The URL can be used to link to this page

Home My WebLink About204-1107. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU K-09C Perforation Squeeze, Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-110 50-029-21736-03-00 12352 Surface Intermediate Liner Liner Liner 9007 2647 7568 2888 174 2132 12310 13-3/8" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 9008 28 - 2675 26 - 7594 7409 - 10297 10130 - 10304 10213 - 12345 28 - 2674 26 - 6996 6837 - 8996 8973 - 8996 8989 - 9007 12285 2670 4760 5410 7500 10530 None 5380 6870 7240 8430 10160 10672 - 12290 4-1/2" 12.6# L-80 24 - 9437 9007 - 9009 Conductor 80 20" 30 - 110 30 - 110 4-1/2" Baker S3 Packer 9380, 8462 9380 8462 Torin Roschinger Area Operations Manager Kirsty Glasheen Kirsty.Glasheen@hilcorp.com 907.564.5258 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028303, 0028304 24 - 8509 Perforations from 9440' - 9461' MD Squeeze 5.2-bbls of 15.8-ppg Class G cement with final squeeze pressure of 2469-psi. 28 3871 22854 12980 6 418 0 0 1373 256 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:14 pm, Jul 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.07.21 06:40:49 -08'00' Torin Roschinger (4662) RBDMS JSB 072523 WCB 3-8-2024 DSR-7/24/23 ACTIVITY DATE SUMMARY 7/12/2023 LRS CTU #2 1.75" Blue Coil . Job Objective: Cement Squeeze MIRU and RIH with HES GR/CCL logging toolstring in 2.20" carrier with 2.25" JSN. L&K the tubing with 140 BBL's of 1% KCL. Establish an injectivity of ~ 2 BPM at 1630 psi. Tag at 10164' CTM, and log up at 50 FPM to 9300' CTM. Painted a red flag at 9500' CTM. Start POOH to check data. ***Job in Progress*** 7/13/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Squeeze Continue POOH with logging tools and confirm good data (+12' correction). RIH with LRS cement BHA & 2.50" BDJSN. Fill the 7" from CIBP to 9561 with powervis. Circulate well to diesel. Establish static WHP of 443 psi. Establish baseline injectivity with diesel to be .5bpm at 2050psi, and 1bpm at 2270psi. Circulate down 14bbl of 15.8ppg class G cement. Built initial squeeze pressure with 3.9bbl behind pipe and then laid in remaining cement. Pushed an additional 1.3bbl behind pipe during final squeeze. Held final squeeze pressure for one hour. Final pressure 2469psi (2026psi over static). Contaminate/cleanout down to the CIBP at 10175 and chase out of hole. WOC to reach 1500 psi compressive strength. ***Job in Progress*** 7/14/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Squeeze Continue to WOC to reach compressive strength. Pressue test the tubing to 1500 psi. Lost ~340 psi in 30 mins (LLR ~0.42 gal/min). RIH with 2-7/8" Yellowjacket milling BHA with 3.70" venturi burnshoe (2.40" I.D.). Dry tag @ 10167' CTM and begin milling. Start stacking weight and not making any hole (minimal motor work and no stalls). POOH and to check venturi (recover composite plug slip, formation rocks, and a few metal shards). RBIH w/ same venturi burnshoe. Mill the plug and push to the LTP at 10188' CTM / 10213' MD. POOH and recover the 4-1/2" CIBP plug core. RBIH with 3.70" venturi junk basket and hoover from the TT to the LTP. POOH to check venturi (recover 1/2 gallon of 1-2" rubber & metal plug debris). RBIH with the same toolstring. ***Job in Progress*** 7/15/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Squeeze Continue RIH with 3.70" venturi junk basket with mule shoe and hoover from the TT to the LTP. POOH to check venturi (recover 2 cups of debris, 1 slip). RBIH with same BHA (recover 1 cup of fines and some slips parts). MU 1-11/16" Yellowjacket milling BHA with 2.33" venturi burn shoe. RIH and venturi 10190 - 10196' before the well starts to take returns. RIH and tag the 2-7/8" CIBP at 10976' CTM / 11000' MD. Start milling on the plug. ***Job in Progress*** 7/16/2023 LRS CTU #2 1.75" Blue Coil. Job Objective: Cement Squeeze Continue milling on the CIBP at 10976' CTM / 11000' MD. POOH to check tools (venturi is packed with CBP debris). RBIH with venturi & 2.30" burn shoe. Mill and push plug/debris to bottom @ 12285' CTM. Freeze protect the well with DSL to 2500' TVD. RDMO. ***Job Complete*** 7/16/2023 ***WELL S/I ON ARRIVAL*** (Cement squeeze) RU POLLARD SLU #60 ***CONTINUED ON 7/17/23 WSR*** 7/17/2023 ***CONTINUED FROM 7/16/23 WSR*** (Cement squeeze) RAN 4 1/2" BLB & 3.80" GAUGE RING TO XN AT 9,436' MD SET 4 1/2" DREAM CATCHER AT 9,403' MD ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU K-09C IH and tag the 2-7/8" CIBP at 10976' CTM / 11000' MD. Start milling on the plug LRS CTU #2 1.75" Blue Coil . Job Objective: Cement Squeezej MIRU and RIH with HES GR/CCL logging toolstring in 2.20" carrier with 2.25" JSN.gg g g L&K the tubing with 140 BBL's of 1% KCL. Establish an injectivity of ~ 2 BPM at 1630gjy psi. Tag at 10164' CTM, and log up at 50 FPM to 9300' CTM. Painted a red flag atgg 9500' CTM. Start POOH to check data. g() Fill the 7" from CIBP to 9561 with powervis. Circulate well to diesel. Establish static WHP of 443 psi. Establish baseline injectivity j with diesel to be .5bpm at 2050psi, and 1bpm at 2270psi. Circulate down 14bbl of 15.8ppg class G cement. Built initial squeeze pressure with 3.9bbl behind pipe and g then laid in remaining cement. Pushed an additional 1.3bbl behind pipe during finalg squeeze. Held final squeeze pressure for one hour. Mill and () push plug/debris to bottom @ 12285' CTM • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, February 6, 2018 8:47 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad DG;AK,OPS Well Pad EKG;AK, OPS Well Pad VP;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;Cerveny, Philip F; Derrick, Laurie R; Oshiro,Joleen Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: K-09C (PTD#2041100) Passed MIT-IA external-email: 0 All, Producer K-09C(PTD#2041100)was put Under Evaluation on 01/10/18 for having inner annulus pressure above NOL. On 01/18/18 Fullbore performed a passing MIT-IA to 2,560 psi.The passing MIT-IA confirms two competent well barriers. DHD has also performed follow up monitors and the IA has not exhibited any signs of repressurization.The well is now classified as OPERABLE. Please keep in mind the fluid packed annulus when bringing the well online. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 SC NE° From: AK, GWO Well egrity Engineer Sent: Wednesday, Janua 0, 2018 8:27 AM To: 'Regg, James B (DOA) (jim. -a g@alaska.gov)' Cc: 'chris.wallace@alaska.gov'; AK, WO SUPT Well Integrity; AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: K-09C •1 D #2041100) sustained IA casing pressure over NOL. Mr. Regg, Producer K-09C(PTD#2041100)was reported to have sus ed inner annulus casing pressure above NOL on 01/09/18. The T/I/O pressures were reported to be 2150/2040/0 psi.The . ••malous IA pressure indicates the potential failure of one or more wellborebarriers. Plan Forward: 1. Fullbore—MIT-IA 2. Well Integrity Engineer—Additional diagnostics as needed. 1 N • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,January 10, 2018 8:27 AM To: Regg,James B (DOA) Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information Subject: UNDER EVALUATION: K-09C (PTD#2041100)sustained IA casing pressure over NOL. Mr. Regg, Producer K-09C(PTD#2041100)was reported to have sustained inner annulus casing pressure above NOL on 01/09/18. The T/I/O pressures were reported to be 2150/2040/0 psi.The anomalous IA pressure indicates the potential failure of one or more wellbore barriers. Plan Forward: 1. Fullbore—MIT-IA 2. Well Integrity Engineer—Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 1 STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations EZ1 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved�Prrogram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 1 /£J'J� Ig- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-110 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory El AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21736-03-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PRUDHOE BAY UNIT K-09C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY.PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED(C Total Depth: measured 12352 feet Plugs measured 10175/11000 feet true vertical 9007 feet Junk measured 10690 feet FEB V n $ 2017 Effective Depth: measured 10175 feet Packer measured 9380 feet true vertical 8983 feet Packer true vertical 8462.24 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 30-110 30-110 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7567 9-5/8"47#L-80 27-7594 27-6997 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9440-9461 feet feet 10672-10697 feet 10772-10797 feet 10797-10822 feet 11070-11370 feet 11650-12080 feet 12220-12290 feet True vertical depth: 8512-8529 feet feet 9007-9006 feet 9005-9006 feet 9006-9006 feet 9012-9010 feet 9012-9009 feet 9011-9009 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-9437 25-8509 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: t'r ; -: IVIAR 01$2017 Intervals treated(measured): -• Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 431 42011 5 820 1388 Subsequent to operation: 531 25746 84 350 392 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature (4' 9- Phone +1 907 564 4424 Date 2/8/17 .f-C� z-.1 l G G/ Form 10-404 Revised 5/2015" 1, 11V 1 RBDMS L)- FEB 1 0 2017 Submit Original Only • • m p G. d) O O O O O UD C N N N Cr U) ti 01• r` V O e cc) 00) C D CD O. CD CD Cr cc) UDCD 01 00 OD m Cr CD CD CD Ns OD M• OOD O 0) T- — Is CD CD CD CD I,- CD CD r` r• CD CA CD CA O O O c- N N (D CO CD 0 O0 OD 00) 00) OD CD CD N- M O CD CD O 00 CD CA r` M Ns CD CD 0 U M N 00 CO N OD 0) CD 0) O N — — CD (0 00 00 CA � V �i oOD DCDU� MCD CD CD CD cr co NNMCI -CY � N CV 0) co• N QZ 0) O 0) O M_ CC) O c0OD Na0Da00Ns N0 NcMCON N, 0 0 0 0 C r ' ' .� M▪ Q C Wu, O ` • CO 0) 00000 " CD O O 00p O ao Oo J 00 00 C)= UJOOJODJJ JJ C O N 3CV JQ0c- 44 CyODQ0 � � No _ CN 1 N iy Lim O 0 N N : N � 00 _ CO V a O 01 w _0\O � � N (V 00N N co M co T- MCD �1 • 00 M M co N Ct rr 0 M CO 00 rCO 0 Cr CC) In N �O r` - to v- C 00 00 UD CO N- CA M CD Cr W o)O 7) QQQ2 C7 U O u_ u cc cc cc cc cc CC Z ZWcwwwwwwwm O D D H Z Z Z Z Z D • U) U0 0) Z J J J J J F- • • Packers and SSV's Attachment PRUDHOE BAY UNIT K-09C SW Name Type MD TVD Depscription K-09C PACKER 7409.07 6837.34 7" Baker ZXP Top Packer K-09C TBG PACKER 9380.27 8462.24 4-1/2" Baker S-3 Perm Packer K-09C PACKER 10130.12 8972.81 5" Baker Flex Lock Packer K-09C PACKER 10213.42 8989.5 3-1/2" Baker 45 KB Packer . III, • 0. c) ,,, .- a).2 7 ,-• as c.) co ,,, 3 a. 0 co c co ,.. •,,- ai 2b 713 ca)'-.L- ai c 2 (7) (:) .c .5 u) 3 a) N _.c co — o U) o)0 , 0 N. cd1 o a a " -7l c • CM 00 0 S0 ,_.00 2 u), 0,_ 2 7 "5 0 D < C ' = '- 6 cu F- .§ E ° c -c -1 o Z • = •c i - 3 as o >,eo = a) ,-- o 0- 1- (13 , d o •c El2 c) 7') ° -a 0 z us u) .c . (...) as •- c (i) ai as o 0_ 0_ 0) Cl) U) 7 tO 0 a) N a) o CO ri D N 0 1,- - 4= 7 2 2 a) C (1) " Vi b .s - 2 0--1 • -0 •- o a) as _IT) cs C 3 C-) i .i 0 72 as CD -t: - _0 D - CI-ZO IL CL 0 •=- 0 0 ›- 1 _c _0- ' 0 •,ir, 0Q '- Fe al 0 < 6. . 2 -0 = * _c-- (13 .......+ C 0 •S 10 Cs' 7 W 2 co IX w 7 CD LICI 45 15 MC al 0- C • 0 a) 2 = (4:i * m 0.5 i, 0 * 0 5 u) z * 1,- 2 D 4-_- 1,- (.0 p X - 3'...- 0 a) o 1-- - — — = 0 , --- • 20 a : - -I co 11) • _CD Ce U) 10 0) cs)5 cr>- ± 2 4 - - ,- O w 't E tso 0 0 E Lt4.- a).P, 0_ (f) 03 o < F- Et a) I Cl) ‘.2 o_a) m -cs = 2 (I) -0 ala g -C " (i) 0 "0 (1) 0W _c 't ILI 0- * c - t- •- 0_ 17 0 -.--, * .4... EL ... O 0 a: * 73 0: = * 0 73 0: CU rt/ .-- ... .1., * * 0 a., CO -0 p: 0 ,t): a) -- r-- r-- - a) ...., i_ o = a) , r... * - ma) co 3 CD 0 5 N. E "0 '0 o0) (3) 7 = o a) c (1).. 5 z ,....-7. g (K) 0 (0 RI --- -2 ,- * - o a) * a)t ›. '- * di•S `- 1 Ci 0 • c * oa) .. 0 K 00)-au- 20 ,_ 0 " ° 0 (!) 1-• _1 0) 0 .._ 0 0 .._ -43 0 43 1- 0 " o • 0 -J 45' Kw 1 0 °-li:D3 0 '-'-''-0 •S 1,7 - 0 co •,:r 0 - >, -0 (.0 to 0 = 0 2 i. to in. a6co ± s -cs Cl) (J) to 6- a [.... 0 - N' 0) *Z" - N' N W 0 -) C (1) Ca C .4-' 'S ‘- ‘-: Cel) N• E ai -E- 0 .c. 't c .5 0 c‘i -a 0 (.1 as c di as •- c -.- >,-- L_ • -• -0 o 0_•.= ocLa) 1:3 0 .4- 0 2.71 0 -1- o = 0- 01/4-) •to -c00- (a _ a 01. 2 ,a- occ - 0 -.• 0 - -I-, ,-* 0 ••-• - C 44= l.) @ - a) 0) * ff) -0 18 4t U) 5 cr)7 -° .u) 4t U) :2 Fz; 0 a, a) -Te -0 -0 ,- s , N., 0 (7) 0 0) 0_ c..) 00 _0 = C) 0 CO -'-' C -0 = -J -) 0 -• .- C _a -0 -) 0000) .-Ea3 - 2C * * I- Ca ri- OC * 0 0 c•Ni r, < 0t7c ,- coc. 3 3 _8 (n _Ne : : 4T20 : (.) . ) Wr. L1.1 F- < r-- 0-- 1,- P.-- r•-• r-- r-- 0 o N N N 0 0 N N 0 c\I o cv 5 a) L- ✓ r-- r-- L.- ..- co co L- o) L- a) L- i= --. ,- ,- L- -- -- -- --. .- L- -..... ,- --. ‘•-• 0 < • • CO• 0 aI Li- g o d m I o / C 3E 2CeCLa = 2 o _ . oL- = . I / 2 / k 02 / 0 N- 0 -2 § cn _ = a E � 2 ¥ > )/ 0 \ 2 % kk 1 2 0 0 ± 0 0 = i- 4- I / \ % CC o E k t c 00 � 2 . 2A £ 52 tO 7 2 7 0_ 00 ,4-! 0E0 / 0 0 11 0 • c o ', Q / o -I .0 7 CL a0 k2 / = 2 / 0 / k2 ma@ < = � . o ■ R .E & $ 00) 2 = _E, ,_ 70 § G $ '« H ƒ ° f 2 E t / 2 § ! o.%f I o k • 0 E E @ Y & w 3 % & m ® _ 2 m > 0. A 6 3 27k % I o = 2w z- (--c?; • CO / = / bQ � a) 0 5 \ § / _ a / / § + G QE o (3E: E & : cob ^ G = O � / t '*c ' ° ft2U2 « Z § = 2 tW = 0_ o � mf � = ire / f � �= = t @ 0 � j k 2 % a) / E %f 0- o_k k 2 ._ m � Cl \ gp_ 2 / � \ ¥ / / o / � � SJS _ c . oN- @ >, $ 0 -0 o � a) E c cca / - . u. * @ 7 R « t = 0. Q \ as G Ci w 0 7 § « @ CT)2 = 0 2 ( / Q _1 73 0 % U o m m = : / G f a 22 § - o § G f E \ E g 0_ 1-0 o $ % » 2 / § f / k °- a.0 cs� OC U) 0 k v- U) 0- g_ k v- o ¥ « a. o o - o o O §- 2 o Q ■ 0 2 / � c6 3= � ƒ �k / / � /c) QO00t k kk 0 - 2 2 0 2 12 ; o k e / O i 2 % g 8 , co O N- I-- c.; \ u) •- o � 2f c / TREE=,. 4-1/16"aw • ,WELLHEAD= tut EVOYSAFETY NOTES: CATEGORY I I.NO SSSV.WELL ACTUATOR= AXEISON K-09C ANGLE>-70°@ 10043. OKB.ELEV= 55.6' BF.ELEV= 26.21 I I I I KOP= 3200' Max Angle= 93°@ 12207' o_ 2160' 1-14-1/2"HES HXO SSSVN,ID=3.813" Datum M)= 9867' Datum TVD= 8800'SS f GAS LIFT MA NDRB_S 12.34r H 2676' ST MD ND DEV TYPE VLV LATCH PORT DATE __ 2 4305 4236 25 CAMCO DMY RK 0 03/04/09 IESTNA Id)TOP OF IA CMT(09/25/15) 1- -4642' yvv‘o 1, i 1 7377 6810 30 CA MCO DMY RK 0 12/05/13 ‘ i-ti Minimum ID =2.375" @ 10218' le +.1 7409' i--[9-5/8"X 7"ZXP PKR w/BKR HGR ID=6.276" I LOCATOR SUB 4 .4 9-5/8"CSG,47#,L-80,ID=8.681" H 4-1/2"TBG PUNCH HOLES(07/16/15) --9316'-9321' ELM >iii ; 9297' i--Ictvrr RETAINER(07/16/15) . ._______ _. _ ____ ___ r 9369' -14-1/2"HES X NP,ID=3.813" 9380' -17"X 4-1/2"BKR S-3 PKR ID=3.875" i I I 9403' -14-1/2"HES X NP,ID=3.813" I I 9424' 1--14-1/2"HES XN NIP,MILLED ID=3.80" I 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" H 9436' j______/ \ 9436' -14-1/2"WLEG,ID=3.958" 0 -I ELMD TT NOT LOGGED 10130' -r X 5"BKR ZXP PKR w/BKR HAC HGR,ID=4.375" 7: 3 [ 10160' [--15-1/2-X 4-1/2"X0, 1110"11111 "."--4-1/2"WFD CIBP(01/21/17) I TOP OF 3.70"LNR H 10213' 10213' 10221' -13,7"BKR LMi TOP FKR,ID=2.375" H "BKR DEPLOYMENT SLV,ID=2.972" I 10240' -[3-1/2"HES XN NIP,ID=2.765"I 17"LNR,26# L-80,.0383 bpf ID=6.276" I-I 10297' o [3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,ID=2.992" I-1, 10306' 0 4 10305' -13-1/2"X 3-3/16"X0,ID=2.786" i, [MECHANICAL HOLLOW W-IPSTOCK H 10306' 0 4 [WHIPSTOCK ANCHOR 1-L 10317' • • •1'.„ 4-1/2'MLLOUT WINDOW(K-09C)10304'- 10319' 4-1/2"LNR,12.6#,L-80,.0152 bpf,U=3.958' H 11200' I'•••• • PERFORATION -1016909 .'0 H MLLE!)COMPOSITE PLUG(10/01/15) SUMMARY ‘ Rff LOG: -I 3-3/16"X 2-7/8"XO,ID=2.387" ANGLE AT TOP PERE:34*@ 9440' \ IIE 06 11000' -2-7/8"BKR CP(11/13/08) Note.Refer to Production DB for historical perf data N SIZE SPF INTERVAL Opn/Sqz SHOT SQZ wive. 2-7/8" 6 9440-9461 0 01/21/17 ..... ••••4 2" P' 6 10672-10697 C 11/13/08 2" ' 6 10772-10822 C 11/13/08 3-3/16"LNR,6.2#,L-80, H 10690' 2" ' 4 11070-11370 C 07/16/04 .0076 bpf,ID=2.80" 4. 2" 6 11650-12080 C 07/16/04 2" 6 17270-12290 C 07/16/04 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,U)=2441" - 12345' DATE REV BY COfvfvENTS DATE REV BY CONVENTS PRLCHOE BAY UNIT 09/09/87 ORIGINAL COMPLETION 10/27/15 SJW/TLH MILL CMT&PLUGS(10/03/15) WELL K-09C 12/13/94 RIG SCITRK-K-09A-WELL SUSP 09/22/16 JM) MICR EDITS PERNT No:' 041100 -05/30/97 RIG SOTRK (K-09B) 02/01/17 MZJJMD SET PLUG&ADFERFS(01/21/17) API No: 50-029-21736-03 07/16/04 KAK CTD SIDETRACK(K-09C) SEC 4,T11N R14E,2113'FM_&493'FVVL 07/15/15 JC PJC CBP/T PUNCH'CMT RET - 10/27/15 siwrnA TBG PUNCHIA CMT SQZ(9/25/15) BP Exploration(Alaska) ti ti tO C 1 V C STATE OF ALASKA OCT 2 8 2015, . •ALASKA OIL AND GAS CONSERVATION COMM.N REPORT OF SUNDRY WELL OPERATI S 1. Operations Performed :AQGCC Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool CIRepair Well Re-enter Susp Well 0 Other:Cement IA m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-110 3. Address: P.O.Box 196612 Anchorage, Development 11 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21736-03-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU K-09C 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 12352 feet Plugs measured 11000 feet true vertical 9007 feet Junk measured 10690 feet Effective Depth: measured 11000 feet Packer measured 9380 feet true vertical 9012 feet Packer true vertical 8462.21 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"Conductor 29-109 29-109 0 0 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7567 9-5/8"47#L-80 27-7594 27-6996 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10672-10697 feet 10772-10797 feet 10797-10822 feet 11070-11370 feet 11650-12080 feet 12220-12290 True vertical depth: 9007-9006 feet 9005-9006 feet 9006-9006 feet 9012-9010 feet 9012-9009 feet 9011 -9009 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-9436 24-8508 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9316-9321;Estimate Top of Cement in IA to be 4642'MD. A t Treatment descriptions including volumes used and final pressure: CANNEf6ftO r` /1, 185 Bbls 15.8 ppg Class G Cement,89 Bbls 60/40 Methanol,30 Bbls Fresh Water,145 Bbls Slick 1%KCL. 4, a 2015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 607 36021 16 1380 1026 Subsequent to operation: Shut-In 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-329 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 64.441. C Phone +1 907 564 4424 Date 10/28/15 / RBDMS uL l 19 2015 Form 10-404 Revised 5/2015 vIC, /0 !z /I -' //� /� Submit Original Only • • � • O o O O o O I� N CO r- O O CO M V LO (O N N 'CrLU r-- U i CO CD o O� o (ncp O) co co N CO MV Ca CO CO CO CO 0) 0) NCOCOCO0COr- 00 O O f� O O O (A O O O CO CO O) O) O) O) O O (C) N CO CO CO CO C)) 0) CO H O h M CO CO CO C)) O O) N- M O) O) O N N C- N CO () O O) O N CO CO CO CO O) I • CO O CO O O M V CA O O O) '' a) O O O N CO M CO CO M N O O O O CV ▪ U Q 0) O 0) O CO 1.0O o O O O r` O M N v N N (A N O O O O N • Y r c M � m a (3) 00000 o co O 0 00 co co 00 co C) U J O J d -C3 N *k J CSO - (N o Co ijj •(/) N p •N N Rf U Eo _ CO N _ C° U - co p0 N N 0\0 N ON C`7 co d) r �- M .c I` (IOCf) N 0 O r- M CO CO C co 00 (O co N- 0) CO O V C> f— N M J w - C_ F- w w U 1 u fX CC o Z zwwwwwwm p D D F- z z z z z J O (n (n Z J J J J J 0 • Packers and SSV's Attachment PBU K-09C SW Name Type MD TVD Depscription K-09C PACKER 7415 6842.46 7" Baker ZXP Top Packer K-09C _ TBG PACKER 9380.24 8462.21 4-1/2" Baker S-3 Perm Packer K-09C PACKER 10130.09 _ 8972.8 5" Baker Flex Lock Packer K-09C PACKER 10213.42 8989.5 3-1/2" Baker 45 KB Packer , • • O J cow d N - 0 is H 0 OH (O 0 H C II U) CH 60 0) c _0 ___I ‹ IIH �' Q E N U 0 I- t o U } 0 J H LO m wU Ta W c7Q v=j � Q Q � m a Z N a. � � E ET N2 00 �) m Q iI 0 I- - CL 0 c > w W � Oft") o fl- C co0 W � O Hc2 . L0 O C ,_ H 0 Z J M 0 N to O rn Z 0m Urnoo >' 4- _ w 0 ' N - O C J Q m L — 2 a_ i__. -- b c) - a) O E o a) U Off, N- M t a� o t C � � II - (n 03 • 3 _J 2 w U U 0 II J c T H tl) mcn (A (n 2 O Z OH OQ � H ao = - - ;1- ;1- J D ...... 0 0 > H - W a) O >- 2 0a) CMM C 2 d inw w0 2 0 J _ i < N C CS) O 6' O N m U) Q Z Z Q >, O H d ai ( c_ 00 a) - in -1 cow 0 - -co Q. N co , H H - H - II r O U 0 c O (� (n N w Y O 45 cn E E g< 0) W 0 O N Z (/) fn N �v° CX 0 Z 0X0 II DW * D O-m Q 00 s3 a COC o o O O H Q � d � : o r, H c0 U p) , J .L' m W M p n a) Usu) co • � MYY c0iO2D m _ M co OZO pE, z 0 m E * �J M M O O * Z O * O O ? m a N N O O fi a a) * m Cn M C C m m * * N H N J N J C7 Q * * CC J N. O « CC t(' O N W J J Q II — Z ON - .c 0 H 0 * � JD � MOHI� I�lI cn �? 2 � OQ Qm J V � (` CO mtn II CL Ce J (n a. Cn O H u) J J M H > O O U Q O c' f� W '- _o C (/) (n > ° O 07 N Z N -O n . �+ > = NON. - <g � - HwasQc \ aw - a) 000 .( c� N E > cci Et - - 61- u_ O0 tc' vZ0ZLOL.IQ (NU - w II L.L. 0Q -12 N 2 d d < 41---- 0m2 1-- _122L-151---- 0 -11110 Zoci. Z = 0 n W `. QD - zD 200M (� DD — Oa. C..) ZOtn W N OH OZ10 � ENr O � N- OMIw-OMIa 1� 0wX "v0D II = Zw W - 1 \ tea. O _ Z U- 0 i(' if) Z M a l'-__ -_ _____ 0c12 d 0 O H IzzV - +� (nN0U _ Q (ncLm = NN0U- § iv (n (nO 0_ u_ 00 -oo co p J Lo H H O ^U rN N N H H .- > J _1 1-1. 1 0 rX u_i Z 0r) z Q O 0 ° 0x > rn �WO- 0mW460001JHwwQH = WM00 � � m -0 UUZJ1JZZZZUU0J = = OO4O * 5 * .. QQ > > QQQQ * * QDm * ZWQU o w : : w2a a. a' wCtCt : : HO- 0 : Q' 021Y0J (n : H (a O * w I- < Q to L0 to 10 u' C) 0 0 C)C) H N N N N N M V In to _ r r H i i i i U Q 0 • c M Q' N - C O O o C Z U J c a) o m w 0 Q a) H ~ Q O d o 4- 5 o O N J Q 0 m a) a) _o O o J Ur C U F- F- 2 0 (o f F c c CrQ Cl) a) In L O W M W U' d7 N - E E > 6- 0 U Q I i Z m L - v) a) a) Lo C U U = 0 .> C a) a) c E a o 6 O Z I OwZ cn E a) - a) ) Q c _o D Z f/ � Q c) � 0 (1) -0 o CIL 0 2I- .E"00To 3 = * L � c") m C5 W \ ZI- U � o 0 C �n E •_- oU U wcn W � �, __ ;_ ca 25 -° § -o * io __ cl - a o * J Q co to J U 5 a) N 4- 0) 0 -O C * d W W LL C C a) -O -0 N C N Q' Z 0 C C I I N 0 O Q Q C Q C N C Cl)N 0 C- * E ca ' O � cao O Z Z Q (no � a0- 92 °' E � D fl o E * F- _ L 4' 4' L CO 0 0) IL u) c aa)) c0 m co > -0 Y a) N a) * W 2 ZciO F= ° c 2 � 4 o co .( m c N O W CO W O O r o O 0 Ti C - - .. w .� V * W Q Et Z .- w (n Oco . O to - a) co O U ) L D' a 4 w II d O N .c N .� NI- o U a) w C - II Y (N 0 F- HC 0 aw E L-- - � a c � L E Q CN O � -1 p wwa_ d * ao0 :C_ C) OD * 3 aI) U .c c Z * � � c is � ~ *-. (1 c Z w * * U oCA p d n V a 0 � o � p 0 Q aa) * * - la a) O 2L— =.L.. W G. w � F- HN Qom * � .c Loto o a) 9- = c a) 2 m J Q' J W r0O - U N "O C . a) _O w O 0 CD -I c QJ O_-- _oQ to Ta N NN ch E N ,, W �+ Q pU � Nw6 `- Q ENS C Neu > Ts a) � U 0 •� 0 a U Ct o ,_ LO a) -- c\i C c a) - U 0 < o c) 0) a) c c > co d o LU 2 � O MZW � oF- och a) O E �) o � ' ° 0 oa * 0 D Cr) ON- o0F- NNS 0 > a 0 c 09- 2 U a) rn_ ., c'o co it Z H USO- co coZ - occoo ` TUU ? a' - � ID Cn E .QID cn02 cn * Z N II W II _....Cr) a) V) ma) O U E 00 > N U 0 * f- M Z W F- O ~ --o ._ _ > d Q) a) y co Q E L * 0U > QQpw � Hu O orn � 0 3 aSm ~ a, 0 o 3 0- aa)) - ami oNc * U U o coO O +7 L .- * CO Uw2F- C - JJm � a II QMO c -0 -0 E U }• a) O o cc,-8 * -) > i_ _JCt Zw0 0Mp OD rM E o o co Dio c o c E c 73 * * ZwWUOQ * * � c * F- O 1 * * H 0 0 o E c -0 * * * .� (nUU2ti5 * * ciF- * U � 2 � Q* * la U � Uw Lo co co L U) U) - r r ,- r .- c) o O O o o O N N N N N N CO CD N N N N N- N- 0) 0) 0) CM S • pro ; ' a3 � t , E \ .g „ a o •'a I k \ cL \ / / / / \ k%• -- % 2 k \ / ) / a) x / 22 _a' � $ I < E i / \- -0 o / § ƒ u) .= - 0 ° t E e ' § U k E / y / ® 3 o r •- = a) „ 0 C\I / k .% CC 0 / \ � a) ± 0M .Q •® § $ co 03 CD o 2 - a -e =_ / E E E CD / % C / k s 5 m 0. G n U. / CO e m U a \ / c % 7 U \_ W9E7 . I F—S RY / ) ƒ y \ 2 ® q < 8 E G I a e .§ < / I m 5 \ E O ) o neo 0_ % .o = n y / � q J - .2 62� / a) / / f 2 1 I a S o 2 " R 7 ' ® I- < / k E 0 'I CV c - X22E � / ¢ 2 2 / k 3 » \ ) ® o R c = 1 1 o 2 5 5 / E : ( > a g c / c co / _1 o CL k ID % 2 / I t o k _ \ a / In. n & ? � .g c E¢ ƒ ° q ® o - = 5 » co o o_= e / f = _ _ - E \ / 7 2 3 7 ® % f / E E \ $ / k 0 / / \ k / / 2 \ 2 7 0 • Li, r \ ,_ / k ® hco \ c- / 2 / \ TREE_ 41/16"CNV SNOTES: CATEGORY I I.NO SSSV. w WELL.FE4D= MvEVOY I(_O ACTUATOR= AXELSON OKB.ELEV= 55.6' BF.BEl/- 26.21' III j ,- LI KOP= 3200' Max Angle= 93 @ 12207 2160' -j4-112"HES HXO SSSV N,D=3.813" Datum MD= 9867 Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" -j 2675' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 4305 4236 25 CAMCO DMY RK 0 03/04/09 .• ' 1 7377 6810 30 CAMCO DMY RK 0 12/05/13 BKR TIEBACK SLV,D=7.500" H 7409' 9-5/8"X 7"BKR ZXP PKR,D=6.375" H 7415" . it 9-5/8"X 7"BKR HMC HGR D=6.276" -I 7422' - 4642' H ESTIMATED TOP OF IA CMT(09/25/15) 9-5/8"CSG,47#,L-80,D=8.681" -{ 7594' I , • 9297' - CMT RETAINER(07/16/15) 4-1/2"TBG PUNCH HOLES(07/16/15) - 9316'-9321'ELM P 4 9369' -14-1/2"HES X NP,D=3.813" _ 9380' H7"X 4-1/2"BKR S-3 PKR,D=3.875" c. Minimum ID =2.375" @ 10218' I I 9403' -14-112"HES X NP,ID=3.813" LOCATOR SUBI I 9424' -1 4-1/2"1/2"HESX NP,MILL®ID=3.80" 4-1/2"TBG,12.6#,L-80,.0152 bpf,ID=3.958" H 9436' / ‘--19436' -14-112"WLEG,D=3.958" --1 ELMD TT NOT LOGGED BKR TIEBACK SLV,D=5.250" H 10130' 7"X 5"BKR ZXP PKR,ID=4.375" H 10136' 7"X 5"BKR FMC HGR,ID=4.375" --1 10144' 48 5-1/2"X 4-1/2"XO,ID=3.958" - 10150' TOP OF 3.70"LNR H 10213' 10213' --13.7"BKR LNR TOP FKR,D=2.375" 10221' -13.7"BKR DEPLOYMENT SLV,D=2.972" 7"LNR 26#,L-80,.0363 bpf,D=6.276" 10297 1 10240' -13-1/2"HES XN MP,ID=2.765" 3-1/2"LW,6.2#,L-80 TCII,.0076 bpf,D=2.990" 10305' o 10305' H 3-1/2"X 3-3/16"XO,D=2.786" MECHANICAL HOLLOW WI-NPSTOCK -j 10305' WHPSTOCK ANCHOR -I 10317' 4 • ♦4%4 4-1/2'MLLOUT WINIDOW(K-09C)10304'-10319' 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" -I 11200' 1 J ::. ��SLIA/IAARY -10690' H MLLED COMPOSITE PLUG(10/01/15) PERFORAREF LOG: ` 10690' -13-3/16"X 2-7/8"XO,ID=2.387" ANGLE AT TOP PERE:90'@ 10672' 11000' H 2-7/8"BKR CDP(11/13/08) Note:Refer to Production DB for historical perf data SIZE SPF I'1TERVAL Opn/Sqz SHOT SOZ ..1. 2" r 6 10672 10697 0 11/13/08 Q...... NN4 2" ' 6 10772-10822 0 11/13/08 2" ' 4 11070-11370 C 07/16/04 3-3/16"LNR,6.2#,L-80, -1 10690' 2" 6 11650-12080 C 07/16/04 .0076 bpf,ID=2.80" ,. 2" 6 12220-12290 C 07/16/04 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,13=2.441" -1 12345' DATE REV BY COM/UNITS DATE REV BY COIMMENTS PRUDHOE BAY UNIT 09/09/87 ORIGINAL COMPLETION 12/10/13 RKT/JMD GLV GO(12/05/13) WELL: K-09C 12/13/94 RIG SDTRK K-09A-WEDL SUSP 07/15/15 RJK/PJC PULL PX PLUG FERNIT No:'2041100 05/30/97 RIG SDTRK (K-09B) 07/15/15 JCM/PJC CBPP T PUNCH/CMT RET API No: 50-029-21736-03 07/16/04 KAK CTD SIDETRACK(K 09C) 10/27/15 SJW/TLH TBG PUNCH/IA CMT SQZ(9/25/15) SEC 4,T11N,R14E,2113'FNL&493'FWL 12/04/08 JKCIPJC SET CDP/PBS(11/13/08) 10/27/15 SJW/TLH MLL CMT&PLUGS(10/03/15) 09/02/10 MSE/SV LTP/MN D CORRECTION BP Exploration(Alaska) OF r 1j/�,STTHE STATE Alaska Oil anti Cas ��A, of T Conservation Commission AsiKAL ori,,,-_-,_„:„.; 333 West Seventh Avenue OF P, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 ALAS Fax 907 276.7542 www aogcc.alaska goy SCANNED JUN 1 7 2015 Aras Worthington Well Interventions Engineer0 BP Exploration(Alaska), Inc. ^� 0 V 1' P.O. Box 196612 ` • Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-09C Sundry Number: 315-329 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, " ' Daniel T. Seamount, Jr. Commissioner DATED this /.2X day of June, 2015 Encl. RECEWED STATE OF ALASKA MAY 2 7 2015 SC7C eW ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1 Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown❑ Suspend❑ Perforate❑ Other Stimulate ❑ Alter Casing' Change Approved Program❑ Plug for Rednll❑ Perforate New Pool❑ Repair Well 0 . Re-enter Susp Well ❑ Other: C(IV2 I.J /A 21 2 Operator Name. 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Exploratory ❑ Development 0 • 204-110-0 ' 3 Address: Stratigraphic ❑ Service CI6.API Number: P.O.Box 196612,Anchorage,AK 99519-6612 50-029-21736-03-00 ' 7.If perforating: 8 Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU K-09C • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9 Property Designation(Lease Number): 10.Field/Pool(s): f1b4:.0040-?" -. .r ADL0028304/ 57Z.-•ISS PRUDHOE BAY, PRUDHOE OIL • f1. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 12352 . 9007 ' 9403 8481 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"Conductor 29.16-109.16 29.16-109 16 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 7567 9-5/8"47#L-80 26.66-7594 26.66-6996.41 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 24-9436 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Strang raphic❑ Development 0 Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: OIL 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Contact Aras Worthington Email Aras.Worthington@BP.Com Printed Name Aras f(tUungton Title Well Intervetions Engineer Signature Pone 564-4102 Date Prepared by Garry Catron 564-4424 , .'d7/. S/2 FA?"' COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3l5 — 3 29 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other Spacing Exception Required? Yes ❑ No Ii Subsequent Form Required: /a -4 ° 4 — / APPROVED BY L { I h� Approved by: A COMMISSIONER THE COMMISSION Date. 6 ( �l ORIGINAL � ZG�-�s Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the a e of approval. Submit Form and Attachments in Duplicate RBDMS JUN 1 0 2015 '4'�S Plug Attachment ADL0028304 Well Date MD Plug Type TVD K-09C 3/7/2009 9403 4-1/2" PX Plug 8481 K-09C 11/13/2008 11000 2-7/8" Baker CIBP 8959 LO Ln - 000000o °' a' o Ci) cocoococ cococoa6co J J J J J„ 2., 0 ,:::OO cn &) a) Q O 0 0 0 0 0 0 CO COCDCO O� V CO CONCONLO CO p V N- LO N N N N- 0 0 in o ,n oo0CO rnrno 3 CO V V N O) co co V m CO ,- M N- V CO CO 00 a) CO CO N- CO CO CO 0) N N CO m O) O) O O O) O) O) O) N- N O O s-O O) O O O) O) O) CO CO CO 10 CO O) O) co co 00 - N N co I- ca.. O CO CO O CO N- 0) 0) ~ O) N- O) O O) N- CO O) O) O) V- 0 0 N N O) O O) O) CO N CO CO N CO 0) 00 CO CO >, ~ %.- al al E o N � O Ln Ln V f� CM N O) V O) V O O O O M M CO M m O s CO co co CO N 8 co ,r !O N 0 ,- N O N O O o v N N O) vJ 0 O CD J OQ p LC) O CO 0 0) O O wco O N N O co O O V N O) O) N U 2 LOU) DCD00 O °) °) o LoC °O °° °DOCOJ 0000 °° U J J J J J O O J 7 C * It ' It U) 4t a) p *k N J CO N c N-- Cfl � CO N 4* N. N N N C; U _ - CO 0 co eo ti r O = a0 N N . M Co 00 N N ' M M M (-4-5 7 O co N CO V c- CO CO .4- s- L N- LO LC) V CO M M N O CO L() 00 J W W W W W N D 2 Q Q Q O 0 p CC Ct CC CC CC Et u_ W u_ Z Z W W W W W W c c m Q F' Z Z Z Z Z J j j Z 0 Z J J J J J Cn U) Cn H Packers and SSV's Attachment ADL0028304 Well Facility Type MD Top Description TVD Top K-09C PACKER 7415 7" Baker ZXP Top Packer 6842 K-09C PACKER 9380 4-1/2" Baker S-3 Perm Packer 8462 K-09C PACKER 10130 5" Baker Flex Lock Packer 8973 K-09C PACKER 10213 3-1/2" Baker 45 KB Packer 8990 ee"74 K-09 PC Leak Cement Squeeze Interventions Engineer: Aras Worthington (907) 440-7692 Pad Engineer: Mackie Derrick (907) 564-5891 History K-09C was sidetracked with CTD in 2004. K-09A was drilled out of the 9-5/8" casing in 1994 but was suspended, K-09B drilled in 1997 and produced. The well maintained annulus integrity until around 2009. An LDL (leak detect log) confirmed the exact location of the PC (production casing) leak to formation: the liner hanger @ 7409' MD. Two seal tite jobs were executed in 2010 on the well however both were not successful in fixing the communication problem. A Rig Workover to fix the PC leak was and still is deemed uneconomical. Objective The goal of this cement job is to repair a PC leak at the liner hanger @ 7409' MD, and make this well operable. Cement will be circulated down CT and up the IA. The new cement top in the IA will be © -4600' MD. Procedural steps Slickline 1. Pull tubing tail plug E-Line 2. Set bridge plug just above production packer 3. Punch holes in tubing directly above bridge plug Coiled Tubing 4. Set cement retainer above tubing holes 5. Sting into cement retainer and pump Class G cement into the IA to get the TOC in the IA up to -4600' MD Fullbore 6. MITIA to 2500 psi Coiled Tubing 7. Mill out/retrieve cement retainer and bridge plug Operations 8. Bring well online • TRF= 4-1/163C1W Y1l3LFEA0= Ak;EVOYO c SAFETY NOTES: CATEGORY I I.NO SSSV. !ACTT14TOR= AXELSON 0KB. BEV- 55.6' BF.ELEV= 26.21 II KOP= 3200' Max Angle- 93" 12207' p 2160' I�4 1l2'FES 1-C(0 SSSV N,U=3.813" l Datum N©= 9867. ()alum TVD= 8800'SS ' 113-3+6 CSG 7?Jl,180 n,:1214J7 -j675' ;�/ GAS LFT MANDRELS ST NO NU LEV TYPE `: VLV LATCH PORI DATE 2 4305 4236 25 CARCO! DAY RK 0 03/04/09 [BKR TIEBACK SLV D=7.500' 7406' '_�l� J 1 7377 6810 30 CA MOO'; DAY RK 0 12105/13 1-5/8 X 7"BKR 7XP RLR D-8.375' — 7415' i 19-5/W X 7'BI(R FRN FCR,0=6.276' — 7427 ' ie_-k I9-518'CSG,47#.L-80,D-8 681 ,H 7654. I F 9369'-{4-1123 HES X NP,D=1813' I Minimum ID •2.375" @ 10218' 2 .� 9360 1r X4 irr8KR8.-3 iKR,D 3.875" I LOCATOR SUB 9403' ]-[4-112"FES X NIP,D=3.813' I 9403' H 4-1/2"PX PLUG(02127110) I 9424' -j4-1/2'I-ES X NP,MILLED D a 3.803 1 i4-112'TBG 1'24:L-10,.0152 bpi.ID=3.958'-1-r- E 9436' 1 9436• J-14-1/7 1ALEG,13=3.958' I I—I3MD TT NOT LOGGED IBKR TEBACK SLV,D=5250' -f 10130' -.,�` 7'X 5'6KR D(PR(R,D=4.375" — 10136' 1 7X 5"BKR FMC HGR{D=4.375" H 1014.4' 5-12'X 4-1/2'XO,D=3.958" — 10160' I IOP OF 3.70'LNR H 10213' r l ,r 10213' I--{3.7'BKR LErR TOP PKR,D=2 379' 1 10221' HI 3.r BKR DER.OY NWT SLY,ID=2.972" I T Lr41 zee,L-00,.ovla ,D-c 27C 1048T /7 HBS lfN np,D-2 765" 13-1/2"LIR,6 2, L-80 NCL 0076 bpf,D■2.900' -', 10305 305' —13-1/2-X 3-3/16'X0,D=2.786' MECHANICAL HOLLOW VM1STOO( H 10306' WI-IPSTOCK ANCHOR A Ic102.14Y I J�. ." 11'MLLOUT W'DOW(KOYCI10304' 10319' 4- 2•L+i 12.64L-80, 0152 bpf,D=3 958' H 11200' I • � �� 10690' —3-3/16"X 2-7/8'XO,D-2.367" J RET LOG: ANGLE AT TOP PERF 903 1• 10677 11000' 2-718'81(8 CSP(11113I0e) Woe Refer to P,oductjon OB/or historical pert data SYF si]R 1 PITS!/AL Opn/Sgz SHOT ' SOZ 4,44 2' ' 6 10672-10697 0 11113108 111111111 r ' 6 10772- 10622 0 11113/08 2' 4-6 11070-11370 C 07116814 3-3/18'LNR,6.24,L-80, 10690' I 2' s 11650- 12080 C 07116/04 = 4' amab bpf, P 1—i 2' 6 12220- 12290 C 07,160341 I 2-7/8"LNF;6.164,L-80.511,.0058 bpf,D=2.441' I- 12345' DATE REV BY COIV0U'1TS a (Wit REV BY COMEN S PRLUNDE BAY LINT 00109117 ORIGINAL CON PLETNJMI 08/03/10 AISS/A(i1L'ULV(%O((N1/W11 u) wtLL: K-39C 12/13/!4 RIG 3DTRK-K-09A-WELL SUM 09/02/10 MSE/SV LTP1N9J D CC•RRECTION u PEPM1 Ni `1011100 05/30/97 RIG 301TRK (140983) 12110/13_ RK7AX) GLV C/O(12/05/13) API No 50-029-21736-03 07116/04 KAK CTD SIDETRACK(K-09C) SEC 4,T1 l N,R14E 2113'FNL 8 493 FAIL - 05/26/08 JL.VSV GLV GO(05/10/08) _ , 12/04/08 JKOPJC]SET CIBPI RW(11/13/08) — BP Exploration(Alaska) 2 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ O!:+- 1 LOWell History File Identifier Organizing (done) D Two-sided 11I11111111 III" III o Rescan Needed II 111111111 " 1/111I RjSCAN \¢' Color Items: o Greyscale Items: D,TAL DATA ¢ Diskettes, No. D Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: Date g /17 io~ I o Other:: NOTES: BY: ~ 151 MP BY: ~ 11111111111111111/1 Date~ /17/ Q b I'; k'11f -L x 30 = "3 0 +~ = TOTAL PAGES a~ I (Count does not include cover sheet) If) ~~: ~ ~ r 11/11111111111 "1/1 Project Proofing Scanning Preparation BY: Production Scanning Stage 1 Page Count from Scanned File: .Lf- 0 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date: <6/ '7 loCo Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 151 Mf NO BY: Maria Date: 151 11111111111I11111/1 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked 11/1111111111111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~~ ~ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q SEAL TITE Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ ' 6~" Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 204-1100 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-21736-03-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number ~ ADLO-028304 ® ~ . PBU K-09C 10. Field/Pool(s): PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12352 feet Plugs (measured) 9403 11000 feet true vertical 9006.89 feet Junk (measured) ' None feet Effective Depth measured 12310 feet Packer (measured) 7415 9380 10136 true vertical 9008.16 feet (true vertical) 9842 8462 8974 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2675 13-3/8" 72# L-80 SURFACE - 2675 SURFACE - 2674 5380 2670 Production 7594 9-5/8" 47# L-80 SURFACE - 7594 SURFACE - 6996 6870 4760 Liner 2875 7" 26# L-80 7422 - 10297 6849 - 10297 7240 5410 Liner 173 4-1/2" 12.6# L-80 10144 - 10317 8976 - 8996 8430 7500 Liner 2132 3-1/2"X2-3/16"X2-7/8" 10213 - 12345 8990 - 9007 L-80 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 27 - 9436 27 - 8508 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Packer 7415 9842 4-1/2" Baker S-3 Perm Packer 9380 8462 5" Baker ZXP Toa Packer 10136 8974 3.7" BAKER KB LINER TOP PACKER 10213 ~~~~® 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,z ,.~ ~~ ,IUL .1 4 2010 ~ .y., AI8S~8 Qf~ & G~ COG',= ~OrrM111SSi Treatment descriptions including volumes used and final pressure. " k-fcher~ge 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry. Number or N/A if C.O. Exempt: 310-136 Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 7/14/2010 Form 1 - Jam`- 7-l~~r~ K-09C 204-110 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas De th Top Meas De th Base Tvd Depth To Tvd Depth Base K-09C 7/16/04 PER 11,070. 11,370. 9,011.66 9,009.64 K-09C 7/16/04 PER 11,650. 12,080. 9,011.96 9,009.12 K-09C 7/16/04 PER 12,220. 12,290. 9,011.01 9,008.83 K-09C 11/13/08 BPS 11,000. 11,010. 9,012.13 9,012.11 K-09C 11/13/08 PER 10,797. 10,822. 9,005.5 9,005.96 K-09C 11/14/08 PER 10,772. 10,797. 9,004.88 9,005.5 K-09C 11/15/08 PER 10,672. 10,697. 9,006.63 9,005.98 K-09C 2/27/10 BPS 9,403. 11,070. 8,476.11 9,011.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • K-09C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/16/2010 T/I/0= 5/400/0+. Temp= SI. Pump 5 bbls diesel from IA to TBG & verify 10.5 ppg brine (pre-Sealtite treatment). Pumped 4.4 bbls Sealtite, followed by 10.2 bbls brine and 105 bbls diesel down TBG, taking returns from IA to production through K-06 F/L. See log for details. III **Job complete** SV,WV=C. SSV, MV=O. IA,OA=OTG. 5/16/2010 T/I/0=160/580/0 Assist DHD w/ Seal Tite job (repair PC leak). Pumped 10.2 bbls I 10.5# brine followed by 105 bbls DSL down TBG, up IA, taking returns to the ~ flowline on well #6. Freeze protected flowline on well # 6 w/ 10 bbls 60/40 meth, 20 bbls crude and 7 bbls DSL (taken from CH2 transport #39016). **Wellhead valves ~ ' left in the following positions: SSV, MV, IA & OA left open. SV, & WV left S/I."* t a FW P's=1220/160/50 , 5/16/2010 "** WELL S/I ON ARRIVAL***(sealtite) E ON LOCATION, STAND BY FOR WEATHER ' 5/18/2010 ***W ELL S/I ON ARRIVAL"*'` (seal tite treatment) SET 4 1/2" WHIDDON CATCHER @ 9366'SLM SET 1.5" DGLV IN STA #1 @ 7363'SLM (737TMD) I MIT-T TO 1500# -PASSED -LEFT PRESSURE ON TBG AS PER PROCEDURE PULLED 4 1/2" WHIDDON CATHCER @ 9366'SLM. DUE TO LEAKING WING I I*** HAD TO CLOSE LATERAL VALVE ON FLOW LINE, VALVE TO GET MIT-T, LEFT SHUT IN AND FLAGGED -NEEDS TO STAY SHUT IN FOR REMAINDER OF SEAL TIGHT JOB AS PER WSL -PAD OP NOTIFIED "*'` __ ~ ~~~~5/20/2010;T/I/0=1480/140/5. Temp=S1. T @ IA FL (eval Sealtite). No AL. IA FL @ near ';surface, T FL @ surface. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. 6/2/2010 T/I/0= 1430/160/0+. Temp= SI. Pump Seal-Tite into place (assist Seal-Tite). No AL. IA FL @ 114' (6 bbls). Assisted Seal-Tite with Gel Treatment squeeze down IA to mitigate production casing leak (see log for details). Final W Hps= ! 1430/850/0+. **Job in progress** SV,WV= C. SSV,MV= O. IA,OA= OTG. 6/3/2010 T/I/0= 1450/400/0+. Temp= SI. Pump Seal-Tite into place (assist Seal-Tite). No AL. IA FL @ surface. Assisted Seal-Tite with Gel Treatment squeeze. Pumped ~ (9.8 bbls) of diesel down IA with tri Ig ex pump to push Seal-Tite pill down IA t~ ~ mitigate production casing leak. (see log for details). Final W s 0/780/0+. j *"Job Complete** ~SV,WV- C. SSV,MV- O. IA,OA= OTG. { 6/6/2010 T/I/0=1240/210/0. Temp=S1. LLR-IA = 4.24 gpm @ 2100 psi. (Seal-Tite treatment). FL SI @ wing and lateral valves with 1030 psi. Used 217 gal Diesel to pressure IA from 210 psi to 2100 psi. TBG pressure increased 240 psi. Used 127.38 gal to maintain 2100 psi for 30 min establishing aLLR-IA of 4.24 gpm @ 2100 psi. Monitored for 30 min, TBG pressure decreased 170 psi, and the IAP ~ decreased 1090 psi. See log for details. Final WHP's = 1310/910/0. **Note: There ! is an ANSI 1500 series blind on the IA.''* ! Job Complete. ~_____V___. ~ _ SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. _ __ _ _. 6/7/2010: ***WELL S/I ON ARRIVAL*** (seal tite treatment) SET 4-1/2" WHIDDON CATCHER SUB ON PX PLUG @ 9371' SLM ~ ***CONT. ON 06/08/10 WSR*** ' 6/8/2010 '""*CONT. FROM 06/07/10 WSR*"* (seal tite treatment) PULLED RK-DGLV FROM STA#1 @ 7363' SLM/7377' MD ~ LRS PUMPED 25 BBL DIESEL DOWN TBG. TO ADJACENT FLOWLINE ~ , SET RK-DGLV IN STA#1 @ 7363' SLM/7377 MD MIT-T TO 2,000 PSI PASSED, BLED BACK TBG. TO 1700 PSI PULLED WHIDDON C-SUB FROM 9,371' SLM. '""*WELL S/I ON DEPARTURE"** 6/8/2010 T/I/0=1250/380/40 temp= si Assist S/L- load tubing- MIT Tubing 2000 psi ! PASSED [Repair of PC leak- Seal tite] Rigged up to Pump-In-Sub and pumped ~ 25 bbls diesel down tubing taking returns through open pocket, up IA and down K- ! 06 F/L to underbalance tubing prior to Seal tite job. MIT Tubing 2000 psi Pumped ' 1 s gained 30 psi .4 bbls diesel to reach test pressure Tubing lost 20 psi in 15 min 2nd 15 min 3rd 15 min lost 10 psi for a total of 60 psi in 45 min Bleed TBP down S- line on well on dep. Wing shut swab open ssv open master open casing valves open to gauges Final Whp's=1700/500/50 6/9/2010 ~T/I/O=1710/350/40. Temp=S1. Assist Sealtite with LLR on IA (Sealtite treatment). Pumped 30 bbls diesel down IA in an attempt to locate Sealtite pill. Never noticed any sealent activity at leak site. LLR varried from 4.2 gpm to 5.75 gpm @ 2100 psi. Rigged down for further Eval. (see pump log). Final WHPs=1650/1700/40. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. FLUIDS PUMPED BBLS 10 METH 10 10.5# BRINE 139 DIESEL 159 Total cE+= . 4-1/16" CNV WELLHEAD = McEVOY ACTUATOR = AXELSON KB. ELEV = 52.86' BF, ELEV = 26.21' KOP = 3200' Max Angle = 93 @ 12207' Datum MD = 9867' Datum TV D = 8800' SS 0 13-3/8" CSG, 72#, L-80, ID = 12.347" (- j 2675• BKR TIEBACK SLV, ID = 7.500 7409` 9-5(8" X 7" BKR ZXP PKR, ID = 6.375" 7415' 9-5/8" X 7" BKR HMC HGR, ID = 6.276" 7422' 9-5/8" CSG, 47#, L-80, ID = 8.681 " -~ 7$94' Minimum ID = 2.387" @ 10690' 3-3/18" X 2-7/8" XO I4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9436' BKR TIEBACK SLV, ID = 5.250" ) 10130' 7" X 5" BKR ZXP PKR, ID = 4.375" 10136' 7" X 5" BKR HMC HGR, ID = 4.375" 10144' 5-1/2" X 4-1/2" XO, ID = 3.958" 10150' TOP OF 3.70" LNR 10213' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10297' 3-1/2" LNR, 6.2#, L-80 TCii, .0076 bpf, ID = 2.990" 10305' MECHANICAL HOLLOW WHIPSTOCK - 10305' WHIPSTOCK ANCHOR 10317' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11200' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90° @ 10672' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2" 6 10672 - 10697 O 11/13/08 2" 6 10772 - 10822 O 11/13/08 2" 4 - 6 11070 - 11370 C 07/16!04 2" 6 11650 - 12080 C 07/16/04 2" 6 12220 - 12290 C 07!16!04 10690` 13-3/16" X 2-7/8" XO, ID = 2.387" 11000' 2-7/$"BKRGBP(11(13/08) 3-3/16" LNR, 6.2#, L-80, -~ 10690` .0076 bpf, ID = 2.80" 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.441" 12345' DATE REV BY COMMENTS DATE REV BY COMMEMS 09!09/87 ORIGINAL COMPLETION 03/06/09 DAVlSV GLV GO 12!13/94 RIG SDTRK-K-09A-WELL SUS 03/19/10 DTR/SV SET PX PLUG (02/27!10) 05!30!97 RIG SDTRK (K-09B} 04/19/10 SWGSV GLV GO (04/19!10) 07!16/04 KAK CTD SIDETRACK (K-09C} 05/28/10 GR(JMD CHGD MIN ID &CIBP SIZE 05(26/08 JLJ/SV GLV GO (05/10/08) 06!14110 MBPNSV GLV GO (06/08/10} 12/04/08 JKGPJC SET CIBP/ PERF (11/13/08) PRUDHOE BAY UNfT WELL: K-09C PERMIT No:2041100 API No: 50-029-21736-03 SEC 4, T11 N, R14E, 2113' SNL $~ 493' EWL BP Exploration (Alaska} 2160' I-(4-112" HES HXO SSSV N, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4305 7377 4236 6810 25 30 CAMCO CAMCO DMY DMY RK RK 0 0 03!04/09 06!08/10 9369, I-14-1/2" HES X NIP, ID = 3.813" I 9380' 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" 9403' 4-112" HES X NIP, ID = 3.813" 9403' 4-1/2" PX PLUG (02!27110) 9424' 4-1/2" HES X NIP, MILLED ID = 3.80" 9436' 4-1/2" WLEG, ID = 3.958' ---I ELMD TT NOT LOGGED 10213' ~ 3.7" BKR LNR TOP PKR, ID = 2.560" 10221' 3.7" BKR DEPLOYMENT SLV, ID = 2.972" 10240' 10305' 3-1/2" HES XN NIP, ID = 2.765" 3-1/2" X 3-3/16" XO, ID = 2.786" 4-1/2' MILLOUT WINDOW (K-09C} 10304' - 10319' • • Gavin Ramsay Petroleum Engineer ~ . ~~~; ~~ ~ ~, 1 ~~~} BP Exploration (Alaska), Inc~~~'~;, ~~ P.O. Box 196612 ~ Q ~ ` ~ ~ Q Anch~ra~c, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU K-09C Sundry Number: 310-136 Dear Mr. Ramsay: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. 2 ®~ DATED this _ day of April, 2010. Encl. Sincerely, Daniel T. Seamount, Jr. Chair lI~G~~~ V ~V 'i~ D STATE OF ALASKA ~ ~ SKA~L AND GAS CONSERVATION COMMISSI~ O APR ~'4AICATION FOR SUNDRY APPROVALS +~(~~ 20 AAC 25.280 ;,~~ /D 1. Type of Request: Ab Plug for Redrill ^ Pertorate New Pool^ Repair Well ^ Change Approved Program ^ Suspend Plug Pertorations ^ Pertorate^ Puil Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp Well ^ Stimulate^ Alter Casing ^ ^ . Other: SEALTITE JOB 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 204-1100 - 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21736-03-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ ^ PBU K-09C - Spacing Exception Required? Yes No 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028304 PRUDHOE BAY Field / PRUDHOE OIL Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 12352 - 9006.89 - 12310 - 9008.16 - 9403' 11000' NONE Casing Length Size MD ND Burst Collapse Conductor 110 20" sSurface 110 Surtace 110 Surtace 2675 13-3/8"72# L-80 Surface 2675 Surface 2674 5380 2670 Production 7594 9-5/8" 47# L-80 Surtace 7594 Surtace 6996 6870 4760 Liner 2875 7"26# L-80 7422 10297 6849 10297 7240 5410 Liner 173 4-1/2" 12.6# L-80 10144 10317 8976 8996 8430 7500 Liner 2132 3-1/2"X2-3/16"X2-7/8" 10213 12345 8990 9007 L-80 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): see attached - - 4-1/2" 12.6# L-80 27 9436 Packers and SSSV Tvpe: 7" Baker ZXP Packer Packers and SSSV MD and ND (ft): 7415 9842 4-1/2" Baker S-3 Perm Packer 9380 8462 5" Baker ZXP Top Packer 10136 8974 3.7" BAKER KB LINER TOP PACKER 10213 8989 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/23/2010 Oil ~- Gas ^ WDSPL ^ Plugged ^ 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gavin Ramsay Printed Name Gavin Ramsay Title P E Signat re Phone Date ~ 564-4883 4/19/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: /O • ~/Q APPROVED BY ~ ~ Approved by: I I E THE COMMISSION Date: O G Form 10-403 ~~€d'127260 ~~iC iG 1 W N ) 1 1 F ` ` V "v ! ~ L ~ yl0 'l Submy4k~uplic5t~~/(-~ K-09C 204-110 PERF ATTACHMENT u Sw Name Operation Date Perf Operation Code Meas Depth Top Meas De th Base Tvd Depth Top Tvd Depth Base K-09C 7/16/04 PER 11,070. 11,370. 9,011.66 9,009.64 K-09C 7/16/04 PER 11,650. 12,080. 9,011.96 9,009.12 K-09C 7/16/04 PER 12,220. 12,290. 9,011.01 9,008.83 K-09C 11/13/08 BPS 11,000, 11,010. 9,012.13 9,012.11 K-09C 11/13/08 PER 10,797. 10,822. 9,005.5 9,005.96 K-09C 11/14/08 PER 10,772. 10,797. 9,004.88 9,005.5 K-09C 11/15/08 PER 10,672. 10,697. 9,006.63 9,005.98 K-09C 2/27/10 BPS 9,403. 11,070. 8,476.11 9,011.66 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • To: J. Bixby/C. Olsen April 19, 2010 GPB Well Ops Team Leaders From: Tiffany Quy /Taylor Wellman Well Integrity Project Engineers Subject: K-09C Seal-Tite Treatment for a PC Leak IOR: 200 Please perform the following procedure(s): 1. S Pull DGLV in STA #1 @ 7377' 2. F Pump 11 ppg brine into IA, hold for fluid swap / Circ well to 10.5 brine /Pum Seal-Tite in lace 3. S Set DGLV in STA #1, MIT-T to 1500 si 4. W Pum Seal-Tite into IA w/diesel 5. DP MIT-IA to 3000 si Pendin 4 da cure 6. SP Pull 4-1/2" PX Plu C~ 9403' MD Status: Natural Flow Producer with a PC leak Max Deviation: 94° @ 10,402'MD Min ID: 2.375"@ 10,213' MD, BKR Liner Top Packer Seal Unit Last TD Tag: 10,147' 02/27/2010 (slm) - to Deviation Last Ops: MIT-T to .3000 psi (02/28/2010) Last Downhole Ops: Set 4-1 /2" PX Plug @ 9403' MD (02/28/10) Latest H2S value: 12 ppm (07/30/09) Est. BHP: 3288 psi @ 8800' (02/26/2010) Purpose: Mitigate a PC leak at the tie-back packer @ 7415' MD in tre IA. Mechanical History: > 05/09/08: Pulled DGLV in STA # 1, set LGLV in STA # 2 > 05/10/08: Set S/O in STA # 1 > 01/10/09: TIFL Passed > 02/20/09: PO reported high IAP > 02/22/09: TIFL Failed > 03/04/09: DGLV#3,4, MIT-IA Failed > 03/06/09: TTP set @ 9403' MD, MIT-T Passed to 3000 psi, MIT-IA Failed to 3000 psi, caliper; 157 jts 0-10%, 77 jts 10-20%, 1 jt 20-40% > 04/08/09: LDL confirmed leak @ 7409' > 05/31/09: TTP Pulled from 9403' MD > 11/16/09: Est IA infectivity into IA of ~3.5 gpm @ 3000 psi > 02/27/10: Set TTP @ 9403' MD > 02/28/10: MIT-T Passed to 3000 psi K-09 has a confirmed PC leak at the tie-back packer @ 7415' MD. A TecWel LDL was run on 04/08/09 for confirmation. DHD confirmed the LLR = 3.5 gpm on 11 /16/09. The PC leak has enough pressure to create a sustained IA casing pressure of 1000 psi with a loaded column of dead crude. As part of this procedure the IA will be filled with heavy weight brine which should over-balance the IA pressure at the leak site upon completion. Contact Tiffany Quy or Taylor Wellman at x5098 with any questions or comments. Operational Steps Prior to Seal-Tite Technician Arrival: Slickline 1. RU and set TTP @ 9403' MD. -DONE 02/27/10 ~ 2. MIT-T to 3000 psi -DONE 02/28/10 3. RU and pull GLV from STA #1 @ 7377' MD. r Hardline/VUell Support 4. Rig up hardline and choke trailer to allow LRS pumping down the tubing or IA while taking returns to the flowline of an adjacent well (K-06 is the next well down and is an Operable Production well) and have an open 1502 connection point with a block valve on the choke trailer. Seal-Tite Procedure Objectives Repair IA Communication and restore IA Integrity using Seal-Tite Sealants and Procedures Mechanical Considerations The K-09C has failed MITIA tests. A TecWel LDL identified the leak source to be the 7" liner hanger assembly, and more specifically the 7" x 9 5/8" liner top ' packer. The observed leak rate is approximately 3.5 gpm at 3000 psi. In addition to failing the MITIA, the IA also shows pressure buildup. The well _ passed an MIT-T, so the source of pressure feed-in is most likely the liner top. The lowest gas lift mandrel in the well is located at 7377' MD. The dummy will be pulled and the mandrel used as a circulation path for the brine and sealant. The 7" x 4 '/z" packer is at 9380 with 8.56 inhibited seawater as the packer fluid. This fluid must be displaced with a heavier fluid to ensure that the sealant will be spotted accurately and stay supported. - The production casing is 9 5/8" 47 #/ft L80 to the top of the 7" liner @ 7409' - The 7" liner extends to the 7" x 4 Yz" packer at 9380'. - The production tubing is 4 ~/z" 12.6#/ft, 0.0152 bbls / ft - Capacity of tubing to GLM @ 7377' is 112.1 bbls - Capacity of 9 5/8" x 4 1/2" is 0.0535 bbls/ft, 396.3 bbls to the 7" liner top - Capacity of 7" x 4 ~/2" is 0.0175 bbls/ft, 34.5 bbls from the liner top to the packer. The basic steps of the procedure will be as follows: - Install a TTP in the X nipple @ 9403' (already installed) - Pull the dummy from the lower gas lift mandrel - Mix 40 bbls of gelled 10.8 ppg fluid -pump down tubing and into IA. Once the pill is in the IA, shut down 6 hours and allow to fall to bottom. - Pump 400 bbls of 10 ppg fluid followed by a 5 bbl pill of 10.5 ppg Flo-Seal down tubing. Displace the Flo-Seal down the tubing with seawater or diesel. - Once the Flo-Seal is pushed out of the tubing, shut down and re-install the dummy in the gas lift mandrel. - Pressure up on the annulus to squeeze sealant into the liner top and leaking packer - Allow sealant to cure, perform MITIA. - Pull plug and return well to service Repair Procedure 1. Meet with field personnel; travel to location and verify well condition. • 2. Perform Job Safety Analysis with all concerned personnel. 3. Take pressure readings as follows: - Tubing - IA - OA 4. Install a TTP in the X nipple at 9403'. (Note: the plug was installed 2/27/10 and tested to 3000 psi. 5. Rig Up slickline. Pull bottom dummy valve and either leave empty or replace with orifice to allow T x IA circulation 6. RU pump to be able to pump down tubing or IA with choke manifold to take brine returns from tubing down the flowline of an adjacent well (K-06 is - currently an Operable Production well). Establish circulation and ensure both Tubing and IA are full of fluid. 7. Prepare 40 bbls of gelled 11.0 ppg inhibited NaCI/NaBr brine with Diutan gel and corrosion inhibitor. 8. Pump gelled pill into tubing and displace with 150 bbls of 10.5 ppg NaCI/NaBr brine. Maintain injection rates per PE manual guidelines to avoid cutting GLV. Shut down for a minimum of 6 hours to allow 11 ppg brine to fall to bottom and displace seawater in the IA and for the 10.5 ppg brine to displace the crude in the tubing. Insure non-freezeable fluids are pumped at surface based on weather conditions to allow for shutting down for 6 hours. 9. Line up pump to pump down the IA while taking returns from the tubing to the adjacent well. Pump 35 bbls of diesel down the IA while taking returns from a the tubing. 10. Line up pump to pump down the tubing while taking returns from the IA to the adjacent well. Pump 400 bbls of 10.5 ppg NaCI/NaBr brine at 80° F down the tubing and shut down pumps. 11. Line up the pump truck to pump down the IA while taking returns from the tubing to other well's flowline. Pump 153 bbls of dead crude down the IA. Shut down pump. 12. Using the choke skid isolate the pump truck from the well and line up the Seal-Tite mixing tote to the tubing and the IA through the micro-motion meter and to a tank. At this time there should be approximately 440 psi on the IA and 0 psi on the tubing. Bleed 5 bbls off of the IA while `sucking' the Flo-Seal pill into the tubing. 13. Line up the pump to the tubing and to take returns from the IA down the flowline of the adjacent well. Pump 10 bbls of 10.5 ppg NaCI/NaBr brine followed by 105 bbls of diesel down the tubing to displace the Flo-Seal pill into the IA. Shut down pumps. RDMO. 14. Rig up slickline, replace dummy in lower gas lift mandrel. MIT-T to 1500 psi to verify the valve is fully set. Note: Leave 1500 psi on tubing to minimize the potential for tubing collapse during the rest of the operation. 15. DHD to pressure up on IA to 2000 psi to begin squeezing sealant into liner top with triplex. 16. The sealant was over-displaced into the IA by approximately 3 bbls, and there is 1.6 bbls volume from the GLM to the liner~dp. Compression of fluid below the liner top is 0.12 bbls per 1000 psi. Therefore it should take approximately 4.3 bbls of displacement at 2000 psi before the sealant reaches the liner top. 17. Once sealant is observed to contact leak, reduce injection pressure to 500 psi and monitor until stable. Allow to cure for 4 hours. 18. Increase IA pressure to 1500 psi. Allow to cure for 4 hours. 19. Increase IA pressure to 2500 psi. Allow to cure for 4 hours. 20. Increase IA pressure to 3000 psi. Allow to cure for 4 hours or overnight. Record data for IA integrity test records. 21. Reduce IA pressure to1500 psi and lock in. Allow seal to cure for 4 days. 22. Conduct MITIA to 3000 psi with triplex. If passes, proceed to next step. 23. RU slickline and pull 4-1/2" PX Plug. Note: There is 2000' of 10.5 ppg brine in the tubing. Take precautions as needed for equalization and pulling of the plug. 24. Operations to POP well. r TREE= 4-1/16" CNV WELLHEAD= 'fiAcEVOY ACTUATOR= ____ AXELSON'. _ ~ KB. ELEV = 52.86' BF. ELEV = 26.21'', KOP= 3200'I, Max Angle = 93 @ 1220T'. Datum MD = 986TH Datum TVD = 8800' SS' S ES: CATEGORY I I. NO SSSV. K-09C C 13-3/8" CSG, 72#, L-80, ~ = 12.347" (-) 2675• BKR TIEBACK SLV, ID = 7.500"~ 7409' 9-5/8" X 7" BKR ZXP PKR, ID = 6.375" 7415' 9-518" X 7" BKR HMC HGR, ~ = 6.276" 7422' 9-5/8" CSG, 47#, L-80, ID = 8.681" 7594' Minimum ID = 2.375" @ 10213' BKR LNR Tt3P PKR SEAL UNIT ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958" J--j 9436 BKR TIEBACK SLV, ID = 5.250"~ 10130' 7" X 5" BKR ZXP PKR, ID = 4.375" 10136' 7" X 5" BKR HMC HGR, ~ = 4.375" 10144' 5-112" X 4-1/2" XO, ID = 3.958 10150' TOP OF 3.70" LNR 10213' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 10297' 3-1/2" LNR, 6.2#, L-80 TCII, .0076 bpf, ~ = 2.990" 10305' MC-GHANICAL HOLLOW WHIPSTOCK 10305' WHIPSTOCK ANCHOR 10317' 4-1 /2" LNR 12.6#, L-80, .0152 bpf, ID = 3.958" 11200' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 90° @ 10672' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10672 - 10697 O 11/13/08 2" 6 10772 - 10822 O 11/13108 2" 4 - 6 11070 - 11370 C 07/16/04 2" 6 11650 - 12080 C 07/16/04 2" 6 12220 - 12290 C 07/16/04 2160' ('-14-1/2" HES HXO SSSVN, ID = 3.813" GAS LIFT MANDF2EIS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4305 7377 4236 6810 25 30 CAMCO CAMCO DMY DMY RK RK 0 0 03!04!09 03/04!09 ~EA)< 9369' --~ 4.112" HES X N~, ID = 3.813" 9380' 7" X 4-1/2" BKR S-3 PKR, D = 3.875" 9403' -~4-1/2" HES X NIP, ID = 3.813" 9403' 4-1/2" PX PLUG (02/27/10) 8424' 4-1/2" HES X NIP, MILLED ID = 3.80" 6436' 4-112" WLEG, ID= 3.958" ELMD TT NOT LOGGED 10213' -j 3.7" BKR LNR TOP PKR, ID = 2.560" 10221' 3.7" BKR DEPLOYMENT SLV, ID = 2.972" 10240' 3-1/2" HES XN NIP, ID = 2.765" 10305' 3-112" X 3-3116" XO, ID = 2.786" 4-112' MILLOUT WINDOW (K-09C) 10304' - 10319' 10690' (-~ 3-3116" X 2-7/8" XO, ID = 2.387" 11000' ~ 3-3/8" BKR CBP {11/13108) 3-3/16" LNR, 6.2#, L-80~--( 10690' ~ 0076 bpf, ID = 2.80' 2-7/8" LNR 6.16#, L-80 STL, .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/09!87 ORIGINAL COMPLETION 03/06/09 DAVlSV GLV GO 12/13/94 RIG SDTRK-K-09A-WELL SUS 03!19!10 DTR/SV SET' PX PLUG (02/27/10) 05130/97 RIG SDTRK (K-09B) 07118/04 KAK CTD SIDETRACK (K-09C) 05!26/08 JLJ/SV GLV C/0 (05/10/08) 12(04/08 JKCiPJC SET CBP/ PERF (11/13!08) PRUDHOE BAY UNIT WELL K-09C PERMIT No: x1041100 API No: 50-029-21736-03 SC-C 4, T11 N, R14E, 2113' SNL 8~ 493' EWL BP Exploration (Alaska) To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 j907~ 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing InspectionjCaliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 ~ ~~~ and ~ c~C~l~ll0 j~~4 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C z;.. ~~ ~~~ Q~~ r,--~ 2'0~~ Anchorage, AK 99518 Fax: (907j 245-8952 ~1 j Leak Detection - WLD 07 Aprv09 K-09C Color Log / EDE 50-029-21736-03 2j Coil Flag ~ ~ ~ 13 Apr~09 07-138 EDE 50-023.2033&02 ~~ Signed : ~ i !~.,~~~~ ~ - Date -~ Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8961 FAX: (907)245-88952 E-MAIL : - - - wEBSITE : _. _ C:~Documents and Settings\Ownec~Desktop\Transmit_BP.docx NOT OPERABLE: K-09C (P'I~2041100) Packer or PC leak • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~(Z~~ Sent: Saturday, March 07, 2009 10:46 AM ~~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad EKG; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Randall, Jaclyn S Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: K-09C (PTD #2041100) Packer or PC leak All, Well K-09C failed an MIT-IA after dummy gas lift valves were run~n 03/06/09. A tubing tail plug was set and the well passed an MET-T to 3000 psi. However, the well failed a CMIT-TxIA which narrows down the communication to a failed packer o_ja oroduction casina leak. The well has been reclassified as Not Operable, as the wellbore has been isolated from the perforations by a tubing tail plug, and is to remain shut-in until it has been repaired. Please call with any questions or concerns. Thank you, Andrea Hughes _ tt ~,~~, From: NSU, ADW Well Integrity Engineer Sent: Wednesday, February 25, 2009 7:30 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; GPB, Well Pad EKG; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Randall, Jaclyn S Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot Subject: UNDER EVALUATION: K-09C (PTD #2041100) TxIA Communication All, Well K-09C (PTD #2041100) was found to have sustained casing pressure on the IA. The TIOs were 2280/2270/0 psi on 02/22/09. The well failed a subsequent TIFL on 02/24/09 when the IA pressure increased over 500 psi over two days. The well has been reclassified as Under Evaluation and placed on a 28-day clock; during which time the well may be put online. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: C/O GLVs 3. D: Re-TIFL A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. 3/9/2009 NOT OPERABLE: K-09C (P'1~2041100) Packer or PC leak i Page 2 of 2 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/9/2009 PBU K-09C PTD 204-110 2/25/2009 TIO Plot ,uoo D001 goo a ~ -~ Tbg ~~ -i- IA -~ OA ODA OOOA On r izn~iDa Dtro31o9 Du7Dros o7r7~~D~ oi~zaios mr~v~9 oumios oznaros Dz~n~os TREE= 4-1116" C(W WELLHEAD = McEVOY ACTUATOR = AXEL SO N KB. ELEV =~ _ _ 52.86' SF. ELEV = KOP = Max Angle = Datum MD = 26.21' 3200' 93 @ 12207' 9867' Datum TVD - 8800' SS 13-3(8" CSG, 72#, L-80, ~ = 12.347" ~--~ 2675' LSKRT~BACK SLV, ID = 7.500" ~-j 7409, 9-518" X 7" BKR ZXP PKR, ~ = 6.375" 7415' 9-5/8" X 7" BKR HMC FIGR ~ = 6.276" 7422' 9-518" CSG, 47#, L-80, ~ = 8.681" 7594' Minimum ID = 2.375" @ 10213' BKR LNR TOP PKR SEAL UNIT 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-I 9435' BKR TIEBACK SLV, ID = 5.250" ~- j 10130' 7" X 5" BKR ZXP PKR, ~ = 4.375" 10136' 7" X 5" BKR HMG HGR, ~ = 4.375" 10144' 5-1 J2" X 4-112" XO, ~ = 3.958" 10150' 3.7" BKR LTP SEAL UNtT, ID = 2.375" 10213' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~-~ 10297, 3-112" LNR, 6.2#, L-80, .0076 bpf, ID = 2.990" 10305' MECHANICAL HOLLOW WHIPSTOCK 10305' WHIPSTOCK ANCHOR 10317' 4112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 11200' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: ??° @ 10672' Note: Refer to Production DB for his#orical perf data SCZE SPF INTERVAL OpnlSgz DATE 2" 6 10672 - 10697 O 11113!0$ 2" 6 10772 - 10822 O 11(13108 2" 4 - 6 11070 - 11370 C 07/16/04 2" 6 11650 - 12080 C 07/16/04 2" 6 12220 - 12290 C 07!16104 K-09C 216(1' -~4-112" HES HXO SSSVN, ~= 3.813" GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 4305 7377 4181 6755 25 30 CAMCO CAMCO DOME SO RK RK 16 20 05110f08 05110!08 9369' -~4-112" HES X N~', ~ = 3.813" 9380' 7" X 4-112" BKR S-3 PKR ID = 3.875" 9403' 4-112" HES X NIP, ~ = 3.813" 9424' 4-112` HES X N~', M ILLS ID = 3.80" 9436' 4-112" WLEG, ~ = 3.958" -1 ELMD TT NOT LOGGED 10213' -~ 3.7" BKR LNR TOP PKR m = 2.560" 10221' 3.7" BKR DEPLOYMENT SLV, ~ = 2.972" 10240' 3-1 t2" HES XN N~', ID = 2.765" 10305' 3-"i12" X 3-3116" XO, ~ = 2.786" MILLOUT L'VINDOW 10304' - 10319" 1(1690' 3-3f16" X 2-7!$" XO, ID = 2.440" V~\ 11000' --~3-318" BKR GBP (1 i 1113/08} 3-3(16" LNR, 6.2#, L-80, 10690' .0076 bpf, ID = 2.80" 2-718" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 12345' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/09187 ORIGINAL COMPLETION 01/18/07 JRA/PAG MIN tD 1 PKR CORRECTIONS 12!13!94 RIG SDTRK-K-09A-WELL SUS 05/26108 JLJ/SV GLV GO (05110108} 05f30I97 RIG SDTRK (K"09B} 12!04!08 JKGPJC SET CIBPI PERF (11/13108} 07(16(04 KAK GTD SiDEI'RACK (K 09C} 08!05!04 RVULiTLP GLV GO 02117/06 KSBJTLH GLV GO PRUDHOE BAY UNfT WELL: K-09C PERMff No: 1041100 API No: 50-029-21736-03 SEC 4: Ti 1 N, R14E, 2113' SNL & 493' EWL BP Explaratian (Alaska} • ALL L 1"R~4~f~1"~I L t_ ,. ProActive Diagnostic Servi:Ces, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hale/Open Hole/Mechanical Logs and/or Tubing Inspectaon(Caliper/ MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Bfixi. Anchorage, Alaska 99508 and w ;..... ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road suite C ~p<(- t ~ o /~ S~ZS Anchorage, AK 99518 Fax: (907) 2+458952 1) Static STp Survey 11-Nov-0S K-09C 1 Color Log / EDE 50.029-2173fi-03 2j Signed Print Name: Date ~ ~ ~ ~. dk PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAf3E, AK 99518 PFIONE: (907)245-8951 FAX: (907)245-88962 E-AAAIL : ~d~anc~aorage(a)rne~e~aor~lor~ com WEBSITE : v~nv~ru.rr~eo7aor~~~og.~orr~ C:~Docamentia and Settingsl0wnec\DesktoplTransmit BP.docx STATE OF ALASKA /~ ~-~I G ~ ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS /~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other Performed: Alter Casing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 204-1100 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21736-03-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 52.86 KB - PBU K-09C 8. Property Designation: 10. Field/Pool(s): - ADLO-028304 ~`OOo?~30~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12352 - feet Plugs (measured) 11000' 11/13/08 true vertical 9006.89. feet Junk (measured) None ~~~~~~y ~~~ ~~~ ~ ~ ~~~~ > Effective Depth measured 12310 - feet ~ true vertical 9008.16 - feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" Surface - 110' Surface - 110' Surface 2675' 13-3/8" 72# L-80 Surface - 2675 Surface - 2674' 5380 2670 Production 7594' 9-5/8" 47# L-80 Surface - 7594' Surface - 6996' 6870 4760 Liner 2875' 7" 26# L-80 7422' - 10297' 6849'.- 10297' 7240 5410 Liner 173' 4-1/2" 12.6# L-80 10144' - 10317' 8976' - 8996' 8430 7500 Liner 2132' 3-1/2X3-3/16X2-7/8 10213' - 12345' 8990' - 9007' L-80 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 27 - 9436 0 0 - Packers and SSSV (type and measured depth) 7" Baker ZXP Packer 7415 4-1/2" Baker S-3 Perm Packer 9380 5" Baker ZXP Top Packer 10136 3.7" BAKER KB LINER TOP PACKER 10213 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~'' ';~j~~4.~~ ,.1~~FS ~ ~f ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 524 47606 6 1195 Subsequent to operation: 675 58815 98 255 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory 1-`` Development - Service C` Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~' - Gas ~ WAG ~ GINJ Iw WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 11/25/2008 orm - ews u i ngina n y r K-09C 204-110 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base K-09C 7/16/04 PER 11,070. 11,370. 9,011.66 9,009.64 K-09C 7/16/04 PER 11,650. 12,080. 9,011.96 9,009.12 K-09C 7/16/04 PER 12,220. 12,290. 9,011.01 9,008.83 K-09C 11/13/08 BPS 11,000. 11,010. 9,012.13 9,012.11 K-09C 11/13/08 PER 10,797. 10,822. 9,005.5 9,005.96 K-09C 11/14/08 PER 10,772. 10,797. 9,004.88 9,005.5 K-09C 11/15/08 PER 10,672. 10,697. 9,006.63 9,005.98 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • K-09C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE 11/8/2008 SUMMARY CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> MIRU, MU CTC - and during PT it looks like we have an ice plug in the coil. It looks like we have problems with IFC cable 430'+ in the coil. RIH to 2500' to unthaw ice plug. POOH. Freeze protect CT. Begin cutting pipe. Continue on WSR on 11/9/08. ***Job in Progress*** 11/9/2008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/8/08. Continue cutting pipe. Found breaks in IFC at 422', 435', Cut off a total of 570' before we had a good signal on the IFC. Begin pumping N2 down IFC to purge the cable. N2 did not make it to the end of the IFC, RU to pump hot fluid and purge with N2 at the same time. IFC is thawed and the N2 is pushing fluid out, continue to purge until IFC is dry. IFC dry. Begin slack managemnent process. Continue on WSR on 11/10/08 ****Job in Progress**** 11/10/2008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»>Continue from WSR on 11/10/08. Continue with slack management pumping rates from .5bpm to 1.8bpm while feeding IFC cable into end of pipe. At crew change we had 45' of IFC cable fed into coil. Several attempts to get more slack pumped back failed. MU iCoil tools and proceed with job. Test BOPE. Good Test on BOPE. Continue on WSR on 11/11/08. ****Job in Progress**** ~ 11/11/2008 _ CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/10/08. RIH w/2.2 JSN. Tag at 12305 CTM. Paint flag at 12275 CTM POOH. MU BTT MHA and PDS STP, FBS and X Y Calliper and RIH. Inflow was to much to RIH with the choke closed to 45%, decision was made to shut in well and lop static pass and send data to town. OOH LD tools and check for data and send off to town for plan forward. Continue on WSR on 11/12/08. ****Job in Progress**** 1 1 /1 212008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/11/08. Waiting on results from APE and PDS. APE called and the de_cisio_n was made to set CIBP and Add Perfs. (-6' Correction on logs.) Unable to et ast 10690' 3 3/16" b 2 7/8" XO POOH. At surface ck CIBP u er & lower slips & rubber element are missing. RIH with venturi to 10225' unable to get down POOH look at tools. ****** Continued on 11/13/08 ****** 11/13/2008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/12/08.POOH with venturi At surface venturi basket clean no marks on mule shoe. MU venturi with motor RBIH. OOH recovered most of the slip se ments and most of the rubber element. Tie into 10' marker joint @ 10708' with icoil CCL. Correct coil depth -10'. Set CIBP @ 11000' CTM RIH w run #1 25' 6 spf PJ 2006 60 degree phasing guns shoot from 10797 to 10822'. POOH break i down guns recover ball confirm all shots fired. ******* Continued on 11/14/08 ', ~ WSR *.***.** . .. ~ ~ ~ 11/14/2008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/13/08 RIH w run #2 25' 6 spf PJ 2006 60 degree phasing guns pert from 10772' to 10797'. POOH Recovered ball from firing head. Change pack off rubbers and preform chain inspection. Replaced 18 bearings on injector.M/U MHA "*""* Continued on 11/15/08 WSR """'`*** 11/15/2008 CTU #5 iCoil with ACTive Tools «<InterACT is Publishing»> Continue from WSR on 11/14/08 RIH w run #3 25' 6 spf PJ 2006 60 degree phasing guns pert from 10672' to 10697'. POOH OOH confirmed guns fired all shots. Recovered 1/2" aluminum ball.Freeze protect from 2500' with 60/40 methanol 37 bbls. RDMO """""Job complete"""""' FLUIDS PUMPED BBLS 629 60/40 METH 679. 2% KCL 1308 Total • ~ .,~.. MICROFILMED 03/01/2008 DO NOT PLACE ,IX:, ;v. ~~" ~': ,~,,. ~~ ~. ANY NEW MATERIAL UNDER THIS PAGE F:\L,aserFiche\CvrPgs_Inserts\Microfilm Marker.doc I 7 ~'4- DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2041100 Well Name/No. PRUDHOE BAY UNIT K-09C Operator BP EXPLORATION (ALASKA) INC ~ ~ ~&/\A~~V API Nf 50-029-21736-03-00 MD 12352/ TVD 9007 /' Completion Date 7/17/2004./ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples -No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR. MGR 1 CCL 1 CNL Well Log Information: Electr Digital Dataset Med/Frmt Number D Asc (data taken from Logs Portion of Master Well Data Maint Rpt r-'LiS ~LTa~ ~ Name Directional Survey Directional Survey Induction/Resistivity Log Log Run Interval OHI Scale Media No Start Stop CH Received Comments 8/5/2004 MWD 8/5/2004 MWD 10025 12352 Open 2/22/2006 ROP DGR EWR plus Graphics 9948 12298 Open 1 0/20/2004 MWD/GRlEWR4/ROP :>-£'l 9948 12298 Open 1 0/20/2004 MWD/GRlEWR4/ROP 2 Blu 10078 12300 2/3/2005 cnl/mem gr/ccl Sample Interval Set Start Stop Sent Received Number Comments . 13511 12786 Induction/Resistivity ~IS Verification t ') Neutron Well Cores/Samples Information: Name ADDITIONAL INFORM1\ION Well Cored? Y l~ Chips Received? ~ . Formation Tops ~ Daily History Received? Analysis Received? ~ Comments: ~ Compliance Reviewed By: Date: e:rtl.; ~ ¡c . . WELL LOG TRANS MITT AL ,~é'A -- II () To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 I ð5+ I RE: MWD Formation Evaluation Logs K-09C, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 K-09C: LAS Data & Digital Log Images: 50-029-21736-03 1 CD Rom Gf:QQQtJ~) :3// uðJtlo K-09C (PTD #2041100) Classified as Problem Well . . All, Well K-09C (PTD 2041100) has sustained casing pressure on the IA and has been classified as a Problem Well. Wellhead pressures on 2/9/06 were 2350/2120/vac psi. A TIFL failed on 2/11/06 due to IA repressurization. The plan forward for this well is as follows: 1. SL: DGLV's 2. FB: MITIA to 3000 psi Attached is a wellbore schematic. Please call if you have any questions. «K-09C.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: K-09C.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCP /vl~tf> J.A O}r Z" \ZDpS: \1 (U:_ 6CblO r< 3ð.q~ '- òLL .~ CölftZ j (~4~MÞlP) .......-- S1?e1r z{{.lö<o 1 of 1 2/16/2006 1: 13 PM TREE = WELL HEA 0 = AClUATOR= KB, ELEV = BF. ELEV - KOP- r.tax Angle = l:atum MD- l:atum lVO- 4-1/16" OW McEVOY AX8..S0N 52.86' 26.21' 3200' 93 @ 12207' 9867' 8800' SS K-09C . 13-3/8"CSG, 72#, L-80, 10 =12.347" 7409' 7415' 7422' TOP OF BAKER llEBACKSLV, 10 =7,500" 9-518" X 7" BAKERZXP A<R, 10= 6.375" 9-5/8" X 7" BAKERHIVC HGR, 10= 6.276" 19-518" CSG, 47#, L-80, 10= 8.681" H 7594' r-- Minimum ID = 2.440" @ 10690' 3-3/16" X 2-718" XO 14-112" lBG, 12.6#, L-80, .0152 bpi, 10 = 3.958" I 7" LNR, 26#, L-80, 10 = 6.276" 3-1/2" LNR, 6.2#, L-80, .0076 bpi, 10 = 2.990" WECHA NlCAL HOLLOW IM-HPSTOCK 1 WHIPSTOCK ANCHOR I 14-112" LNR, 12.6#, L-80, .0152 bpi, 10=3.958" PERFORATION SUNMARY REF LOG: ANGLEA TTOP ÆRF: 91 @ 11070' Note: Refer to Production OB for historical perf data SIZE SPF INIERVA L OpnlSqz D6.IE 2" 4-611070-11370 0 07/16/04 2" 6 11650 - 12080 0 07116/04 2" 6 12220 - 12290 0 07/16/04 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" I SAFETYNOTES: CATEGORY I I. NOSSSV. 2160' -14-112" HES HXO SSSVN,IO = 3.813" I GAS LIFT MANDRELS ST M:> TVO OEV TYPE VLV LATCH POR 2 4305 4181 25 CAIVCO OOWE RK 16 1 7377 6755 30 CAIVCO S/O RK 20 D6. IE 08/05/04 08105104 9369' -14-1/2" HES X NIP, 10 = 3.813" I 9380' 7" X 4-1/2" BKR $03 A<R, 10 = 3.875" 9403' -14-1/2" HES X NIP, 10 = 3.813" 1 9424' -14-112" HESX NIP, MILLS) 10= 3.80" 9436' -14-112" IM...ffi, 10 = 3.958" I HELM:> TT NOT LOGGS) I TOPOF BKR llEBACKSLV, 10 = 5.250" -17" X 5" BKR ZXP A<R, 10 = 4.375" I 7" X 5" BKR HIIIC HGR, 10 = 4.375" 5-1/2" X 4-1/2" XO, 10 = 3.958" -13.7" BKR LNR TOP PKR, 10 = 2.560" I -3.7" BKR DEPLOYMENT SLV, 10= 2,972" 3-1/2" HES XN NIP, 10 = 2.765" 3-112" X 3-3116" XO, D =2.786" -13-3/16"X 2-7/8" XO, 10=2.440" I 2-7/8" LNR, 6.16#, L-80, .0058 bpf, 10= 2.441" D6.IE 09109/87 12/13/94 05130197 07116104 08/05/04 REV BY COMMENTS REV BY COMWENTS ORIGINAL COMPLETION RIG SDTRK-K-09A-WELL SUS RIG SDTRK (K-09B) KAK CTO SJDETRACK(K-09C) RIM...IlLP GLV C/O OATE PRUOHOEBAY UNrr WELL: K-09C PERMT No: 2041100 API No: 50-029-21736-03 SEe 4, T11 N, R14E, 2113' SNL & 493' EWL 8P Exploration (Alaska) iD 7SPVA ~:<vt/- //Ú 01/24/05 Schlumberger NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . 2, Well ob# og Descnptron ate ue me rmts '{)'!J...}II G-12B 10715391 MCNL 03/21/04 1 7L'·).//~ 15-398 ).,0 :,.. i'1 4 10728396 MCNL 04/03/04 1 .~ 7-vJ·( I (", D-04B 10715393 MCNL 04/07/04 1 DS 18-13A 10715395 MCNL 04/16/04 1 70'.3-1<{5 K-10B 10715402 MCNL 05/16/04 1 DS 02-15A 10715404 MCNL 05/18/04 1 t~- ¡¿; DS 2-33A 10670016 MCNL OS/23/04 1 ì 9f-CX1' DS 07 -03A 10715406 MCNL 06/03/04 1 '2a}·iql. DS 07 -29C 10715407 MCNL 06/04/04 1 h;'ðf2- E-15B 10861913 MCNL 06/05/04 1 %1;'15' DS 18-27C 10715410 MCNL 06/13/04 1 ß"t,·Y{1 E-24B 10861916 MCNL 06/20/04 1 11,-/09 DS 18-31 10715413 MCNL 07/05/04 1 J6/l iJ 0 K-09C 10861920 MCNL 07/16/04 1 t?·0'11 C-17B 10715418 MCNL 08/10/04 1 t'l-j .0:14 C-39 10715421 MCNL 08/19/04 1 Prints,-- only-Job not complete) J L D BI ' Color p' CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc, Petrotechnical Data Center LR2-1 900 E, Benson Blvd, Anchorage, Alaska 99508 ~;68 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Date Delivered: . . ¿;¿'o cf - (! 0 WELL LOG TRANSMITIAL # 12-1~ 10 To: State of Alaska Alaska Oil and Gas Conservation Comm, Attn.: Robin Deason 333 West 71lt Avenue, Suite 100 Anchorage, Alaska 99501 October 07, 2004 RE: MWD Formation Evaluation Logs: K-09C, AK-MW-3167150 1 LDWG formatted Disc with verification listing. API#: 50-029-21736-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Date loÞfl RECEIVED ') (ì 0N1 ~ .'. C'.:V"'· · STATE OF ALASKA . ALASKA1I8'rL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a, Well Status: ~ Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ~ Development o Exploratory DGINJ DWINJ o WDSPL No, of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp" Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc, 7/17/2004 204-110 3, Address: 6. Date Spudded 13, API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 7/8/2004 50- 029-21736-03-00 4a, Location of Well (Governmental Section): 7, Date T.D. Reached 14, Well Name and Number: Surface: 7/12/2004 PBU K-09C 2113' SNL, 493' EWL, SEC. 94, T11N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3465' SNL, 2826' WEL, SEC. 05, T11 N, R14E, UM 52.86' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ rvD) 3616' SNL, 1594' WEL, SEC, 05, T11 N, R14E, UM 12310 + 9008 Ft 4b, Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+rvD) 16, Property Designation: Surface: x- 670766 y- 5975091 Zone- ASP4 12352 + 9007 Ft ADL 028304 TPI: x- 667482 y- 5973665 Zone- ASP4 11, Depth where SSSV set 17, Land Use Permit: Total Depth: x- 668717 y- 5973542 Zone- ASP4 (Nipple) 2160' MD 18, Directional Survey 19, Water depth, if offshore 20. Thickness of Permafrost ~Yes DNo N/A MSL 1900' (Approx,) 21, Logs Run: SGRC Combined GR & EWR, MGR I CCL / CNL 22. CASING, LINER AND CEMENTING RECORD \i_ CASING SEttIN(;1 EPTH MD ~I;TTINQ EP1:ffT\I'D HOLE \\ SIZE WT,P~RFT; GRADE lOP tsOTTOM lOP 160TTOM SIZE 20" Conductor 30' 110' 30' 110' 8 cu vds Concrete 13-3/8" 72# L-80 / S-95 30' 2675' 30' 2674' 17-1/2" 1901 cu ft AS III, 1860 cu ft AS II 9-5/8" 47# L-80 30' 7594' 30' 6996' 12-1/4" 1920 cu ft Class 'G' 7" 26# L-80 7422' 10297' 6849' 10297' 8-1/2" 533 cu ft Class 'G' 4-1/2" 12,6# L-80 10144' 10317' 8976' 8996' 6" 140 cu ft Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2# /6.16# L-80 10213' 12345' 8990' 9007' 4-1/8" x 3-3/4" 118 CU ft Class 'G' 23, Perforations open to Production (MD + rvD of To,e and 24. '\ i Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 - 6 spf 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9436' 9380' MD rvD MD TVD 11070' - 11370' 9012' - 9010' 11650' - 12080' 9012' - 9009' 25. > )~ ·..ETêU 12220' - 12290' 9011' - 9009' ) ...,.....11;.1.\.., ,......,.",.." ),.,. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc,): August 6, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl CHOKE SIZE I GAS-Oil RATIO 8/8/2004 4 TEST PERIOD ... 616 1,854 17 95° 3,011 Flow Tubing Casing Pressure CALCULATED + Oll-BBl GAs-McF W A TER-BBl Oil GRAVITY-API (CORR) Press. 1,1 OE 1,604 24-HoUR RATE 3,694 11,121 104 27, CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~T~'~ None i. . ,.P".JN I ?~~A ~fIDIS 8Ft AUG 1 "1 ')f"\f1i .J!ÆD I Gç -.--=:"'-:..1 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE Rt INAL O. G 28, GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Zone 1 B 10130' 8973' None (Kicked off in Zone 1 B from K-09B and stayed in Zone 1 B the entire sidetrack,) 30, List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 0 Prepared By Name/Number: Terrie Hubble, 564-4628 Drilling Engineer: Mary Endacott, 564-4388 PBU K-09C Well Number 204-110 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated, Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments, ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness, ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26, (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval), ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain), ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information. If none, state "None", Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/5/2004 14:00 - 14:15 0,25 MOB P PRE Rig released from 15-46L 1 @ 14:00Hrs on 7/5/2004, Prep to move rig off well. 14:15 - 14:30 0,25 MOB P PRE PJSM for moving rig off well. 14:30 - 15:00 0.50 MOB P PRE Pull rig off well. Clean up location, Conduct post-operations pad inspection, 15:00 - 15:30 0,50 MOB P PRE Held pre-move safety meeting, 15:30 - 00:00 8,50 MOB P PRE Move rig from 15-46L 1 to K -09, 7/6/2004 00:00 - 01 :30 1,50 MOB P PRE Arrive K-09. Prep to back rig over well. Check WHP - Opsi with a closed SSV. 01 :30 - 01 :45 0.25 MOB P PRE PJSM, Review procedure, hazards & mitigation for backing rig over well. 01 :45 - 02:00 0,25 MOB P PRE Back rig over well & set down, ACCEPT RIG @ 02:00 HRS ON 07/06/2004, 02:00 - 04:00 2.00 BOPSU P PRE N/U BOPE, grease tree valves & open up SSV, 04:00 - 10:00 6.00 BOPSU P PRE Perform initial BOPE function/pressure test. AOGCC test witness waived by Chuck Scheve. Meanwhile, spot trailers & tanks, Fill rig pits with 290 bbls, 2# Biozan, Pick up WF whipstock and install 3 SWS RA tags in whipstock, Top of whipstock to RA tag = 2,20 ft, 10:00 - 10:15 0,25 WHIP P WEXIT SAFETY MEETING, Review procedure, hazards and mitigation for M/U WF Whipstock BHA, 10:15-13:30 3,25 WHIP P WEXIT Change out CT pack-off and M/U WF CTC. Pull test. Fill coil, pump dart, dart on seat at 58,0 bbls, Pressure test inner reel valve and CTC, M/U WF Whipstock BHA with TF set for 45R with packer lug at 168L. 13:30 - 16:40 3,17 WHIP P WEXIT RIH with BHA #1, WF Whipstock with latch assembly, OAL = 60,86 ft. Send returns to tiger tank, Working on CTDS computer, will not track volumes and stay running. 16:40 - 16:45 0,08 WHIP P WEXIT Latch into pkr at 10370 ft, work wt down, PUH and sheared at 54k (11 k over) TOW at 10304,25 ft RA Markes at 10306,50 ft Packer at 1 0350 ft 16:45 - 18:41 1,93 WHIP P WEXIT POOH, Painted flag at 10180 ft (EOP) 18:41 - 19:30 0,82 WHIP P WEXIT LD WS setting BHA and PU Window mill BHA 19:30 - 20:13 0,72 WHIP N RREP WEXIT Working on Power Pack hydraulic pop off 20:13 - 22:10 1,95 STWHIP P WEXIT RIH, PU Wt at 10210 = 41k Tagged at 10316' uncorrected Corrected to 10304 ft 22:10 - 22:30 0.33 STWHIP P WEXIT PUH, start pump Q = 2,67 bpm; Pp = 2100 psi (off-btm) Vp = 311 bbl 22:30 - 00:00 1.50 STWHIP P WEXIT Milling window as per programmme. Q= 2.75 bpm, Pp=21 00/2420 psi, WOB at 4,5k IA= 800 psi; OA = 110 psi 7/7/2004 00:00 - 01 :30 1,50 STWHIP P WEXIT Milling window as per programme, Stalled twice, at 10306.9 ft, Q= 2,73 bpm, Pp = 2100 1 2470psi. Bleed IA down from 893 psi to 366 psi 01 :30 - 03:35 2,08 STWHIP P WEXIT PU and restarted milling window, Milled to 10307,9 ft, PUH, restarted, could be outside 4-1/2" liner at approximately 3.0 ft from TOWS, Milled down to 10311 ft, 7 ft below TOWS Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/7/2004 01 :30 - 03:35 2.08 STWHIP P WEXIT 03:35 - 04:00 0.42 STWHIP P WEXIT 04:00 - 04:30 0,50 STWHIP P WEXIT 04:30 - 05:40 1,17 STWHIP P WEXIT 05:40 - 07:45 2.08 STWHIP P WEXIT 07:45 - 08: 1 0 0.42 STWHIP P WEXIT 08:10 - 08:30 0,33 DRILL P PROD1 08:30 - 09:20 0,83 DRILL P PROD1 09:20 - 11 :30 2.17 DRILL P PROD1 11 :30 - 11 :50 0,33 DRILL P PROD1 11 :50 - 13:00 1,17 DRILL P PROD1 13:00 - 13:45 0.75 DRILL N WAIT PROD1 13:45 - 16:30 2.75 DRILL P PROD1 16:30 - 19:20 2,83 DRILL N DPRB PROD1 19:20 - 22:01 2,68 STWHIP N DPRB WEXIT 22:01 - 00:00 1,98 STWHIP N DPRB WEXIT 7/8/2004 00:00 - 01 :00 1,00 STWHIP N DPRB WEXIT 01:00 - 02:15 1.25 STWHIP N DPRB WEXIT 02:15 - 03:15 1,00 DRILL N DPRB PROD1 03: 15 - 05:00 1.75 DRILL N DPRB PROD1 05:00 - 05:44 0,73 DRILL N DPRB PROD1 05:44 - 05:50 0.10 DRILL N DPRB PROD1 05:50 - 06:00 0,17 DRILL P PROD1 06:00 - 18:20 12,33 DRILL P PROD1 Checked samples at 10309 ft."Formation sample" Backed reamed window area, PU clean, Drill rathole to 10,319'. Drift window several times wI pump, Drift wlo pump twice. Displace well to flo pro, POOH displacing well bore to reconditioned flo pro, LD window milling BHA. Window mill 3.80", string mill 3,78", Cut off Weatherford CTC. Install Schlumberger CTC. Pull test to 38K, PT to 3,900 psi. PU drilling BHA wi 3.0 degree motor, Hycalog DS100 H+GJNU bicenter bit, DIR/GR. RIH, Did not perform SHT in the 4 1/2" tubing with the 3 degree motor. Test MWD and orienter inside the 7" casing at 9,600', RIH to 9,985', Correct to 9,400' EOP flag. +17,5' correction. Orient HS, Tie in logging down to 10,015', +18' correction. Circulate while waiting on DD. Orient to 45R. Shut down pump, Attempt to RIH past window. Saw a bobble at 10,325' and stacked out at 10,330'. PU and check orientation, 122L, Orient to several different TF, unable to work past window. Same results each time, weight bobble at 10,325' and stacking out at 10,330', Set down at 10,330' wi 45R TF, Roll pump and still cannot pass. OOH, Inspected bit, 2 gauge insert broken, fomation on pilot, no damage on pilot. PU/MU Wfd dia 3,8" Crayola mill, 1,04deg mtr. RIH to dress up window Orient TF at 9834ft to HS and shallow hole test MWD Tie in at 9965 ft to 10030 ft (Corrected -0.5 ft) RIH to 10330 ft, tagged, PUH and Orient TF to 76R Reamed 10330' to 10300' at 82R TF Tagged at 10330.1 ft, Oriented TF to 167L Reamed 10330' to 10300' at 167R TF, Orient TF to 90L Reamed 10310' to 10325' at 93L TF Little motor work at 10315', 200 psi at bottom of window @ 10319', Backed reamed from 10325' to 10310', < 100 psi P inc at 10317' Orient TF to 30L Reamed 10307' to 10325'. Small motor work at 10315' (skate) Orient TF to 30R, Reamed to 10325 ft, no pressure or wt changes PUH to 10307', SD pumps and dry tag at 10330 ft PUH and oriented TF to 132 L RIH tagged at 10330 ft, Window uncorrected depth from 10315 ft to 10319 ft POOH to try drilling 3,06 deg BHA Changeout BHA. Mill at <3,79" OD, Formation on nose RIH Tie-in 7" from 9980 ft to 10026 ft (corrected -1 ft) RIH and tagged at 10330 ft Orient TF Drill at 2,6/2.61 3,700/4,000 psi. Drill w/90R-100R TF to achieve directional plan right turn. ROP 40 fph average, Some tough drilling, When orienting is necessary, having to pull up hole to just below the window to get clicks, Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/812004 06:00 - 18:20 12,33 DRILL P PROD1 Following Tie-in to RA Marker TOW = 10317 It BOW = 1 0320 It RA Marker = 10319 It 18:20 - 18:32 0,20 DRILL P PROD1 Wiper trip to clean hole and orient TF 18:32 - 18:47 0.25 DRILL P PROD1 Orient TF 18:47 - 19:00 0,22 DRILL P PROD1 RIH at TF 7L 19:00 - 19:30 0,50 DRILL P PROD1 Drilling- Q = 2.66/2,76 bpm- Pp 3500/3746psi, IA 359-0A 105, Vp = 282 bbl TF at 80R Unable to get a TF at 80 R on btm with 3 deg bend 19:30 - 19:53 0,38 DRILL P PROD1 PUH to below window to get correct orientation, RIH tagged at 10657 ft, TF flopped to 128R, need to build hole angle 19:53 - 21 :23 1.50 DRILL P PROD1 PUH to orient TF around Orient TF at 10328 ft 21 :23 - 22:46 1.38 DRILL P PROD1 Drilling- Q = 2,66/2.76 bpm- Pp 3500/3746psi, IA 359-0A 105, Vp = 279 bbl TF at 77R. ROP = 30 to 40 fph 22:46 - 23: 15 0.48 DRILL P PROD1 PUH to window to orient TF 23:15 - 23:45 0.50 DRILL P PROD1 Drilling- Q = 2,66/2.76 bpm- Pp 3500/3746psi, IA 359-0A 105, Vp = 286 bbl TF at 90 R 23:45 - 00:00 0,25 DRILL P PROD1 PUH to window to orient TF 7/9/2004 00:00 - 00:15 0,25 DRILL P PROD1 Orient TF and RIH to 10701 ft 00:15 - 01:57 1.70 DRILL P PROD1 Drilling at 1 06R TF Q = 2.65/2.75 bpm P=3525/3850 psi Vp = 279 bbl. ROP 40 to 80 Hole angle not dropping as designed 01 :57 - 02:18 0.35 DRILL P PROD1 PUH to window to orient 1 click 02:18 - 03:22 1,07 DRILL P PROD1 Drilling at 128R TF Q = 2,65/2.75 bpm Pp = 3525/3850 psi Vp = 280 bbl. ROP 30 to 40 fph Using MI/Swaco Centrifuge Van 03:22 - 04:38 1,27 DRILL P PROD1 PUH to below window to orient around 04:38 - 05:04 0.43 DRILL P PROD1 Drilling at 89R TF Q = 2,65/2,70 bpm Pp = 3500/3790 psi Vp = 270 bbl. ROP 30 to 40 fph 05:04 - 05:29 0.42 DRILL P PROD1 PUH to window to orient 1 click 05:29 - 06:00 0,52 DRILL P PROD1 Drilling at 111 R TF Q = 2.65/2,70 bpm Pp = 3430/3790 psi Vp = 269 bbl. ROP 40 to 65 fph, Turn made at a 8951 ft TVD 06:00 - 08:00 2,00 DRILL P PROD1 POOH 08:00 - 09:00 1,00 DRILL P PROD1 LD BHA. Bit graded 1-2-BT-G-X-NA-NO-BHA. 09:00 - 09:30 0,50 DRILL P PROD1 Rig evacuation drill and safety meeting, 09:30 - 11 :10 1.67 DRILL P PROD1 MU lateral BHA w/ 3,75"x4,125" Smith bicenter bit, new 1,04 deg motor, DIR/GR/RES. 11:10 -13:00 1,83 DRILL P PROD1 RIH and tag bottom at 10,803' (uncorrected), No problems Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/912004 11:10 -13:00 1.83 DRILL P PROD1 going through window. Hole in good condition, 13:00 - 14:00 1,00 DRILL P PROD1 MAD pass for RES data, Tie in to RA marker, -2' correction, 14:00 - 14:20 0,33 DRILL P PROD1 RIH, Tag bottom at 10,802', 14:20 - 18:23 4.05 DRILL P PROD1 Orient to 100R. Start mud swap pumping reconditioned flo pro, Drill at 2,7/2,8, 3,600/3,730 psi. Tough drilling getting started, 18:23 - 19:24 1,02 DRILL P PROD1 Orient TF around 19:24 - 20:00 0,60 DRILL P PROD1 Drilling at 70 R TF Q = 2,53/2.61 bpm Pp = 3430/3625 psi Vp = 325 bbl. Pulled tight at 10900 ft 70k while orienting 20:00 - 20:30 0,50 DRILL P PROD1 PUH to window to orient and wiper trip 20:30 - 21 :34 1,07 DRILL P PROD1 Drilling at 91 R TF Q = 2,65/2,70 bpm Pp = 3225/3950 psi Vp = 323 bbl. Pushing WOB to build hole angle, 21 :34 - 22:34 1,00 DRILL P PROD1 Orient TF to approximately 5 R. Having trouble orienting in open hole 22:34 - 22:42 0,13 DRILL P PROD1 Drilling at 9 - 29R TF Q = 2.65/2,70 bpm Pp = 3225/3950 psi Vp = 323 bbl. 22:42 - 23:04 0,37 DRILL P PROD1 Orient TF, Having trouble orienting in open hole 23:04 - 00:00 0,93 DRILL N DFAL PROD1 POOH to change orienter and bit 7/1 0/2004 00:00 - 00:57 0.95 DRILL N DFAL PROD1 POOH 00:57 - 02:04 1.12 DRILL N DFAL PROD1 Change out BHA, download Res tool 02:04 - 03:45 1,68 DRILL N DFAL PROD1 RIH to 10380' 03:45 - 04:20 0,58 DRILL N DFAL PROD1 Tie-in at RA Marker at 10319 ft Corrected -4 ft at 10357 ft 04:20 - 04:30 0,17 DRILL N DFAL PROD1 RIH and tagged at 10740 ft (shale) TF 180 out 04:30 - 04:44 0,23 DRILL P PROD1 Orient TF to R-side, SD Pumps, RIH past shale ledge 04:44 - 04:50 0,10 DRILL P PROD1 Orient TF to 80 to 90 R 04:50 - 08:30 3.67 DRILL P PROD1 Drilling at 85R TF Q = 2.65/2,70 bpm Pp = 3225/3950 psi Vp = 319 bbl. Off of NPT time at 0430 hrs ROP =50 to 120 FPH with DS 49 No signs of prognosed fault. 08:30 - 09:15 0.75 DRILL P PROD1 Wiper trip to window. Set down at 10,750' oriented 120L. PU, slow pump and went through, 09:15 - 12:55 3,67 DRILL P PROD1 Orient. Drill to 11,292' at 2,7/2,83,550/3,700 psi. 12:55 - 15:10 2,25 DRILL P PROD1 Wiper trip, Pull into tubing tail. Wash down to 10,130', bottom of 7", Wash up and pull into tubing tail. RIH, Tie in to RA marker, Orient to RTF above 10,740', RIH and slight motor work at 10,740'. RIH. Tag bottom. 15:10-18:15 3,08 DRILL P PROD1 Drill from 11,292' to 11,450' at Q= 2,62/2,75 Pp = 3,550/3,730 psi, ROP= 90-100 fph avg, 18:15 - 18:55 0,67 DRILL P PROD1 Wiper trip to window, Tagged shale at 10740 ft w/ 90L TF, 18:55 - 19:30 0.58 DRILL P PROD1 Tried wo/ pump, no, PU and orienet TF. after 8 clicks, no movement. PUH to 10335' and orient TF to HS RIH at 9R RIH with 9R TF Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/10/2004 19:30 - 19:53 0,38 DRILL P PROD1 RIH past 10740ft 19:53 - 20:10 0,28 DRILL P PROD1 Orient TF 90 R 20:10 - 21 :51 1,68 DRILL P PROD1 Drill from 11 ,450' to 11526 at 90R TF Q= 2.62/2,75 Pp = 3,200 /3,618 psi, ROP= 50-60 fph avg. Possible fault at 10495 ft 21 :51 - 22:03 0,20 DRILL P PROD1 Orient TF to compensate for Faulted area 10500 ft 22:03 - 22:11 0,13 DRILL P PROD1 Drill from 11526 ft to 11544 ft, At 90R jumped to 90L TF after getting through fault Q= 2.62/2,75 bpm Pp = 3,200 /3,518 psi Making ready to conduct mud swap 22:11 - 22:27 0,27 DRILL P PROD1 Orient TF from 90L to R-side 22:27 - 23:22 0.92 DRILL P PROD1 Drill from 11544 ft, TF @ 110R Q= 2,62/2,75 bpm Pp = 3,200 I 3,560 psi Started new mud down CT at 2240 hrs 23:22 - 23:32 0.17 DRILL P PROD1 Orient TF to L-side 23:32 - 23:40 0.13 DRILL P PROD1 Drill from 11581 ft. TF @ 99L Q= 2,62/2.75 bpm Pp = 3,200 / 3,360 psi ROP = 50fph 23:40 - 00:00 0,33 DRILL P PROD1 Wiper trip to 7" liner 7/11/2004 00:00 - 01 :37 1,62 DRILL P PROD1 Wiper trip to 4-1/2" TT. Oriented TF to HS before going in open hole, Didn't see anything at 10740 ft with 90R TF 01 :37 - 01 :53 0.27 DRILL P PROD1 Orient TF L-Side 01 :53 - 03:25 1.53 DRILL P PROD1 Drill from 11581 ft to 11701 ft, TF HS to 90 L Q= 2,74 1 2,86 bpm Pp = 2,900 I 3,156 psi Finish Mud Swap at 0200 hrs Vp = 284 bbl 03:25 - 04:12 0,78 DRILL P PROD1 Drill from 11701ft to 11742 ft at TF 55L to 90 L Q= 2,74/2.86 bpm Pp = 2,900 / 3,156 psi Vp = 284 bbl Lots bit stacking Make BHA wipers to get better WOB, Hole angle dropping due to soft formation. Reactive Torque at 80 deg 04:12 - 05:26 1.23 DRILL P PROD1 Wiper trip to WS (No problem at 10740 ft) 05:26 - 05:50 0.40 DRILL P PROD1 Orient TF to HS, Vol P = 282 bbl following wiper trip 05:50 - 06:00 0,17 DRILL P PROD1 Drilling at HS TF, ROP = 120 fph 06:00 - 06:20 0,33 DRILL P PROD1 Orient TF to L-Side 06:20 - 07:00 0,67 DRILL P PROD1 Drill at 80 to 90 L TF Q= 2.70/2,81 bpm Pp = 2,900 1 3,322 psi Vp = 275 bbl 07:00 - 09:20 2,33 DRILL P PROD1 Pit vol. 276 bbls, IA=283, OA=96 psi. PU=36,000 Ibs, SO=18,500 Ibs, Drill at 2,7/2,7 bpm, 3,050/3,300 psi. Getting a little sticky, 18K Ib overpulls, Stacking weight. 09:20 - 12:30 3.17 DRILL P PROD1 Wiper trip to tubing tail. Wash down to bottom of 7", Pull into tubing tail pumping at 2,9 bpm. RIH. Attempt to go through 10,740' w/o pump. Set down lightly, PU to just below window and orient to 90R. Run past 10,740' no problem, 12:30 - 13:45 1,25 DRILL P PROD1 Orient to 80R. Drill from 11,795' to 11,992'. Q=2,9/2,9 bpm Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/11/2004 12:30 - 13:45 1.25 DRILL P PROD1 Pp=3,300 / 3,900 psi. Vp=270 No differential sticking, ROP 130 fph, 13:45 - 14:50 1.08 DRILL N RREP PROD1 Rig generator motors overheating, Pull up hole while working on gen 1, 14:50 - 15:45 0.92 DRILL P PROD1 Drill at 94R TF to 12,050', 0=2,65/2,77 bpm Pp=3.030 /3,460 psi. Vp=270 No differential sticking, ROP 80 fph, 15:45 - 16:00 0,25 DRILL N STUC PROD1 PU for wiper trip and differentially stuck, Circulate OH volume and shut down pump, 16:00 - 16:30 0,50 DRILL N STUC PROD1 Work pipe. Let pipe and formation relax, Call for crude, 16:30-17:15 0,75 DRILL N STUC PROD1 Orient 6 times, Got all 6 clicks, Stuck above BHA. CBU. Crude on location at 16:55, 17:15 - 17:30 0,25 DRILL N STUC PROD1 SD pump and let formation relax, Work pipe up to 84K, 17:30 - 18:00 0,50 DRILL N STUC PROD1 Pump 26 bbls of crude. Pump 19 bbls out of coil. SD pump. 18:00 - 18:15 0,25 DRILL N STUC PROD1 Let crude soak, PU to 80K and pipe came free, 18:15 -19:04 0.82 DRILL P PROD1 Wiper trip to above WS at 10286 ft 19:04 - 19:40 0,60 DRILL P PROD1 Circulate oil to surface and to tiger tank Cir 54 bbl's to Tiger tank, Orient TF to HS 19:40 - 20:30 0,83 DRILL P PROD1 RIH to 10375 ft to Tie-in. Tie-in and corrected +11ft 20:30 - 21:15 0.75 DRILL P PROD1 RIH 21 :15 - 21 :22 0.12 DRILL P PROD1 Cycled tool, TF at 40L off btm 21 :22 - 22:30 1,13 DRILL P PROD1 Drill at 80 to 76L TF 0=2,55/2,60 bpm Pp=2900 / 3,360 psi. Vp=225 bbl. Lost 54 bbl from dead crude Some well bore sticking. Any stacking and it will take to 60k to pull free, Need to move CT at 20 fpm to keep from sticking, Having trouble keeping TF, possible frac area at12100 ft 22:30 - 22:49 0,32 DRILL P . PROD1 Orient TF 22:49 - 22:55 0,10 DRILL P PROD1 Drill at 60L TF 0=2,55/2,60 bpm Pp=2900 13,360 psi. Vp=225 bbl. Adding 100 bbl new flo-pro TF flops 180R when tagging bottom, doesn't act likes its locking 22:55 - 23:30 0.58 DRILL P PROD1 PUH 100 ft to orient TF and compensate for reactive torque, >90 deg 23:30 - 23:48 0.30 DRILL P PROD1 Drill at 26L TF 0=2,55/2,56 bpm Pp=2900 I 3,460 psi. Vp=317 bbl. 23:48 - 00:00 0.20 DRILL P PROD1 Orient TF to L-Side, tagged bottom and unable to orient TF to L-Side Pulling to 50 to 70 k off btm when stacking. 7/12/2004 00:00 - 02:30 2.50 DRILL P PROD1 POOH 02:30 - 04:54 2.40 DRILL P PROD1 OOH, Vp = 220 bbl Changed out orienter, MWD probe, motor, MHA. down load Res tool, scribed to HS, Printed: 7/20/2004 12:19:12 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/12/2004 04:54 - 06:45 1,85 DRILL P PROD1 RIH to window, 06:45 - 08:20 1,58 DRILL P PROD1 Tie in to RA marker logging up, -8' correction, RIH oriented 90R. 4K Weight stacking at 10,740', 08:20 - 10:30 2,17 DRILL P PROD1 Drill HS TF from 12,146' to 12,147', Q= 2,57/2.6 Pp=3,030/3,300 psi TF jumping around, Stacking weight through apparent fault rubble zone, 10:30 - 13:30 3,00 DRILL P PROD1 OrientTF to 85R, Drill from 12,147' to 12,305', 13:30 - 15:30 2,00 DRILL P PROD1 Wiper trip to window, Run through 10,740' oriented 90R TF w/o problem, Ratty going through 12,100' - 12,200', 15:30 - 18:43 3.22 DRILL C PROD1 Drill from 12,305' to 12,350'. Progress is slow in increasing GR. 18:43 - 19:40 0,95 DRILL P PROD1 Wiper trip to tie-in 19:40 - 20:00 0,33 DRILL P PROD1 Tie-in up at 10375 ft (corrected =1,5 ft) 20:00 - 20:53 0.88 DRILL P PROD1 RIH to confirm TD Tagged at 12267 ft with L-Side TF PUH and Orient TF to HS 20:53 - 21 :00 0.12 DRILL P PROD1 Orient TF to HS 21 :00 - 21 :09 0,15 DRILL P PROD1 With HS TF RIH Tagged 12329 ft, PUH and RIH with Low WOB to 12354 ft Tried 3 times and TD is 12352 ft MD 21 :09 - 22:58 1,82 DRILL P PROD1 PUH logging MAD Pass up hole 12,352 ft to 10,800 ft 22:58 - 23:36 0.63 DRILL P PROD1 RIH and lay in 33 bblliner pill 23:36 - 00:00 0.40 DRILL P PROD1 POOH laying in 33 bblliner pill 7/13/2004 00:00 - 02:00 2,00 DRILL P PROD1 POOH to run liner 02:00 - 03:00 1,00 DRILL P PROD1 OOH, LD Drilling BHA. Fill hole with 2 bbl 03:00 - 04:30 1,50 CASE P RUNPRD Install BOT CTC, pull test to 35k and PT to 3000 psi. Installed dart catcher and dart. Displaced CT Vol = 58,6 bbl. Maker ready to run liner 04:30 - 06:00 1,50 CASE P RUNPRD PU and run liner. 06:00 - 08: 15 2,25 CASE P RUNPRD Run 27/8" STL x 3 3/16" TCllliner. PU 2 joints of 31/2" STL and BOT deployment sleeve and CTLRT. MU injector, Seepage losses of 1 bph, 08:15 - 11 :00 2.75 CASE P RUNPRD RIH w/ liner on CT, PU=39K, SO=24K at 10,240'. Run liner in OH, Wt bobble at 10,740', Set down at 12,170', PU and work through. Set down at 12,335', PU and work through, Land liner on bottom at 12,352', 11 :00 - 11 :40 0.67 CASE P RUNPRD Drop 5/8" ball and circulate down, Ball on seat at 46.6 bbls, Pressure up to 4,000 psi to release from liner. PU and confirm liner is released, PU=32K. 11:40-14:15 2,58 CASE P RUNPRD Displace well to KCI. No losses. 14:15 - 14:30 0,25 CASE P RUNPRD PJSM on Liner cement job way forward 14:30 - 14:55 0.42 CEMT P RUNPRD Take on water, batch mix cement, mix Bio pill Cement at density 15,8 ppg at 1451 hrs 14:55 - 16:03 1,13 CEMT P RUNPRD Pumped 5 bbl water, PT lines to 3500 psi, pumped 5 bbl water followed by 21 bbl 15.8 ppg cement. Displaced with 25 bbl 1-1/2ppb Bio water and 12,6 bbl KCL, LWP latched at 57,9bbl and sheared at 3600 psi. Pumped 13 bbl and LWP landed at 70 bbl. Circulated 18.4 bbl up the liner annulus. Note: With 1,6 bbl cement out of liner, packed off occurred due to water/shale reaction, Pressured up to 4400 psi at 1.00 bpm before breaking back. Circulation remained 95% during Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/13/2004 14:55 - 16:03 1.13 CEMT P RUNPRD job, SD checked floats, held, with 300 psi on CT, unstung from deployment sleeve. 16:03 - 17:52 1.82 CEMT P RUNPRD POOH replacing CT voidage (5.48 bbl/1000ft) 17:52 - 18:30 0.63 CEMT P RUNPRD LD BOT CTLRT 18:30 - 19:30 1,00 EVAL Ip LOWER1 Loadlunload pipe shed, Function test BOPE, Notice the well was flowing out of 2" opening 1" to 1.5" stream, SWI and built no WHP, Open well no flow, 19:30 - 22:00 2,50 EV AL P LOWER1 MU and RIH with Logging/Cleanout BHA - Mill, motor, 2 jts CSH, MCNUGRlCCL, 68 jts CSH - Cement at 60 psi compressive strength. 22:00 - 23:30 1,50 EVAL P LOWER1 RIH with cleanouVlogging BHA at 100 fpm at 1bpm, - Cement at 700 psi compressive strength at 22:40 hrs, 23:30 - 00:00 0,50 EVAL P LOWER1 Attempt to log down at 30 fpm from 10,100' MD to 12,317' MD, - Cement at 1500 psi compressive strength, - PU wt 34k; SO wt 22k, - 1.5 bpm at 2700 psi free spin. - Tag cement stringer at 10,130' MD, - At 10,145' MD, consistent milling at 1,0 fpm. 7/14/2004 00:00 - 00:45 0,75 EVAL P LOWER1 Mill cement at 1.5 bpm, 3000 psi, and 1,0 fpm from 10,145 - 10,210' MD. 00:45 - 02:00 1,25 EVAL N STUC LOWER1 Attempted to pick up to ensure free, Stuck at 10,180' MD, Attempt many variations of pump rate and over pull. - Max pump 1,68 bpm (1,75 bpm allowable due to motor restriction) . - Max pull 50k (60k allowable due to logging tool restriction), - Pumped 2 each 15 bbls perf pill "sweeps", - Finally pulled free with high-gear upward pull of 50k at 1,5 bpm, 02:00 - 03:00 1,00 EVAL N DPRB LOWER1 POOH, 03:00 - 05:00 2.00 EVAL N DPRB LOWER1 LD BHA. - Rack back 34 stands CS Hydril. - Unload source, 05:00 - 05:30 0,50 EVAL N DPRB LOWER1 PU cleanout BHA for 4-1/2" liner. 05:30 - 07:21 1,85 EVAL N DPRB LOWER1 RIH with cleanout BHA 07:21 - 07:51 0,50 EVAL N DPRB LOWER1 Started 2ppb Bio down CT at 9,777 ft Motor work at 10,124 ft, PUH and cir Bio water 07:51 - 11 :38 3,78 EVAL N DPRB LOWER1 Milling cement Reaming at Q = 2,9/3,00 bpm. Pressure off btm = 2120 psi -Reamed 10,124' to 10,148' with 100 psi motor work, chased to TT at 9,436', RIH at 100 fpm to 10148 ft at 2.9 bpm -Reamed 10,148' to 10,160', Harder cement at 10,157' PU at 10,160 ft, pulled tight with motor work, PU to 10,100 ft and RIHt010,160ft Wash to 10,165'stall, chasetoTT,RIHat 104 fpm to 10,165 ft -Reamed 10,165 ft to 10,175' fell through, PUH, clean, RIH to 10190', washed down to 10,197 wo/ motor wok, -Reamed 10,197 ft to 12,210 ft w/125 to 150 psi motor work. Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/14/2004 07:51 - 11 :38 3,78 EVAL N DPRB LOWER1 Wiper trip to TT, -Reamed 10,210 ft to 10,225 ft wI 200 psi motor work, PUH 10130 ft, clean, RIH -Reamed 10,225 ft to 10226 ft, Tagged the top of the 3-1/2" liner at 10,226 ft 11:38-12:12 0,57 EV AL N DPRB LOWER1 PUH, circulate, work CT and drop 13/16" ball to open CS. Pumped 20 bbl HV Bio pill behind ball, Open CS at 2900 psi, inc Qp to 3,50 bpm 12:12 - 14:00 1,80 EVAL N DPRB LOWER1 POOH, chasing HV pill; to surface @ 3,5 to 4,0 bpm, Washed up BOP 14:00 - 14:41 0.68 EVAL N DPRB LOWER1 Handle BHA, PU 2,3" slim hole BHA w/71 jts 1-1/4" CSH to clean out liner 14:41 - 18:30 3,82 EVAL N DPRB LOWER1 RIH and working on SLB Computer. 18:30 - 19:00 0,50 EVAL N DPRB LOWER1 Tagged cement at 10,224' MD, Milling ahead cement to 10,240' MD, - 33k PU; 20k SO - 54 fph, 1,65 bpm, 2400 psi. - Wipe section to ensure clean, 19:00 - 20:30 1,50 EVAL N DPRB LOWER1 RIH to 12,317' PBTD at 30 fpm, 2424 psi. 20:30 - 21 :30 1,00 EVAL N DPRB LOWER1 POOH to 10,100' MD at 60 fpm, pumping at 0.4 bpm, - Lay in 15 bbls of perf pill at PBTD, 21 :30 - 23:30 2,00 EVAL N DPRB LOWER1 POOH to surface. - Drop ball to open circ sub, No indications that the CS IN opened. - Displace well to 2% KCI fluid, 23:30 - 00:00 0,50 EVAL DPRB LOWER1 Rack back CS Hydril. LD bit and motor, 7/15/2004 00:00 - 00:45 0,75 EVAL N DPRB LOWER1 Rack back CS Hydril. LD bit and motor. - Circ sub open, ball on seat. 00:45 - 01 :15 0.50 EVAL N DPRB LOWER1 MU BHA #12, polish mill (2,99"), 01:15 - 03:00 1,75 EVAL N DPRB LOWER1 RIH with polish BHA to liner top at 10,227' MD. - 100 fpm; 0,5 bpm, 267 psi 03:00 - 03:45 0.75 EVAL N DPRB LOWER1 Polish PBR, - 38k PU - 2.5 bpm, free spin at 1900 psi - Entered liner top at 10,224.4' MD, - Minimal motor work while polishing PBR. - No-go on liner top at 10,230.4' MD 03:45 - 05:00 1,25 EVAL N DPRB LOWER1 POOH with polish mill. - 67 fpm, 2,48 bpm at 1700 psi. - 120 fpm, 2.48 bpm at 1630 psi. 05:00 - 05:45 0,75 EVAL N DPRB LOWER1 POOH and Lay down BHA. - Left polishing mill in the hole. Unscrewed at connection, Bucked up at the shop prior to the job, - Looking up: 2-3/8" PAC pin. - Fish: 2,38' long; 2.990" OD; 1" ID 05:45 - 08:24 2,65 EVAL N DFAL LOWER1 Wait on fishing tools 08:24 - 09:20 0,93 EVAL N DFAL LOWER1 PU SIS, Extension, Flutted No-Go Motor, CS, HDC Up/Down Jars 09:20 - 11 :35 2,25 EVAL N DFAL LOWER1 RIH with Fishing BHA. Tagged the top of fish at 10232.2' with 1000lb, Cycled pumps 6 times, pressure increased, PUH, no indication, RIH and tagged with 1500 Ib and cycled pumps 4 Printed: 7/20/2004 12:19:12 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/15/2004 09:20 - 11 :35 2,25 EVAL N DFAL LOWER1 times, Acted like it moved and we screwed into fish? 11 :35 - 13:36 2,02 EVAL N DFAL LOWER1 POOH with fishing BHA 13:36 - 14:15 0,65 EVAL N DFAL LOWER1 OOH "Moment of truth" recovered fish, LD BOT fishing string, 14:15-16:00 1,75 EVAL P LOWER1 RU to PT liner lap Pressure up on IA to 920 psi. Test 1 P=1970 psi, bleed off 100 psi 5 min, IA 840 psi T = 4 min Test 2 P=21 00 psi, bleed off to 1783 psi, IA 800 psi T = 15 min; Delta = 317 Test 3 P=21 00 psi, bleed off to 1611 psi, IA 795 psi T = 24 min; Delta = 489 Test 4 P=2010 psi, bleed off to 1626 psi, IA 790 psi T = 22 min; Delta = 384 Bleed liner and IA down. Test failed, 16:00 - 16:15 0.25 EVAL N DPRB LOWER1 PJSM on handling CNL source and CSH 16:15 - 17:48 1.55 EVAL N DPRB LOWER1 PU/MU MCNL-CCL-GR with 70 jts 1-1/4" CSH 17:48 - 19:15 1.45 EVAL N DPRB LOWER1 RIH with MCNUGR/CCL 19:15 - 20:30 1,25 EVAL P LOWER1 Log down at 30 fpm, - No pumps. 20:30 - 21:15 0,75 EVAL P LOWER1 Log up at 60 fpm, - Tagged bottom at 12,324' MD, - No pumps, Filling hole across the top, 21:15-22:45 1,50 EVAL P LOWER1 POOH with logging BHA, - No pumps, Filling hole across the top, Hole fill correct. 22:45 - 00:00 1,25 EVAL P LOWER1 PJSM, Rack back 35 stands CSH, LD logging tools, 7/16/2004 00:00 - 01 :00 1,00 EVAL P LOWER1 Finish LD logging tools. - Download MCNLlCCUGR logs, -22,5' correction required, - TOL at 10,219' MD - PBTD at 12,310' MD 01 :00 - 01 :30 0,50 PERFO LOWER1 PJSM for perforating 01 :30 - 04:00 2,50 PERFO LOWER1 RIH with 58 perf guns set up to shoot the following intervals: 11,070 - 11,370 11,650 - 12,080 12,220 - 12,290 04:00 - 05:00 1,00 PERFO LOWER1 RIH with 16 stands of CS Hydrill. 05:00 - 06:43 1.72 PERFO LOWER1 RIH on coil with perf guns and CSH, - 40-100 fpm, 06:43 - 06:55 0,20 PERFO LOWER1 Tagged 12317', correct to 12310 ft Started 10 bbl Flo-Pro Cali berated 5/8" ball, dropped, pumped 5 bbl flo-pro then to 2% KCL 06:55 - 07:30 0,58 PERFO P LOWER1 Displacing ball Red Qp at 45 bbl 54,9 bbp Perf at 3200 psi Perf: 11 070 ft to 11370 ft 6 spf 11650 ft to 12080 ft 6 spf 12220 ft to 12290 ft 6 spf 07:30 - 09:33 2.05 LOWER1 POOH keeping hole full till out of liner, Fill down back side keeping 300 psi on annulus 09:33 - 09:55 0.37 PERFO LOWER1 OOH, set injector back make ready to stand back 16 stds CSH 09:55 - 11 :00 1,08 PERFO LOWER1 POOH standing back 16 stds CSH 11:00-11:15 0,25 PERFO LOWER1 PJSM on handling perf guns 11 :15 - 14:45 3,50 PERFO LOWER1 POOH LD Perf guns, all shots fired. Some guns were set up as 4 spf instead of 6 spf 14:45 - 15:53 1,13 PERFO LOWER1 Unloaded pipe shed and PU BOT KB L TP 15:53 - 18:06 2,22 CASE RUNPRD RIH wI KB Packer and Seal Assembly. Well taking some fluid while TIH. Wt check at 10200 ft PU 37k, Printed: 7/20/2004 12:19:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 7/16/2004 18:06-18:10 0,07 CASE P RUNPRD RIH and had to work into deployment sleeve, Worked in to 10238' with 11 k, PUH and get to ball drop, Dropped 5/8" AI ball 18:10 - 19:00 0.83 CASE P RUNPRD Displace ball - Pump down ball at 2 bpm for 44 bbls, - Decrease rate to 0,5 bpm until seat at 51.1 bbls, 19:00 - 19:15 0,25 CASE P RUNPRD SD pumps. Perform multiple attempts to get into deployment sleeve, - PU at 37k, SO at 24k - Successful with 10,237,7' MD, 13k on weight indicator. - At 1 Ok on weight indicator, 10,237.9' MD 19:15-19:30 0,25 CASE P RUNPRD Set Packer: - PU to 36k, 10232,5' MD - PU 1,5' to 10231' MD - Pressure up coil to 2100 psi (packer set at 1400 psi), - SO to 14k, 10235,7' MD - PU to 41 k, 10228,7' (5k over) to confirm set. - SO to 14k. Bleed pressure, - SO to 10k, 10237.4' MD, - Confirmed packer set. -TOL at 10,220,65' MD -- Top of KB L TP at 10,213.43' MD Line up to pressure test. 19:30 - 20:00 0.50 CASE P RUNPRD Pressure up to 2000 psi down the backside (1,9 bbls to pressure up). Schedule: Min Pressure Delta 0 2083 5 2058 0 10 2058 0 15 2058 0 20 2058 0 25 2058 0 30 2058 0 20:00 - 20:15 0.25 CASE P RUNPRD Release from packer. - Bleed pressure to 0 psi. - PU to 20k. - Pressure up to 35k psi, release from packer. 20:15 - 21:45 1,50 CASE P RUNPRD POOH with LTP running tool at 100 fpm, - Rate in 1.73 bpm; Rate out 1,30 bpm, - Cirulating pressure at 565 psi. - Trip sheet accurate, 6,5 bblloss, BBL DEPTH DELTA 287 10200 286 10000 1 280 9000 6 274 8000 6 267 7000 7 261 6000 6 254 5000 7 247 4000 7 241 3000 6 235 2000 6 230 1000 5 21 :45 - 22:00 0,25 CASE P RUNPRD LD BHA and running tool. MU Swizzle stick. Printed: 7/20/2004 12:19:12 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: K-09 K-09 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 7/5/2004 Rig Release: Rig Number: N1 Spud Date: 8/24/1987 End: 23:15·00:00 0,75 RIGD P POST Jet BOPE, RIH and FP from 2000' MD. POOH at 50% (120fpm pumping at 1 bpm) to 100 ft, Ensure MEOH to surface, POOH and LD swizzle stick. Rig down injector head, Off load fluid from pits. Prepare rig for move, 7/17/2004 00:00·00:15 0,25 BOPSU P POST Off Critical Path Operation: - Kill K-05C with HOT and VECO. 290 bbls heated SW plus 20 bbls MEOH, Rig down injector head. Off load fluid from pits. Prepare rig for move, Prepare BOP's for ND operation, 00:15 - 02:00 1,75 BOPSU P Off Critical Path Operation: - Kill K-05C with HOT and VECO. 290 bbls heated SW plus 20 bbls MEOH. ND BOPE, Test Tree, POST Off Critical Path Operation: - Kill K-05C with HOT and VECO, 290 bbls heated SW plus 20 bbls MEOH, RIG RELEASE: 02:007/17/2004 FROM K-09C Printed: 7/20/2004 12:19:12 PM e II 02-Aug-04 AOGCC ,--ROLJill Dt::asðfY' 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well K-09 C .ÄÒ'1'- ~I Ù Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,287.36' MD 10,377.00' MD 12,352.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1W DliJ Date 5- /~J ~!l.f1 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA K Pad K-09C Job No. AKMW0003167150, Surveyed: 12 July, 2004 Survey Report 30 July, 2004 Your Ref: API 500292173603 Surface Coordinates: 5975091.00 N, 670766.00 E (70020'16.3150" N, 148036' 51.5865" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 975091.00 N, 170766.00 E (Grid) Surface Coordinates relative to Structure Reference: 1918.39 N, 467.15 E (True) Kelly Bushing Elevation: 52.86ft above Mean Sea Level Kelly Bushing Elevation: 52.86ft above Project V Reference Kelly Bushing Elevation: 52. 86ft above Structure Reference SP'E!I"""I"""Y-SUf1 DRtL.L.rNG· seRvrces A Halliburton Company DEFINITIVE e e Survey Ref: svy4314 Halliburton Sperry-Sun Survey Report for PBU_WOA K Pad - K-09C Your Ref: API 500292173603 Job No. AKMW0003167150, Surveyed: 12 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10287,36 87.630 269,510 8942,22 8995,08 1354,20 S 3471,26 W 5973658,10 N 667326.48 E -3395,63 Tie On Point 10317,00 87,810 270,030 8943.40 8996,26 1354.32 S 3500,88 W 5973657,31 N 667296,87 E 1.855 -3425,20 Window Point 10349.86 92,020 280,390 8943.45 8996,31 1351.34 S 3533,55 W 5973659.54 N 667264,14 E 34.025 -3457.99 10371.43 93.700 287,210 8942,37 8995,23 1346,21 S 3554.46 W 5973664,20 N 667243.12 E 32,524 -3479,13 10401,58 93,950 298,210 8940,36 8993.22 1334.61 S 3582,17 W 5973675,16 N 667215.15 E 36.412 -3507.41 e 10431.41 89.120 306.470 8939,56 8992.42 1318,68S 3607.33 W 5973690,52 N 667189,63 E 32,061 -3533,37 1 0462.48 89,380 318.420 8939.96 8992.82 1297.75 S 3630,21 W 5973710,92 N 667166,28 E 38.467 -3557,32 10493,91 85,780 329,670 8941 ,29 8994,15 1272,38 S 3648,62 W 5973735.86 N 667147,30 E 37,546 -3577.03 10526,24 85,080 341,270 8943,88 8996,74 1243,11 S 3661,98 W 5973764,82 N 667133.28 E 35,831 -3591.90 10558.43 86,040 354,810 8946.38 8999,24 1211.79S 3668,61 W 5973795,98 N 667125,93 E 42.041 -3600,17 10592,16 85,250 5.180 8948,95 9001,81 1178,20 S 3668.62 W 5973829,56 N 667125,16 E 30,744 -3601,93 10621.98 85,600 17,310 8951,34 9004.20 1149,10 S 3662,83 W 5973858,78 N 667130.29 E 40,564 -3597.67 10653.54 87,540 27,850 8953.23 9006.09 1120.06 S 3650,75 W 5973888,10 N 667141,70 E 33.897 -3587,13 10682,85 91.670 37.170 8953.43 9006,29 1095,37 S 3635,02 W 5973913.13 N 667156,87 E 34.773 -3572,71 10713.41 92,720 47,540 8952,26 9005.12 1072,84 S 3614.47 W 5973936,13 N 667176,90 E 34,081 -3553.37 10742,54 90.350 57,210 8951.48 9004,34 1055,08 S 3591.44 W 5973954,40 N 667199,52 E 34,165 -3531,30 10771,14 88,240 68.990 8951,83 9004,69 1042,17 S 3565.98 W 5973967,90 N 667224,68 E 41,839 -3506.55 10801.34 88,990 76,670 8952,56 9005,42 1033,26 S 3537,16 W 5973977.46 N 667253.29 E 25,544 -3478,23 10833,31 88,900 83,190 8953.15 9006,01 1027.68 S 3505,70 W 5973983.76 N 667284,61 E 20.393 -3447,11 10868,62 88,190 89,010 8954,05 9006.91 1025,28 S 3470,50 W 5973986,96 N 667319,75 E 16,599 -3412,09 10898,15 86,960 93,760 8955,30 9008,16 1025,99 S 3441.02 W 5973986.92 N 667349,24 E 16.602 -3382,60 10940.26 87,490 100.460 8957,34 9010.20 1031,19 S 3399,30 W 5973982,66 N 667391,06 E 15,942 -3340.68 e 10976,04 88.190 104,510 8958.69 9011,55 1038.92 S 3364,40 W 5973975,73 N 667426.13 E 11.479 -3305,42 11009,01 90.400 109,270 8959,10 9011,96 1048.49 S 3332.87 W 5973966,88 N 667457,88 E 15,916 -3273.42 11041.58 90,310 113,150 8958,89 9011,75 1060,28 S 3302,51 W 5973955,79 N 667488.49 E 11.916 -3242.49 11070,95 90,750 117,200 8958,62 9011.48 1072,77 S 3275.94 W 5973943.91 N 667515,34 E 13,870 -3215,30 11101.07 90,840 120,200 8958,20 9011,06 1087,23 S 3249,52 W 5973930,05 N 667542,08 E 9,964 -3188,17 11135,08 91.370 116.320 8957.55 9010.41 1103,32 S 3219.58 W 5973914.64 N 667572.38 E 11,512 -3157.42 11165.34 90,130 112,800 8957,15 9010,01 1115,90S 3192,06 W 5973902,70 N 667600,18 E 12,332 -3129,29 11197,39 88.460 112,090 8957.55 9010.41 1128,13 S 3162.44 W 5973891,14 N 667630.07 E 5,662 -3099.07 11227,94 90.400 108,920 8957,85 9010.71 1138,83 S 3133,83 W 5973881,10 N 667658,91 E 12,164 -3069,94 11260,14 90,930 104,690 8957.48 9010.34 1148.14 S 3103,02 W 5973872.49 N 667689,93 E 13,238 -3038,68 11293,17 90,570 100,280 8957,04 9009,90 1155.28 S 3070.78 W 5973866.09 N 667722,32 E 13,395 -3006.11 11326,30 90,750 95,530 8956,66 9009.52 1159,83 S 3037,98 W 5973862,29 N 667755,22 E 14,347 -2973,11 11363,13 89,520 96,760 8956,57 9009.43 1163,77 S 3001,36 W 5973859.18 N 667791,92 E 4,723 -2936.34 30 July, 2004 - 15:26 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for PBU_WOA K Pad - K-09C Your Ref: API 500292173603 Job No. AKMW0003167150, Surveyed: 12 July, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 11395,52 90,570 100,640 8956,55 9009.41 1168,67 S 2969,35 W 5973855,01 N 667824,03 E 12.410 -2904.12 11434.86 90,040 106,100 8956.34 9009,20 1177,77S 2931,09 W 5973846,79 N 667862.49 E 13,944 -2865,43 11468.05 90,310 111,390 8956.24 9009.10 1188.43 S 2899,67 W 5973836.85 N 667894,14 E 15.959 -2833,50 11500.30 91.100 117,020 8955,84 9008,70 1201,64 S 2870,27 W 5973824,30 N 667923,84 E 17.627 -2803.45 11530,21 91,100 120,550 8955,27 9008,13 1216,04S 2844,07 W 5973810,51 N 667950.36 E 11,800 -2776.53 e 11566,67 88.630 124.430 8955,35 9008.21 1235.62 S 2813.32 W 5973791.63 N 667981,55 E 12.614 -2744,80 11603,09 86.960 122,310 8956,75 9009.61 1255,64 S 2782.93 W 5973772,31 N 668012,38 E 7.407 -2713.40 11632,62 87.400 118.960 8958,21 9011,07 1270,66 S 2757,56 W 5973757,87 N 668038.09 E 11 ,428 -2687.28 11663,97 88,110 115,610 8959.44 9012,30 1285,02 S 2729,72 W 5973744,15 N 668066.25 E 10,915 -2658,73 11694,88 89,960 114,380 8959.96 9012.82 1298.08 S 2701,71 W 5973731,73 N 668094,55 E 7.187 -2630,07 11737,35 89.520 108,920 8960,15 9013,01 1313,74 S 2662.25 W 5973716,97 N 668134.35 E 12,898 -2589,85 11772,39 90,750 105.570 8960.07 9012,93 1324,13 S 2628,79 W 5973707,35 N 668168,04 E 10,184 -2555.89 11821,63 90,220 101.520 8959.65 9012,51 1335,66 S 2580,94 W 5973696.91 N 668216,15 E 8,295 -2507,50 11855.88 90,660 97.460 8959.39 9012,25 1341,30S 2547,16 W 5973692,04 N 668250,04 E 11,923 -2473.47 11887,20 91.010 96,760 8958,93 9011.79 1345.18 S 2516.09 W 5973688,87 N 668281,20 E 2.499 -2442.24 11929,74 91,190 96.410 8958.11 9010,97 1350,06 S 2473,84 W 5973684.96 N 668323.55 E 0,925 -2399,79 11958,55 91,190 100,110 8957,51 9010,37 1354.19 S 2445,34 W 5973681.47 N 668352,14 E 12.840 -2371,11 11994.86 91,630 103,980 8956,62 9009.48 1361.77 S 2409.84 W 5973674,71 N 668387,79 E 10.724 -2335,27 12027,25 90.750 108,040 8955,95 9008.81 1370,70 S 2378.72 W 5973666,49 N 668419,11 E 12,823 -2303.73 12058,79 89,600 111,390 8955,85 9008.71 1381,34 S 2349,04 W 5973656.53 N 668449,03 E 11,230 -2273,52 12097,17 88,630 106.980 8956.44 9009.30 1393,94 S 2312,80 W 5973644,75 N 668485,54 E 11.764 -2236.68 12138.38 86:780 109.270 8958,10 9010,96 1406,75 S 2273,67 W 5973632,84 N 668524.95 E 7,140 -2196,93 e 12170.00 88,990 110,500 8959,26 9012,12 1417.50 S 2243.96 W 5973622,77 N 668554,90 E 7,997 -2166,70 12207,39 93,040 111.390 8958,60 9011.46 1430,86 S 2209.05 W 5973610,21 N 668590,10 E 11.090 -2131,14 12240,98 91,630 115,790 8957,23 9010,09 1444.29 S 2178,30 W 5973597.48 N 668621.15 E 13,745 -2099.73 12271,50 91,630 118,610 8956,36 9009,22 1458.23 S 2151.17 W 5973584,16 N 668648,59 E 9,236 -2071,91 12304,36 91,980 122,840 8955,33 9008.19 1475,01 S 2122,95 W 5973568,03 N 668677,19 E 12.910 -2042,84 12318,36 91,720 124.780 8954,88 9007,74 1482,79 S 2111,32W 5973560.51 N 668688,99 E 13,974 -2030,82 12352,00 91.720 124,780 8953.87 9006,73 1501,97S 2083,70 W 5973541.96 N 668717,04 E 0,000 -2002,24 Projected Survey All data is in Feet (US Survey) unless otherwise stated, Directions and coordinates are relative to True North, Vertical depths are relative to Well Reference, Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4, The Dogleg Severity is in Degrees per 100 feet (US Survey), Vertical Section is from Well Reference and calculated along an Azimuth of 93.000° (True). 30 July, 2004 - 15:26 Page 3 of4 DrillQuest 3.03.06.006 .. ... Halliburton Sperry-Sun Survey Report for PBU_WOA K Pad - K-09C Your Ref: API 500292173603 Job No. AKMW0003167150, Surveyed: 12 July, 2004 BPXA North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 12352,OOft., The Bottom Hole Displacement is 2568,61ft., in the Direction of 234.215° (True), Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment e 10287,36 10317,00 12352,00 8995,08 8996,26 9006,73 1354,20 S 1354,32 S 1501,97 S 3471,26 W 3500,88 W 2083,70 W Tie On Point Window Point Projected Survey Survey tool program for K-09C From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0,00 7497.26 0,00 7497.26 6913.31 12352,00 6913.31 BP High Accuracy Gyro - GYD-GC-MS (K-09) 9006,73 MWD Magnetic (K-09BPB1) e 30 July, 2004 - 15:26 Page 4 of4 DrillQuest 3.03.06.006 TREE = WELLI-EA 0 = ACìUA TOR = KB. ELEV = 4-1/16" OW McEV OY AXELSON 52.86' K-09C I SAFETY NOTES: CATEGORY II. NO SSSV. BF. ELEV = 26.21' KOP= 3200' 4-1/2" HES HXO SSSV N, 10 = 3.813" 1 Max Angle = 93 @ 12207' 2160' Datum tv[) - 9867' . Datum1VO= 8800' SS -----' 13-3/8"CSG, 72#, L-80, 10 = 12.347' 2675' 1-4 ---:1 ~ GAS LIFT MANDRELS ST MD TVO OEV TYPE VLV LATCH FORT DATE ---! 2 4305 4181 25 MIVG-M OOIvE RK 16 06/11/97 1 TOP OF BAKffi llEBACKSLV ,10 = 7,500" - 7409' 1 7377 6755 30 MIVG-M SIO RK 20 06/11/97 19-5/8" X 7" BAKERZXP A<R, 10 = 6.375" 7415' l - ~ "i 19-5/8" X 7" BAKER HI'vC H3R,IO = 6.276" - 7422' 19-5/8" CSG, 47#, L-80, 10= 8.681" H 7594' r- · I 9369' 4-1/2" HES X NIP, 10 = 3.813" I . Minimum ID = 2.440" @ 10690" I 9380' 7" X 4-1/Z' BKR 8-3 PKR. ID - 3,875" I 3-3/16" X 2-7/8" XO :8 ~ · I 9403' 4-1/2" HES X NIP, ID = 3,813" I I I · I 9424' 4-1/Z' HES X NIP, MILLEDID = 3.80" 1 I I 14-112" ìBG, 12.6#, L-80, .0152 bpf,lD =3.958" 9435' ~ ") 4-1/2" WLEG, 10 = 3.958" 1 9436' I HELMOTT NOTLOGGED I TOPOF BKRTIEBAO< SLV, 10= 5,250" '- 10130' i I., 17" X 5" BKR ZXP PKR. 10 = 4,375" I- 10136' ~ 17' X 5" BKR HI'vC H3R. 10 = 4.375" I- 10144' 10150' 5-1/2" X 4-1/Z' XO, ID = 3,958" I ¡ ~ 10213' 3.7" BKR LNRTOPPKR, ID = 2.560" I 10221' 3,7" BKR ŒPLOYM8'JT SLY, ID = 2,972" I I I 10240' 3-1/2" rES XN NIP, ID - 2,765" 17" LNR. 2ff#, L-80, 10 = 6.276" 1---1 10297' 1----.... ~ I 10305' 1-13-112" X 3-3/16" XO, D =2.786" I 13-1/2" LNR, 6.2#, L-80, .0076 bpf, ID = 2.990" I- 10305' ~' IvECKl\ NlCAL I-DLLOW WHIPSTOCK I- 1031T f~ I I WHPSTOO< ANa;OR I- 10305' MLLOUTWINDOW 10304' - 10319' 4-lIZ' LNR, 12.6#, L-80, ,0152 bpf, 10=3.958" 11200' 8 '18 10690' 3-3/16"X 2-7/fS' XO, ID = 2.440" :sðõõð PffiFORATION SUWlvtARY REF LOG: ANGLE AT TOP ÆRF: 91 @ 11070' 13-3116" LNR, 6.2#, L-80, 10690' I Note: Refer to Production DB for historcal perf data .0076 bpf, ID = 2.80" SIZE SPF INTERv' AL Opn/Sqz DATE Z' 4-6 11070 - 11370 0 07116/04 Z' 6 11650 -12080 0 0711 6/04 2" 6 12220 - 12290 0 07/16/04 12-7/8" LNR, 6.1ff#, L-80, .0058 bpf, ID= 2.441" 12345' DATE 09109/87 12/13/94 05130/97 07/16/04 REV BY COWlvt8'JTS ORIGINAL COM PLETION RIG SDTRK-K-09A-WELL SUS RIG SDTRK (K-09B) KAK CTDSIDETRACK(K-09C) DATE REV BY COMIvENTS PRLOI-DE BAY LNIT WELL: K-09C PffiMfT I\b: 2041100 AA No: 50-029-21736-03 SEC4, T11N, R14E, 2113' Sf\I... &493' BNL BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AND GAS CONSERVATION COMMISSION 333 W, 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay K-09C BP Exploration (Alaska) Inc. Permit No: 204-11 0 Surface Location: 2113' SNL, 493' EWL, SEC. 04, T11N, R14E, UM Bottomhole Location: 3553' SNL, 1580' WEL, SEC. 05, T11N, T14E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 7 (pager). S' e y, BY ORDER OF_T!JE COMMISSION DATED thisÆ~y of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL W G A-- /;>1 Z- 2-tz..oo 4- CEtVED UN 2 1 2004 Jl,; ;tn 20 MC 25.005 ')xi iJ.: i, , ;;'.; r,c, 1a, Type of work o Drill aa Redrill rb. Current Well Class o Exploratory/aa Dev '.' ", ,'/·mJ:!Multiple Zone ORe-Entry o Stratigraphic Test o Service 0 Development ~Jli'i!t1gle Zone 2, Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc, Bond No, 2S 100302630-277 PBU K-09C 3. Address: 6, Proposed Depth: 12, Field / Pool(s): P,O. Box 196612, Anchorage, Alaska 99519-6612 MD 12300' TVD 8957' 55 Prudhoe Bay Field / Prudhoe Bay 4a, Location of Well (Governmental Section): 7. Property DeSignatio~ I.f¿ If 4 Pool Surface: ADL 0283 o:z.g 303- 2113' SNL, 493' EWL, SEC, 04, T11N, R14E, UM Top of Productive Horizon: 8, Land Use Permit: 13, Approximate Spud Date: 3456' SNL, 2404' WEL, SEC, 04, T11N, R14E, UM 07101/04 Total Depth: 9. Acres in Property: 14, Distance to Nearest Property: 3553' SNL, 1580' WEL, SEC. 05, T11N, R14E, UM 2560 12,400' 4b. Location of Well (State Base Plane Coordinates): 10, KB Elevation 15. Distance to Nearest Well Within Pool Surface: x- 670766 y- 5975091 Zone- ASP4 (Height above GL): 52.86' feet E-05 is 467' away at 11075' MD 16. Deviated Wells: 17, Maximum Anticipated Pressures in psig (see 20 MC 25,035) 0 Kickoff Depth 10305'ft Maximum Hole Angle 94 Downhole: 3300 psig Surface: 2350 psig 1R. <~"""';~ ...""'.,~~ 0 Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD (jncludinQ staQe data) 4-1/8" x 3-3/4" 3-3/16" x 2-7/8" 6,2# 16.16# L-80 TCII / STL ~ 10250' 8940' 1230œ- 8957' 95 cu ft Class 'G' ~o~' Wbk 119;.· PRESENT \Ne:~I.,CØl,pl]IØ""$IqMMARY(To· båçqmpl~teøfØfR~~rill~NPRØ1~Í'ltfY()pe.~~io!)~) .i'i Total Depth MD (ft): Tota' Depth TVD (ft.'ugs (measured)' I Effective Depth MD (ft), Effective Depth TVD (ft): Junk (measured): 11200 9015 None 11112 lliiIl~~~1II None _...i¡; ¡¿.;s; .¡....¡¡.. Structur;:¡I r.nnnllctor 80' 20" 8 cu vds Concrete 110' 110' Surface 2645' 13-3/8" 1901 cu ft AS III / 1860 cu ft AS II 2675' 2674' . iate 7564' 9-5/8" 1920 cu ft Class 'G' 7594' 6996' Production I in¡:'!r 2875' 7" 533 cu ft Class 'G' 7422' - 10297' 6849' - 8996' Liner 1056' 4-1/2" 140 cu ft Class 'G' 10144' - 11200' 8976' - 9015' Perforation Depth MD (ft): 10315' - 11093' IPerfOration Depth TVD (ft): 8996' - 9004' 20. Attachments a Filing Fee, $100 a BOP Sketch a Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report a Drilling Fluid Program a 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Mary Endacott, 564-4388 / Printed Name Mary Endacott Title CT Drilling Engineer Si nature ¡ i i a '/11. 'aC-/J 1!t.. Phone 564-4388 Date t(J/2-1 0 Terrie Hubble. 564-4628 Permit To Drill API Number: Permit Ap ro al See cover letter for Number:2oSl - //0 50-029-21736-03-00 Date: ~Þ;>Il? c¡ other requirements Conditions of Approval: Samples Required DYes~No Mud Log Required / DYes ~No Hydroge Sulfide Measures ,:øYes 0 No Directional Survey Required ~es DNo T~st ß~ 35'00 I Other: pSt Q a~~ Approved BV( -¡ ~ BY ORDER OF 1""\ 1""\ I 1"'\ t .. t A I THE COMMISSION Date Form 10-401 \A€vised\gt2003 '-- U:\ I öll\Jf\L ,gubmit iii Duplfcate . BP K-09C Sidetrack . CTD Sidetrack Summary 1) Mill window off whipstock 2) Drill sidetrack 3) Run liner, cement and perforate Mud Program: " : · Well kill: 8.4 - 8.9 ppg)1fi~ · Milling/drilling: 8.5 -~pg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class rr wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / 12-, 300' / · 3 3/16" x 2 7/8" solid cemented liner comp~o 10,250' -~. · The liner cement volume is planned to be 7- bls of 15.8 ppg class G. Casin2lLiner Information ... 13 3/8", L-80, 72#, Burst 5380 psi; collapse 2670 psi 95/8", L-80 47#, Burst 6870, collapse 4750 7", L-80, 26#, Burst 7240 psi; collapse 5410 psi 4 Y2" L-80, 12.6#, Burst 8430 psi; collapse 7500 psi planned . 33/16" L-80 TCrr, 6.2#, Burst 8520 psi; collapse 7660 psi (hole size 4.125") / 27/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (hole size 3.75") Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi../ · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 94deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · Distance to nearest property 12,400ft · Distance to nearest well within pool 467ft to E-05 at 11,075' Logging · MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. · MCNL will be run cased hole. Hazards ,// · K pad is ~ designated as an HzS pad. · Two small fault crossings anticipated. Lost circulation risk is considered "low". · Extended reach, limited weight to bit, plan to use agitator or tractor tools. Reservoir Pressure · Res. press. is estimated to be 3300 psi at 8800'ss (7.06 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2350 psi. 4-1/16" CrN McEVOY SAFETY NOTES: CATEGORY II. NO SSSV. WELL ANGLE> 70° @ 10050' 8. > 90"@ 10800'. 2160' 1409' 1415' 7422' DATE 06/11/97 06/11/97 9-5/8" MILLOlJr WINDOW (K-09A) 7594' - 7630' (SECTION MILL) 9435' ÆRFORA TION SUMMARY REF LOG: TCP ÆRF ANGLE AT TOP ÆRF: 87 @ 10315' Note: Refer to Production DB for historical perf data SiZE SPF INTERVAL Opn/Sq DATE 2-7/8" 4 10315 - 10340 2-7/8" 4 10410 - 10435 2-3/4" 4 10543 10813 2-3/4" 4 10883 - 11093 COMMENTS PRUDHOE BA Y UNIT WELL: ÆRMIT No: API No: 50-029-21736-03 SEC4, T11N, R14E, 2113' SNL&493'8NL BP BP Amoco WEll-PATH DETAiLS Ptal'l#.4 K4I9C SOO292173ßQZ Parent \IV.Up.tit: ¡{-ODB Tie- OR MD: 10'2n.~e Rig:: NoJ'dic1 R.f,OJlltllm: K..c9B S2.Hff: V,ke!!!",,, Origin aright ~=:¡~ Angl. +NI-$ +EI-W 93.00' 0.1,)0 Ad VSI;ç Tllf1J' ANNQTATIONS 11I8 2 ... 8950 ObP . BP-GDB Baker Hughes INTEQ Planning Report . B.. BAICR ...... ÎÑÜÕ-'---'- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB K Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5973161,33 ft 670342.10 ft Latitude: 70 19 Longitude: 148 37 North Reference: Grid Convergence: 57.435 N 5,245 W True 1.30 deg Well: K-09 Slot Name: 09 K-09 Well Position: +N/-S 1920.09 ft Northing: 5975091.40 ft Latitude: 70 20 16.319 N +E/-W 467,01 ft Easting : 670765,35 ft Longitude: 148 36 51.605 W Position Uncertainty: 0.00 ft Wellpath: Plan#4 K-09C 500292173603 Current Datum: K-09B Magnetic Data: 6/17/2004 Field Strength: 57600 nT Vertical Section: Depth From (TVD) ft 28.86 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0,00 K-09B 10287,36 ft Mean Sea Level 25.28 deg 80,90 deg Direction deg 93.00 Height 52,86 ft Targets K-09B Polygon4.1 0.00 -1330,93 -3640.85 5973678,00 667156,00 70 20 3,221 N 148 38 37,924 W -Polygon 1 0,00 -1330,93 -3640.85 5973678,00 667156,00 70 20 3,221 N 148 38 37,924 W -Polygon 2 0,00 -1132,67 -3737.37 5973874.00 667055,00 70 20 5.170 N 148 38 40,745 W -Polygon 3 0.00 -986,03 -3543,96 5974025.00 667245.00 70 20 6,613 N 148 3835,100 W -Polygon 4 0.00 -958.63 -3341.27 5974057,00 667447.00 70 20 6,884 N 148 38 29.181 W -Polygon 5 0,00 -1425,28 -1782,39 5973626,00 669016.00 70 20 2.299 N 148 3743.653 W -Polygon 6 0.00 -1602,01 -1972.48 5973445,00 668830.00 70 20 0.561 N 148 3749.203 W -Polygon 7 0,00 -1312,23 -2793,15 5973716.00 668003,00 70 20 3,408 N 148 38 13,170 W -Polygon 8 0.00 -1165.29 -3447.01 5973848.00 667346.00 70 20 4.851 N 148 38 32,266 W K-09B Fault 1 0,00 -1554,35 -3537,90 5973457,00 667264,00 70 20 1.024 N 148 38 34,915 W -Polygon 1 0.00 -1554,35 -3537,90 5973457,00 667264,00 70 20 1,024 N 148 38 34,915 W -Polygon 2 0,00 -848,57 -3254,74 5974169.00 667531.00 70 20 7,967 N 148 38 26.655 W K-09B Fault 2 0.00 -1795.84 -3168.28 5973224,00 667639.00 70 19 58,650 N 1483824,118W -Polygon 1 0,00 -1795,84 -3168,28 5973224.00 667639,00 70 19 58,650 N 1483824.118W -Polygon 2 0.00 -1021,12 -2837,53 5974006,00 667952,00 70 20 6.271 N 148 38 14.469 W K-09B T4.1 8957,00 -1148,67 -3166.54 5973871.00 667626,00 70 20 5.015 N 148 38 24.076 W K-09B T4,2 8957,00 -1394.01 -2276.84 5973646.00 668521,00 70 20 2,606 N 148 37 58.092 W Annotation 10287.36 8942,22 TIP 10305.00 8942,92 KOP 10325.00 8943.46 3 10365,00 8942,65 4 10615,00 8950.82 5 ObP . BP-GDB Baker Hughes INTEQ Planning Report . ... SA..... --"'--.--.-----,.-..,..- INTEQ Annotation 10715,00 8956,28 6 11215,00 8956,54 7 11465,00 8956.62 8 11715.00 8956.68 9 11965,00 8956,74 10 112075,00 8956.76 11 12300.00 8956,81 TO Plan: Plan #4 Date Composed: 6/17/2004 Identical to Lamar's plan #4 Version: 4 Principal: Yes Tied-to: From: Definitive Path Plan Section Information ft 10287,36 87,63 269.51 8942.22 -1354,22 -3471,23 0,00 0,00 0,00 0.00 10305,00 87.82 269.82 8942.92 -1354,32 -3488,86 2,06 1.08 1.76 58.48 10325,00 89,09 271.09 8943.46 -1354,16 -3508.85 9.00 6,37 6.36 45,00 10365.00 93,22 286,56 8942,65 -1348.05 -3548,24 40.00 10,31 38.66 75,00 10615.00 84,03 26.29 8950.82 -1147,25 -3636.42 40,00 -3.67 39,89 95.50 10715.00 89.96 65.92 8956,28 -1079.49 -3565.86 40,00 5.93 39,63 82.90 11215.00 89,98 125,92 8956,54 -1128,74 -3090.94 12.00 0.00 12.00 90.00 11465.00 89.98 95,92 8956.62 -1216,99 -2860.08 12,00 0.00 -12,00 270.00 11715,00 89.99 125,92 8956.68 -1305,24 -2629,22 12,00 0,00 12.00 90.00 11965.00 89.99 95.92 8956.74 -1393,50 -2398,35 12.00 0,00 -12.00 270.00 12075.00 89.99 109,12 8956,76 -1417.29 -2291.21 12,00 0.00 12.00 90.00 12300.00 89,99 82.12 8956.81 -1439.12 -2069,36 12,00 0,00 -12,00 270.00 Survey MD ft 10287,36 87.63 269,51 8942.22 -1354,22 -3471,23 5973658.58 667326.09 -3395,60 0,00 0.00 TIP 10300.00 87.77 269.73 8942.73 -1354.30 -3483,86 5973658,21 667313.47 -3408.21 2.06 58.48 MWD 10305.00 87,82 269.82 8942.92 -1354,32 -3488.86 5973658,08 667308.47 -3413.20 2.06 58.47 KOP 10325.00 89.09 271,09 8943.46 -1354,16 -3508,85 5973657.78 667288.48 -3433,17 9.00 45,00 3 10350.00 91,68 280,75 8943.29 -1351,58 -3533,69 5973659.79 667263,60 -3458.11 40.00 75,00 MWD 10365,00 93,22 286.56 8942,65 -1348,05 -3548,24 5973663,00 667248,97 -3472,83 40,00 75,07 4 10375.00 92,83 290.55 8942,12 -1344.87 -3557,71 5973665.96 667239.43 -3482,45 40,00 95,50 MWD 10400.00 91,79 300,50 8941,11 -1334,12 -3580,22 5973676.19 667216.68 -3505.49 40,00 95.71 MWD 10425,00 90.71 310.44 8940.57 -1319.64 -3600.55 5973690.21 667196.03 -3526.55 40,00 96.11 MWD 10450.00 89.60 320,38 8940,50 -1301.85 -3618,08 5973707,59 667178,10 -3544.98 40.00 96.33 MWD 10475,00 88.50 330.32 8940.91 -1281.32 -3632,27 5973727,79 667163.45 -3560,23 40,00 96,36 MWD 10500,00 87.45 340,27 8941.80 -1258.65 -3642,70 5973750,22 667152.51 -3571,83 40,00 96,19 MWD 10525.00 86.48 350.24 8943.12 -1234.54 -3649,04 5973774.18 667145.61 -3579.43 40,00 95,84 MWD 10550.00 85.61 0,23 8944,85 -1209.71 -3651.11 5973798,94 667142.98 -3582,80 40.00 95,31 MWD 10575,00 84,88 10,23 8946,93 -1184,93 -3648,85 5973823.77 667144.68 -3581.83 40.00 94.62 MWD 10600.00 84,30 20.26 8949,29 -1160,95 -3642,31 5973847,89 667150.67 -3576,56 40.00 93.79 MWD 10615,00 84.03 26.29 8950,82 -1147.25 -3636.42 5973861,72 667156.25 -3571,39 40,00 92,84 5 10625.00 84.54 30.28 8951,82 -1138.49 -3631.70 5973870,58 667160,76 -3567.14 40,00 82.90 MWD 10650.00 85,92 40.21 8953.90 -1118,17 -3617.34 5973891.22 667174,65 -3553.87 40.00 82.50 MWD 10675.00 87.42 50,12 8955,36 -1100,60 -3599.67 5973909.19 667191,92 -3537,13 40,00 81,67 MWD 10700.00 89,00 60.00 8956,14 -1086,31 -3579.21 5973923,95 667212,05 -3517.45 40,00 81.10 MWD 10715,00 89,96 65,92 8956,28 -1079.49 -3565.86 5973931,06 667225,24 -3504.47 40.00 80,79 6 10725,00 89.96 67.12 8956,28 -1075,51 -3556,68 5973935,26 667234.32 -3495,52 12,00 90,00 MWD 10750,00 89.96 70.12 8956.30 -1066,39 -3533.41 5973944,90 667257.38 -3472,75 12,00 90,00 MWD 10775.00 89,96 73,12 8956.31 -1058,51 -3509,68 5973953,32 667280.92 -3449.48 12.00 90.00 MWD 10800.00 89.96 76.12 8956.33 -1051,88 -3485,58 5973960.49 667304.86 -3425.75 12.00 90.00 MWD ObP . BP-GDB Baker Hughes INTEQ Planning Report . B.. ...... -'~-,-",,_.,,-,"-,."-- INTEQ Survey j\fD ft 10825.00 89.96 79.12 8956,35 -1046.52 -3461,17 5973966.40 667329,15 -3401,65 12.00 89.99 MWD 10850,00 89.96 82,12 8956.36 -1042,45 -3436.50 5973971,04 667353,71 -3377.24 12,00 89.99 MWD 10875.00 89,97 85.12 8956.38 -1039.67 -3411,66 5973974,38 667378.48 -3352,57 12.00 89.99 MWD 10900.00 89.97 88,12 8956.39 -1038,20 -3386.71 5973976.42 667403.39 -3327.73 12.00 89,99 MWD 10925,00 89.97 91,12 8956.41 -1038,03 -3361,71 5973977,16 667428,38 -3302.78 12,00 89.99 MWD 10950,00 89,97 94,12 8956.42 -1039,18 -3336.74 5973976.58 667453.37 -3277.78 12,00 89.98 MWD 10975,00 89,97 97.12 8956.43 -1041.62 -3311.86 5973974.70 667478.29 -3252,81 12,00 89,98 MWD 11000.00 89,97 100.12 8956.45 -1045.37 -3287.15 5973971,52 667503.08 -3227,93 12.00 89,98 MWD 11025,00 89.97 103,12 8956.46 -1050.41 -3262,66 5973967,04 667527,68 -3203.22 12.00 89.98 MWD 11050.00 89,97 106.12 8956,47 -1056.72 -3238.48 5973961,29 667552.00 -3178,73 12,00 89,98 MWD 11075.00 89,97 109.12 8956.48 -1064.28 -3214,65 5973954.27 667575.99 -3154.55 12,00 89,98 MWD 11100.00 89.97 112.12 8956,50 -1073,09 -3191,26 5973946,00 667599.58 -3130.72 12,00 89,97 MWD 11125,00 89.98 115,12 8956,51 -1083.10 -3168,35 5973936,51 667622.70 -3107,33 12,00 89.97 MWD 11150,00 89.98 118,12 8956.52 -1094,30 -3146,01 5973925,82 667645,29 -3084.42 12.00 89.97 MWD 11175,00 89.98 121,12 8956.53 -1106,66 -3124.27 5973913.96 667667,30 -3062.08 12,00 89.97 MWD 11200,00 89.98 124,12 8956.54 -1120.13 -3103.22 5973900.97 667688.65 -3040.34 12,00 89,97 MWD 11215,00 89,98 125.92 8956.54 -1128.74 -3090.94 5973892.65 667701.13 -3027,63 12,00 89,97 7 11225.00 89,98 124.72 8956,54 -1134,52 -3082,78 5973887.05 667709.42 -3019.18 12.00 270,00 MWD 11250.00 89.98 121,72 8956.55 -1148,22 -3061,87 5973873,84 667730,63 -2997,58 12.00 270.00 MWD 11275,00 89.98 118.72 8956.56 -1160.80 -3040.27 5973861.75 667752,51 -2975.35 12,00 270.00 MWD 11300.00 89,98 115,72 8956,57 -1172,23 -3018.04 5973850,83 667775.00 -2952.55 12,00 270,00 MWD 11325.00 89.98 112,72 8956.58 -1182.49 -2995,24 5973841.10 667798.02 -2929,25 12.00 270.00 MWD 11350,00 89.98 109.72 8956,58 -1191.54 -2971,94 5973832,58 667821,52 -2905.51 12.00 270.00 MWD 11375,00 89.98 106.72 8956.59 -1199,35 -2948.19 5973825,31 667845,43 -2881,39 12.00 270,01 MWD 11400.00 89,98 103.72 8956,60 -1205,91 -2924,07 5973819,30 667869.69 -2856.95 12,00 270,01 MWD 11425,00 89.98 100,72 8956,61 -1211,21 -2899.64 5973814,56 667894.24 -2832,28 12,00 270.01 MWD 11450,00 89,98 97,72 8956.61 -1215.21 -2874.97 5973811.12 667919,00 -2807.43 12.00 270.01 MWD 11465.00 89,98 95.92 8956,62 -1216,99 -2860,08 5973809.68 667933.92 -2792.46 12,00 270,01 8 11475,00 89.98 97,12 8956.62 -1218,13 -2850.14 5973808,77 667943.88 -2782.48 12.00 90.00 MWD 11500,00 89.98 100.12 8956.63 -1221,87 -2825.43 5973805,59 667968,67 -2757,61 12.00 90.00 MWD 11525.00 89,98 103.12 8956,63 -1226,91 -2800,94 5973801.11 667993,27 -2732.89 12,00 90.00 MWD 11550.00 89.98 106.12 8956,64 -1233,22 -2776,75 5973795,36 668017.59 -2708.41 12,00 90.00 MWD 11575.00 89.98 109,12 8956.65 -1240.79 -2752.93 5973788,33 668041,58 -2684,22 12.00 90,00 MWD 11600,00 89.98 112,12 8956,65 -1249,59 -2729,53 5973780,07 668065,17 -2660.39 12.00 90,00 MWD 11625.00 89.99 115,12 8956,66 -1259,61 -2706,63 5973770,58 668088.29 -2637,00 12.00 90,00 MWD 11650,00 89.99 118,12 8956.67 -1270.81 -2684,28 5973759.89 668110,89 -2614,10 12,00 89,99 MWD 11675.00 89,99 121.12 8956,67 -1283.16 -2662,55 5973748.03 668132,89 -2591.75 12.00 89.99 MWD 11700.00 89,99 124,12 8956,68 -1296,64 -2641.50 5973735,04 668154.24 -2570.02 12.00 89,99 MWD 11715,00 89.99 125,92 8956.68 -1305,24 -2629.22 5973726,71 668166.72 -2557.30 12.00 89,99 9 11725.00 89,99 124.72 8956,68 -1311,02 -2621.06 5973721,12 668175.01 -2548.85 12,00 270.00 MWD 11750.00 89,99 121.72 8956,69 -1324,72 -2600.14 5973707,91 668196,22 -2527.25 12,00 270.00 MWD 11775.00 89,99 118,72 8956,70 -1337,30 -2578.54 5973695,82 668218.10 -2505.02 12,00 270.00 MWD 11800,00 89.99 115,72 8956.70 -1348.74 -2556.32 5973684,90 668240.59 -2482.22 12,00 270,00 MWD 11825,00 89.99 112.72 8956.71 -1358,99 -2533.52 5973675.16 668263,61 -2458,92 12,00 270,00 MWD 11850.00 89.99 109.72 8956,71 -1368.04 -2510,22 5973666,65 668287.11 -2435.18 12.00 270,00 MWD 11875.00 89,99 106.72 8956.72 -1375,85 -2486.47 5973659,38 668311.02 -2411.06 12,00 270.00 MWD 11900,00 89,99 103,72 8956,73 -1382.42 -2462,35 5973653.37 668335.29 -2386,63 12,00 270,00 MWD 11925.00 89,99 100.72 8956,73 -1387.71 -2437,92 5973648,63 668359.83 -2361.95 12.00 270,01 MWD 11950,00 89.99 97.72 8956.74 -1391,71 -2413,25 5973645,19 668384.59 -2337,10 12,00 270,01 MWD 11965.00 89,99 95,92 8956.74 -1393,50 -2398,35 5973643.75 668399.51 -2322.14 12,00 270.01 10 11975,00 89.99 97,12 8956.74 -1394.63 -2388.42 5973642,84 668409.47 -2312.16 12.00 90.00 MWD 12000.00 89,99 100.12 8956.75 -1398,38 -2363.70 5973639,66 668434,26 -2287,28 12,00 90.00 MWD 12025.00 89,99 103.12 8956,75 -1403.41 -2339.22 5973635.18 668458,86 -2262,57 12,00 90,00 MWD ObP . BP-GDB Baker Hughes INTEQ Planning Report . ... IIAKEII. ........ ---""'_.__._.~.- IN'TRQ Survey MD ft 12050,00 89,99 106.12 8956.76 -1409,72 -2315,03 5973629,42 668483,18 -2238.08 12075.00 89.99 109.12 8956.76 -1417,29 -2291.21 5973622.40 668507,17 -2213.89 12,00 90.00 11 12100.00 89.99 106,12 8956,77 -1424.86 -2267,38 5973615,38 668531.16 -2189,70 12.00 270.00 MWD 12125.00 89,99 103.12 8956.77 -1431.17 -2243,20 5973609.62 668555.48 -2165,22 12.00 270,00 MWD 12150,00 89.99 100.12 8956.78 -1436.20 -2218.71 5973605,15 668580,07 -2140,51 12.00 270.00 MWD 12175.00 89,99 97.12 8956,78 -1439,95 -2194.00 5973601.97 668604,86 -2115.63 12,00 270,00 MWD 12200.00 89.99 94,12 8956,79 -1442.40 -2169,12 5973600.08 668629,79 -2090,66 12,00 270,00 MWD 12225,00 89.99 91,12 8956,79 -1443.54 -2144,15 5973599.51 668654,78 -2065,66 12,00 270,00 MWD 12250,00 89,99 88.12 8956.80 -1443.37 -2119.15 5973600,25 668679,76 -2040.71 12,00 270,00 MWD 12275.00 ~9,99 85.12 8956.80 -1441,90 -2094,20 5973602.29 668704,67 -2015.86 12,00 270,00 MWD 12300.00 89.99 82,12 8956,81 -1439.12 -2069,36 5973605.63 668729.45 -1991,20 12,00 270.00 TO Nordic 1 bighole All Measurements are from top of Riser 6/21/2004 ~ Q) U) .- a: top of bag BAG 7 1/16" 5000psi bUm of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ......,..............·····7 1/16" 5000psi middle of flow cross Mud Cross 7 1/16" 5000psi middle of blind/shears ........................., middle of pipe/slips TOTs .....................·····7 1/16" 5000psi Flow Tee . . SONDRA D STEWMAN BP EXPLORATION AK INC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 103 "Mastercard Check" DATJYp-Z/ -elf 6~6¡RO 6FHE .A=>(~ c. c.. I $100. CD '- One.. ~Iuryj("º~d a..V\~^-~i" DOLLARS First Nationa~k Alaska ---:--'01 I A.~ge. AK ~501 t'o;-'- \'\ cP\C-~ ~ MEM~~YY\.\A- -Ç'Q£-·-Jt:£t·Cre '-- ~.Á-A-~ .: * 25 2000bO.:Qq *~II'b 2 27111 * Sb~lI· 0.03 . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME$.1f ¡<-OIL PTD# 20ÿ -//ñ X Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUEn APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing weD . Permit No, API No. . (If API number Production. should continue to be reported as last two (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT BOLE In accordance witb 20 AAC 25.005(1), aU (PH) records, data and logs acquired for the pilot bole must be dearly differentiated in botb name (name on permit plus PH) " and API Dum ber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance witb 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing e:J ception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception that may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals tbrougb target zones. o o Well Name: PRUOJiOE BA't'.UNIT K-Q9~__._Program ~_ _ Well bore seg ---'LEV /1-0IL._GeoArea 890, Unit .1J65Q On/Off Shore .o~_ Annular Disposal . nitial ClassfTy~ Yes Yes yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA 640150 Field & Pool PRUDHOE BAY, PRUDHOE OIL _.~._---,_._--"-- Company .BE...E2ŒLO..RATION (ALASKAl.l~__ Permit fee attaChe.d, Lease ,number .appropriate, .U.ntque well.n.ame.a[ld oumb.er . . WellJocated ina defil1e.d pool "/~'lJocated proper .dista[lçe from driJling unit I located prpper .dtstance. from other weils iciel1t ¡;¡creageayail¡;¡ble indrilJiog unit ~viated, is, wellbore plat included bpUl1d¡;¡ry v~oc:J We incpmmeots) (For Qperator only: affected party .Operator bas.apprpprtate. bond tn Jorce can be tssued wnbout conservation order can be i,ssued witbout admil1istrativeapprpvaJ Ca[l permit be approved before 15-day wait. Well'~~~·~d ",,'.":n ~'ð~ ~n'" ~..~.~ ~"·"~':~ð'" .." 'n;", Order #: (puUO# All w I:,ervice welJ only:) . Pre-I s. than 3 mOl1tbs (Forserviœ wel is project. only) \~ I: I~ I~o ·I~~ 13 I '14 15 16 17 PTD#: 2041100 Administration Permit Permit ".~"...~,d.!lõiO !,V__"llIl~ '"'!"Y~ ~I,-U ""J.'~L~ 9~LU,,<!,.I_........\.t LlJ- 1..,'J...diorJ Date 6/21/2004 Appr RPC - CTOU, . . Sidetrack. Max MW8,9 ppg, Test tp35QOpsi.MSF' 2350 psi NA NA NA NA Yes Yes Yes Yes Yes NA Yes Yes Yes Yes Yes No, NA ACMP finding of .Conduçtor stringpfovided Surface casjnQ PJotects all.known USOWs CMT vpt adequ.ate. to circul¡;¡teoncOl1ductor & su.rfcsg .CMT vol. adequate to tie-in long .string to surf csg .CMTwill çoyerall !<I)ownproductiye bori~ons .C.asi[lg designs adequate for C,.T~ B&permafrpst Adequ¡;¡te tankage. Of reserve pit Jfa.re-drilt nasa 10:403 fOJ abandonment beeo approved .Adequ¡;¡te well bore I:,eparation proposed Jf.diverter fequiJed, does it meet reguJatiOl1s DJilJiog fluid program schematic & equip list.adequate BOPEs,dpthey meetreguJa.tiOI1 ,BOPEpJess ratiog appropriate; .test in.commel)ts) to (put psig C.hokemanifold compJies. w/API.RF'-53 (May 64) Work will oCCur without.operationsbutdown - Not ¡;¡O H2S pad. No NA NA NA NA .II:, prel:,ence of H2S gas prob.able Mecha,nicaLCOl)djtion pf wells wtthin AOß yerified (for. service we] only) Permit can be tssued w/o. hydrogen, s,utfide measures .D.ata.pJesel)ted on. pote.ntia\ O\len:!res.sure .zones. .Setsmic,analysis of shaJlow gas.zpoes Seabedconditioo slllvey.(if off-shpre) , , , . . . . . Contact nameLphonefor.weekly progrel:,sreports [exploratory .o[lly] 18 ,19 20 21 22 23 24 25 26 27 ;28 29 30 31 32 ,33 i 134 135 \36 37 38 39 Engineering Date 6/22/2004 Appr WGA Date 6/21/2004 Geology Appr RPC Date ý~~ ner Date Engineering Commissioner: Date: Geologic Commissioner: t\(~~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. ~c . ... . ANNEO SEP 1 :1 2008 To improve the readability of the Well History file and to simplify finding information, infonnation 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. . . ~D{-I(é) Sperry-SuD Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Oct 06 15:49:15 2004 Reel Header Service name.............LISTPE Date.....................04/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. -# J)J ~Co Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/10/06 Origin....... ............STS Tape Name................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBSR: OPSRATOR: LOGGING COMPANY: TAPS CRSATION DATS: # JOB DATA ~CANNED SEP 1 :1 2006 K-09C 500292173603 BP Sxploration (Alaska) Inc. Sperry-Sun Drilling Services 06-0CT-04 JOB NUMBSR: LOGGING ENGINSSR: OPSRATOR WITNSSS: MWD RUN 3 MW0003167150 S. LATZ KOLSTAD/HILD MWD RUN 4 MW0003167150 S. LATZ KOLSTAD/HILD MWD RUN 5 MW0003167150 S. LATZ KOLSTAD/HILD JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0003167150 S. LATZ KOLSTAD/HILD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 4 llN 14E 2113 493 52.86 RECEIVED # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 10317.0 nr'T l) n 1"\(111 A U,., j C L L"'VL~ f~}í1<gkª ~ Gomm!$$Í(¡F' # REMARKS: . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10317'MD AND THE BOTTOM WAS AT 10320'MD IN THE K-09B WELLBORE. 4. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL AND NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. NO PROGRESS WAS MADE ON RUN 1 - THE BHA COULD NOT EXIT THE WINDOW. MWD RUN 2 WAS A MILL RUN TO DRESS THE WINDOW. TIE-IN SGRC DATA ACQUIRED WHILE RIH FOR MWD RUN 2 WERE MERGED WITH MWD DATA FROM RUN 3. 5. MWD RUNS 4 - 6 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GSIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG PROVIDED BY K. COONEY (SIS/BP) ON 15 SEPTEMBER 2004. LOG HEAD DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 3 - 6 REPRESENT WELL K-09C WITH API#: 50-029-21736-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12352'MD/8954'TVDSS. SROP SMOOTHED RATE OF PENSTRATION WHILE DRILLING. SGRC SMOOTHSD GAMMA RAY COMBINSD. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVSD SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DESP File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9948.5 10309.5 10309.5 10309.5 10309.5 10309.5 STOP DEPTH 12298.5 12311.5 12311.5 12311.5 12311.5 12311. 5 ROP $ . . 10330.5 12342.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10303.0 10315.0 10317.5 10321.0 10357.5 10368.5 10383.0 10398.0 10407.0 10411. 5 10418.0 10433.5 10465.0 10470.0 10483.0 10487.0 10491. 5 10497.0 10501.5 10505.5 10508.0 10510.5 10513.0 10515.5 10517.5 10523.0 10529.5 10549.5 10561.5 10594.5 10617.5 10620.5 10624.0 10632.0 10637.0 10648.5 10660.5 10677.5 10684.5 10706.0 10718.0 10721.5 10726.5 10729.5 10734.0 10746.0 10750.0 10755.5 10759.0 10785.0 10795.5 10808.5 10814.5 10857.0 10860.0 10875.0 10883.5 10888.0 10904.5 10919.5 10923.0 10932.5 10953.5 11150.0 11157.0 11164.0 11167.5 11169.5 GR 10303.5 10316.5 10318.5 10320.5 10359.0 10368.5 10384.0 10398.5 10406.5 10410.5 10416.0 10431. 0 10465.0 10469.5 10481.5 10488.5 10492.5 10498.5 10502.5 10504.5 10508.0 10511. 0 10513.0 10516.0 10517.5 10524.5 10530.0 10553.0 10562.0 10594.5 10616.5 10621.5 10625.5 10632.0 10638.0 10650.5 10662.0 10679.5 10685.5 10705.5 10718.5 10723.0 10728.0 10731.0 10735.0 10746.5 10750.0 10754.5 10758.0 10786.5 10799.5 10812.0 10819.5 10860.5 10864.0 10880.0 10885.5 10889.5 10905.0 10916.0 10921.0 10932.0 10957.0 11155.0 11161.5 11167.5 11172.0 11173.5 . . 11180.0 11185.5 11195.0 11209.0 11227.5 11266.0 11306.0 11318.5 11327.0 11353.0 11368.5 11372.5 11374.5 11392.0 11394.0 11401.5 11427.5 11453.5 11473.0 11480.0 11505.5 11508.5 11522.0 11532.0 11541.0 11547.5 11551. 0 11561.5 11568.5 11584.0 11588.0 11595.5 11634.0 11637.5 11642.5 11648.0 11650.0 11675.5 11692.5 11705.0 11711. 5 11722.5 11781.5 11795.0 11819.5 11822.0 11830.0 11845.0 11865.5 11880.5 11888.5 11894.0 11937.0 11964.5 11980.0 11991.0 12012.0 12018.5 12037.0 12046.5 12053.0 12073.5 12079.0 12090.5 12103.0 12104.5 12132.0 12143.0 12157.5 12172.5 12179.5 12189.0 12213.0 12215.5 12224.5 11183.5 11189.0 11199.5 11212.5 11230.5 11269.5 11308.5 11321.0 11330.5 11356.0 11371. 0 11375.0 11377.0 11394.5 11396.0 11405.5 11432.0 11456.5 11475.0 11481.5 11506.5 11509.5 11526.0 11535.5 11545.0 11551. 5 11555.0 11564.5 11571.0 11585.5 11589.5 11597.0 11639.5 11642.5 11649.0 11654.5 11657.0 11680.0 11696.0 11708.5 11715.0 11724.5 11783.5 11794.5 11824.5 11827.5 11834.5 11848.5 11865.5 11882.0 11887.5 11893.0 11937.0 11965.5 11981. 5 11991.5 12013.5 12021. 5 12042.5 12055.0 12062.0 12081. 5 12084.5 12097.5 12111.5 12113.0 12138.0 12148.0 12164.5 12176.0 12190.5 12201. 5 12221. 5 12227.0 12234.5 . . 12234.0 12236.0 12240.5 12246.0 12248.5 12259.5 12276.5 12288.5 $ 12247.0 12249.0 12252.0 12259.5 12261. 0 12270.5 12290.0 12298.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 3 4 5 6 MERGE TOP 9949.0 10800.0 10997.0 12147.0 MERGS BASE 10800.0 10997.0 12147.0 12352.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point...... ........Undefined Frame Spacing.....................60 .1IN Max frames per record....... .... ..Undefined Absent value..................... .-999 Depth Units......... . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9948.5 12342.5 11145.5 4789 9948.5 12342.5 ROP MWD FT/H 0.23 3694.98 86.8762 4025 10330.5 12342.5 GR MWD API 15.8 957.89 50.9114 4096 9948.5 12298.5 RPX MWD OHMM 0.23 2000 20.9833 4005 10309.5 12311.5 RPS MWD OHMM 0.13 2000 28.8193 4005 10309.5 12311.5 RPM MWD OHMM 0.11 2000 30.9951 4005 10309.5 12311.5 RPD MWD OHMM 0.06 2000 30.9391 4005 10309.5 12311.5 FET MWD HOUR 0.22 48.89 6.69689 4005 10309.5 12311.5 First Reading For Entire File..........9948.5 Last Reading For Entire File...........12342.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 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.......04/10/06 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.001 Comment Record FILS HSADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VSNDOR TOOL CODE GR ROP $ 2 . header data for each bit run in separate files. 3 .5000 START DEPTH 9949.0 10330.5 STOP DEPTH 10770.0 10800.0 # LOG HEADER DATA DATE LOGGED: SOFTWARS SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL 1FT): BOTTOM LOG INTSRVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural 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 (DEGF) MUD AT MEASURED TEMPSRATURE (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.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined 09-JUL-04 Insite 7.75 Memory 10800.0 10330,0 10800.0 85.3 94.0 TOOL NUMBER TLGOll 4.125 10307.0 Flo Pro 8.70 65.0 8.7 21500 6.0 .000 .000 .000 .000 .0 154.0 .0 .0 . . Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units...................... . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD030 MWD030 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9949 10800 10374.5 1703 9949 10800 ROP MWD030 FT/H 0.5 183.09 38.3147 940 10330.5 10800 GR MWD030 API 15.8 957.89 43.1859 1038 9949 1077 0 First Reading For Entire File..........9949 Last Reading For Entire File...........10800 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical SOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBSR: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 4 .5000 START DEPTH 10310.5 10310.5 10310.5 10310.5 10310.5 10770.5 10800.5 STOP DEPTH 10966.0 10966.0 10966.0 10966.0 10966.0 10952.0 10997.0 # LOG HSADSR DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VSRSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MSMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 09-JUL-04 Insite 4.3 Memory 10994.0 10800.0 10994.0 . HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM SWR4 $ BOTTOM) TOOL TYPE Dual GR 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 (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLS CORRECTION (IN): # TOOL STANDOFF (IN): EWR FRSQUENCY 1HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units......... ..Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 87.5 88.9 TOOL NUMBER 78005 171170 4.125 10307,0 F10 Pro 8.60 65.0 9.0 20000 5.8 .180 .080 .210 .200 65.0 158.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10310.5 10997 10653.8 1374 10310.5 10997 ROP MWD040 FT/H 0.7 250.89 62.1568 394 10800.5 10997 GR MWD040 API 24.63 142.98 48.4646 364 10770.5 10952 RPX MWD040 OHMM 0.23 2000 23.3519 1312 10310.5 10966 RPS MWD040 OHMM 0.13 2000 41.2378 1312 10310.5 10966 RPM MWD040 OHMM 0.11 2000 51. 602 1312 10310.5 10966 RPD MWD040 OHMM 0.06 2000 51.1025 1312 10310.5 10966 FET MWD040 HOUR 0.38 48.89 17.2198 1312 10310.5 10966 First Reading For Entire File... .......10310.5 . . Last Reading For Entire File...........10997 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... VersioD Number...........1.0.0 Date of Generation.......04/10/06 Maximum Physical Record. .65535 File Type............... .LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 4 header data for each bit run in separate files. 5 .5000 START DEPTH 10952.5 10966.5 10966.5 10966.5 10966.5 10966.5 10997.5 # 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 1FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPS: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): STOP DEPTH 12102.0 12116.0 12116.0 12116.0 12116.0 12116.0 12147.0 11-JUL-04 Insite 4.3 Memory 12147.0 10994.0 12147.0 87.0 91. 6 RESIS. 4 TOOL NUMBER 78005 171170 3.750 10307.0 Fl0 Pro 8.70 65.0 9.2 20500 5.6 . . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .190 .080 .210 .230 71. 0 172.4 71. 0 71. 0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): SWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units.......... .Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10952.5 12147 11549.8 2390 10952.5 12147 ROP MWD050 FT/H 0.78 3694.98 112.663 2300 10997.5 12147 GR MWD050 API 23.77 156.99 51.1991 2300 10952.5 12102 RPX MWD050 OHMM 10.72 135.3 20.476 2300 10966.5 12116 RPS MWD050 OHMM. 11. 25 85.72 21.4948 2300 10966.5 12116 RPM MWD050 OHMM 11.41 64.39 21.17 91 2300 10966.5 12116 RPD MWD050 OHMM 13.15 41. 91 22.1946 2300 10966.5 12116 FET MWD050 HOUR 0.22 24.9 1. 31297 2300 10966.5 12116 First Reading For Entire File..........10952.5 Last Reading For Entire File...........12147 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number. . . . . . . . . . .1. 0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.005 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 . Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VSNDOR TOOL CODS GR RPD RPM RPS RPX FET ROP $ 5 . header data for each bit run in separate files. 6 .5000 START DEPTH 12102.5 12116.5 12116.5 12116.5 12116.5 12116.5 12147.5 STOP DEPTH 12308.0 12321. 0 12321. 0 12321. 0 12321.0 12321.0 12352.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MSMORY OR RSAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR 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 (DEGF) 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 Logging Direction.................Down 12-JUL-04 Insite 4.3 Memory 12352.0 12147.0 12352.0 86.8 93.0 TOOL NUMBER 78012 171170 3.750 10307.0 Flo Pro 8.60 65.0 8.9 21500 5.6 .210 .090 .170 .160 67.0 167.0 67.0 67.0 . . Optical log depth units...........Feet Data Reference Point............. .Undefined Frame Spacing....... ..............60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units.................. . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12102.5 12352 12227.3 500 12102.5 12352 ROP MWD060 FT/H 0.23 405.78 74.8477 410 12147.5 12352 GR MWD060 API 30.96 168.32 70.3897 412 12102.5 12308 RPX MWD060 OHMM 7.98 26.45 16.4793 410 12116.5 12321 RPS MWD060 OHMM 9.79 35.83 19.0538 410 12116.5 12321 RPM MWD060 OHMM 10.14 46.09 20.2848 410 12116.5 12321 RPD MWD060 OHMM 12.71 158.94 21. 6672 410 12116.5 12321 FET MWD060 HOUR 0.45 10.15 2.84512 410 12116.5 12321 First Reading For Entire Fi1e..........12102.5 Last Reading For Entire File...........12352 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/10/06 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date........,.. ..........04/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments........... ......STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date.....................04/10/06 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF . . End Of LIS File . .