 6-10 ALL SEC: TION 36, " " " 6-10 CONTAINING 2,560 ACRES, MORE OR LESS. ~~ ,t ~' http://www.dnr. state.ak.us/las/CaseSummary.cfm?FileType=ADL&FileNumber=25 519&... 8/18/2008 • • TRANSMITTAL LETTER CHECKLIST WELL NAME ~iE'L~ ~~! JQ~~ f PTD# ~?0813..~0 Developmeut~ / Service Exploratory Stratigraphic Test Non-Conventional Weil FIELD: _ ~!.//34.eU~C .G?~Ye2 POOL: y1~LrtsT as".4~t' ~/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~. °!~ 3~C--/OS , (If last two digits in API number permit Noo?O~/3©o, API No. 50-~,~9-.~?,S3QSGi~~ are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - _) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / infect is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any pu~otest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comoanv Namel has designed and i mplemented a water well testing program to provide baseline data on water quality and quantity. (Comoanv Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/11/2008 WELL PERMIT C HECKLIST Field & Pool KUPARUK RIVER, WEST SAKOIL - 490150 Well Name: KUPARUK RIV U WSAK 3K-108L1 Program 5ER Well bore sag PTD#:2081330 Co mpany CONOCOPHILLIPS ALASKA INC Initial ClassrType SER / PEND GeoArea 890 Unit 11160 On10ff Shore ~___ Annular DLsposal Administration 1 Permitfeeattached_____ -- --- ------------------------ ----_-_-- NA___ _____------------- -- ---- -- - 2 l.eesenumberappropnate- --- -- -- ---- -- - -- - - --Yes -- --- - - - -- -- ---- -- -- - - - -- -- -- - 3 Un'tquavleltnameandnumbet - --- -- - - - - -- --- Yea - - ---- - -- -- -- ----- --- --- - - -- -- - - --- 4 WelUocatedina-defined~°ol-- -- ---- - - -- - -- -- ---Yea - -- -- - --- -- - -- -- - - - - - -- - - -- --- 5 Well located p[opardisstanceftomdrilGngunitboundary--------------- --------Yes-- ---------------------- -- -- -- - -- -- - - -- - -- --- 6 VYalllocatedP[opardisianCefromotherwells--------------------- ---------Yes-- ----------------------- -- ----- ----- ----- - ---- - -- 7 5ufficierlt acreage available in_driiling unit- - - - - - - - - - - - - - - Y~ - - - - 2560acres. - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 lfdeviated,iswe114oreRlatincluded -- - - - -- - -- - --- --- Y~ ----- -- -- -- --- - -- -- -- --- -- - --- - -- -- --- 9 _Opetator only affected paffY- - - - - - - - - - - - - - YeS-- - - - - - - - - - -- -- --- - - --- -- --- - - -- --- -- --- -- - 10 Operator bas-appcopnate pond in force - - - - - - - - - - - - - - - - - -Yes - - - - - -Blanket @ond #-59-52-~ $0. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 Pe[mitcanbeissuedwlthQUiconservationordQr------------------- ---------Yes-- ---------------~------------- ------- - - --------- - ---------- Appr Date 12 PetmitcanbeissuedwJth°utadministrative_approval-----._---_-_-- ---------Y~- --- -- --- -- -- -- -- ------ -- -- ------ ---- - - --- ------ 13 CanpeRnit-beapRrovedbe#org15-daywait---- --- - - - -- ---.-Yes-- ----- - -- --- -- - - -- --- - - ---- --- - - -- -- ACS 811612008 14 Welltocated within eras and strata authorized by-Inlection Order # (put IO# in-commenis) (For_ Yes - _ - - . _ _ AIO.2B- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 • All wells v~nthin 114_ mile area_of review identified (For sernce well only)- - - - - - - - - - - - - - - Yes-- ------ -- - --- - - -- --- ------- - --- -- -- - - - --- - 16 P-rR-produced in]actor; Bur~tion of pre~roduGtion ass than 3 montbs_ (For_ssrvice well onty) - - -NA - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - 17 _Nonconven,gas-conformstoA531,05,030Q.1.A)~Q•2•A-D)-- -- -- -- - -- -- ~A-- --- --- ---- - --- -- ----- ---------- --- - - --- -- --- -- --- -- Engineering 18 Conductorstring.P1°vided------------------------ -- - - - --- -- ~A--- -----ConduGtorsetin~K-1t)8(208.130).-.---.---.-------------------------------- -- 19 Sut#acecasingploteFtsellknouvnUSD1Ns---------------------- -------- NA -- -----Alla4udersexempted.40CFR-147.102(b)~3)•---------------------------- - --- -- 20 CMTvoladsquaie_tocirculakeonconductor&surf_csg--------------- --------- NA-__ ____Surfacecasing set in 3K•108,------------------------------------ - - -- 21 CMT-volad~uatetotie-in-langstrin9 to surf GSa----------------- ---------NA--- -----Production_casingset in_3K-10$•----------------------------------- ---- -- 22 C1u1T-will coyerahkn°wn.produGtivab°rizons_------------------- ------- -x0 - -----S°reen_linercompletionplanned,--------------------------------- - - --- - 23 CasingdesgnsadequateforC~LB&_permafrost-- - -- - ------Yes - ----- ----- --- -- --- -- -- ----- - - -- -- -- - - ------ 24 _Adequate tankage_or reserve Dit - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - Rig equ~Rped with steel pits. No reserve pia planned.- Ali waste io approved disposal weU(s). - - - - _ - _ - _ - - - 25 a10.40~forabandonmentkeenaRRroved------ ---- Ifs rs-drill,has - ---- NA--- --------------------------- - - ---- -- ----- -- -- -- -- ---- 26 _ - Adequate_welikote separation proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - _ . - - _ Proximity analysis performed, Nearest segment is mother bore 17_- 45'-tvd deeper._ _ _ - - - _ - _ - - - - _ - - _ 27 dverier-rQquirad.d°esitmeetregulations--------------------- If ----------NA--- -----BOP stackwiUalreadY-beigRiaee,--------------------------------------- -- -- Appr Date 28 _ Arliling fluid- program SGhematic_& equip list adequate- - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - _ -Maximum expected formation Rressure 9,0_ EMW._ MW planned trR to 9.2_ppg._ - - _ _ - - - - - - - - - - _ - _ - _ TEM 811912008 j 29 30 BOPEs,dotheymeetregulation-- - ------ - - -- BOPE_press rating appropriate; lest to_(put prig in comment&)- - - - - - - - - - - -- -- Yes - - - - - - - - -Yes - - - -- -- - -- - - ------- - ------ -- -- - - --- --- - - - _ - MASP Calculated at 1360 psi, 5K stack artangementwith csf rams in love[ set., $000 psi BOP test planned.- - - 31 Choke_manifoldoomplieswlAPl_RP-~3(May$4)-------------- - --------Yes- ----------------,------ --- --- - --- -- 32 -Uy°rk Nnh occur without operation sbuidown - - - - - - - - - - - - - - Yes . No - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - rQpa[ted in 3K W$ production, H2$ may be present in tiff gas and Ml. -Rig bas-sensors and alarms. _ - H25 is not 33 34 1s presence of H2S gas probable - - - - - - - - - - - - - - - - - - - - - - - - - - - _MeCben'tcal-condition of wells within AOR verified (For service well only) - - - - - - - - - - - - - - _ - - - - - - - - -Yes _ _ _ - - - . _ - - - - _ _ 1 proximate Kupautk-yell has surfaGe_cag set below WS, WS proximity in zone. No issues identrf'red.. _ - _ .. - Geology 35 PemritcanbeissuedwlohydrogeRSUifidemeasures--------------- ----------Yes- .------------------------ - ----- -- - -- -- - - -- - -- --- -- 36 Data-preseoiedon potential overpressuremnes- -- -- -- ---- - -- -- Yes. -- -- - ---- ----- ----- ---- ---- --- -- - -- -- Appr Date 37 Seismic analysiso#shallow98szones------------------------ ----------NA-- ---__ --- -- - - -- -- --------------------------------------- - - ACS 8!1812008 38 Seabed conditionsurveX_(ifoff-shore)___-_--_--------------- ------- --~- - ---- - --- 39 Contact nametpb°ne for weeky-plugres~ t~.ports.Iexpiolatory only] - - - . - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering ° pate Spacing exception will be required to complete well as with KRU 3K-108. Commissioner: Date Date: Commissioner: C mis ' r ~~~~ B~s~B ~=14~ • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 3k-10811.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jan 16 08:51:50 2009 Reel Header Service name .............LISTPE Date. .. ...............09/01/16 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................09/01/16 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library :~ Scientific Technical services scientific Technical services Physical EOF Comment Record TAPE HEADER Kuparuk River unit MWD/MAD LOGS WELL NAME: 3K-108 L1 API NUMBER: 500292339560 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-JAN-09 JOB DATA MWD RUN 3 MWD RUN 7 MWD RUN 8 Job NUMBER: Mw0006005292 Mw0006005292 Mw0006005292 LOGGING ENGINEER: A. MUNRO J. PORCIANKO S. POLAK OPERATOR WITNESS: G. RIZEK F. HERBERTH F. HERBERT SURFACE LOCATION SECTION: 35 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 1472 FEL: FwL: 319 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 74.14 GROUND LEVEL: 33.40 WELL CASING RECORD Page 1 v~ e ~ b~' 133 ~~-~o~/ 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 3k-10811.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3070.0 6.750 9.625 7280.0 i 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7280'MD/3483'TVD, WITHIN THE RUN 3 INTERVAL OF THE 3K-108 WELL- BORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. MWD RUN 2 WAS A CLEAN-OUT RUN - NO PROGRESS WAS MADE. 5. MWD RUNS 3,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, .ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), DRILL STRING DYNAMICS SENSOR-ROTATING (DDS-R), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 8 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM JEFFREY HARRISON (CPAI) TO BRYAN BURINDA DATED 03-APR-2008. 7. MWD RUNS 1,3,7,8 REPRESENT WELL 3K-108 L1 WITH API#: 50-029-23395-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13189'MD/3630'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH Page 2 3k-10811.txt SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3031.5 FET 3055.0 RPD 3055.0 RPS 3055.0 RPM 3055.0 RPx 3055.0 RoP 3082.5 all bit runs merged. STOP DEPTH 13130.5 13137.5 13137.5 13137.5 13137.5 13137.5 13189.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 3 MWD 7 MWD 8 REMARKS: MERGED MAIN PASS. MERGE TOP MERGE BASE 3031.5 7280.0 7280.5 7330.0 7330.0 13189.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 Page 3 • 3k-10811.txt RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3031.5 13189 8110.25 20316 3031.5 13189 RPD MWD OHMM 3.17 2000 29.7855 20166 3055 13137.5 RPM MWD OHMM 4.46 2000 28.9105 20166 3055 13137.5 RPS MWD OHMM 4.07 2000 28.2464 20166 3055 13137.5 RPX MWD OHMM 3.77 2000 30.7187 20166 3055 13137.5 FET MWD HR 0.09 1925 1.63172 20166 3055 13137.5 GR MWD API 13.86 128.27 70.9093 20199 3031.5 13130.5 ROP MWD FPH 0.34 1244.54 264.771 20214 3082.5 13189 First Reading For Entire File..........3031.5 Last Reading For Entire File...........13189 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLIB.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SGRC 3031.5 7280.0 SFXE 3055.0 7280.0 SEXP 3055.0 7280.0 SESP 3055.0 7280.0 SEMP 3055.0 7280.0 SEDP 3055.0 7280.0 SROP 3082.5 7280.0 Page 4 i LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 3k-10811.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 • 15-SEP-08 Ins~te 74.11 Memory 7280.0 3031.0 7280.0 67.8 87.1 TOOL NUMBER 242561 230192 12.250 3070.0 Polymer 8.80 58.0 9.8 200 5.2 1.250 72.0 .870 105.8 1.100 72.0 2.000 72.0 Name Service Order units Size Nsam Rep Code offset Channel Page 5 ' ~ • 3k-10811.txt DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MWD030 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3031.5 7280 5155.75 8498 3031.5 7280 RPD MWD030 OHMM 3.17 2000 18.4056 8451 3055 7280 RPM MwD030 OHMM 4.46 1979.63 17.501 8451 3055 7280 RPS MWD030 OHMM 4.07 153.91 14.3008 8451 3055 7280 RPx MwD030 OHMM 3.77 2000 12.0493 8451 3055 7280 FET MWD030 HR 0.09 135.18 1.77625 8451 3055 7280 GR MwD030 API 13.86 128.27 69.0972 8498 3031.5 7280 ROP MWD030 FPH 1.87 1244.54 255.018 8396 3082.5 7280 First Reading For Entire File..........3031.5 Last Reading For Entire File...........7280 File Trailer service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SROP 7280.5 7330.0 LOG HEADER DATA Page 6 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 3k-10811.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ............ ......... Datum specification Block sub-type...0 C~ 02-DEC-OS Incite 74.11 Memory 7330.0 7280.0 7330.0 TOOL NUMBER 11166264 6.750 7280.0 Mineral oil Base 9.20 87.0 .0 34000 4.5 .000 .0 .000 95.0 .000 .0 .000 .0 Name service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FPH 4 1 68 4 2 Page 7 3k-10811.txt First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7280.5 7330 7305.25 100 7280.5 7330 ROP MWD070 FPH 0.34 26.24 11.5236 100 7280.5 7330 First Reading For Entire File..........7280.5 Last Reading For Entire File...........7330 File Trailer Service name... .......STSLI6.003 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header service name... .......STSLI6.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SEXP 7280.5 13137.5 SEDP 7280.5 13137.5 SGRC 7280.5 13130.5 SEMP 7280.5 13137.5 SFXE 7280.5 13137.5 SESP 7280.5 13137.5 SROP 7330.5 13189.0 LOG HEADER DATA DATE LOGGED: 07-DEC-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13189.0 TOP LOG INTERVAL (FT): 7330.0 BOTTOM LOG INTERVAL (FT): 13189.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 8 • MINIMUM ANGLE: MAXIMUM ANGLE: 3k-10811.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ...... Datum Specification Block sub-type...0 Name service order DEPT RPD MWD080 RPM MWD080 RPS MWD080 RPX MWD080 FET MWD080 GR MWD080 ROP MWD080 Name Service Unit 80.2 93.6 TOOL NUMBER 184054 223565 6.750 7280.0 Mineral oil Base 9.20 75.0 .0 28000 3.8 .000 .0 .000 109.4 .000 .0 .000 .0 units size Nsam Rep Code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HR 4 1 68 20 6 API 4 1 68 24 7 FPH 4 1 68 28 8 First Last Min Max Mean Nsam Reading Reading Page 9 3k-10811.txt DEPT FT 7280.5 13189 10234.8 11818 7280.5 13189 RPD MWD080 OHMM 5.96 2000 37.9948 11715 7280.5 13137.5 RPM MwD080 OHMM 6.95 2000 37.1412 11715 7280.5 13137.5 RPS MWD080 OHMM 6.51 2000 38.3065 11715 7280.5 13137.5 RPX MWD080 OHMM 6.25 2000 44.1866 11715 7280.5 13137.5 FET MWD080 HR 0.13 1925 1.52745 11715 7280.5 13137.5 GR MWD080 API 41.11 124.1 72.2254 11701 7280.5 13130.5 ROP MWD080 FPH 3.09 1021.07 273.921 11718 7330.5 13189 First Reading For Entire File..........7280.5 Last Reading For Entire File...........13189 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......09/01/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................09/01/16 origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................09/01/16 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EoF Physical EOF End Of LIS File Library. Scientific Technical Services Library. scientific Technical services Page 10
