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199-051
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-26 KUPARUK RIV UNIT 1C-26 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-26 50-029-22944-00-00 199-051-0 W SPT 6310 1990510 1578 2063 2064 2063 2063 385 410 410 400 4YRTST P Austin McLeod 5/15/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-26 Inspection Date: Tubing OA Packer Depth 810 2910 2850 2840IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220515190527 BBL Pumped:2.1 BBL Returned:2.1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:39:17 -08'00' THE STATE 01ALASKA GOVERNOR BILL WALKER James Hayes Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C-26 Permit to Drill Number: 199-051 Sundry Number: 318-431 Dear Mr. Hayes: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the 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. k� DATED this k day of October, 2018. Sincerely, Hollis S. French Chair RBDMS 1 OCT ' 9 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVE® SEP 2 2018 AO C Ca 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q • Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing F� Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 21. 199-051 3. Address: 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50-029-22944-00 T If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-26 - Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ,4 1>1— noz-9; '% ADL028243 Q 2T./2; 1 Kuparuk River Field/ Kuparuk River Oil Pool ' 11. 1PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,630' 6,622' 7,848' 2,159' 2,159 10,141' 14,068' Casing Length Size MD TVD Burst Collapse Structural Conductor 87' 16" 121' 121' Surface 6,462' 9.625" 6,497' 4,461' Intermediate Production 10,526' 7" 10,556' 6,458' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11,380'-13,580' 6,556'-6,594' 4.5" L-80 10,457' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER SABL-3 PACKER W/ SEAL ASSEMBLY MD= 10,100' TVD= 6,310' 12. Attachments: Proposal Summary Z Wellbore schematic F4-1 13. Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑4 14. Estimated Date for 10/24/2018 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG Q GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Hayes Contact Name: James Hayes Authorized Title: Sr. Wells Engineer Contact Email: 'ameS.C.ha e5 4 Co .COm Contact Phone: 265-6927 p Authorized Signature: Date. 7 `12 G11j'V 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: eop fTSf -lo f Jr00 p 5- '5 J Z'b 5� f}✓rnr✓/a✓,pr-C✓e-r7�-r' 157 !o ai!!uw �ackr✓ }a rs htr warVry gra C &,r N!�{UUrM D �bo V� flirt 7�p ��t/T Post Initial Injection MIT Req'd? Yes No ❑ P) {6'— ¢ -z 6 Spacing Exception Required? Yes ❑ No Subsequent Form Required: (^ /� �' a U tF✓42 2 ✓r• r APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: /� /� Submit Form and \O-\�Fyr 403 Revised 42017 Approved applicatbn�s®it�t{r T2� t s the date o approval. Attachments in Dupliwle V ,� [` V &AS i ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 26, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'h Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Well IC -26 (PTD# 199-051). Injecting well IC -26 was originally completed August of 1999, injecting in the Kuparuk C -sand. In September 2017 a tubing leak was found, and a series of patches were placed to fix the leaks. After many attempts to seal the leaks all patches were pulled, and the well was shut in. If you have any questions or require any further information, please contact me at 265-6927 Sincerely, ames� C Sr. Wells Engineer CPAI Drilling and Wells Loepp, Victoria T (DOA) From: Hayes, James C <James.C.Hayes@conocophillips.com> Sent: Tuesday, October 09, 2018 4:32 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL)KRU 1C-26(PTD 199-051, Sundry 318-431) RWO to CO Tubing Attachments: 1C-26 RWO Prop Schematic 10-9-28.pdf Thanks, James Hayes C: +1918.914.9609 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, October 9, 2018 8:54 AM To: Hayes, James C <James.C.Hayes@conocophillips.com> Subject: [EXTERNAL]KRU 1C-26(PTD 199-051, Sundry 318-431) RWO to CO Tubing James, Please provide: 1. depths of the packers on your schematic(TVD and MD). I have attached a new schematic does this have all you need? 2. 7" PC cement TOC and how it was determined(CBL? Calculated?). I have a calculated top @ 9,763' MD / 6,156' TVD & job went as planned (i.e. no losses while pumping) but there was no CBL ran on this well 3. Which rig is being used? BOP stack schematic? Nabors 7ES and it will be a13 5/8" 5M: Annular, 2-7/8" x 5" VBR, Blind Ram, Mud Cross, 2-7/8" x 5" VBR, & Adapter spool if needed 4. Are you requeb8224' waiver for the packer distance above the top perforation? We will be leaving the current packer which rom the top perforation, so with this plan I will be stacking a packer on top, and yes I will be requestingr. Thanx, 1C1C=26 Proposed RWO Completion 16" 62# H-40 shoe @ 121' RKB 4-1/2" 9.3# L-80 Hyd 563 Tubing 9-5/8" 36# L-80 shoe @ 6,497' RKBc D 4.5" X -Nipple 3.813" ID (Hyd 563) ` A New GLM depth -5,233' MD/4,500' TVD Zj Non -sealing Overshot New Packer depth 9,989' MD/6,262' TVD Old Packer depth 10,099.6" MD/6,309.3' ND �y 7" 26# J-55 shoe @ 10,556' RKB C4 -sand perfs 11,380'- 13,550' RKB JW , I PROPOSED COMPLETION 4-1/2" 9.3# L-80 Hyd 563 Tubing to surface -1 ' 1 4-1/2" Camco KBG-1 gas lift mandrel @ TBD 4-1/2" 9.3# L-80 Hyd 563 Tubing 4.5" x 7" Premier Packer D 4.5" X -Nipple 3.813" ID (Hyd 563) ` A Zj Non -sealing Overshot REMAINING COMPLETION LEFT IN HOLE �y Baker SABL-3 Packer w/ Seal Assembly `0 4.5" HES X -Nipple 3.813" ID Overshot w/ Packoff 4", 14# DP to TD w/ Perforations. 1C-26 Rig Workover Pull & Replace Tubing (Stack Packer) (PTD #: 199-051) Current Status: This well currently is shut in and has a plug installed @ 10,141' Scope of Work: Cut & pull current 4 ''/z" tubing string due to leaks in tubing. Install new 4 '/2" tubing and packer with gas tight threads. General Well info: Well Type: Producer MPSP: 2,159 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 2,802 psi / 6,431' TVD (8.4 ppg) on 6/19/18. Wellhead type/pressure rating: FMC Gen 5, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT-Tbg failed on 6/19/18, CMIT TxIA to 2,500 psi 6/19/18. Earliest Estimated Start Date: October 24", 2018 Production Engineer: Evan Reilly / Jeremy Mardambek Workover Engineer: James Hayes Oames.c.hayes@cop.com) Pre -Rig Work 1. RU Slickline: a. Confirm dummy off GLM #1 at 518' RKB. Confirm production mandrel at 10,053' RKB is open b. Chem cut tubing at —10,083' RKB (middle of first joint before the Baker SLAB packer @ 10,100' RKB) Proposed Procedure W yrd -� 1. MIRU. 2. Reverse circulate seawater. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set TWC & ND tree, NU BOPE & test to 250/2,5., 00 psi. 4. Pull TWC, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 41/2" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the GLM. b. If tubing was cut, RIH w/ overshot & grapple and pull seal assembly from packer. --Proposed Procedure Continued-- 1C-26 Rig Workover Pull & Replace Tubing (Stack Packer) (PTD #: 199-051) 6. RU&RIHw/new4'/2"#1 7. PU, MU and TIH with the following completion to anticipated setting depth. a. Non -sealing 4-1/2" Overshot. Length 13.5'. (Planned top at 10,075' RKB. Minimum swallow 1.2'. Shear pins (14kips SOW) at 6' total swallow.) b. 1 Joints, 4-1/2", 12.6#, L-80 Hyd 563. Length 31'. c. Pup, 4-1/2", 12.0, L-80 Hyd 563. Length 10'. d. Nipple, X landing nipple, 3.813 X. Length 1'. (w/ RHC plug body installed for ball & rod) e. Pup, 4-1/2", 12.6#, L-80 Hyd 563. Length 10'. f. Joints, 4-1/2", 12.6#, L-80 Hyd 563. Length 31'. g. Packer, 4-1/2" Premier, Baker. Length 6'. h. -153 Joints, 4-1/2", 12.69, L-80 Hyd 563 tubing i. Pup, 4-1/2", 12.6#, L-80 Hyd 563. Length 10'. j. 4-1/2" x 1" KBG-2 GL GLMs Type RKB (ft) TVD (ft) Loaded With 1 KBG-2 5,233` 4,500` SOV (2,000# csg->tbg) k. Pup, 4-1/2", 12.64, L-80 Hyd 563. Length 10'. 1. -168 Joints, 4-1/2", 12.6#, L-80 Hyd 563 tubing to surface m. Pup, 4-1/2", 12.6#, L-80 Hyd 563. Length 4' n. FMC Tubing hanger 8. Tag top of fish determine space out, LD joint (s), MU pup joints & hanger & hang off tubing string. 9. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited seawater. Land the hanger, RILDS. 10. Drop ball & rod. Pressure up tubing to 2,600 psi to set packer 11. PT the tubing to 3,000 psi, bleed tubing to 2,500 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then IA. 12. Pull the landing joint, install TWC. 13. ND BOPE, NU tree. Pull TWC, install tree test plug. Test tree. Pull tree test plug. 14. Freeze protect through the SOV, set TWC. 15. RDMO. Post -Rig Work 1. Pull TWC. 2. RU Slickline: Pull SOV, replace w/ DV. &jFkI. KUP INJ 1C-26 Mh '°�'- Well Attributes Max Angle S MD - TD \..V11VLlJrEE CLJnoc&hilfips 11 IT Name WellOpre APIIVIN We110ore Sbtus Thearl .(Wo) ROBRAIRNA) Alaska.InC. KUPARUK RIVER UNIT 500292294400 INJ 94A2 12.56)36 14,6300 H]a ppm/ Oale Mlachu" En40aA NBG,a 1R) Rlg Release Dale Gpmmenl SSV:NIPPLE Last WO 4901 8/23/1999 1428. spedgele 9+155 PM11 Last Tag VMtN sohema0c(ec",u Anrolallm Last Tag: RKB Entl Data 6119/2018 DepIR IRIfBI IMOC ey 104620 fergus0 lurvcEa: xzs Last Rev Reason EnOOofe Iz Motl By Rev esdl. Pulled Patch Rev Rew assem,AID Tel plug 6/192018 lergusp Casing Strings ¢rime Descnpnon OD (in) mgn) Topinel setDeplM1 (nMe BeI DapN lrvm.. WtlLen q... Gra4e rov TR,wV coMoucioR; 3aomo CONDUCTOR 16 15.06 34.0 121.0 1210 62.58 H40 WELDED NIPPLE: 1163 Casing Description SURFACE OO QnI l0 {In) iop{RK8) get OepIN RN01 8518 8.84 34.5 6,496.6 . GraEe ipp TM1ru4 0,4fi09 680 BTC .at up"HVD#2MA Casln80eserlptlon OD (Int IO Sn rep( get OcplhIRNBI Eel Dapll,fNDGIa4a Top TRrW GRUFTl 5173 PRODUCTION 7 528 30.6 10,5563 64457.fi L-80 BTGMOD <aslnp Descrlptbn ODDnI ID (In) Top(tINB) Set OepN IRNBI Set DplR (NOGntle Tap ThIaE DRILL PIPEi7OOLS 4 2.31 10,4546 146050 6,619.2 680 HT38 Tubing Strings Tubing Dese,lptlon "The MA, mgn) TCp Idup sn CARD in.. Bd DapN (ID) I, QGBq ono. rap Lonmeaan FOsaazELRK4.C%0 TUBING IN 41/2 3.96 T1.5 ID457.2 6,433.6 1260 L-80 ABrd40D Completion Details Top (TVD) Top Incl NCminal Top(nKal IIK.A ('1 It.. Des IO An) SUNFACE: se ER 1- 27.5 27.5 O6 HANGER TMG GEN IV 5M TUBING HANGER 4.500 TUBING LEAR IPam,e41; 4763 476.2 245 NIPPLE HET -NIPPLE 3.813 apu o 10,099.6 6309.9 6604 PACKER BAKER SABL-3 PACKER w/ SEAL ASSEMBLY 3.958 GABUFT. 10..E 10,141.3 6,3266 6665 NIPPLE HER X NIPPLE 3.813 10.451.5 6,4320 7435 OVERSHOT OVERSHOT WI RACKOFF SWNLL. WED 786' OF 4- DRILL PIPE 4.063 LEFT DOWNHOLE vACNER; m.0ee.a Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top ITVDI Topincl MIKE, 10,141) nyao led leg llNal InF°el 1°I Des cpm Run Date to (In) 46240 3,508.1 070 POSSIBLE TOEING LEAK (EL LDL 0.5FELT @2300 PT1) I/1fi/2018 0.009 LEAK OYERSMr 100.515 1,9000 5.175.3 5925 TUBING LEAK TUBINGIEAK (PalcRed) 9/25/2017 0.000 (PetCll¢0) 10,1410 6,3265 6664 Plug set 3.81'XX plug w1141 ext (08143"1 6/19/2018 0.000 13,600.0 6,592.7 9 M1 PLUG Cement ApAprereb0ve pippee fist, source w5061tls re- 10/29/199 0000 cement bebw laid in cement 13361Indeed 9 Cement W/2177 SeardI10 13600 1029199 PRODUCTION: MAILIO 53- ROBE0 65867 8983 FISH 81-ALOST811&1999 8/1211999 0.000 Perforations & Slots APERF: TDOI.G11 Mmol PPERE N,Asl Dll,spy0- "Tv., Au.,ed Isoolem 11 (MDA Btm IRNBI (IKEI (INS) UOI,z ne cIA 1 Type enm ,unDee D.57o.0Mtem.O- 11, 80.0 114000 65557 6556.5 C.4. I -26 2127/2000 6.0 APERF r HBO PJ:65deg_ph DP 11,490.0 11,5200 6,556.2 6,555.6 C4, 1C-26 7/3/2003 fig APERF TPJ 20 RMX 60 eg Dh APER': L.&OG1+ 6m0-- 11,5700 11,600.0 6.5564 6,557.9 C4, 1U26 1114/2005 60 APERF TH UPJ: deg Pb OP APERF: nnaan,'raq 11,6400 11,6700 6,5599 6,561.2 4.1C-2 1114/2005 60 APERF THSD PJ20chgs.6adeg ph APERF;T.TW.D11side 11,71 11740.0 6.5624 65620 C . 1CA 1n4/2005 60 APERF 7 MSD PJ20 CII deg an 11,790.0 11,820.0 6,5591 6.5572 C41C.26 7127200 6.0 APERF 2" PJ 20NHMX:60deg ph 12400.0 12430.0 6.5954 6,5992 Ci, 1C-26 7/2/2003 fig APERF IT PJ 20MHMX160deg ph APERPa24mo-Y4m0-�124700 125000 6603.1 6.604.2 C -TIC -26 104/2005 &0 APERF HBO PJ chgs60 deg �_ IT ph MENF.12.410 .0.12`.N 0- 12,5300 12,560.0 6.6033 5.601 2 C4, I0-26 1/142005 6.0 APERF THSD PJ20 ch0560 deg APERF: 12533.G125m0- Ph 12,5900 12,6200 6,5987 6,5964 C4. IC 26 1/14/2005 &0 APERF Z HSU PJ20 chgNE0 deg _ APERF; DANO 012 Wind- ph I 12,669.0 12.690.0 6,5939 6,592.6 C -4.1C-26 711/2003 ED APERF S' PJ 20D5HMX; 60deg ph APERF;CARL) B-135s0.P-: 12)300 12760.0 6,592.5 6,593.6 G4, 1C.26 1/14/2005 Go APERF 2- HSU PJ20 chus.60 deg APERF. UJxD0 1x 760.0-: Ph 12800.0 12830.0 6,595.3 65962 G4. 1C-26 1/14/2005 60 APPLE T HTO PJ20 chgs60 deg MERF; 12.100612830.0-_ pit APERF: 1U70DIZ. 0-- 12,870.0 12,900.0 6596.3 6,596.2 C4. IG26 7/1/2003 6.0 77CRF PJ 2006HMX:60009 ph 12,940.0 12,970.0 6,5958 6595.5 C4.1C-26 1/14/2005 60 APERF P-1470 tl1gs60deg PERF: 12910612970.0- ph MERF: 13.0100-13NO 13,010.0 13,040.0 65955 6.595.7 C -4 ,1C-26 1114/2005 6.0 APERF 2' HBO P420 OVSEO deg PR APERF, t3mDO131100 13.o80.0 13,110.0 6,5959 65960 C4, IC 26 1/142005 6.0 APERF 7HSD PJ20cb9s 60 deg MERF; 13150G13t60.0-- 13,150.0 13,180.0 6,5961 6.596.1 C4IC-26 6/302003 6.0 APERF Y PJ 200611MX60deg ph MERF. lynsIC0.13280.0------ 13,220.0 13.250.0 55965 65965 C-4, 1C-26 1/142005 6.0 APERF T HBO PJ20 chgs 60 deg Ph 7aERF; 13390.G+3.3mo� 13,290.0 13,320.0 6,595.9 6,594.8 C4, IC -26 1/1412005 60 APERF 2` HSD I'M U9s,60 tleg CA IPERF; 1334 D.O13.370.0- mEe'; +3amw341o0- 13,350.0 13,3700 6 d. ,5933 65924 C 1026 11/2/1999 6.0 IPERF 2' HBO PJ 60 dug. p6 UP PERT: 13.410Glssel 13,370.0 13.410.0 6,5924 6592.2 C-I,IC-26 11/1/1999 BO (PERE THSDPJ160deg. ph DP APERF.134mn13.SED0- 13410.0 13,450.0 6.5922 6,593.2 7.4,IG26 10131/1999 6.0 (PERF 2"H DPJ:6Ddeg ph OP 13,490, 13.520.0 B594 4 6.594.8 C4, 1C261/142005 6.0 APERFY"HSD PJ20 chgs,60tleg A°ERF+ 3560613Em.0� OM1 PLUG,13.ON0 13.550.0 13,580.0 6,5944 6,5935 74, IC -26 711412005 ad APERF I THSD PJ2G URI qeg ph Notes: General & Safety BAR 14.MOGet 1¢ Annotation 10,geVI99NOTE-200' CEMENT PLUG ABOVE BHA W/ RADIOACTIVE SOURCE NOTF_ DRILL PIPE ID=2 439 -TOOL JOINT Lot 10489 79' - DRILL PIPE DRIFT 1D=1.313- IN TODL JOINTS DRILLPI'ERogd: 10,4N6 14asC 1C-26 Proposed RWO Completion 16" 62# H-40 shoe n 121' RKB 9-5/8" 36# L-80 shoe @ 6497' RKB 7" 26# J-55 shoe @ 10556' RKB C4 -sand perfs 11380'- 13550' RKB PROPOSED COMPLETION 4-1/2" 9.3# L-80 Hyd 563 Tubing to surface 4-1/2" Camco KBG-1 gas lift mandrel @ TBD 4-1/2" 9.3# L-80 Hyd 563 Tubing 4.5" x 7" Premier Packer 4.5" X -Nipple 3.813" ID (Hyd 563) Non -sealing Overshot REMAINING COMPLETION LEFT IN HOLE Baker SABL-3 Packer w/ Seal Assembly 4.5" HES X -Nipple 3.813" ID Overshot w/ Packoff 4". 14# DP to TD w/ Perforations. Or Tk • 44,1",I�j�s THE STATE Alaska Oil and Gas of LAs]KA Conservation Commission " r = 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 Op,ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. sCANM w## � PO Box 100360 Anchorage,AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-26 Permit to Drill Number: 199-051 Sundry Number: 318-029 Dear Ms. Lyons: 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, CD1) Hollis S. French +` Chair DATED this 36 day of January, 2018. RBDMS - 1 2018 • RECEIVED • STATE OF ALASKA JAN L 4 2018 ALASKA OIL AND GAS CONSERVATION COMMISSION Or, if 36(`e APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations L.J Fracture Stimulate U Repair Well U Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill LI Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ tbg patch " Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 199-051 ' 3.Address: 5tratigraphic ❑ Service 2` 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 500292294400 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a • Will planned perforations require a spacing exception? Yes IllNo 0 ✓ KRU 1C-26 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL28243 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,630' • 6,622' • 10,141'• 7848'• 3800 10,141' n/a Casing Length Size MD TVD Burst Collapse Structural Conductor 87' 16" 121' 121' Surface 6,462' 9-5/8" 6,497' 4461' Intermediate Production 10,526' 7" 10,556' 6458' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,380'-13,580' 6556-6594' 4.500" L-80 10,452' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): No SSSV-X nipple • MD=476' TVD=476' PACKER-BAKER SABL-3 PACKER W/SEAL ASSEMBLY • MD=10100 TVD=6310 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., 14.Estimated Date for 1/27/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: n/a GAS ❑ WAG ❑✓ , GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: -I -,-grity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: Date: 1/21/18 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31e -029 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? YesKr-No ❑ RBE) 'Mw; L L. f:3 - i "i618 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: 19 40 APPROVED BY Approved by: ' I+! P----N___ COMMISSIONER THE COMMISSION Date: I i 30 1 i e, ?'Kb #.11/it a,/ � 07-6/1 Submit Form and Form 10-403 Revised 4/2017 Approved application i li rirlhNre.mate of approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. KRU Well 1C-26(PTD 199-051) SUNDRY NOTICE 10-403 TUBING REPAIR 1/21/18 This Sundry is a request for approval to repair ConocoPhillips (CPA)Kuparuk River Unit Well 1C-26 (PTD 199-051)with a tubing patch. Under sundry permit#317-503, a patch was recently installed across a known leak at 7900'. During the patch installation process, an additional smaller leak was discovered at 4625'. The plan is to now set an additional retrievable tubing patch across this newly identified leak, conduct an MITIA, and return the well to normal WAG injection. REPAIR PLAN 1. Set 3.5"TTS retrievable patch over the leak at 4625'. Current design is for a 30' patch. However,there may be a need to set an extension if placement across suboptimal tubing is not successful. 2. Witnessed MIT as per AOGCC requirements (0.25 x TVD to packer) after well is returned to injection service and stabilized. 3. Submit 10-404 post-repair. 11 , KUP INJ , 1C-26 ConocoPhillips t Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) c Yeepo 500292294400 KUPARUK RIVER UNIT INJ 94.92 12,567.36 14,630.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-26,1/182018 10:4413 AM SSSV:NIPPLE Last WO: 40.01 8/23/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ...............................HANG/B.27.5-1-- I Last Tag: 10,570.0 9/28/2007 Rev Reason:add new tbg leak condijw 1/18/2018 TM, [-ter Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 34.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread !•`f r.I�,anti SURFACE 95/8 8.835 34.5 6,496.6 4,460.8 40.00 L-80 BTC MACONDUCT ;34 OR .0.1210 r 'r p r Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(t...Grade Top Thread PRODUCTION 7 6.276 30,6 10,556.3 6,457.6 26.00 L-80 BIC-MOD NIPPLE 476.3 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ill DRILL PIPE/TOOLS 4 2.313 10,454.6 14,605.0 6,619.2 14.00 L-80 HT-38 GAsuFr;sna Tubing Strings Tubing Description I String Ma...I ID(in) I Top(ftKB) I Set Depth(ft..I Set Depth(TVD)I...IWt(Ibtft) I Grade I Top Connection TUBING 4112 3.958 27.511 10,457.2 6,433.6 12.60 L-80 AST-MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) POSSIBLE LEAK:4,624.0 ir227.5 27.5 0.05 HANGER FMC GEN IV 5M TUBING HANGER 4.500 476.3 476.3 2.45 NIPPLE HES X NIPPLE 3.813 10,099.6 6,309.9 66.04 PACKER BAKER SABL-3 PACKER w/SEAL ASSEMBLY 3.958 SURFACE;34.5-6,496.6— 10,141.4 6,326.6 66.65 NIPPLE HES XNIPPLE 3.813 BAIT SUB;7,886.0 10,451.5 6,432.1 74.35 OVERSHOT OVERSHOT w/PACKOFF SWALLOWED 7.86'OF 4" 4.063 PATCN;7,886.01 .a.c DRILL PIPE LEFT DOWNHOLE TUBINGLEwc(Pa,900.0 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) P 9 P P r Top(TVD) Top Incl Top(ftKB) (ftKB) ('1 Des Corn Run Date ID(In) PATCH;7,910.0 I I 4,624.0 3,508.1 60.70 POSSIBLE TUBING LEAK(EL LDL 0.5 BPM @ 2300 PSI) 1/16/2018 0.000 LEAK 7,886.0 5,168.2 59.31 PATCH 3.76"P2P(#CPP45014),19'SPACER PIPE,LATCH 1/11/2018 2.000 GAS LIFT;10,052.6 SEAL ASSY(#CPAL45001/25.36'OAL/2"I[ 111 7,900.0 5,175.3 59.25 TUBING TUBING LEAK(Patched) 9/25/2017 0.000 PACKER;10,099.6 i. LEAK NIPPLE 10,141.4 >_ (Patched) 7,910.0 5,180.4 59.21 PATCH 3.76"P2P(#CPP45013/4.89'OAL/2"ID) 1/11/2018 2.000 OVERSHOT;10451.5 4, 1 4 13,600.0 6,592.7 92.41 PLUG Cement retainer above radioactive source w/90 bbls 10/29/1999 0.000 re-cement below laid in cement 13361'-13915';milled I cement w/2.175"Bearclaw to 13600'10/29/99 H 14,068.0 6,586.7 89.83 FISH BHA LOST 8/12/1999 8/12/1999 0.000 PRODUCTION;30.6-10,556.3— j Perforations&Slots APERF;11,380.0-11,400.0 Shot Den Top(TVD) Btm(TVD) (shotslf APERF;11,490.0-11,520.0 Top(ftKB) Btm(ftKB) (ftKB) (ft613) Zone Date t) Type Com 11,380.0 11,400,0 6,555.7 6,556.5 C-4,1C-26 2/27/2000 6.0 APERF 2"HSD PJ;eOdeg.ph DP APERF;11570.0.11,600.0 11,490.0 11,520.0 6,5562' 6,555.6 C-4,10-26 7/3/2003 6.0 APERF 2"PJ 2006HMX;60deg .— APERF;11,640.0-11,670.0 ph APERF;11,710.0-11,740.0 1 11,570.0 11,600.0 6,556.4 6,557.9 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ;60deg.ph DP APERF;11,790.0-11,820.0 11,640.0 11,670.0 6,559.8 6,561.2 C-0,10-26 1/14/2005 6.0 APERF 2"HSD PJ2Ochgs,60deg ph APERF;12,400.0-12,430.0 rJ � 11,710.0 11,740.0 6,562.4 6,562.0 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 I deg ph 44— APERF;12,470.0-12,600.0 11,790.0 11,820.0 6,559.1 6,557.2 C-4,10-26 7/2/2003 6.0 APERF 2"PJ 2006HMX;60deg Ph APERF;12,530.0-12,560.0 J -- 12,400.0 12,430.0 6,595.4 6,599.2 C-4,10-26 7/2/2003 6.0 APERF 2"PJ 2006HMX;60deg ph APFRF;12,590.0.12,620.0 12,470.0 12,500.0 6,603.1 6,604.2 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60- APERF;12,660.0-12,650.0 _1 deg ph 12,530.0 12,560.0 6,603.3 6,601.2 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 APERF 12,730.0.12,760.0 . deg ph 1 .y? 12,590.0 12,620.0 6,598.7 6,596.4 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 APERF;12,800.0-12,830.0 --e deg ph APERF;12,870.0-12,900.0 = 12,660.0 12,690.0 6,593.9 6,592.6 C-4,10-26 7/1/2003 6.0 APERF 2„PJ 2006HMX;eodeg P APERF;12940.0-12,970.0 1; 12,730.0 12,760.0 6,592.5 6,593.6 C-4,10-26 1/14/2005 6.0 APERF 2"HOD PJ20 chgs,60 4/4- deg ph APERF;13,010.0-13,040.0 --n: 12,800.0 12,830.0 6,595.3 6,5962 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ2ochgs,60 deg ph APERF;13,080.0-13,110.0 v 12,870.0 12,900.0 6,596.3 6,596.2 C-4,10-26 7/1/2003 6.0 APERF 2"PJ 2006HMX;60deg ph APERF;13,150.0.13,180.0 12,940.0 12,970.0 6,595.8 6,595.5 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 APERF;13220.0-13,250.0 deg ph -� 13,010.0 13,040.0 6,595.5 6,595.7 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 APERF;13,290.0-13,320.0 " deg ph 13,080.0 13,110.0 6,595.9 6,596.0 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 IPERF;13,350.0-13,370.0 deg ph IPERF;13,370.0-13,410.0 13,150.0 13,180.0 6,596.1 6,596.1 C-4,10-26 6/30/2003 6.0 APERF 2"PJ 2006HMX;60deg IPERF;13,410.0-13,450.0 J ,, ph APERF;13,490A-13,520.0 r `" 13,220.0 13,250.0 6,596.5 6,596.5 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;13,550.0.13.580.0 13,290.0 13,320.0 6,595.9 6,594.8 C-4,10-26 1/14/2005 6.0 APERF 2"HSD PJ2ochgs,60 4- deg ph PLUG;13,600.0 13,350.0 13,370.0 6,593.3 6,592.4 C-4,1C-26 11/2/1999 6.0 IPERF 2"HOD PJ;60 deg.ph DP FISH;14,068.e 13,370.0 13,410.0 6,592.4 6,592.2 C-4,10-26 11/1/1999 6.0 IPERF 2"HSD PJ;60 deg.ph DP DRILL PIPE/TOOLS;10,454.6- A..J 14,605.0-* v.._ KUP INJ • '1026 ConocoPhillips 1 Alaska,Inc. mw..seh up: 1C-26,1/1W2018 10:44:15 AM Vertical schematic(actual) .............._...............HANGER;27.5 ___t; Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shotsh Yae Top(ORB) Btm(ftKB) (ttKB) (1KB) Zone Date t) Type Com 'M�CONOUCTOR:34.0-021.0�� ,� 13,410.0 13,450.0 6,592.2 6,593.2 C-4,1C-26 10/3111999 6.0 IPERF 2D"P SD PJ;60deg.ph NIPPLE;476.3 rE 13,490.0 13,520.0 6,594.4 6,594.8 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph f 13,550.0 13,580.0 6,594.4 6,593.5 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 GAB LIFT;517.7 deg ph Notes:General&Safety End Date Annotation 10/24/1999 NOTE:200'CEMENT PLUG ABOVE BHA W/RADIOACTIVE SOURCE POSSIBLE LEAK 4,624.0 6/30/2003 NOTE:DRILL PIPE ID=2.438"TOOL JOINT©10489.79'-DRILL PIPE DRIFT ID=2.313"IN TOOL JOINTS 1/14/2005 NOTE:ALL 1/14/2005 PERFORATIONS DONE WITH COILED TUBING 2/14/2011 NOTE:View Schematic w/Alaska Schematic9.0 SURFACE;34.5-6,496.6—. t BAIT SUB;7,686.0 PATCH;7,868.01 TUBING LEAK(Patched); 7,900.0 ! , PATCH;7,910.0 GAS LIFT;10,052.6 IF ,k . PACKER;10,099.6isakt NIPPLE;10,141.4 I OVERSHOT;10,451.5 JI PRODUCTION;30.8-10,556.3 ^ APERF;11,380.0-11,400.0 1 APER F;11,490.0-11,520.0 .- APERF;11,570.0-11,600.0 APERF;11,640.0-11,670.0 APERF;11,710.0-11,740.0 APERF;11,790.0-11,620.0 APERF;12,400.0-12,430.0 " '— APERF;12,470.0-12,500.0 APERF;12,470.0-12,500.0 4 APERF;12,530.0-12,560.0 APERF;12,590.0-12,620.0—J ^_ APERF;12,660.0-12,690.0 C APERF;12,730.0-12,760.0 APERF;12,800.0-12,830.0 APERF;12,870.0-12,900.0 APERF;12,940.0-12,970.0 APERF;13,010.0.13,040.0 r APER F;13,080.0-13,110.0 APERF;13,150.0-13,180.0 APERF;13220G-13,250.0 --.0 —_ WERE;13,290.0-13,320.0 _r IPERF;13,350.0-13,370.0 7 IPERF;13,370.0-13.410.0 IPERF;13,410.0-13,450.0 APERF;13,490.0-13,520.0 APERF;13.550,0-13,580.0 SH;13,600.0 FI FISH;14,068.0 DRILL PIPE/TOOLS;10,454.6- A—.6, 14.605.0-' RECEIVED ConocoPhillips JAN Z 4 2018 Alaska AOG CC P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 21,2018 Commissioner Hollis French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1C-26 (PTD# 199-051). In the course of setting a tubing patch under sundry approval#317-503, an additional leak at 4625' was discovered. This request is for approval to set a 2nd tubing patch above the packer to regain tubing integrity. If you need additional information,please contact myself or Jan Byrne at 659-7224. Regards, • Kelly Lyons Well Integrity Supervisor e • IP li � �oo n oo v -CU o 4.,C7NZ tlA a ra ? c6 fT 4 O 0 r r r r r r r r > F Y CO (0 aN+ O Ql �- ¢ ... a C C ++ O O co 4O+ C C 4 'O 0 J Ci d ao co w co Co c0 CO ▪ N E a 0- m V r Q 0 C C C C C cc E --' .z 73 0 N 1,00305mm ea '� F.. t0 N M M tO h 0 C ro U L Ql V1 Na4-'p� U -0 c0 O` C O U O C i O 0 ® 0 ® Cf CJ v▪ -0 N U W J J J J J J J J C s_ cu 0 >a. W W W W W W W W C V O N Ql L- 1.- LL LL LL LL LL LL LL LL ; ¢ J J J J J J J J - A > Ql '. Q Q Q Q Q Q Q Q Q al N C `C p Z Z Z Z Z Z Z Z U ra Ql O C LL LL LL LL LL LL LL LL Ql t cu t > C ' _ _ - co 4 > +O-+ N coCO C Ql E. r O .Q E z e-. 0 p C O OA U Ql _ 0 C 0,,, .� x. 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Z cr) E > V OD v fag r - e CI _ C 4I ; nom Ze r o o o rcr tOi c 4, ETo cu 4, v°i `'' z 'n m N J Q �i o® 6J +' a s 'Cc d s ^ �Wr. M W M M M r M E Z f6 v, N r-1 U 2. C C ® CO ti.., L •C a, n3 h- a a ...TZ OF 744, • • //jsv THE STATE Alaska Oil and Gas � ►:'si �, ofLAsKA Conservation Commission IL #z �= 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O ` p. Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jan Byrne Well Integrity Supervisor OO NOV 0 92017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 C-26 Permit to Drill Number: 199-051 Sundry Number: 317-503 Dear Ms. Byrne: 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 consideredtimely 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, 1635 Hollis S. French Chair DATED this Z.. day of November, 2017. RBoaMS i;OV - 2 2017 • • RECEIVED STATE OF ALASKA f(T 2 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGC+ 20 AAC 25.280 1.Type of Request: Abandon H Plug Perforations H Fracture Stimulate LJ Repair Well U ' Operations shutdown H Suspend ❑ Perforate H Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill H Perforate New Pool H Re-enter Susp Well ❑ Alter Casing ❑ 1'1/b Patch •Other: H Operator Name: 4.Current Well Class: 5.Permit to Doll Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 199-051 ' 3.Address: LI Service Q' 6.API Number: Stratigraphic P. 0. Box 100360,Anchorage,Alaska 99510 500292294400 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require a spacing exception? Yes 111No 0 KRU 1C-26 . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0028243 , Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 14,630' 6,622' , 10,141 7848' 10,141' Casing Length Size MD TVD Burst Collapse Structural Conductor 87' 16" 121' Surface 6,462' 12" 6,497' Intermediate Production 10,526' 10" 10,556' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11,380'-13,580' • 6556'-6594' 4.500" L-80 10,452' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SABL-3 PACKER W/SEAL ASSEMBLY MD=10100 TVD=6310 - 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑✓ 14.Estimated Date for 12/30/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ H WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ - GSTOR H SPLUG H Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jan Byrne Contact Name: Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: 1617@conocophillips.com Contact Phone: 907-659-7224 Authorized Signature: 7„` �� Date: 10/21/17 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes "o ❑ RBDk,6 S ( L' OVl - 2 CM261 furT Spacing Exception Required? Yes H No ' Subsequent Form Required: /4 "-- 4d 4- APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z �� 4 , ?ikis 10/0/7- 4 s/O (/T t/!F ,\ oiSubmit Form and \./li Form 10-403 Revised 4/2017 Approved application is valid fornnflAttachments in Duplicate • RECEIVED ConocoPhillips OCT 2 5 20w? Alaska AOGC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 21, 2017 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1C-26 (PTD# 199-051). The request is for approval to set a tubing patch to regain tubing integrity. If you need additional information,please contact myself or Kelly Lyons at 659-7224. Regards, Jan B me Well Integrity Supervisor • • 1C-26 DESCRIPTION SUMMARY OF PROPOSAL KRU WAG injection well 1C-26 (PTD# 199-051)was reported to the AOGCC on 9-15-17 for an unexplained increase in the IA pressure. Diagnostics culminated in an LDL locating a tubing leak at—7900'. CPA intends to set a retrievable patch over the leak location to repair tubing integrity. After the patch has been installed the well will be brought online and stabilized for a state witnessed MITIA. Repair Plan: 1. Set a 4.5", —25' retrievable patch over the leak at 7900'. 2. Perform a diagnostic MITIA post patch installation. 3. Bring well online and allow to stabilize. 4. Perform SW MITIA. :5. Submit 10-404. KUP INJ 1C-26 ConocoPhillips 0 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,,,roe�vellops 50029229440D KUPARUK RIVER UNIT INJ 94.92 12,567.36 14,630.0 --- Comment H25(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1C-26,10/22017 2:43:32 PM SSSV:NIPPLE Last WO: 40.01 8/23/1999 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;27.5 `®e,� Last Tag: 10,570.0 9/28/2007 Rev Reason:SET PXX PLUG,X PRONG& pproven 10/2/2017 TUBING LEAK FOUND...SEE NOTES -. Casing Strings fill Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 34.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) -ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1:'� f.1: ..SURFACE 9 5/8 8.835 34.5 6,496.6 4,460.8 40.00 L-80 BTC ,/�/`^ 1�P P Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread • CONDUCTOR,34.0-1210 PRODUCTION 7_ 6.276 30.6 10,556.3 6,457.6 26.00 L-80 BTC-MOD NIPPLE;4763 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread DRILL PIPE/TOOLS 4 2.313 10,454.6 14,605.0 6,619.2 14.00 L-80 HT-38 Tubing Strings GAS LIFT;517.7 * Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 27.5 10,457.2 6,433.6 12.60 L-80 ABT-MOD Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 27.5 27.5 0.05 HANGER FMC GEN IV 5M TUBING HANGER 4.500 476.3 476.3 2.45 NIPPLE HES X NIPPLE 3.813 SURFACE;34.5-0,496.6� 10,099.6 6,309.9 66.04 PACKER BAKER SABL-3 PACKER w/SEAL ASSEMBLY 3.958 10,141.4 6,326.6 66.65 NIPPLE HES X NIPPLE 3.813 TUBING LEAK;7,900n II 10,451.5 6,432.1 74.35 OVERSHOT OVERSHOT w/PACKOFF SWALLOWED 7.86'OF 4" 4.063 DRILL PIPE LEFT DOWNHOLE III GAS LIFT;10,052.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) i. Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,900.0 5,175.3 59.25 TUBING TUBING LEAK 9/25/2017 0.000 PACKER;10,099.6 LEAK NIPPLE;10,141.4 �� 10,141.0 6,326.5' 66.64 PLUG -3.81"PXX PLUG(DAL=28")&X PRONG(DAL= 9/22/2017 0.000 87") PLUG;10,141.0 13,600.0 6,592.7 92.41 PLUG Cement retainer above radioactive source w/90 bbls 10/29/1999 0.000 re-cement below laid in cement 13361'-13915';milled OVERSHOT;10,451.5 'F cement w/2.175"Bearclaw to 13600'10/29/99 I I I 14,068.0- 6,586.7 89.83 FISH BHA LOST 8/12/1999 8/12/1999 0.000 Perforations&Slots Shot PRODUCTION;30.6-10,556.3— Dens Top(TVD) etm(TVD) (shotsM Top(ftKB) Btm(965) 18KB) (ftKB) Zone Date t) Type Com APERF;11,360.0-11,400.0 11,380.0 11,400.0 6,555.7 6,556.5 C-4,1C-26 2/27/2000 6.0 APERF 2"HSD PJ;60deg.ph DP APERF;11,490.0-11,520.0 11,490.0 11,520.0 6,556.2 6,555.6 C-4,1C-26 7/3/2003 6.0 APERF 2"PJ 2006HMX;60deg ph APERF;11,570.0-11,600.0 11,570.0 11,600.0 6,556.4 6,557.9 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ;60deg.ph DP APERF;11,640.0-11,870.0 11,640.0 11,670.0 6,559.8 6,561.2 C-4,1C-26 1/14/2005 6.0 APERF 2"HSDPJ20chgs,60deg APERF;11,710.0-11,740.0 ph 11,710.0 11,740.0 6,562.4 6,562.0 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ2ochgs,60 APERF;11,790.0-11,820.0 deg ph 11,790.0 11,820.0 6,559.1 6,557.2 C-4,1C-26 7/2/2003 6.0 APERF 2"PJ 2006HMX;60deg APERF;12,400.0-12,430.0—_, ph 12,400.0 12,430.0 6,595.4 6,599.2 C-4,1G26 7/2/2003 6.0 APERF 2"PJ 2006HMX;60deg APERF;12.470.0-12,500.0 ph 12,470.0 12,500.0 6,603.1 6,604.2 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 APERF;12530.0-12,560.0 deg ph APERF;12,590.0-12,820.0 12,530.0 12,560.0 6,603.3 6,601.2 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 —.. deg ph APERF;12,880.0-12,890.0 - 12,590.0 12,620.0 6,598.7 6,596.4 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;12,730.0-12,760.0 12.660.0 12,690.0 6,593.9 6,592.6 C-4,1C-26 7/1/2003 6.0 APERF 2"PJ 2006HMX;6Odeg - ph APERF;12,800.0-12,830.0 12,730.0 12,760.0 6,592.5 6,593.6 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;12,870.0-12,900.0 —. 12,800.0 12,830.0 6,595.3 6,596.2 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;12,940.0-12,970.0 12,870.0' 12,900.0 6,596.3 6,596.2 C-4,1C-26 7/1/2003 6.0 APERF 2"PJ 2006HMX;60deg ph APERF;13,010.0-13,040.0 12,940.0 12,970.0 6,595.8 6,595.5 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;13,080.0-13,110.0 13,010.0 13,040.0 6,595.5 6,595.7 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;13,150.0-13,180.0 � 13,080.0 13,110.0 6,595.9 6,596.0 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 deg ph APERF;13,2200-13,250.0 13,150.0 13,180.0 6,596.1 6,596.1 C-4,1C-26 6/30/2003 6.0 APERF 2"PJ 2006HMX;60deg APERF;13,290.0-13,320.0— ph 13,220.0 13,250.0 6,596.5 6,596.5 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 IPERF;13,350.0-13,370.0 deg ph (PERF;13,370.0-13,410.0 13,290.0 13,320.0 6,595.9 6,594.8 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 IPERF;13,410.0-13,450.0 deg ph 13,350.0 13,370.0 6,593.3 6,592.4 C-4,1C-26 11/2/1999 6.0 IPERF 2"HSD PJ;60 deg.ph APERF;13,490.0-13,520.0 DP 13,370.0 13,410.0 6,592.4 6,5922 C-4,1C-26 11/1/1999 6.0 IPERF 2"HSD PJ;60 deg.ph APERF;13,550.0-13,580.0 E DP PLUG;13,600.0 1111413,410.0 13,450.0 6,592.2 6,593.2 C-4,1C-26 10/31/1999 6.0 IPERF 2"HOD PJ;60 deg.ph DP II FISH;14,068.0 2 13,490.0 13,520.0 6,594.4 6,594.8 C4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 g p 13,550.0 13,580.0 6,594.4 6,593.5 C-4,1C-26 1/14/2005 6.0 APERF 2"HSD PJ20 chgs,60 DRILL PIPE/TOOLS;10,454.6- deg ph 14.805.0 KUP INJ i 1C-26 Conoc hiAlaihps ka,Inc. gip: a cmo�oPrNeil „„t 12-26,10/2/2017 2:43:33 PM Vertical schematic(actual) .... ..... . .. HANGER;2727.6�- _ � r Notes:General&Safety End Date Annotation 10/24/1999 NOTE:200'CEMENT PLUG ABOVE BHA W/RADIOACTIVE SOURCE L 6/30/2003 NOTE:DRILL PIPE ID=2.438"TOOL JOINT @ 10489.79'-DRILL PIPE DRIFT ID=2.313"IN TOOL JOINTS .A.N/s w w w w w w-w w .r 1/14/2005 NOTE:ALL 1/14/2005 PERFORATIONS DONE WITH COILED TUBING CONDUCTOR;34.0-121.0 2/14/2011 NOTE:View Schematic w/Alaska Schematic9.0 NIPPLE;476.3 9/25/2017 NOTE:TUBING LEAK CONFIRMED BY LDL @7,900'RKB GAS LIFT;517.7 II E SURFACE;34.5-8,496.6—A i TUBING LEAK;7,900.0 GAS LIFT;10,052.6- bi PACKER;10,099.6 "o'4 NIPPLE;10,141.4 `t" PLUG;10,141.0 OVERSHOT;10,451.5 I T I PRODUCTION;30.6-10,558.3—A APERF;11,380.0-11,400.0 APERF;11,490.0-11,520.0 APERF;11,570.0-11,600.0 APERF;11,640.0-11,670.0 APERF;11,710.0-11,740.0 APERF;11,790.0-11,820.0 APERF;12,400.0-12,430.0 APERF;12,470.0-12,500.0 APERF;12,530.0-12,560.0 e APERF;12,590.0-12,620.0 APERF;12,660.0-12,690.0 APERF;12,730.0-12,760.0 APERF;12,800.0-12,830.0 APERF;12,870.0-12,900.0 APERF;12,940.0-12,970.0 APERF;13,010.0-13,040.0 APERF;13,080.0-13,110.0 le— APERF;13,150.0-13,180.0 le— APERF;13,220.0-13,250.0 APERF;13,290.0-13,320.0 (PERF;13,350.0-13,370.0 (PERF;13,370.0-13,410.0 (PERF;13.410.0-13,450.0 APERF;13,490.0-13,520.0 APERF;13,550.0-13,580.0 PLUG;13,600.0 ;IPII_ 111 FISH;14,068.0 I, DRILL PIPE/TOOLS;10,454.6- ,' Cak. 14,605.0 f • • a t O I- > ° L Y yJ ON z CIO Y (D f0 ',: CD w- 1:54.% a CD f✓) -'7m o u ° > QTY C ._ O) O a 4 a u - t o Q g- .,.., I. 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F- • ' = z v) 2 r > > X m O O Q N N E co d C �•1 d Q Q N N N N N CO N N v, Z N co L C ''' CD v, .c ea v1 c R CO .� d ( 0 CPS n~ Q F- 0- a Q • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Friday, September 15, 2017 4:53 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1C-26 (PTD# 199-051) Report of suspect IA pressure increase Attachments: 1C-26.pdf; 1C-26 90 day TIO trend 9-15-17.PNG Chris, KRU WAG injector 1C-26(PTD#199-051)was reported today for an unexplained IA pressure increase following WAG to MI yesterday 9-14-17. The IA pressure increase was initially thought to be thermally related, but after it had been bleed multiple times and re-pressurized it was deemed suspect. The well has been shut in and freeze protected. The plan is to have DHD perform initial diagnostics to include an MIT-IA, pack off tests,and draw down test on the IA. Dependent upon diagnostic results the well may be brought online for a 30 day monitor period on gas and/or water injection. Any required paperwork for corrective action or continued injection will be submitted after the monitor period or once an alternate plan has been determined. Attached is a wellbore schematic and 90 day TIO trend. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM peps SCANNED S E P 1 9 201-: • 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by: Bevedy Mildred Daretha~i~owell Date: ~/7 Isl ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Mildred Daretha Nathan Lowell Date: Is~ • • IPPei • • ConocoPhillips Alaska ;� P.O. BOX 100360 r l � ANCHORAGE, ALASKA 99510 -0360 MAT 2Oa March 9, 2012 �,, a Alaska Oil & Gas Cons. Commission . iA Anchorage Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 F C'9 — OS/ Anchorage, AK 99501 ^ acp Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerel , MJ veland ConocoPhillips Well Integrity Projects Supervisor • • • Conoco fillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 3-09 -2012 1B, 1C, 1 D, 1E PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement , pumped cement date inhibitor sealant date ft bbls ft gal 18-02 50029205310000 1801330 SF NA 16" NA 2.98 1/21/2012 18-06 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW -04 50029208330000 1821590 6'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW-06 50029208510000 1821770 20" NA 20" NA 2.13 1/21/2012 1C -11 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 1C -18 50029229390000 1990050 SF NA 18" NA 2.55 2/10/2012 1C-26 50029229440000 1990510 SF NA 18" NA 3.75 2/10/2012 1D -128 50029229000000 1981330 2" NA 26" NA 3.83 2/10/2012 MEMORANDUM • TO: Jim Regg ~~~ ?(~ i~`G P.I. Supervisor FROM: John Crisp Petroleum Inspector ~te of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-26 KUPARIJK RIV UNIT 1 C-26 Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 1C-26 API Well Number: 50-029-22944-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524062756 ~ Permit Number: 199-051-0 Inspection Date: 5/21/2010 Rel Insp Num: MITOP000003067 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1C 26 /~ ~ w r ~ 6433 ~ 860 ~ Well ~ YPe Inj~VD ~ IAy- ~ P.T.D 1990510 IITypeTest I SPT TCSt pSl 1608 OA i 300 J ~ -~- 2730 2700 i 2700 ~ ~___ ~ 350 340 ~ 340 __ ~- Interval Four Year Cycle ~ per, Pass ~Tubing~2162 2163 ~-2162 2162 Notes: 1.7 bbls pumped for test. No problems witnessed. ~.,, Monday, June 28, 2010 Page 1 of 1 N0.4947 r~..~ tt ; Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # p ,~ t Log Description ~. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C iC-26 iC-119 3H-15 iC-121 3H-18 iJ-159 1 F-10 1C-121 12066554 11978487 11978488 12080445 11978490 12080446 12097431 12080453 11978490 MEM PRODUCTION PROFILE (U - '~' SBHP SURVEY .-b ( INJECTION PROFILE ~ INJECTION PROFILE - '3 C,/ INJECTION PROFILE - INJECTION PROFILE ~ - p PRODUCTION PROFILE ~ Y INJECTION PROFILE ~- INJECTION PROFILE I - 10/14/08 10/15/08 10/16/08 10/16/08 10/17/08 10/17/08 10/13/08 10/27/08 10/17/08 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~i ~~~~~~~~~~~ ' I ~~ 1 N0. 4505' ` ' i ..~--° Schlumberger -DCS ~ ~""`-~'~~-~~~~~~~~~ 2525 Gambell Street, Suite 400 ~ c 7 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ i NdV ~+ '~ ~~ Attn: Chr~stme Mahnken ATTN: Beth '" 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 11 /16/07 3J-16 11850468 INJECTION PROFILE I 11/02107 1 1J-122 11745241 MEM PROD PROFILE - ~-(~ 11/03/07 1 1C-26 11745244 MEM INJECTION PROFILE U 1 11/09107 1 2Z-07 11850476 PRODUCTION PROFILE 11111107 1 1Y-01 11839683 INJECTION PROFILE 11/15/07 1 1Y-24AL1 11837535 LDL p 11/15/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • .~ . . Conoc;p"illips Afaska RECEIVED AUG 2 9 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 23, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 0 6 2007 \ G.¡O(rft\ Dear Mr. Maunder: . Enclosed please find a spreadsheet with a list of wells ftom the Kuparuk field (KRU). Eac!1 of these wells was tôund to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water ftom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The corrosion inhibitor/sealant was pumped between August 19 & 21,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. ~~~~/ M.J. ¿el~d ConocoPhillips Wen Integrity Projects Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/21/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date 0" ft bbls ft !:Ial 1 0-28 204-237 18" N/A N/A N/A 10 8/19/2007 1 0-30 200-104 24" N/A N/A N/A 6.5 8/19/2007 1 0-34 200-143 14" N/A N/A N/A 4 8/19/2007 10-12 199-084 1" N/A N/A N/A 1.7 8/20/2007 10-14 199-089 2" N/A N/A N/A 3.4 8/20/2007 10-140 200-136 29'9" 3.4 12" 12/16/2006 14.5 8/20/2007 10-141 200-112 SF N/A N/A N/A 0.5 8/20/2007 . 1C-11 199-172 - SF NA NA NA 0.5 8/21/2007 1C-12 196-177 SF NA NA NA 0.5 8/21/2007 1C-15 198-229 SF NA NA NA 0.5 8/21/2007 1C-16 198-246 22" NA NA NA 8 8/21/2007 1C-17 198-224 17" NA NA NA 1.7 8/21/2007 1C-18 199-005 SF NA NA NA 0.5 8/21/2007 1 C-24 201-248 20" NA NA NA 11 8/21/2007 1~26 199-051 3" NA NA NA 0.85 8/21/2007 1 C-27 199-043 4" NA NA NA 1.7 8/21/2007 1 C-28 205-104 SF NA NA NA 0.5 8/21/2007 1C-117 201-121 26" NA NA NA 12.3 8/21/2007 MEMORANDUM e State of Alaska e ~ Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,..,-; , I<;eft¡ 5/ \'lfOG :. \.. DA TE: Tuesday, May 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lC-26 KUPARUK RIV UNIT 1C-26 ,.Ð,6~:;r¡ikr ~~gf FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed Br.; P.I. Suprv.·¡S¡Z- Comm Well Name: KUPARUK RIV UNIT lC-26 API Well Number 50-029 -22944-00-00 Inspector Name: Jeff Jones Insp Num: miùJ060508175943 Permit Number: 199-051-0 Inspection Date: 5/8/2006 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 1C-26 IType Inj. i W j TVD i , 6433 j IA ~ 400 2900 2890 2890 P.T. i 1990510 ,TypeTest i SPT I Test psi I -- 1608.25 i OA 350 375 ì 350 350 I Interval 4YRTST P/F P Tubing i 2138 2136 i 2136 2135 Notes 1 well house inspected; no exceptions noted. NON-CONFIDENTIAL o' "}.o ~, "í""Í!i' -..c ~^-loJ\íEn OJ!)... i~ ! 'i ()Jv) 'tiP 1\!'" ~ "1. ip';';;;;,." <-"-" Tuesday, May 09, 2006 Page 1 of I 'ROOUCTlON (0-10556, 00:7.000, Wt:26.00) Perf :11380-11400) Perf :11490-11520) DRILL PIPE :10457-14131, 00:4.000, Wt:14.00) Perf :11570-11600) Perf :11640-11670) Perf :11710-11740) Perf :11790-11820) Perf : 12400-12430) Perf :12470-12500) Perf :12530-12560) Perf :12590-12620) Perf :12660-12690) Perf :12730-12760) Perf :12800-12830) Perf :12870-12900) Perf :12940-12970) Perf :13010-13040) Perf :13080-13110) Perf :13150-13180) Perf : 13220-13250) Perf :13290-13320) Perf :13350-13370) Perf :13370-13410) Perf :13410-13450) Perf :13490-13520) Perf :13550-13580) PLUG :13600-14020, 00:4.000) e ConocoPhillips Alaska, Inc. 1 C-26 Reference Lo : Last Ta : 10412 SLM Last Ta Date: 12/27/2004 Casin Strin - ALL Oeser; tion CONDUCTOR SURFACE PRODUCTION DRILL PIPE Tubin Strin - ALL Size To 4.500 0 Perforations Summar Interval TVD 11380 - 11400 6556 - 6556 11490 - 11520 6556 - 6556 11570 - 11600 6556 - 6558 11640 -11670 6560 - 6561 11710 - 11740 6562 - 6562 11790 - 11820 6559 - 6557 12400 - 12430 6595 - 6599 12470 - 12500 6603 - 6604 12530 - 12560 6603 - 6601 12590 - 12620 6599 - 6596 12660 - 12690 6594 - 6593 12730 - 12760 6593 - 6594 12800 - 12830 6595 - 6596 12870 - 12900 6596 - 6596 12940 - 12970 6596 - 6596 13010 - 13040 6596 - 6596 13080 - 13110 6596 - 6596 13150 - 13180 6596 - 6596 13220 - 13250 6596 - 6596 13290 - 13320 6596 - 6595 13350 - 13370 6593 - 6592 13370 - 13410 6592 - 6592 13410 -13450 6592 - 6593 13490 - 13520 6594 - 6595 13550 - 13580 6594 - 6593 Gas Lift Mandrels/Valves St MD TVD Man Mfr Man Type Ori Size 16.000 9.625 7.000 4.000 Zone C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 C-4 Status V Mfr Ft 20 30 30 30 30 30 30 30 30 30 , 30 30 30 30 30 30 30 30 30 30 20 40 40 30 30 e Bottom 121 6496 10556 14131 SPF 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 6 Date 2/27/2000 7/3/2003 1/14/2005 1/14/2005 1/14/2005 7/2/2003 7/2/2003 1/14/2005 1/14/2005 1/14/2005 7/1/2003 1/14/2005 1/14/2005 7/1/2003 1/14/2005 1/14/2005 1/14/2005 6/30/2003 1/14/2005 1/14/2005 11/2/1999 11/1/1999 10/31/1999 1/14/2005 1/14/2005 KRU 1 C-26 TVD 121 4461 6457 6588 11290 Wt 62.58 40.00 26.00 14.00 Grade H-40 L-80 L-80 L-80 Thread WELDED BTC-MOD BTC-MOD HT-38 Thread ABT-MOD T e APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF APERF IPERF IPERF IPERF APERF APERF V Type V 00 Lateh Port TRO Date Vlv Run Cmnt 8/30/1999 8/29/1999 DMY 1.0 INT 0.000 0 DMY 1.0 INT 0.000 0 Deseri tion 10 HES X NIPPLE 3.813 HES X NIPPLE 3.813 4.063 Cement retainer above radioactive source w/90 bbls re-cement below laid in cement 0.000 13361'-13915" milled cement w/2.175" Bearclawto 13600' 10/29/99 Fish - FISH De th 14068 BHA Safet Notes Date Note 10/24/1999 200' CEMENT PLUG ABOVE BHA W/ RADIOACTIVE SOURCE 6/30/2003 DRILL PIPE ID;: 2.438" IN TOOL JOINT @ 10489.79' DRIFT 10 OF DRILL PIPE;: 2.313" IN TOOL JOINTS 1/14/2005 ALL 1/14/2005 PERFORATIONS DONE WITH COILED TUBING Comment ) ') Mike Mooney Wells Group Team Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 February 1, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 EI ED 0 8 Z005 Commission Subject: Report of Sundry Well Operations for 1C-26 (APD # 199-051) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 C-26. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 44~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad '~~'=\f\', Ff'"B' ¿l"" 1 2DD5 r""C411i,ÍI\'~~I';ooo2,.} r:.. - ~ ~ l'""'tn~. ,,(';;;;;. OR\G\NAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well D Pull Tubing D Operat. ShutdownD ) Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 95' 8. Property Designation: ADL 28243, ALK 3814 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION DRILL PIPE Perforation depth: measured 14630' 6622' ') true vertical measured 1 0412' 0 S 200S Plug Perforations D Perforate New Pool D Perforate 0 4. Current Well Status: Development D Stratigraphic D Stimulate D &I, I. 0. ,ttI~f;'; CommissiûR M~aSh~1 th0 Waiver D Time Extensio~~,nWnage Re-enter Suspended Well D 5. Permit to Drill Number: j 99~O51 6. API Number: 50-029-22944-00 true vertical Length Size Exploratory D Service 0 9. Well Name and Number: 1 C-26 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool feet feet Plugs (measured) Junk (measured) 13600' 121' 6401' 1 0461' 3674' 16" 9-5/8" 7" 4" feet feet MD TVD Burst Collapse 121' 6496' 10556' 14131' 121' 4461' 6457' 6588' Measured depth: 11380'-11400'. 11490'-11520', 11570'-11600', 11640'-11670', 11710'-11740', 11790'-11820', 12400'-12430', 12470'-12500', 12530'-12560', 12590'-12620' Packers & SSSV (type & measured depth) no packer HES X Nipple 477' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Mike Mooney @ 263-4574 Mike Mooney )W~~ Form 10-404 Revised 04/2004 12660'-12690',12730'-12760', 12800'-12830', 12870'-12900', 12940'-12970', 13010'-13040', 13080'-13110', 13150'-13180', 13220'-13250', 13290'-13320', 13350'-13450', 13490'-13520', 13550'-13580' true vertical depth: 6556'-6556',6556'-6556',6556'-6558', 6560'-6561', 6562'-6562', 6559'-6557', 6595'-6599', 6603'-6604', 6603'-6601', 6599'-6596', 6594'-6593',6593'-6594',6595'-6596',6596'-6596', 6596'-6596', 6596'-6596', 6596'-6596', 659S~1-\~6f9~5'J?5~'~QС'94'-6595" 6594'-6593' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10457' MD. SCANNED FEB 1 1. ZUUJ 13. Treatment descriptions including volumes used and final pressure: N/A Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 2800 4900 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: oilD GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature CasinQ Pressure TubinQ Pressure WDSPL D Title Phone Wells Group Team Leader 907-263-4574 Date Prepared bv Sharon Allsup-Drake 263-4612 t<tsUMS tSFt FEB 0 8 2005 Submit Original Only ORIGINAL ') 1 C-26 Well Events Summary ) Date Summary 12/31/04 RAN PDS MEMORY TOOL IN 4" LINER LOGGING FROM 10,000' CTD -13,375' CTD (HARD TAG). FLAGGED PIPE TO PREP FOR PERFORATING. [Perf] 01/01/05 PERFORATED 30' WITHIN THE 4" PIPE FROM 13,290' -13,320' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. WILL CONTINUE IN AM. [Perf] 01/02/05 PERFORATED 13,220' -13,250' MD & 13,080' -13,110' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. CHANGED OUT THE WEATHERFORD MHA FOR NEXT SET OF PERFS. WILL CONTINUE IN THE AM. [Perf] 01/03/05 PERFORATED 13,010' -13,040' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. DRIFTED WITH A 2.7" NZL TO 1ST TOOL JOINT @ 10,484' MD WITH MINIMUM 10 = 2.43" TO COORELA TE DEPTH. [Perf] 01/04/05 PERFORATED 12,940' -12,970' & 12,800' - 12,830' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. [Perf] 01/05/05 PERFORATED 12,730' - 12,760' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. DRIFTED WITH A 2.7" NZL TO 1ST TOOL JOINT @ 10,484' MD WITH MINIMUM 10 = 2.43" TO COORELATE DEPTH. [Perf] 01/06/05 PERFORATED 12,530' -12,560' & 12,590' -12,620' MD WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. [Perf] 01/08/05 PERFORATED 12,470' -12,500' WITH 2" HSD GUNS, 6 SPF, 60 DEG PHASING. DRIFTED WITH A 2.7" NZL TO 1ST TOOL JOINT @ 10,484' MD WITH MINIMUM 10 = 2.43" TO COORELATE DEPTH. [Perf] 01/13/05 PERFORATED FROM 11,710'-11,740'/11,640'-11,670' CTMD.. ALL SHOTS FIRED. WILL PERFORATE FINAL DEPTHS IN THE AM. WELL CURRENTLY SHUT IN FOR CONTINUATION OF PERFORATING PROCEEDURES. NO SIGNIFICANT CHANGE IN PRESSURES WHILE PERFORATING. 01/14/05 PERFORATED FROM 11,570'-11,600' CTMD. WITH 2" HSD GUNS 6 SPF @ 60 DEG PHASE, 20 GRAM POWERJET CHARGES. ConocOPhillips Mike Mooney Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 August 11,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1C-26 (APD # 199-051) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforating operations on the Kuparuk well 1C-26. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M. Mooney Wells.Group Team Leader CPAI Drilling and Wells MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon [] Suspend F'-] Operation Shutdown ~] Perforate ~-~ Variance F-~ Annular Disp. r'-] Alter Casing r---1 Repair Well [] Plug Perforations [~ Stimulate [~] Time Extension E~ Other [~ Change Approved Program ~ Pull Tubing [] Perforate New Pool [~ Re-enter Suspended Well r-1 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r-'l Exploratory [] 199-051 / 3. Address: Stratigraphic [~ Service [-~ 6. APl Number: P. O. Box 100360, Anchora~le, Alaska 99510 50-029-22944-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 C-26 8. Property Designation: 10. Field/Pool(s): ADL 28243, ALK 3814 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 14630' feet true vertical 6622' feet Plugs (measured) 11500', 13600' Effective Depth measured 13600' feet Junk (measured) true vertical 6593' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURFACE 6401' 9-5/8" 6496' 4461' PRODUCTION 10461' 7" 10556' 6457' DRILL PIPE 3674' 4" 14131' 6588' Perforation depth: Measured depth: 11380'-114oo', 11490'-1152o',11790'-1182o', 124oo'-1243o', 12660'-12690', 12870'-12900', 13150'-13180', 13350'-13450' true vertical depth: 6556'-6556', 6556'-6556', 6559'-6557', 6595'-6599', 6594'-6593',6593,'6596,,III, ' ','659,6'6596,. ' ...' .6593',6593' Tubing (size, grade, and measured depth) 4-1/2", L-80, 10457' MD. ~,~!..!t~ ¢7 ~. ':"~i~ .'i'.,~~ ~:~:! el :~" . Packers & SSSV (type & measured depth) no packer .l[i",l~i: !';: ~I I'!'? . , :: SSSV= NIP HES X nipple @ 477' ,, 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casin,q Pressure Tubin,q Pressure Prior to well operation N/A N/A 10007 - 2240 Subsequent to operation N/A N/A 6209 1150 2308 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run __ Exploratory r-] Development E~] Service [~ Daily Report of Well Operations __X 16. Well Status after proposed work: o r-I Gasl-I WAGI I S NJr--I W NJ I--I WDSPLI--I -- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Mike Mooney @ 263-4574 Printed Name Mike/Mooney Title Wells Group Team Leader Signaturel///j/~ /'r///~¢~/~ Phone Date ~ Prepared by Sharon AIIsup;Dr~ke ,265-4612 Form 10-404 Revised 2/2003 · ORIGINAL SUBMIT IN DUPLICATE ConocoPhillips Alaska, Inc. (0-10457, 0D:4.500, ID:3.958) ~ODUCTION (0-10556, OD:7.000, Wt26.00) Perf (11380-11400) Pe# (11490-11520) PLUG (11500-11501, 0D:4.000) (11790-11820) Per[ (124O0-12430) Per[ (12660-12690) Per[ (12870-12900) Per[ (13150-13180) Per[ (1335O-1337O) Per[ (13370-13410) Per[ ¢3410-13450) PLL, G (13600-1z,:)2,? OD:4.::,CC, i KRU 1C-26 ~ 1C-26 APl:1500292294400 SSSV Typo1 Nipple Annular Fluid:I Reference Log:I Last Tag:I Last Tag Date:I Well Type:I INJ Orig 18/23/1999 Completion:I Last W/O: I Ref Log Date:I TD:114630 ftKB Max Hole Angle:195 deg ~ 12567 Angle @ TS: 185 deg @ 11290 Angle @ TD:I85 deg @ 14630 I Rev Reason: ADD PERFS Last Update: 7~5~2003 Casin9 Strin9 - ALL Description CONDUCTOR Size Top 16.000 Bottom 0 121 SURFACE 9.625 0 6496 PRODUCTION 7.000 0 10556 DRILL PIPE 4.000 10457 14131 Tubing String - ALL Size I Top I Bottom TVD 4.500 0 10457 6433 Perorations Interval TVD 11380-11400 6556-6556 :11490-11520 6556-6556 11790-11820 6559-6557 12400-12430 6595-6599 12660-12690 6594-6593 12870-12900 6596-6596 13150-13180 6596-6596 13350-13370 6593-6592 13370-13410 6592-6592 13410-13450 6592-6593 TVD Wt Grade 121 I 62.58 I H-40 4461 14o.ool L-8o 6457 26.oo I L-80 6588 14.00 L-80 Thread WELDED BTC-MOD BTC-MOD HT-38 Wt Grade 12.60 L-80 Thread ABT-MOD Comment 2" PJ 2006HMX; 60 deg. ph 2" PJ 2006HMX; 60 deg. ph 2" PJ 2006 HMX; 60 deg. ph 2" PJ 2006 HMX: 3h 2" PJ 2006 HMX; 60 deg. ph 2" PJ 2006 HMX; 60 deg. ph 2" HSD P J; 60 deg, ph DP 2" HSD P J; 60 deg. ph DP 2" HSD P J; 60 deg. ph DP IstI MD I TVD I Man I Man I V Mfr I v Type I v OD I Latchl Port I TRO I Date I V,v I I" I Mfr tType~~- I [111 , I Run ICmnt~,ao 1 519 o19 CAMCO B~2L~M..,~ CAMCO DMY 1.0 INT 0.u00 0 ,~.'30'1~ 2 1100521 62901CAMOO~;BG2LSMOq CAMCOI DMY I 1.0 IINT 10.900 I 0 18.'29,1999l Other (plugs, equip, etc.I - JEWELRY Depth lTVD I Type ~ Description ID 477 1477 I NIP IHESXNIPPLE 3.813 10141 I 6326 I NIP IRES X NIPPLE 3,813 10457 16433 IOVERSHOTI 4.063 11500 I 6556 I PLUG ~BAKER IBP set 4/1/2003 0.000 13600 6593 PLUG ]Cement retainer above radioactive source wi90 bbls re-cement below laid 0.000 ~ in cement 13361'-13915'; milled cement wi2.175" Bearclaw to 13600' I 110/29/99 Fish;FISH .... :::: :::: :: : :::~::: :: :: :::::: :: Depth Description 14068 BHA Comment Date / Note I 0/24/199~ 200' CEMENT PLUG ABOVE BHA W/RADIOACTIVE SOURCE 5/30/20031 DRILL PIPE ID = 2.438" IN TOOL JOINTS ! DRIFT ID OF DRILL PIPE = 2.313" IN TOOL JOINTS Date Comment 1C-26 Event History 06/28~03 O6/3O/03 07/01/03 07/02~03 07/03/03 PULL IBP AT 11,480' CTMD. RIH WITH BAKER SURE CATCH OVERSHOT AND LATCH FISHING NECK OF IBP. RUN HYDRAULIC CENTRILIZER NEAR BO'I-I'OM OF BHA WITH MULE SHOE OVERSHOT TO ENTER DRILL PIPE LINER. [FISH] RUN CT MEMORY LOG FROM 13,250' - 11,750' CTMD. TIE LOG INTO RST/TEMP LOG AND PERFORATE FROM 13,150'- 13,180' MD. PERFORATE USING 2" HSD PJ 2006 HMX, 6 SPF, 60 DEG PHASING. [PERF] PERFORATED FROM 12,870-12,900', 12,660-12,690' CORRECTED MEASURED DEPTH, USING 2" 6 SPF- 60 DEG PHASING-PJ2006-HMX 6.5GM .23" ENT HOLE-19" PENETRATION. DUE TO MAST CABLE ISSUES UNABLE TO PERFORM THIRD RUN. WILL CONTINUE IN THE AM. [PERF] PERFORATED 12,400-12,430', 11,790-11,820' CORRECTED CTMD. PERFORMED A SECOND TIE IN LOG PRIOR TO START OF PERFORATION OPERATIONS. TOTAL THREE RUNS. ALL SHOTS FIRED. WILL SHOOT LAST SET OF PERFORATIONS IN THE AM. [PERF] PERFORATED 11,490-11,520' CORRECTED CTMD. USED 30' OF 2" 6 SPF-60 DEG- P J2006 HMX- 6.5GM - .23" ENT HOLE- 19" PENETRATION. ALL SHOTS FIRED, TURNED WELL OVER TO DSO FOR INJECTION. [PERF] Page 1 of I 7/10/2003 MEMORANDUM TO: Randy Ruedrich ~(~_'! ~ Chair THRU: Jim Regg P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 18, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 1C 190, 09, 14, 17,26 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,I lC-190 I Type,nj.I S I T.V.D. 13833 I Tubing 11000 11000 11000 11000 I'nterva'I I P.T.D.I 2030030 I Typetestl P I Testpsil 958 I Casingl 3000 I 3000 I 3000 I 3000 I P/FI Notes: WellI lC-09 I Typelnj.IS I ~.v.~. I~o~ I Tubing I ~o I ~ I~° I~I lnterval'l 4 P.T.D.I 1821850ITypetestl P ITestpsil 1551 I Casingl 400 I 3100 I 3125 I 3100I P/FI ,p.,P Notes: We,,I ~C-~4 IType,.j.I G I T.V.D. 1~259 I Tubingl 3~06 I~ I~ I~ I,nterw, I 4 P.T.D.I 1980170ITypetestl P ITestpsil 1565 I Casingl 50 I 3000 I 3000 I 3000 I P/F I -P-P Notes: We,,I~c-~I Typelnj.I s I T.v.D. 1~45 I Tubingl ~0 I ~0 I~ 12~ I lntervall 4 P.T.D.I 1982240ITypetestl P ITestpsil 1536 I Casingl 1000I 3100I 3100I 3050 I P/F I -P Notes: we,,I ~c-2~ IType,nj.I s I ~.V.D. 1~4~I~.~,.,I~ I~ I~ I~ I,.~e~v~,l 4 P.T.D.I 1990510 ITypetestl P ITestpsil 1608 I Casingl 900 I 3000 I 3000 I 3000 I P/FI P Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: Attachments: Number of Failures: Total Time during tests: cc: MIT report form ~/t ?/00 L.G. 2003-0618_M IT_KRU_ 1C-26.js.x Is 7/9/2003 Kuparuk and Alpine Annular Disposal during the third quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-32 12701 100 0 12801 379 18636 31816 June 2o02 July 2002 CD2-19, CD2-23, CD2-41 CD2-50 31530 100 0 31630 370 0 32000 July 2002 Sept 2002 CD2-41, CD2-19, CD2-16, CD2-38 1C-18 27969 100 0 28069 379 4276 32724 June 2002 July 2002 1C-104 CD2-39 1966 100 0 2066 379 27500 29945 Oct. 2001 Sept 2002 CD2-15, CD2-47, CD2-44 CD2-15 10459 100 0 10559 371 20722 31652 March Sept 2002 CD2-50, CD2-25, CD2-44 2002 CD2-26 13802 100 0 13902 380 0 14282 Sept 2002 Sept 2002 CD2-38, CD2-44, CD2-29 Cook Inlet Annular Disposal durin the third q'uarter of 2002: h(1) h(2) h(3) ' Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes Hansen #1 52255 100 0 52355 0 14869 67224 January Sept 2002 Hansen #1 2002 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2002: ~ Freeze Pi~otect Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-24 33524 100 0 375 33999 Open, Freeze Protected July 2001 Oct 2001 CD2-33, CD2-39, CD2- 14, CD2-15 1C-26 34160 100 0 0 34260 Open, Freeze Protected August September 1C-123, lC-119, 1C-102 2001 2001 2N-332 31453 100 0 325 31878 Open, Freeze Protected August 2001 Sept 2001 2N-348, 2N-350 1C-16 32017 100 0 0 32117 Open, Freeze Protected Sept 2001 Oct 2001 1C-102, 1C-131, 1C-125 P, ECEIVED OCT 2 4 2002 Alaska Oil& G~s ~ns. ~mmission Anchorage Annular Dis ~osal durin the third '~2001: ,/"~f~f~l,~l,L~f ~I~I~FU~I~I~ L~L~I ~f~ ~f~G ~f~I L~, Lr/.,f,L/,I /,Gl U,J ~,L/L/.,[ o h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July 20Ol 1C-127, lC-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May 2001 July 2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 ( 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 7 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2001: ' ' Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000t,~, Freeze protect 2N-332 only 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 20~g 2N-349, 2N-305 ~ 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2~1~ 1D-30, 1D-40, 1D-141,~ ._~.~0 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 1D-36, 1D-34 2N-318 ' 17498 100 0 17598 Open, Freeze Protected Dec 2000 Julll~01 2N-314, 2N-302 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Ad~2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. Th~olumes for the expired permit applies just to that permit. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 95 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__X Kuparuk Unit 4. Location of well at surface 8. Well number 1699' FNL, 3938' FEL, Sec. 12, T11 N, R10E, UM (asp's 562348, 5968538) 1 C-26 At top of productive interval 9. Permit number / approval number 2422' FNL, 119' FWL, Sec. 17, T11 N, R11 E, UM 199-051 / At effective depth 10. APl number 50-029-22944 At total depth 11. Field / Pool 2517' FN L, 4578' FEL, Sec. 17, T11 N, R11 E, UM (asp's 571979, 5962525) Kuparuk Oil Pool 12. Present well condition summary true vertical 6622 feet 200' CMNT Plug above BHA w/RA source Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu Yrds High Early 121' 121' SURFACE 6401' 9-5/8" 750 sx AS m & 705 sx C~ass G 6496' 4461' PRODUCTION 10461' 7" 18o sx C~ass G 10556' 6458' DRILL PI PE 3674' 3-1/2" (included above) 14131' 6588' DRILL PIPE '::::: ::::: ::: ':::: :.:.:::::::: ::::: ::: ::::: :':: :::: :: :::::::::: :::::::: :::::: :::::::':::::: :-:::':::::: :::::':: :::::::::::::::::::::::::::::::::::::::::: - ..:! :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ........................... :::.:::. ............................................ . .................................................................................................. :::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 13. Stimulation or cement squeeze summary · ' ': ': ': ..... ": ': ':' :': '::'::': ============================================================================ ............. -- Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure ., .... , ..... ,,-,-,,- ............................... , . , . . , ,, .- 15. Attachments Copies of Logs and Surveys run __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed Title Production Engineering Supervisor Date "~/~ ' ~'/ ~~.- Jeff A. Spencer Prepared by Robert C~tensen 659-7535 Form 10-404 Rev 06/15/88 ORIGINAL,,o,s JAN 9 '~,,3ns ~ SUBMIT IN DUPLICATE Date Event Summary 12/14/011Commenced WAG EOR Injection -. . ' . . "' ' :~ - .::-.::~i ~ '. '.-.'-'-i ~:-i.- ~i" - 'i'- i 199-051-0 KUPARUK RIV UNIT 1 C-26 50- 029-22944-00 PHILL1PS ALASKA INC Roll #1: Start: Stop Roll #2: Start Stop MD 14630- TVD 06622 ~Completion Date: /~2~/99 Completed Status: 1WINJ Current: T Name C 9654~ C 9657 D 9063 Interval 1 SCHLUM PDC/GR/CCL CH 1 SCHLUM RST CH 5-8 SPERRY MPT/GR/EWR4/CNP/SLD OH L DGR/EWR4-MD .5..~_r. FINAL 6507-14630 L DGR/EWR4-TVD :.~.-" FINAL 4466-6621 L DGR/SLD-MD /J FINAL 6507-14630 L DGR/SLD-TVD ~.-'- FINAL 4466-6621 OH 2/5 OH 2/5 OH 2/5 OH 2/5 L PDC/GR/CCL RST~' . L SCMT R SRVY RPT ~"~- FINAL 13600-10300 FINAL 11300-13530 FINAL BL(C) 9426-10380 8~0/99 SPERRY 0-14630 CH 5 CH 5 CH 5 OH Sent Received T/C/I) 6/27/00 5/12/00 5/19/00 11/16/99 11/18/99 11/23/99 11/22/99 11/23/99 11/22/99 11/23/99 11/22/99 11/23/99 11/22/99 6/13/00 6/27/00 C 5/12/00 5/19/00 9/17/99 9/22/99 8/26/99 8/31/99 Wednesday, June 20, 2001 Page 1 of 1 STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMI~S'ION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate_ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Disposal 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 95 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface f ~,/' ,,/' 8. Well number 1699' FNL, 3938' FEL, Sec. 12, T11 N, R10E, UM (asp's 562548, 5968538) 1 C-26 At top of productive interval 9. Permit number/.approval number 199-051 At effective depth 10. APl number 50-029-22944 At total depth 11. Field / Pool 2517' FNL, 4578' FEL, Sec. 17, T11 N, R11 E, UM (asp's 571979, 5962525) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 14630 feetJ' Plugs (measured) cement plug @ 13600' MD true vertical 6622 feet*/ Effective depth: measured 13600 feet Junk (measured) true vertical 6593 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 9 cu yds High Early 1 1 5' 1 15' SURFACE 6401' 9-5/8" 70 sx AS Hk 705 sx Cbss G 6496' 4461' PRODUCTION 10461' 7" 180 sx C~ass G 10556' 6458' DRILL PIPE 3674' 4" 14131' 6588' DRILL PIPE RECEIVED Perforation depth: measured 11380- 11400', 13350- 13450' true vertical 6556'-6556', 6593'-6593'JUL J ,9 2001 Alaska Oil & Gas Cons. Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 10457' MD. Anchorage Commission Packers & SSSV (type & measured depth) No packer HES X @ 477' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: August 1,2001 16. If proposal was verbally approved Oil__ Gas __ Suspended __ 17.1 hereby certi~ th~,e.~../.... ,oregoi~q. is,~e and .o~'rrect ,o the best of my k~owledge. Questions, Call Mark Chambers 265-1319 ~/.~.' "~..~ ~,,,,-~z~.-~----~t7 Title: Interim Drilling Engineering Supervisor Date~ ~./' -;. Signed Td/~;OZc~:a; '--' ~ ProparodbySharonAllsup. Drake263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__:~~I~L SIGNEDSUbsequent f°rm required 10(31'~~ ~%(:~\AY % "'~~~)~/ .... A__pproved_by order of the Commission _.J. lj~ ~1~:~ ................. Commissioner Date · . . Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE Annulus Disposal Transmittal Fb- m a. Designation of the well or wells to receive drilling wastes; lC-26 b. The depth to the base of freshwater aquifers and permafrost, if present; No Aquifers; Bpf=1759' tvd - RKB c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission From the 9-5/8" shoe to the Cement top all that finding that the waste will be confined and will not come to the is open is shale or minor Campanian Sands surface or contaminate freshwater; that were not hydrocarbon bearing. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste; See Attached Map indicating no wells within 1/4 miles or water wells within I mile e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry; Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls, and the estimated density of the waste slurry ranges from 9.2 to 9.5 ppg. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. Maximum anticipated pressure at casing shoe during disposal operations is 1848 psi. See attached calculation page g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. attached cementing reports, LOT/FIT reports, and casing reports h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. attached: casing summary sheet and calculation pages. i. Any additional data required by the Commission to confirm containment of drilling wastes. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY lC-26 TUBING (0-10457, OD:4.500, ID:3,958) ;.__.,.;RU 1C-26 APl: 500292294400 Well Type: ;INJ ! Angle @ TS: 85 deg @ 11290 SSSV Type:, Nipple Orig Completion:: 8/23/99 Angle @ TD: 185 deg @ 14630 Annular Fluid: Last W/O:' I Rev Reason: Set cement retainer & mill by ImO Reference Log: Ref Log Date: Last Update: 5/9/01 Last Tag: TD: 14630 ftKB Last Taq Date: i Max Hole Angle:~= 95 deg (~ 12567 Casing String - ALL . SURFACE (0-6496, OD:9.625, Wt:40.00) PRODUCTION (0-10556, OD:7.000, Wt:26.00) !Description Size Top Bottom TVD Wt Grade Thread SURFACE 9.625 0 6496 4461 40.00 L-80 BTC-MOD PRODUCTION 7.000 0 10556 6457 26.00 L-80 ~ BTC-MOD CONDUCTOR , 16.000 I 0 121 121 62.58 H-40 . WELDED DRILL PIPE 4.000 I 10457 14131 6588 14.00 L-80 · HT-38 Tubing String - ALL ' . . . Size Top ] Bottom TVD Wt GradeI Thread 4.500 0 I 10457 6433 12.60 L-80I ABT-MOD Perforations Summary · Interval TvD ; Zone ' Status Ft SPF;, Date Type ~ Comment 11380 - 11400 i 6556 -6556 c-4 20 6 2/27/00 APERF 2" HSD Powerjets; 60 deg. r J ; i phased 13350- 13370 r 6593--6592 : C--4 20 6 i 11/2/99 IPERF 12" HSD Powerjets; 60 deg. , :phased DP 13370 - 13410 r 6592 ' 6592 C--4 i 40 6 ~, 11/1/99 IPERF 12" HSD Powerjets; 60 deg. i ~ phased DP 13410 - 13450 6592 - 6593 C-.4 i 40 6 : 10/31/99 IPERF 2" HSD Powerjets; 60 deg.~ ' i :phased DP Gas Lift Mandrels/Valves St r MD TVD Man Man V Mfr V Type V OD ! Latch ~; Port TRO i Date i Vlv r Mfr Type i ' Run ~Cmn' 1 - 519 519 CAMCO ~BG2LSMOE CAMCO DMY 1.0 ! INT ; 0.000 0 , 8/30/99 2 10052 6290 CAMCO ;BG2LSMOE CAMCO DMY 1.0 i INT ' 0.000 0 i 8/29/99 Other (plugs, equip., etc Depth TVD Type 477 477 NIP 10141 6326 NIP 10457 6433 OVERSHOT 13600 6593 PLUG - JEWELRY Description ID 3.813 HES X NIPPLE HES X NIPPLE 3.813 4.063 Cement retainer above radioactive source w/90 bbls re-cement below laid in 0.000 cement 13361'-13915'; milled cement w/2.175" Bearclaw to 13600' 10/29/99 'Fish - FISH ' , Depth Descri )tion Comment 14068 BHA Safety Notes Date ~Note 10/24/99 200' CEMENT PLUG ABOVE BHA WI RADIOACTIVE SOURCE Peri (11380-11400) Ped 13350-13370) Peff 13370-13410) Perf 1341O-13450) PLUG 1360O-14020, OD:4.000) DRILL PIPE 10457-14131, OD:4.000, Wt:14.00) , ................. Phillips Alaska Plol Reference ~s PMSS <0-t4630'>. Coord;notes ore ~n (eel reference slo[ ~T ...... fl~' Dep ........t ...... fl~8 (Pool ~ ~m Well 2 6 m'r~ ~ Field · Kup~ruk River Unif Loc~fion · Norfh Slope .......................... : .~ ............................. East (feet) -> _~0 960 1200 1440 1680 1920 2160 2400 2640 2880 3120 3560 3600 3840 4080 4520 4560 4800 5040 i i i i i i i i i i i i i i f I i i i i i i f i i i i i i i i i i i f i 4461 240 480 72O 960 1200 1440 1680 1920 2i60 2400 2640 2880 3120 3360 -3600 3840 4080 4320 4560 4800 Phillips Alaska, Inc. Pad lC 26 slot #26 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : PMSS <0-14630'> Our ref : svy5993 License : Date printed : il-Jul-2001 Date created : 6-Ju1-1999 Last revised : 24-Aug-1999 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.433,w149 29 40.041 Slot Grid coordinates are N 5968537.231, E 562346.302 Slot local coordinates are 1702.00 S 1339.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 2000 feet ARCO Alaska, Inc. Cementing Details Well Name: lC-26 Report Date: 07/08/99 Report Number: 1 Rig Name: Pool 6 AFC No.: AK0025 Field: Kuparuk Casing Size Hole Diameter. I Angle thru KRU: Shoe Depth: LC Depth: % washout: 9.625" 12.25"I N/A 6496 6420 Centralizers State tyPe used, intervals covered and spacing Comments: I Bowspring in the center of joints I & 2, over the collars of joints 3-14 & joint 169. I solid Rotco centralizers in the middle of Iolnts 144 & 145. Mud Weight: PV(pdor cond): PV(after cond): YP(pdor cond): YP(after cond): Comments: 10.2 32 17 31 16 Gels before: Gels after:. Total Volume Circulated: 12/31 8/23 1140 bbls Wash 0 Type: Volume: Weight: Comments: ARCO 20 8.4 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 50 10.5 Lead Cement 0 ~Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: ASIII 70 750 10.5 4.43 Additives: Class 'G' w/50% D124, 9% D44, 0.4% D46, 30% D53, 1.5% S1, 1.5% D79 Tall Cement 0 Type: I Mix wtr temp: I No. of Sacks: · Weight: Yield: Comments: GI 70I 705 15.8 1.17 Additives: Class 'G' w/1% Sl, 0.2% D46, 0.3% D65 Displacement 0 Rate(before tail at shoe): IRate(tail around shoe): Str. Wt. Up: Comments: 8 BPM 8 BPM Reciprocation length: . Reciprocation speed: Str. Wt. Down: 0' 160k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 488 bbls 490 Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:07/08/99 No Yes 'Rme:01:48 Remarks:Casing went In the hole wltrh no problems. Had good returns thru entire job. Contaminated mud @ surface w/240 bbls into displacement. Good cement returns to surface with 368 bbls Into diplacement. Dumped 118 bbls cement @ 10.7+. Could not recip casing when on bottom. Hanging up shallow, possibly on the conductor shoe. Cement Company: Rig Contractor: Approved By: DS POOL Fred Herbert ARCO Alaska, Inc. Casing Detail 9. 625" Surface Casing WELL: 1C-26 DATE: 07/04/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Pool 6 RT to LR = 34.00' 9.625" Landing joint 34.00 FMC GEN V- Kuparuk 9.625" Csg Hgr 1.99 34.00 jts 145-170 9.625", 40#, L-80 BTC (25 jts) 989.00 35.99 TAM 9 5/8" Port Collar 2.93 1024.99 j'ts. 3-144 9.625", 40#, L-80 BTC (141 jts~) 5392.29 1027.92 Gemeco Float Collar 1.45 6420.21 its 1-2 9.625", 40#, L-80 BTC (2 jts~) 73.18 6421.66 Gemeco Float Shoe 1.75 6494.84 Casing shoe @ 6496.59 T.D. @ 6507' leaving 10.41' of rathole 15 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2 over stop collars and over casing collars on Jts. 3-14 and over collar of it. 169 Run 1 ROTCO Rigid Straight Blade Centralizer in middle of joints 144 and 145 w/stop rings Remarks: String Weights with Blocks: ???k Up, 160k Dn, 70k Blocks. Ran 170 oints of casing. Drifted casing with 8.679" plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Pool 6 Drilling Supervisor: Fred Herbert ARCO ALASKA INC CASING TALLY PAGE: 1 of 2 WELL: 1C-26 Kuparuk Unit RIG: Pool 6 TUBING DESCRIPTION: 9-5/8", 40#, L-80, BTC, R3, Class A DATE: 07/04/99 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 COlumn 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 !i.i.!i!!i.~i~ii??i 26 35,15 51 38,91 76 38,11 101 37;23 126 36.40 151 38.46 176 2 ~!iii!~!ii~i~iiiiiiii 27 38.97 52 38.56 77 39.20 102 37.10 127 39.05 152 39.13 177 3 ?~'ili'i~i~!~iiii!~ 28 37.78 53 38.31 78 39.13 103 34,75 128 35.28 153 38.74 178 4 i!i.i!i.i~i~.!.ii!::!i~!::i 29 39,15 54 36.78 79 38.02 104 35,49 129 37.26 154 39.27 179 5 i:i!i!iiiiii~!ii~?i!i 30 39.22 55 37.65 80 38.80 105 39,11 130 38.87 155 39.14 180 6 i:.i.i.i,~!~ii.ii!ii!iii1 31 36.69 58 37.11 81 39.13 108 36,74 ~81 34,21 ~58 36,~ 181 7 ~~ 32 37.12 57 38.06 82 38.42 107 37,97 ~82 35,24 ~57 39,23 g ~.~.~,~.~,~.?~ 34 38,42 59 39.34 84 38.94 109 38,64 ~84! 38.48 ~5~ 39.01 ~84 ~0 ~~??~ 85 38.36 ~0 39.04 85 38,50 1~0 38,35 ~85 39.07 ~0~ 33.86 ~85 ~ :~~ 3~ 39.28 ~ 38,05 8~ 39,23 ~ 39,11 ~8~ 36,90 ~ 38.91 ~8~ .'.'.'.'.'.'.'.L'.:7.:.~7.'.~.'.L'~ 12~.~.~.~.~::~:: 37 36,18 ~2 39.24 87 39,32 ~12 38,58 ~87 35.50 ~2 37,98 ~87 18,~,~,~?~ 88 36.50 ~8 37,53 88 39,79 ~8 37.88 ~88 34,52 ~8 38.74 ~88 .-....................................... ~g 37.37 44 38.50 ~e 36,82 84 38,08 ~g 38,10 ~44~~g 37.50 ~.................................. 2~ 39.05 4~ 37,30 7~ 39.12 g~ 39.35 ~2~ 39.06 ~4~ 37.94 ~7~ ~ ~g~ 22 39,23 47 36,75 72 38.~ 97 39.90 ~22 36.61 ~47 38,14 ~72 34.05 ~97 23 36.35 48 37.87 78 37.85 98 38.77 1~8 36.09 ~48 37.72 ~73~~.~,~ ~ ~ ~8 24 35.07 49 37.94 74 39,11 99 37.50 124 39,25 149 38.~ 174 38.56 199 ~S' ~.27 50 -39.13- 7~ ~-8T25 10-0 34~4 ~ ~5~0 ~9~6~---~ 200 Tot 942.75 Tot 949.93 Tot 955.27 Tot 966.96 Tot 943.40 Tot 937.05 Tot 946.03 Tot TOTAL LENGTH THIS PAGE = 6641.39 TOTAL JOINTS THIS PAGE = 175 DIRECTIONS: CASING TEST and FORMATION INTEGRITY TEST Well Name: 1 C-26 Reason(s) for test: Date: 07/09/1999 Supervisor: Scott Reynolds [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8"; 40# L-80 BTC Casing Setting Depth: 6,497' TMD 4,465' TVD Hole Depth: 6,528' TMD 4,476' TVD Mud Weight: 8.5 ppg Length of Open Hole Section: 31' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 1,300 psi + 8.5 ppg 0.052 x 4,476' EMW for open hole section = 14.1 ppg Pump output = 0.0846 bps Fluid Pumped = 5.1 bbl 3.200 psi 3.100 psi 3.000 psi 2,900 psi 2.800 psi 2,700 psi 2,600 psi 2,500 psi 2.400 psi 2.300 psi 2.200 psi 2.100 psi 2.000 psi 1.900 psi 1.800 psi 1,700 psi 1.600 psi 1,500 psi 1.400 psi 1,300 psi 1,200 psi 1.100 psi 1.000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 3OO 0 psi i ~ ~ , ] i ~ ~ i i i , i J i , i , i , i i i , i i i , , i J ~ i il, i , , = LEAK-OFF TEST --.~--CASING TEST ,~-.,~i! ..... LOT SHUT IN TIME ---~,~ CASING TEST SHUT IN TIME ~ TIME LINE STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE =' ................................................ i ~' ................................................ 5' 0 stks 0 psi : : 0 stks 0 psi ............... ~- .............. ,J- ................ ~ l ................ r ................................. : 4stks : 240 ps!.: : : 4stks 350 psi ............... +, .............. +, ................ . -,~ t .~a~, ........... ,~ ............... ~ ................ . -i : 8stks : 360 psi,: ~ ~ 8stks ~ 600pm ...... ............. i ............. : ............... 4 .............. ¢ ......... P- .... 4.~-~ ............ i ............... ~----' ...... -P--L--4 j ) 24stks j 840 psi :'~, : 24stks : 1,520psI, ,- .............. ~ .............. --r ............... "~..' :- ............... ~- ............... ). .............. : : 28stks : 940 psi , ~ , 28stks : 1,800ps, m ............... ..r- .............. .~- ............... m ~ .............. ~. ............... ~. ................ j j 32 stks j 1,020 psi~i5 ) 32 stks ) 2,000 psi ': --- :' .............. 36 stks :' .............. 1,080 psl?~~: ............... Ir ............... 36 stks t: .............. 2,200 psi;'1 .................. ............................................... 40 stks 2,450 psi ............... ~ ............... ~- ............... -~,~l't ............. F ............... r ................. ~ 44 stks ~ 1,180 psi 3 ~" : 44 stks : 2,700 psi .... , ........... ,.L .............. .,'___,_ ...... R .... i>~ ............. L ................................ ................... 9P_ _~_t_ _k_~_ .... J_ '. _39P_ R.S_[ _i ................................................. I ............................... T ................ ; ................................................. 4 .............................. .' ................ J ................................................... ! ! ! ! ................. ~. .............. ~ ................ i ! ! ! ! ! ! ! i ............... -4 .............................................. · ................................................... , ! I I SHUT IN TIME i SHUT IN PRESSURE =r' SHUT IN TIME 0.0 min ! 3,050 psi i .... j.._g___m_Ln' .................. [__3_.,.o._2__o__p__s..): .................. ............... __4_._9___m_!_n___L ............... k I SHUTIN PRESSURE 1.0 min [ 1,100 psi 5.0 min j 3,020 psi ............... · -r- .............. .~- ................ -~ ! ................ r ............... t- ................ ,___.a:p...m.i..n_ ................ i_l,_9__o_o__p.s_[ ...... 9-.9._.m. Ln. .................. 3.0min ! 990 psi , , 7.0min , [ 3,010 psi ," i ............... ..1_ .............. i"[- ................ '~ ............................................... 4.0 min ~_ 950 psi 8.0 min i 3,010 psi ............... ............... ~ ............................................... i ................................ r ................ 6.0 min i 920 psi 10.0 min j 3,010~si l ............... .~- .............. --r. ................ m P ............... r ............... ~- ............... ,._Z:_O___m_[.n_ ................. i__~_o__o___p._s.L ...... j__5_._9___m_Ln._L ............... [__a_,.o_!9__.p_sj.j ,____8_._o___m_i..n_ ............. ,_i__p_o__o_.p.?.i._] L_2__o_._g_._m_Ln__L ............... L]_,.o.g.§_._p~i_j ! . ! ! · !, . i i . m i 9.0mln ] _L 890 psi j ! 25.0mln L [ 3,005 psij i ............... · ............... / ................ / , ................ i ............... · ................ ! · m i · ! , ' I I · L]__O_._O__.m_l.n__z ........... ,_ ,_, __§~_O___p._s.m___.: L~_O_.__O___m_ m_n__t ............... L ~_,.0_ _O.f__ _p_s_ m _ j NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY / CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-26 DateI,: 7/12/99 [] Initial Casing Sh~)e Test Reason(s) for test: [] Formation AdeqUacy for Annular Injection [] Deep Test: Ope~ Hole Adequacy for Higher Mud Weight / Casing Size and Description: 9-5/8"; 40# L-8OBTC Casing Setting Depth: 6,497' TMD Hole Depth: 10,063' TMD 4,465' TVD 6,298' TVD Mud Weight: 9.1 ppg Length of Open Hole Section: 3,566' Supervisor: Reynolds/Cunningham EMW = Leak-off Press. + Mud Weight = 800 psi + 9.1 ppg 0.052 x TVD 0.052 x 6,298' EMW for open hole section = 11.5 ppg Pump output = 0.0846 bps Fluid Pumped = 5.6 bbl TME:E'Ni I E 900psi III III II',',',',',;',:l ',',', 800 psi oop.. ~ , ~ ~oopsl ~ ~ ~ 400 psi ~ ~CASING TEST ' IJ~ ~ ..... ~=,~;~' LOT SHUT IN TIME 3OO psi -~ CASING TEST SHUT IN TIME 2oo ps~ ~ .... J --- TIME LINE 100 psi ~ 0 psi STROKES NOTE: STROKES TURN TO MINUTES DURING" HUT IN TIME":see time line above LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE , ................................................................................... ............................................................ 0 stks 0 psi ................. ~____O___s_t__k_s_ ................ __O__p__s_! .['" .................. _4_._s__t_k__s_ ...... .s_.o__.p__s! .................................... 8 stks 100 psi i ............... .w- .............. .N- ................ , 12 stks 190 psi ................ L ................ ............................... ,d- ................ 4, [- ............... .................. .l_.6___s_t__k__s_ .... _2__s_.o___p__s_L_, 325 Psi .................. _ _2_O___s_t__k_?_ .... _______,._=_ .................... , ................ ~- 24 stks -~ 390 psi , !.~.~ ............... ~ -'~'~';i~'- ~ '--~'/;~'i---', i ................ L__~:~-'~ ................ ............... T-:¥ff~;i~;'-T--'~-F;-f'-! i ............... T--~i:i-iiiii~--T--~§ii-ii~-f--i i ................ r-'~7; ....... :: ............... ~i ............... 44 stks +i ................ 670 psi l ............... T-'~'~';ii~-'T-'~iiJ'/;~i-"l i ......... '~of~]~ ......... ~-~? ....... i ............... i'-~'~-;~-'T--'~-~;;'i"-i i ................ , ................. .... ' ........................ , 58 stks 700 psi , 59 stks 670 psi l .................. _6__o___s_t__k..s_ .... .6_.s_.o__p.__s!_.. i 61 stks 650 psi ......... ~_~.3_._s_t__k..s. .... ~_4__0___p__s!.., 64 stks 640 psi ' 65 stks 640 psi 66 stks 640 psi SHUT IN TIME~ SHUT IN PRESSURE . _S?__U_T__I.N_ !I.M._E_ l ............. .S..H..U.T.I..N. _P.R. _E_S_ .S.U..R,, E 0.0 min : 0 psi j 1.0 min ! 2.0 min , .... _3_._°___m_Ln___, .................................. 4.0 min J _.]:_O___m__i_n__. 590 psi ! 5.0 min 3.0min i 520 psi ! i 7.0min 4.0 min ! . 510 psi j 8.0 min L ............... ~ ............... -I- ................ 1 ................................................ ._. _5:.0_ ___m_i_n_._ j ............... i.__s. J__O_.p_.s.i___ j 9.0 min 6.0 min : 505 psi i "':l-~)-'r~i~'-[ ............... : .................. ..................................... . ............ . ............... 7.0min i 500 psi i 15.0min~. , , ............... ..i ........... ,---.d- ................ d, i ................ , 80min : , 500 psi i i 20.0min --L.~'-' ......... J ............... -J- ................ .."~ ................ k--= ............ i. ................ .,.t __..9:.o....m_i_n___j ............... 1 __ _s_ _o_ _o_p__s_i_ _ _ j ._.2__5_._9_..m_ Ln_., ................ 10.0mini : 500 psi i 30.0min: ; ............... .. ............... ~ ................. ; ................ .. ............... ~ ................. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY uo~ss4.wu~oo 'suoo se9 ~ I!0 CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-26 Reason(s) for test: Date: 07/18/1999 Supervisor: R.W. SPRINGER [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7", 26.0 PPF L-80 BTC MOD Casing Setting Depth: 10,556' TMD 6,458' TVD Hole Depth: 10,590' TMD 6,466' TVD Mud Weight: 10.6 ppg Length of Open Hole Section: 34' EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 640 psi + 10.6 ppg 0.052 x 6,466' EMW for open hole section = 12.5 ppg Pump output = 0.0846 bps Fluid Pumped = 1.5 bbl 3,600 psi 2,865 psi 2,130 psi 1,395 psi 660 psi -75 psi ..-e.- LEAK-OFFTEST I~--CASING TEST .... ~ii~-- LOT SHUT IN TIME --.,~ CASING TEST SHUT IN TIME t ~TIME LINE ! STROKES LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE ................... _0___s__t_k__s_ ....... _0__ _p__s_[ .... i ..................... .0_._s_t.k_.s_ ........ __0__p_s_! ..... ................... .5___s__t_k__s_ ....... Z_5___p__s!___i .................... _5___s_t_k_.s_ ...... _ _7. _5.0_ _ _p_ .s_ b .................. .~__0___s_t__k__s_ .... .2_7__s___p__s_L_! ................... _t_0__s__tk_.s_ .... _!,.o__5..O_.e.s_L .................. .~_.5__.s_t__k__s_ .... _5_.2_.5__e__s.L_j ................... !_5__s__tk__s_ .... .l__,.s__5_.o_.e.s_L .................. . l_ .8_ _ .s_ t_ _k_ _s_ .... _6__4_.o__.p__sj__j ................... _2__0__s__t.k__s_ .... _l_,.9_.o_.o_.p.s__i_j ................................................ i ................... _2__5__s__tk__s_ .... .2__,.2__5..0_.p_.s_!_.~ ' . 30 stks r 2,600 p ! ..................... ................................................. ............... ~ .............. ~ ................ '~ ~- ............... t- ............... ~- ................ ................................................ j ................... _4__o__s__t~_s_ .... _3_ ,_2__7_ _5__p__s__L ~ ! : : ............ 45 stks , 3,500 psi ................................................ ,- .............................................. 4 .................................................. 4 I , ............................... ,4- ................ '~! ! ................................ t ................ , I I I SHUT IN TIME; SHUT IN PRESSURE 0.0mm . = 640~s~ , 1.0 min i 590 psi ! , ................ L ............... L ................ ,.~ I ! ................................ I ................ ! ................ ~. ............................... ~- ; ' ! I SHUT IN TIME SHUT IN PRESSURE ................................................. 0.0 min 3,500 psi i 1.Omin ~ .3,500 psi 1 ~ .__a_.__o___m_!_n___! ................. 4.0 rain ~ 3,500 p~i 2.0 min ' i 590 psi i 6.0 min i 3,500 psi ............... -~- .............. ~ ................ 4 I ................ ~- ............... ~- ................ 4 3.0min i i 590 psi i [ 7.0min [ ~ 3,500.E_.si ............ :---t .............. t ............. .---~, ............... , .............................. 4.0m~n i i 590ps~ ~ 8.0min , 3,500~si ............... 1- .............. 1-'-~-. ........... 1 ................. · ' ' 0 si' ' ............... t ............... ___5_._0__m__~_n.__~ .............. ~____5__9____.p_ ..... ~ 9.0 min , 3,500 psi .............. ,__Z..o___m__~_n___ ,.L .............. i___s_~_o__e_.s!_.j ,.J_ .s_..9_ ._m_Ln_.[ ................. ~,.5..o_.o..e~!_~ ,__._8:.o__.m__~_.i .............. i.__s.~_o__p__s!__j L.2_.o_...o_..m.!.n__L ............... [_].,.s..o._o.p_.s.]_j 9.0 min i i 590 psi i 25.0 min i i 3,500 Psi ............ · '-I ............... T ............. -'--I ................ r ............... ~ ................ .___~_o__._9__m__'_n__'_ .............. :___s_~_o__e__s_,___.: ._.3_.o_..9_..m_Ln__! ............... L~,5._o__o__.e.s_L NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Maximum Pressure @ The Shoe 1c-26 Surface Casing: Size Weight Grade Shoe Depth Burst (100%) Burst (85%) Assumptions: 9-5/8 40# L-80 6,497' MD / 4,461' TVD 5,750 psi 4,887 psi Water on Backside of 9-5/8" (Worst Case) 1,500 psi Maximum Injection Surface Pressure Maximum Mud Weight Required to Drill 1C-Pad West Sak Wells = 9.8 ppg Maximum Fluid Density to Burst 9-5/8" Casing: 4,887 psi + 8.3 ppg (.052) (4,461') = 1,500 psi + MW (.052) (4,461') MW = 22.90 ppg Maximum Pressure on 9-5/8" Shoe: Max Pressure - 1,500 psi + 9.8 ppg (.052) (4,461') - 8.3 ppg (.052) (4,461 ') Max Pressure = 1,500 psi + 2,273 - 1,925 Max Pressure = 1,848 psi Maximum Fluid Density to Collapse 7" Casin.q 1C-26 Casinq: Size Weight Grade Shoe Depth Collapse (100%) Collapse (85%) Assumptions: 11 26# L-80 10,554' MD / 6,458' TVD 5,410 psi 4,598 psi 9-5/8" Casing Shoe @ 4,461' TVD Inside 7" Casing - Diesel from 2,400' TVD to Surface (6.7 ppg) Inside 7" Casing - Seawater from 4,461' TVD to 2,400' TVD (8.4 ppg) Maximum Fluid Density to Collapse 7" Casing: 4,598 psi + 6.7 ppg (.052) (2,400') + 8.4 ppg (.052) (4,461'- 2,400') = 1500 + MW (.052) (4,461) MW = 20.84 ppg CASING TEST and FORMATION IN'[ Well Name: 1C-26 Date Reason(s) for test: [] Initial Casing Sh [] Formation Ade¢ [] Deep Test: Op6 Casing Size and Description: 9-5/8"; 40# L-81~ Casing Setting DePth: EGRITY TEST 7/12/99 Supervisor: Reyn°lds/Cunningham )e Test Jacy for Annular Injection Hole Adequacy for Higher Mud Weight BTC 6,497' TMD 4,465' TVD MUd Weight: 9.1 ppg EMW = Leak-off Press. + Mud Weight 0.052 x TVD Hole Depth: Length of Open Hole Section: 10,063' TMD 6,298' TVD 3,566' Pump output: 0.0846 bps EMW for open ' LM Fluid Pumped = 800 psi 0.052 x 6,298' hole section = 11.5 ppg + 9.1 ppg = 5.6 bbl 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi I STROKES STROKES TURN TO MINUTES DURING "sHUT IN TIME":see time line above NOTE: LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT STROKES PRESSURE CSG TEST STROKES PRESSURE 0 stks 0 psi 0 stks 0 psi ~_ 16 stks 250 ~.si , .................. ._2_O.__s_t_.k._s. .... ~.2..s...p..s.L.. .................. ._2.4___s. Lk__s. ..... ~?..R.s.L_ ................... ._2~__s_t__k__s. .... _4_~.0__p.. _s.i_._. ............. ~ .... .3_.2_ ..s.t__k_ _s_ .... _5..2..5..p...s.i__, ............................................~ 36 StkS .~= 5'70 ESi ,~ .................. .4_.O.__s_t__k__s_ ..... .S._3._O__R _s.L_. ........... : ..... ..4.4._.s.t..k..s. .... .E7__o__.p..sL. ................. .4_.8. __s_t__k__s_ .... _7_~.O.__p_.s!.' 52 stks 770 psi ............................... .i., ................ .~ .................. .S..4...s_t_.k..s_ .... .8..o..o..R.s_L' .................. ..S.?..s.t..k..s. ..... ~.o..o..R.s_i__' ................. _S. Ls.t..k..s. .... Z_°..°..R.s.L.. .................. .S_~_.s_t_.k..s_ ..... .s_Z_O___p..s.L._' ................. .Eo...s.t..k..s_ .... ~_s._°__R.s.L.. 61 stks 650 Psi i ! ............................... ,.~ ................. ................. _e_~__s_t__k..s_ .... .e_.4__O__ _p. _s_i___. SHUT IN TIME SHUT IN PRESSURE 65 stks 640 psi 1.0 min ............... ~ .............. ~ ............................................ ! i ................ 66 stks 640 psi 2.0 min i ............... i i ~- ............... ._~_.__uz.,.,..T,.,__~,~ ............. .s_,_ _u?.. ,. _,.~_ _~ .U.R E .... .3_...O_..m. Ln___, ............... r ................. .___O:_O___m__i..n_ .................... _ _6_4__O__.p__s_i ....... .4_...O...m.i.n__: ............... [ ................. .__l_:_0...m._i..n__. 590 IE. si 5.0 min ' 2.0 min ..................-~,~-I~'i--- i--~)'-r~i~--'i ............... ........................................................... '; .... I' ............... t ............... 3.0 min 520 psi 7.0 m~n , ' 40min ! J 510psi 8.0min L .... JJ .......... ' .............. -I- ......... ~' ..................................................... 5.0min : 510 si 9.0min : ~ _..6._..o_..m..Ln.__i .................. .s..o._s__p...sL_ '--~-~:6--~i~--:, ................ 7.0 min i 500 psi "--1-[.'6--~i~"[ ............... .............................. -r ................ ~ ................................ t ................ 80min : , 500 psi 20.0min' : __-_L'-' ......... -,.. .............. ..~ ......... ~- ...... .~ ~- ............... "- ............... ~' ................. i 90min i = 500Rsi 25.0min ' .... ~'~ ......... 4 ............... -!- ................ , · , -~.~,,,.-,~'-~-~-';~T~'-" ............... ! ................ L ..~.g:.o...m.J..n. ~_ .............. _,, ...s..o..o___R.s:___. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY UO!S~U~LUO3 'SUO3 Se9 ~ I!0 e~se~V LO0~ 9 g -1hi" -. .r STATE OF ALASKA -_/-~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other__ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1699' FNL, 3938' FEL, Sec. 12, T11 N, R10E, UM At top of productive interval 1393' FNL, 2667' FEL, Sec. 18, T11 N, R11 E, UM At effective depth At total depth 2517' FNL, 4578' FEL, Sec. 17, T11 N, R11 E, UM 5. Type of Well: Development __ Exploratow__ Stratigraphic__ Service__X (asp's 562348, 5968538) (as/o's 568596, 5963623) (asp's 571979, 5962525) 6. Datum elevation (DF or KB feet) RKB 95 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-26i 9. Permit number / approval number 199-051 10. APl number 50-029-22944 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 14630 feet 6622 feet Effective depth: measured 13600 feet true vertical 6593 feet Plugs (measured) Casing Length CONDUCTOR 115' SURFACE 6401' PRODUCTION 10461' DRILL PIPE 3674' Junk (measured) Size Cemented 16" 9 cu yds High Early 9-5/8" 750 SxAS III, 705 Sx G 7" 180 Sx Class G Cement Plug @ 13600' MD Measured Depth 115' 6497' 10556' 14131' True vertical Depth 115' 4461' 6458' 6588' Perforation depth: measured 11380 - 11400'; 13350 - 13450' true vertical 6556 - 6556'; 6593 - 6593' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 10457' MD. Packers & SSSV (type & measured depth) No Packer. HES X @ 477' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure RECEIVED FEB 3 2001 Alaska 0il & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl - 1400 2750 Casing Pressure Tubing Pressure 2250 22OO 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service ~(Water Inj).__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Date ~/7/~ ? Prepared by John Pekoe 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1C-26i PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/27/00: MIRU & PT equipment. RIH w/E-Coil perforating guns & shot 20' of perforations as follows: Added perforations: 11380 - 11400' M D Used 2" HSD carriers & shot the perfs at 6 spf at 60 degree phasing. POOH w/guns. RD. Returned the well to water injection & obtained valid injection rates. 6/13/00 ~-0. oq Q 0o-o. Schlumberger NO. 238 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 1 C-26 99450 MEM GR/CCL 991030 I I 1 1D-125 I~J(' 20248 SCMT 000529 1 1 D-137 -- 20249 SCMT 000604 1 1D-138 20250 SCMT 000604 I RECl VED Alaska 0il & Gas Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address or fax t° (907) 561-8317. jl~l~l~Su. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1C-26, AK-MM-90131 November 23, 1999 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, .41( 99518 1C-26: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22944-00 2"x 5" TVD_Resistivity & Gamma Ray_Logs: 50'--029-22944-00 2" x 5" MD..L',J_eutron & DensityLogs: 50-029-22944-00 2"x 5" TVD2~/et~tr. on~ Density.Logs: 50,029-22944-00 0il & Gas Cons. Commimion 1 Blueline 1 Folded Sepia ..1231ueline 1 Folded Sepia .1 Blueline 1 Folded Sepia 1BluelJne 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907o273-3535 A Halliburton Company D IR I LLI !~1 !~ c:; lie R ~/I r" l!Ei ~=; To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 16, 1999 RE: MWDFormation Evaluation l.og.q 1C-_26, .AK-MM,90131 1 LDWG fo~tmatteADisc with verificationlisti_ng. APl#: 50-029-22944-00 PLEASE ACKNOWLEDGE RECEIPt BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTERTO_ IB:E.A.TTENIIO~ OF:. Sperry-Sun. Drilling.Service Attn: Jim Galvin 5631 Silver, ado WaT,_Suite O. Date: - o ....... ~.0~illt~t,2 aSigned.k-~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company ARCO Alaska, Inc. - r Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 10, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1 C-26 (Permit No. 99-51) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on 1C-26. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Drilling Engineering Supervisor AAI Drilling GCA/skad ?. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil BI Gas BI Suspended D Abandoned D Service [] Injector 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-51 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22944 4. Location of well at surface ~' .,'.~, ';~ , ....... _.."~ ~ 9. Unit or Lease Name 1702' FNL, 1339' FWL, Sec. 12, T11N, R10E, UM ; '~.~,-, '!'i',(~..! ""~" ,~,,~,~,,,~]~ Kuparuk River Unit At Top Producing Interval .~'~/~_'~, i! I~t 10. Well Number 2422' FNL, 119' FWL, Sec. 17, T11 N, Rl1 E, UM ...',.'~h~; '~ 10-26 At Total Depth _ _. r 11. Field and Pool 2522' FNL, 701' FWL, Sec. 17, T11 N, R11 E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool Rig RKB 34' feetI ADL 28243 ALK 3814 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions July 1, 1999 July 27, 1999 August22, 1999I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set !21. Thickness of Permafrost 14630' MD/6622' TVD 14068' MD/6587' TVD YES [] No DI N/A feetMD 1853' 22. Type Electric or Other Logs Run GR/Res, Density, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-Iq-OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 20" 9 cu yds High Early 9.625" 40# L-80 Surface 6497' 12.25" 75o sx AS III, 705 sx Class G 7" 26# L-80 Surface 10556' 8.5" 18o sx Class G 4" 14# S-135 10457' 14131' 6.125" cement retainer @ 14015' retrievable bridge plug @ 14068' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 10457' 10100' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13410'-13450' MD 6592'-6593' TVD 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13370'-13410' MD 6592'-6592' TVD 6 spf N/A 90 bbls red cement below retainer 13350'-13370' MD 6593'-6592' TVD 6 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. .:. ".-~ :~"" ~"' '::i~' ! ;.?-.?'? ?''~;::' "'_r ::!'.::; :i'~ :~'~ ~ : ,~ Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top Kuparuk D Bottom Kuparuk D Top Kuparuk A Bottom Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 14038' 14200' 14630' 14630' TRUE VERT. DEPTH 6587' 6593' 6622' 6622' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Sig ned,,,¢~~ ~---. d.,,~ Title Drillinq Enqineering Supervisor Date Chip Alvord INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lC-26 WELL_ID: AK0025 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/01/99 START COMP: RIG:POOL 6 BLOCK: FINAL: -- WI: 0% SECURITY:0 API NUMBER: 50-029-22944-00 06/30/99 (D1) TD/TVD: 115/115 SUPV:FRED HERBERT MW: 8.3 VISC: 28 PV/YP: 1/ 0 (115) P/U HWDP, JARS & STAND BACK IN DERRICK Move rig from 1C-27 to 1C-26. NU diverter. UPCOMING OPERATIONS:SPUD WELL APIWL: 0.0 07/01/99 (D2) TD/TVD: 465/465 SUPV:FRED HERBERT MW: 9.1 VISC: 235 PV/YP: 33/66 (350) DRILLING ~ 1130' APIWL: 6.4 Function test diverter system. Drilling 12.25" hole from 115' to 316' POOH. Tight ~ 252'. Pump out to 192'. RIH wash from 192' to 283' Drill from 316' to 465' UPCOMING OPERATIONS:CONTINUE DRILLING AHEAD, SHORT TRIP 07/02/99 (D3) MW: 10.0 VISC: 172 PV/YP: 28/56 TD/TVD: 2493/2378 (2028) SHORT TRIP (RIH) SUPV:FRED HERBERT Drilling 12.25" hole from 465' to 2493' UPCOMING OPERATIONS:DRILL AHEAD APIWL: 6.2 07/03/99 (D4) MW: 10.0 VISC: 152 PV/YP: 32/36 APIWL: 5.8 TD/TVD: 3626/3998 (1133) DRILLING AHEAD; DEPTH 4265' SUPV:FRED HERBERT Wiper trip. Pump out from 2028' to 1465' (swabbing). RIH, bridge ~ 678', ream thru bridge and continue in hole. Drilling 12.25" hole from 2493' to 3626' UPCOMING OPERATIONS:WIPER TRIP, DRILL TO TD 07/04/99 (D5) MW: 10.2 VISC: 188 PV/YP: 41/51 TD/TVD: 5027/3712 (1401) CIRC SWEEP AROUND FOR BIT TRIP SUPV:FRED HERBERT APIWL: 5.6 Drilling 12.25" hole from 3626' to 4741'. Circ around hi density barofiber sweep. POOH to 2123' Swabbing ~ 2750' Pump out from 2686' to 2310' Pulled ok from 2310' to 2123'. RIH to 4741' w/no trouble. CBU. Mud thick w/lots of clay and gravel. Drilling 12.25" hole from 4741' to 5027'. UPCOMING OPERATIONS:TRIP FOR BIT. DRILL TO TD Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/05/99 (D6) TD/TVD: 5681/4047 SUPV:FRED HERBERT MW: 10.2 VISC: 128 PV/YP: 38/48 654) DRILLING AHEAD, DEPTH 6150' APIWL: 5.4 Drilling 12.25" hole from 5027' to 5280' Circ hi density barofiber sweep around for bit trip. Monitor well. Begin swabbing ~ 2150' Pump out from 2120' to 1270' Change bit. TIH. CBU. Ream from 5215' to 5280'. Drilling 12.25" hole from 5280' to 5681' UPCOMING OPERATIONS:DRILL TO TD, WIPER TRIP, RUN CASING 07/06/99 (D7) MW: 10.2 VISC: 81 PV/YP: 30/33 APIWL: 5.0 TD/TVD: 6507/4466 826) L/D BHA SUPV:FRED HERBERT / SCOTT REYNOLDS Drilling 12.25" hole from 5681' to 6507'. Circ hi density, barofiber sweep around for wiper trip. Pump slug. Tight & swabbing ~ 1786'. Pump out from 1746' to 1185' UPCOMING OPERATIONS:RUN 9.625" CASING 07/07/99 (D8) MW: 10.2 VISC: 47 PV/YP: 17/16 APIWL: 5.8 TD/TVD: 6507/4466 0) NIPPLE UP WELLHEAD SUPV:FRED HERBERT / SCOTT REYNOLDS POOH to run casing. Tight from 725'-680'. Work thru tight spot. Safety meeting. Run 9-5/8" casing. Pump cement. UPCOMING OPERATIONS:TEST BOPE. DRILL OUT CEMENT. LOT 07/08/99 (D9) MW: 8.4 VISC: 42 PV/YP: 10/14 APIWL: 10.2 TD/TVD: 6507/4466 ( 0) DRILL PLUGS, FLT COLLAR, CEMENT SUPV:FRED HERBERT / SCOTT REYNOLDS Pump cement. ND diverter. Nil BOPE and test to 250/5000 psi. UPCOMING 0PERATIONS:TRIP FOR RTTS TO FIND CASING LEAK 07/09/99 (D10) MW: 8.5 VISC: 41 PV/YP: 9/14 APIWL: 10.0 TD/TVD: 6507/4466 ( 0) MAKING HOLE ~6602' SUPV:HERBERT/REYNOLDS/CUNNINGHAM RIH to tag cement stringers ~ 6300'. Cleanout to 6390' Circulate out contaminated mud. Cleanout to float collar e 6418' Drill out same and soft cement to 6436' Continue to RIH w/RTTS tool. RIH to drill out float shoe and 20' new hole. UPCOMING OPERATIONS:MAKE HOLE 07/10/99 (Dll) MW: 9.0 VISC: 42 PV/YP: 14/11 APIWL: 6.6 TD/TVD: 8528/5503 (2021) DRIILING AHEAD @ 8566' SUPV:HERBERT/REYNOLDS/CUNNINGHAM Clean out cement and fit equip, from 6436' to 6496' Drill 20' of new hole to 6527'. Perform FIT to 14.0 EMW. Drilling 8.5" hole from 6527' to 8528' UPCOMING OPERATIONS:DRILL TO CASING POINT Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 07/11/99 (D12) MW: 9.2 VISC: 42 PV/YP: 13/12 APIWL: 5.4 TD/TVD:10063/6298 (1535) DRILLING AHEAD ~10,255' SUPV:HERBERT/REYNOLDS/CUNNINGHAM Drilling f/8528' to 8566' Short trip to shoe, start to swab ~ 6650'. Drilling from 8566' to 10063' UPCOMING OPERATIONS:DRILL TO CASING POINT, RUN USIT LOG ON 9.625, RUN 7" CASING 07/12/99 (D13) MW: 9.5 VISC: 44 PV/YP: 15/16 APIWL: 4.6 TD/TVD:10570/6462 (507) PIPE FREE ~ 01:30. 3 STNDS OUT OF HOLE. HOLE PACKS OF SUPV:HERBERT/REYNOLDS/CUNNINGHAM Pump hi vis/lo vis sweep. Open hole FIT, 11.6 ppg EMW. Drill from 10063' to 10570' Methane gas alarm went off, check for flow at bell nipple. Well appeared to be flowing with bubbles at surface. Shut well. Come up slow on pumps. Hole packed off, loss circulation. Start working pipe off bottom. Work pipe by adding torque. UPCOMING OPERATIONS:WORK PIPE TO HRZ TO ESTABLISH GOOD CIRCULATION. WEIGHT MUD UP TO 10-10.1 PPG. 07/13/99 (D14) TD/TVD:10570/6462 ( SUPV:R.W. SPRINGER MW: 10.3 VISC: 51 PV/YP: 20/21 0) CIRC & COND PRIOR TO POH APIWL: 4.6 Working stuck pipe while jarring, work pipe free. CBU, lots of gas. Packing off. Wash and back ream out to 8478'. RIH, hit tight spot ~ 10420'. Wash and ream from 10380', packing off while reaming down to 10420'. Wash and ream from 10471' to 10540' UPCOMING OPERATIONS:POH, RUN CSG & CEMENT 07/14/99 (D15) TD/TVD:10570/6462 ( SUPV:R.W. SPRINGER MW: 10.3 VISC: 53 PV/YP: 23/25 0) WASH & REAM 60' TO BTM. APIWL: 4.2 Packing off, pull back up to 10400', start over washing and reaming down to 10570' trying to packoff. Circ around lo-hi vis sweep, no packing off. Spot hi-vis pill from bottom to 8570' RIH w/hole opener. UPCOMING OPERATIONS:CIRC, PUMP PILL, POH & RUN CSG. 07/15/99 (D16) TD/TVD:10570/6462 ( SUPV:R.W. SPRINGER MW: 10.5 VISC: 56 PV/YP: 24/26 0)RUNNING 7" CASING APIWL: 4.0 RIH w/hole opener, hit know ~ 10175-10176' Hit bridge ~ 10510', pull up 30', couldn't establish circ. Wash and ream to bottom, lots of gas on bottoms up. Spot hi vis pill from bottom to 9500' Rig up to run casing. PJSM. Run 7" casing. UPCOMING OPERATIONS:CEMENTING, TESTING BOPE Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 07/16/99 (D17) TD/TVD:10570/6462 ( SUPV:R.W. SPRINGER MW: 10.2 VISC: 48 PV/YP: 18/16 0) LAYING DOWN DRILLPIPE F/DERRICK. APIWL: 5.4 PJSM, continue running 7" casing. Circ pipe volume 0 shoe, no losses. Continue running casing. Circ, started having losses, cut rate to 30 spm, circ bttms up. Continue running casing. Pump cement. Install packoff and test. UPCOMING OPERATIONS:TEST BOPE, P/U 4" DP & BHA, RIH. 07/17/99 (D18) MW: 10.6 VISC: 51 PV/YP: 18/24 APIWL: 5.6 TD/TVD:10570/6462 ( 0) RIH PICKING UP DRILLPIPE. SUPV:R.W. SPRINGER Test BOPE. Pull test plug. PJSM. Pick up BHA. UPCOMING OPERATIONS:DRILLOUT CASING, CONTINUE DRILLING. 07/18/99 (D19) MW: 10.6 VISC: 52 PV/YP: 19/23 TD/TVD:10590/6466 ( 20) DRILLING 6-1/8" INTERVAL SUPV:R.W. SPRINGER APIWL: 4.8 Test circ sub, test MWD & mud motor/plastic opening ball broken up when tool closed, P0H clean pieces out of bit jet, change out MWD innards when pastic pieces found in it. Pick up drill pipe, break circ every 2000', rabbit all its. Break circ, tag cement ~ 10420', wash down. Test casing to 3500 psi. Drilling cement from 10420' to 10570' Drill new hole from 10570' to 10590' UPCOMING OPERATIONS:CONTINUED DRILLING 07/19/99 (D20) MW: 10.8 VISC: 54 PV/YP: 20/30 APIWL: 4.0 TD/TVD:l1311/6552 (721) DRILLING ~ 11380' SUPV:R.W. SPRINGER Change over to new mud. perform FIT to 12.5 ppg EMW. Drilled from 10590'-11038'. Increase mud weight to 10.8 ppg. Drilled from 11038'-11311' UPCOMING OPERATIONS:CONTINUE HORIZONTAL DRILLING. 07/20/99 (D21) MW: 10.8 VISC: 53 PV/YP: 20/27 APIWL: 4.0 TD/TVD:l1380/6556 ( 69) DRILLING ~ 11445' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 11311'-11380', MWD tool failure. CBU. Pump out of hole to shoe, pump dry job. Attempt to pull out not taking correct fill. Remove bit, clean and remake. Work on MWD, chang out pulsar. RIH. UPCOMING OPERATIONS:CONTINUED DRILLING. 07/21/99 (D22) MW: 10.8 VISC: 50 PV/YP: 20/28 APIWL: 3.6 TD/TVD:l1922/6552 (542) WIPER TRIP FROM 11966' SUPV:R.W. SPRINGER/SCOTT REYNOLDS RIH to 10639'. Circ btms up. Drilled from 11380'-11922' UPCOMING OPERATIONS:CONTINUED HORIZONTAL DRILLING Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 07/22/99 (D23) MW: 11.0 VISC: 48 PV/YP: 22/28 APIWL: 3.6 TD/TVD:12180/6571 (258) DRILLING HORIZONTAL SECTION ~ 12271' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 11922'-11966'. Circ btms up, monitor well. Pump out of hole from 11966'-11311' RIH, no hole problems. Drilled from 11966'-12094'. Slug of cuttings over shaker, check well, bubbling gas, shut down pumps, no flow, circ out gas cut mud f/10.8 cut to 9.9 ppg. Circ and condition mud, raise mud weight from 10.8 to 11.0 ppg. Drilling from 12094'-12180' UPCOMING OPERATIONS:WIPER TRIP, CONTINUED DRILLING. 07/23/99 (D24) MW: 11.1 VISC: 48 PV/YP: 22/27 APIWL: 3.6 TD/TVD:12604/6599 (424) DRILLING HORIZONTAL ~ 12752 SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 12180' to 12564' Ream hole to attempt to drop angle from 12463'-12559' Drilled from 12564' to 12604' UPCOMING OPERATIONS:CONTINUED DRILLING 07/24/99 (D25) MW: 11.1 VISC: 47 PV/YP: 20/27 APIWL: 3.2 TD/TVD:13310/6596 ( 706) DRILLING AHEAD @ 13397'. SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drill from 12604' to 12848' Pump out of hole from 12848' to 11892' 1st 5 stands took proper fill. 2nd 5 did not take proper fill. Circulate out trip gas for 2 btms up. Drill from 12848' to 13310' UPCOMING OPERATIONS:CONTINUE DRILLING HORIZONTAL. 07/25/99 (D26) MW: 11.1 VISC: 46 PV/YP: 22/23 APIWL: 3.2 TD/TVD:13904/6589 (594) DRILLING HORIZONTAL ~ 14020' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 13310' to 13342'. Pump sweep. Problems sliding. Reduce pump rate to 60 spm to lower ECD and sticking problems while sliding, drilled from 13342'-13904'. Circ btms up. Short trip to 12853' pumping out. Circ btms up. UPCOMING OPERATIONS:CONTINUE DRILLING TO T.D. @ -14727' 07/26/99 (D27) MW: 11.1 VISC: 47 PV/YP: 21/29 APIWL: 3.0 TD/TVD:14275/6599 (371) DRILLING HORIZONTAL @14438' SUPV:R.W. SPRINGER/SCOTT REYNOLDS Drilled from 13904' to 14090'. Ream stand while picking up drillpipe. Drilled from 14090' to 14275'. UPCOMING OPERATIONS:CONTINUE DRILLING TO T.D.. Date: 09/29/99 ARCO ALASKA INC. WELL SI/MMARY REPORT Page: 6 07/27/99 (D28) MW: 11.1 VISC: 45 PV/YP: 16/29 APIWL: 4.0 TD/TVD:14630/6622 (355) WORK STUCK PIPE SUPV:F.HERBERT/M. CUNNINGHAM PJSM. Drill from 14275' to 14606'. Circ connection, gas out of hole, gas cut mud weight 10.4. Drill from 14606 to 14630'. Circ and cond. mud to 11.2 ppg, balance mud weight. Bring mud weight up to 11.5. work stuck pipe ~ 14605'. Pump down Lube-tech and baro-fibre. UPCOMING OPERATIONS:WORK STUCK PIPE 07/28/99 (D29) MW: 11.1 VISC: 50 PV/YP: 23/38 APIWL: 3.2 TD/TVD:14630/6622 ( 0) POOH W/ FREEPOINT. NOT ABLE TO GET PAST 2628' SUPV:F.HERBERT/M. CUNNINGHAM PJSM. Work stuck pipe ~ 14605'. Circ bttms up to check for gas. Work stuck pipe. RIH w/freepoint tools, will not go past 2620'. Circ and cond mud, shake out LCM. Gas cut mud to surface. UPCOMING OPERATIONS: CONTINUE WITH FREEPOINT OPERATION 07/29/99 (D30) MW: 11.6 VISC: 51 PV/YP: 21/36 APIWL: 3.0 TD/TVD:14630/6622 ( 0) R/D WIRELINE EQUIPMENT. STRING BACKED OFF AT 10322' (W SUPV:F.HERBERT/M. CUNNINGHAM Raise weight to 11.2 ppg. Shut in well and monitor for press increase. No increase. RIH w/freepoint tool. WIH w/sinker bars, work down to 10400'. Gas cut mud to surface, continue to circ out gas cut mud (10.4) until cleaned up. UPCOMING OPERATIONS:POOH FOR FISHING ASSY #1 07/30/99 (D31) MW: 11.6 VISC: 48 PV/YP: 22/36 APIWL: 3.0 TD/TVD:14630/6622 ( 0) JAR ON FISH SUPV:F.HERBERT/M. CUNNINGHAM Spot SFT pill on bottom. Work torque into string. POOH. No gas cut mud. No flow well. static. Test BOPE to 250/5000 pssi. RIH w/fishing assembly. UPCOMING OPERATIONS:CONTINUE FISHING OPERATIONS 07/31/99 (D32) MW: 11.6 VISC: 45 PV/YP: 20/30 APIWL: 3.6 TD/TVD:14630/6622 ( 0) CIRC BTTMS UP FOR TRIP OUT. SUPV:F.HERBERT/M. CUNNINGHAM RIH w/fishing assembly #1. Circ bttms up ~ 10103', no gas cut mud. RIH to 10322'. Engage fish and jar on same. PJSM on stuck pipe. Work stuck pipe. Begin circ & jarring. Loosing returns packed off. Continue jarring and attempting to circ. UPCOMING OPERATIONS:CONTINUE W/ FISHING OPERATIONS Date: 09/29/99 ARCO ALASKA INC. WELL SUMFiARY REPORT Page: 7 08/01/99 (D33) MW: 11.6 VISC: 48 PV/YP: 24/36 APIWL: 3.2 TD/TVD:14630/6622 ( 0) RUN IN W/ STRING SHOT SUPV:F.HERBERT/M. CUNNINGHAM jar on stuck pipe. drill string parted. Circ out SFT pill and gas cut mud. Slight flow, flow decreased and stopped. Circ bttms up, no gas cut mud. POOH. String parted in the top of the acc jars. Retrieved top sub & 6.5' of spline. L/D fish. TOF 9911'. RIH w/fishing assy. ~2. UPCOMING OPERATIONS:CONTINUE W/ FISHING OPERATIONS 08/02/99 (D34) MW: 11.6 VISC: 45 PV/YP: 18/30 APIWL: 3.4 TD/TVD:14630/6622 ( 0) POOH W/ WIRELINE. BACKED OFF $ 10319' (?) SUPV:F.HERBERT/M. CUNNINGHAM CIrc bttms up $ 9750. No gas cut mud. RIH & engage fish $ 9911' w/overshot. PJSM. RIh w/sinker bar assy. Work thru spot $ 9898' RIH to 10260' UPCOMING OPERATIONS:CONTINUE W/ FISHING OPERATIONS 08/03/99 (D35) MW: 11.6 VISC: 46 PV/YP: 20/33 APIWL: 3.2 TD/TVD:14630/6622 ( 0) JAR ON FISH SUPV:F.HERBERT / S. REYNOLDS RIH w/string shot to 10500' PJSM. Work LH torque into string. Back off @ 10290' Circ bttms up. Mud wt coming back @ 12.7 ppg. Hole taking approx 35 bbls/hr while circ. Monitor well. R/D side entry sub. Well flowed back 10 bbls. POOH w/fish. Recovered fish. RIH w/fishng assy #3. UPCOMING OPERATIONS:CONTINUE W/ FISHING OPERATIONS 08/04/99 (D36) MW: 11.6 VISC: 49 PV/YP: 20/38 APIWL: 3.6 TD/TVD:14630/6622 ( 0) RIH W/ STRING SHOT SUPV:F.HERBERT / S. REYNOLDS RIH w/fishing assembly. Circ bttms up. Engage fish $ 10319', jar on fish, pump periodically with little or no returns. RIH w/string shot, pump down tool f/4000' Can't get past 10520'. Lost returns w/pumping down tool. POOH w/string shot. RIH w/string shot. Assist w/pump could not get past 10538' UPCOMING OPERATIONS:POOH W/ FISHING ASSY. L/D SAME. RIH W/ DP. R/U COIL. 08/05/99 (D37) MW: 11.6 VISC: 48 PV/YP: 19/ 0 APIWL: 3.6 TD/TVD:14630/6622 ( 0) RIH W/ FISHING ASSY. SUPV:F.HERBERT / S. REYNOLDS RIH w/sinker bars. Pump down from 4900' to 10560'. RIH w/string shot. POOH. RIH w/string shot. Pump down from 3000' to 10386' PJSM. POOH. UPCOMING OPERATIONS:SCREW INTO FISH. RIG UP COIL TUBING UNIT. Date: 09/29/99 08/06/99 (D38) TD/TVD:14630/6622 ( SUPV:FRED HERBERT 08/07/99 (D39) TD/TVD:14630/6622 ( SUPV:FRED HERBERT 08/08/99 (D40) TD/TVD:14630/6622 ( SUPV:FRED HERBERT ARCO ALASKA INC. WELL SUMMARY REPORT MW: 11.6 VISC: 49 PV/YP: 20/37 RIH W/ COIL TUBING. Page: 8 APIWL: 3.6 POOH. RIH w/fishing assembly ~4. Screw into fish ~ 10386' and jar. PJSM. Rig up coil tubing unit. UPCOMING OPERATIONS:CONTINUE FISHING OPERATIONS. CLEAN OUT W/ COIL TO PBL SUB & ATTEMPT TO ACTIVATE SAME. NOTE; WEEKLY BOP TEST WAIVED UNTIL LATER BY AOGCC REP. CHUCK SCHEVE. MW: 10.7 VISC: 48 PV/YP: 23/35 APIWL: 3.2 0) RIH W/ COIL AFTER CHANGING OUT MOTOR (PLUGGED) Rig up coil tubing unit. Test coil tubing BOPE to 400/4000 psi. RIH w/coil to 11547'. Attempt to work down w/no success. POOH w/coil. Cut off coil 15' (damaged). RIH w/coil to 11500' UPCOMING OPERATIONS:CONTINUE W/ COIL CLEAN OUT MW: 11.6 VISC: 50 PV/YP: 19/41 APIWL: 3.4 0) CUT DP W/ DOWELL CUTTER. DISPLACE CUTTING FLUID & SPAC POOH w/coil. Mud motor failed (plugged). RIH w/coil. Wash down, tag PBL sub ~ 14355' Pressure up to 3000 psi attempt to shear open PBL sub w/no success. POOH w/coil. RIH w/cutter. Would not go past 10343' (jars). Attempt to work thru jars. POOH. UPCOMING OPERATIONS:POOH W/ COIL & JAR ON FISH. 08/09/99 (D41) TD/TVD:14630/6622 ( SUPV:FRED HERBERT MW: 11.6 VISC: 48 PV/YP: 20/36 0) RIH W/ COIL & PERF GUN APIWL: 3.4 RIH w/coil & cutter to 14112' PJSM. Rig up and pump cutting fluid to cut DP ~ 14112'.POOH. Work torque into string attempt to get DP to part. RIH w/coil & dummy head. Could not get past jars w/dummy. POOH. UPCOMING OPERATIONS:PERF DP. ESTABLISH CIRCULATION. CONTNUE W/ FISHING OPERATIONS. 08/10/99 (D42) TD/TVD:14630/6622 ( SUPV:R.W. SPRINGER MW: 11.6 VISC: 49 PV/YP: 20/38 0) RIGGING UP CTU APIWL: 3.4 POH w/coil tubing. Rig up perf guns. RIH w/perf gun. Pump down ball to fire gun @ 14108'-14110'. POOH. Rig up wireline unit to work pipe and attempt to circulate thru perforations. No circulation. Rig up free point tool and RIH. Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 9 08/11/99 (D43) TD/TVD:14630/6622 SUPV:R.W. SPRINGER MW: 11.6 VISC: 50 PV/YP: 26/38 0) RIGGING UP TO RIH W/LOCATOR ON COIL APIWL: 3.8 RIH w/free point tool, pump tool downhole, unable to get past 10668' POH. Rig down wireline, lost bottom 26" of pump down tool. Rig up coil tubing unit. RIH w/guage ring on 1.75" coil. Well flowing back f/injection thru perfs, RIH w/coil pushing free point tool junk to btm. POH. PJSM. RIH w/severing tool on coil, cut pipe ~ 14090' 08/12/99 (D44) TD/TVD:14630/6622 ( SUPV:R.W. SPRINGER MW: 11.6 VISC: 51 PV/YP: 21/40 0) PREPARING TO CEMENT APIWL: 3.4 Cut pipe @ 14090', start getting returns. Circ w/rig pump while coil tubing POH, returns stopped. Attempt to establish circulation while working and jarring pipe. No circulation and no pipe movement. Run in hole w/coil tubing. Perform injection test. 08/13/99 (D45) TD/TVD:14630/6622 SUPV:R.W. SPRINGER MW: 11.6 VISC: 51 PV/YP: 20/36 0) RIH W/INFLATABLE BRIDGE PLUG ON COIL APIWL: 4.2 Start cement plug/squeeze, circulating pressure too high, drag on coil abort cement mixing. Move coil while circulating, drag and circulating pressures OK. Spot cement 8 coil tail, squeeze cement. POH w/coil. Attempted to wash down w/coil tubing, packed off, started injecting, P0H w/coil. Some buildup around nozzle. Shut in adn conducted pressure test, wouldn't test. RIH w/coil, clean out to severing cut ~ 14090'. POH f/Baker inflatable bridge plug. 08/14/99 (D46) MW: 11.6 VISC: 52 PV/YP: 21/36 APIWL: 3.8 TD/TVD:14630/6622 ( 0) CIRCULATING BTMS W/COIL ~ INFLATABLE PACKER SUPV:R.W. SPRINGER POH w/CTU. RIH w/inflatable plug and set @ 14068' POH. RIH w/abrasion cutter. Attempt to cut 4" DP ~ 10391' Pump slick & gel water ahead garnet sand slurry. Pressure drop in coil after 10 bbl indicating tool washout. POH. 08/15/99 (D47) TD/TVD:14630/6622 SUPV:R.W. SPRINGER MW: 11.6 VISC: 47 PV/YP: 19/30 0) POH W/COIL APIWL: 3.8 Displace cutting slurry from coil w/mud. RIH w/overshot retrieving tool on coil. Circulate bottoms up. Attempt to retrieve bridge plug, unable to get overshot on fishing neck. POH. RIH w/coil for flag, spaceout run to jars. Cut coil weld on new connection. RIH w/cutter. Date: 09/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 10 08/16/99 (D48) MW: 11.6 VISC: 49 PV/YP: 20/32 APIWL: 3.8 TD/TVD:14630/6622 ( 0) POH W/E-LINE, BACK OFF STRING SHOT DID NOT SHOOT. SUPV:R.W. SPRINGER Attempt cutting DP w/Weatherford cutter @ 10411', failed. POH w/coil. RIH. Attempt cut of DP @ 10418', unsuccessful. POH. PJSM. RIH w/perf guns. Shoot 9 shots @ 14051'. Test perfs. 08/17/99 (D49) MW: 11.6 VISC: 48 PV/YP: 19/35 APIWL: 3.6 TD/TVD:14630/6622 ( 0) RIG UP STRING SHOT ~4 SUPV:R.W. SPRINGER/SCOTT REYNOLDS PSJM. RIH w/string shot. Work torque downhole, fire shot, no backoff. POH w/wireline, attempt to work additional torque down hole w/no success. RIH w/string shot. Work back torque downhole, fire string shot, no movement on surface, work pipe to see if free, no movement. Rig up to jar on pipe, jar on pipe, wouldn't move, try to inject down DP x 7" annulus, couldn't inject. RIH w/string shot, fire shot, no movement. RIH w/free point, tool wouldn't work. POH. 08/18/99 (D50) MW: 11.6 VISC: 49 PV/YP: 21/38 APIWL: 3.8 TD/TVD:14630/6622 ( 0) CIRCULATE AND CONDITION MUD AT 9200' SUPV:R.W. SPRINGER/SCOTT REYNOLDS RIH w/free point to 10480' POOH. RIH w/string shot to 10480' Fired shot but failed to back off. POOH. RIH w/string shot. Fired shot, no back-off. POOH. RIH w/string shot, fire shot, pipe backed off. POOH. 08/19/99 (D51) MW: 11.8 VISC: 49 PV/YP: 19/36 APIWL: 3.8 TD/TVD:14630/6622 ( 0) POH W/DRILLPIPE, FREEZE PROTECTED 9-5/8" X 7" ANNULUS SUPV:R.W. SPRINGER/SCOTT REYNOLDS Circ and cond mud @ 7983'. Screw back into fish. RIH w/wireline string shot to 9275'. Work back torque down hole, fired shot @ 9190', pipe free. POH. RIH w/string shot to 10469'. Work left torque down hole, string backed off before shot fired. Log w/CCL to find out where pipe backed off. Screw back into drill collars. Work left torque down, fore shot @ 10450', pipe backed off. Circ bttms up, monitor well, well flowing back. Shut well in. Bleed press off, circ bttms up, monitor well. Well flowing back. Bring mud weight up to 11.8 ppg. 08/20/99 (D52) MW: 11.8 VISC: 50 PV/YP: 21/33 APIWL: 3.8 TD/TVD:14630/6622 ( 0) POH W/MILLING ASSY SUPV:R.W. SPRINGER/SCOTT REYNOLDS Test BOPE. RIH w/e-line log, log from 10380' to 9000' top of cement @ 9685' Good bond. RIH w/milling assembly. 08/21/99 (D53) MW: 47.0 VISC: 18 PV/YP: 18/35 APIWL: 3.8 TD/TVD:14630/6622 ( 0) RUNNING COMPLETION 4-1/2" TUBING SUPV:R.W. SPRINGER/SCOTT REYNOLDS RIH w/mill to burn over DP box. Tag DP @ 10450' mill over outside of box end of drillpipe fish. Change out shoe mill to outside cutter, RIH. Work over fish & cut DP. POH. 08/22/99 (D54) MW: 11.8 VISC: 50 PV/YP: 19/37 APIWL: 4.0 TD/TVD:14630/6622 ( 0) NIPPLE UP & TEST TREE. SUPV:R.W. SPRINGER/SCOTT REYNOLDS PJSM. Run 4.5" completion. Set tubing packer. Freeze protect well. 08/23/99 (D55) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:14630/6622 ( 0) RIGGING DOWN FOR MOVE TO iD PAD SUPV:R.W. SPRINGER/SCOTT REYNOLDS ND BOPE. NU tree. Release rig ~ 2100 hrs. 8/23/99. Start rigging down. Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C-26 1C-26 Job No. AKMM90131, Surveyed: 27 July, 1999 ORIGINAL SURVEY REPORT 26 August, 1999 Your Ref'. API500292294400 Surface Coordinates: 5968538.08 N, 562347.92 E (70° 19' 28.4410" N, 149° 29' 39.9939" W) Kelly Bushing: 94.0Oft above Mean Sea Level sper',r -sun D R I L L, I N I~ SE R V I C: ~= S Survey Ref: svy8840 A I'IAI,LIBUR'IX~N COMPANY Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July,' 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -94.00 0.00 189.24 0.340 16.710 95.24 189.24 290.21 O. 1 O0 45.890 196.21 290.21 374.41 1.120 174.630 280.40 374.40 462.47 2.210 179.390 368.42 462.42 556.27 3.830 192.510 462.09 556.09 647.46 5.570 179.820 552.97 646.97 737.31 6.390 177.770 642.33 736.33 824.27 6.110 177.320 728.78 822.78 915.40 6.530 176.830 819.35 913.35 1004.21 6.770 177.990 907.57 1001.57 1095.04 7.080 169.990 997.74 1091.74 1186.21 8.390 156.530 1088.08 1182.08 1279.14 9.300 146.910 1179.91 1273.91 1372.84 10.680 138.350 1272.19 1366.19 1465.87 12.890 128.850 1363.26 1457.26 1560.65 14.430 132.500 1455.36 1549.36 1654.45 17.350 137.220 1545.57 1639.57 1748.66 20.200 138.760 1634.76 1728.76 1844.92 22.320 134.670 1724.47 1818.47 1939.10 25.170 130.760 1810.67 1904.67 2032.17 28.430 130.540 1893.74 1987.74 2126.05 30.640 131.660 1975.41 2069.41 2220.05 33.500 132.480 2055.06 2149.06 2314.20 36.870 133.220 2132.00 2226.00 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5968538.08 N 562347.92 E 0.54 N 0.16 E 5968538.62 N 562348.08 E 0.89 N 0.31 E 5968538.97 N 562348.22 E 0.12 N 0.44 E 5968538.20 N 562348.36 E 2.44 S 0.54 E 5968535.65 N 562348.48 E 7.30 S 0.12 W 5968530.78 N 562347.86 E 14.70 S 0.77 W 5968523.37 N 562347.28 E 24.06 S 0.56 W 5968514.02 N 562347.56 E 33.52 S 0.15 W 5968504.56 N 562348.05 E 43.54 S 0.36 E 5968494.55 N 562348.64 E 53.81 S 0.82 E 5968484.28 N 562349.19 E 64.67 S 1.98 E 5968473.42 N 562350.44 E 76.31 S 5.61 E 5968461.82 N 562354.16 E 88,82 S 12.41 E 5968449.37 N 562361.07 E 101.65 S 22.31 E 5968436.62 N 562371.08 E 114.61 S 36.13 E 5968423.78 N 562385.00 E 129.22 S 53.07 E 5968409.31 N 562402.06 E 147.38 S 71.19 E 5968391.29 N 562420.33 E 169.93 S 91.46 E 5968368.92 N 562440.79 E 195.28 S 115.42 E 5968343.77 N 562464.95 E 220.94 S 143.31 E 5968318.34 N 562493.06 E 248.26 S 175.15 E 5968291.28 N 562525.12 E 278.70 S 210.01 E 5968261.14 N 562560.24 E 312.14 S 247.04 E 5968228.00 N 562597.55 E 349.04 S 286.80 E 5968191.43 N 562637.61 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.180 -0.15 0.255 -0.21 1.408 0.31 1.247 1.76 1.867 3.82 2.212 7.24 0.943 12.44 0.327 17.86 0.465 23.67 0.310 29.57 1.114 36.38 2.443 45.68 1.865 58.13 2.160 73.38 3.154 91.98 1.861 114.12 3.4O2 139.16 3.070 168.36 2.687 202.18 3.456 239.48 3,504 281.01 2.426 326.76 3.078 375.96 3,608 429.31 Continued... 26 August, 1999 - 14:04 - 2 - DrillQuest Sperry-Sun Drilling Services · Survey Report for 1C-26 Your Ref: API500292294400 Job No, AKMM90131, Surveyed: 27 July; 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2408.16 40.060 133.520 2205.56 2299.56 2500.53 43.480 133.230 2274.44 2368.44 2599.32 46.350 132.750 2344.39 2438.39 2691.21 49.330 131.870 2406.06 2500.06 2786.52 52.500 131.730 2466.14 2560.14 2880.31 55.470 130.670 2521,29 2615.29 2972.48 58.420 130.010 2571,56 ' 2665.56 3067.67 59.560 130.390 2620,60 2714.60 3163.01 58.780 130.390 2669,46 2763.46 3254.75 58.620 130.490 2717.12 2811.12 3350.44 58.780 130.060 2766.83 2860.83 3444.09 58.570 130.050 2815.52 2909.52 3534.85 60.130 129.370 2861.79 2955.79 3627.22 59.490 129.250 2908.24 3002.24 3720.52 59.250 129.950 2955.77 3049.77 3816.37 58.440 130.140 3005.36 3099.36 3910.09 59.460 130.520 3053.70 3147.70 4003.64 60.490 129.560 3100.51 3194.51 4096.26 59.440 130.290 3146.87 3240.87 4189.68 58.530 130.900 3195.00 3289.00 4281.92 58.620 129.280 3243.10 3337.10 4376.01 59.290 129.410 3291.62 3385.62 4469.72 60.130 129.100 3338.89 3432.89 4564.49 61.270 127.950 3385.26 3479.26 4656.08 60.410 127.970 3429.89 3523.89 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 389.18 S 329.28 E 5968151.65 N 562680.42 E 431.43 $ 374.00 E 5968109.78 N 562725.49 E 478.98 S 425.02 E 5968062.65 N 562776.91 E 524.81 S 475.40 E 5968017.24 N 562827.66 E 574.11 S 530.54 E 5967968.39 N 562883.21 E 624.07 S 587.62 E 5967918.92 N 562940.71 E 674.06 S 646.50 E 5967869.41N 563000.00 E 726.72 $ 708.81 E 5967817.27 N 563062.75 E 779.77 S 771.17 E 5967764.74 N 563125.54 E 830.62 S 830.83 E 5967714.39 N 563185.62 E 883.48 S 893.21 E 5967662.06 N 563248.44 E 934.96 S 954.44 E 5967611.09 N 563310.10 E 984.84 S 1014.51 E 5967561.71 N 563370.58 E 1035.42 $ 1076.28 E 5967511.64 N 563432.77 E 1086.59 S 1138.14 E 5967460.98 N 563495.05 E 1139.36 S 1200.94 E 5967408.73 N 563558.28 E 1191.33 S 1262.14 E 5967357.28 N 563619.92 E 1243.43 S 1324.15 E 5967305.69 N 563682.36 E 1294.89 S 1385.65 E 5967254.75 N 563744.28E 1346.98 S 1446.44 E 5967203.16 N 563805.50 E 1397.67 S 1506.65 E 5967152.98 N 563866.13 E 1448.78 S 1568.99 E 5967102.39 N 563928.90 E 1499.98 S 1631.65 E 5967051.71N 563991.98 E 1551.45 S 1696.31E 5967000.78 N 564057.06 E 1600.65 S 1759.37 E 5966952.11 N 564120.53 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (ft) Comment 3.401 486.69 3.708 547.10 2.925 615.66 3.320 682.77 3.328 755.76 3.296 830.73 3.256 907.24 1.246 988.08 0.818 1069.16 0.198 1146.79 0.419 1227.79 0.224 1307.09 1.836 1384.54 0.702 1463.81 0.695 1543.47 0.862 1624.77 1.142 1704.30 1.415 1784.59 1.323 1864.09 1.123 1943.35 1.502 2021.35 0.722 2101.38 0.941 2181.73 1.602 2263.91 0.939 2343.52 Continued... 26 August, 1999 - 14:04 - 3 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4752.20 59.950 125.850 3477.69 3571.69 4844.37 59.140 127.720 3524.41 3618.41 4938,01 58.780 127.840 3572,70 3666.70 5031.37 60.000 127.830 3620.24 3714.24 5124.57 59.010 127.980 3667.53 3761.53 5217.86 58.650 127.570 3715.82 3809.82 5310.90 59.820 126.510 3763.41 '3857.41 5405.62 58.700 125,060 3811.82 3905.82 5498.87 57.790 126.060 3860.90 3954.90 5591.89 58.600 129.020 3909.93 4003.93 5686.22 57.970 129.890 3959.52 4053.52 5779.08 58.610 129,360 4008.33 4102.33 5872.17 58.520 131.280 4056.88 4150.88 5965.49 60.800 131.890 4104.02 4198.02 6061,04 61.640 130.550 4150.02 4244.02 6154.66 60.910 130.060 4195,02 4289.02 6247.50 60.440 130.030 4240.49 4334.49 6339.87 59,720 129.610 4286.56 4380.56 6422.89 59,150 129.480 4328.78 4422.78 6532.25 58.510 129.750 4385.38 4479.38 6626.93 60.690 130.960 4433.29 4527.29 6721.92 60.560 129.790 4479.88 4573.88 6815.94 60.350 130.320 4526.25 4620.25 6909.11 60.170 130.650 4572.46 4666.46 7003.62 59.900 130.950 4619.67 4713.67 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1650.73 S 1826.04 E 5966902.58 N 564187.61E 1698.30 S 1889.67 E 5966855.54 N 564251.64 E 1747.45 $ 1953.08 E 5966806.92 N 564315.46 E 1796.73 S 2016.54 E 5966758.16 N 564379.32 E 1846.07 S 2079.91 E 5966709.35 N 564443.09 E 1894.97 S 2143.00 E 5966660.98 N 564506.59 E 1943.12 S 2206.82 E 5966613.36 N 564570.80 E 1990.73 S 2272.85 E 5966566.31N 564637.23 E 2036.83 S 2337.35 E 5966520.74 N 564702.12 E 2085.00 S 2400.02 E 5966473.09 N 564765.18 E 2135.99 S 2461.98 E 5966422.62 N 564827.56 E 2186.37 S 2522.83 E 5966372,75 N 564888.82 E 2237.76 S 2583.38 E 5966321.86 N 564949.80 E 2291.22 S 2643.61E 5966268.91N 565010.48 E 2346.40 S 2706.61E 5966214.25 N 565073.93 E 2399,50 S 2769.22 E 5966161.67 N 565136.98 E 2451.58 S 2831.18 E 5966110.11N 565199.37 E 2502.85 S 2892.67 E 5966059.35 N 565261.28 E 2548.36 S 2947.79 E 5966014.30 N 565316.78 E 2608,03 S 3019.88 E 5965955.24 N 565389.36 E 2660.91 S 3082.09 E 5965902.87 N 565452.02 E 2714.53 S 3145.15 E 5965849.78 N 565515.52 E 2767.16 S 3207.76 E 5965797.66 N 565578.56 E 2819.69 S 3269.29 E 5965745.65 N 565640.53 E 2873.19 S 3331.27 E 5965692.67 N 565702.95 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1.972 2426.65 1.957 2505.87 0.400 2585.76 1.307 2665.75 1.071 2745.70 0.539 2825.17 1.594 2904.86 1.769 2986.13 1.336 3065.30 2.841 3144.o3 1.030 3223.67 0.843 3302,05 1.762 3380.73 2.507 3460.24 1.511 3543.00 0.905 3624.33 0.507 3704.56 0.873 3783.96 0.700 3854.90 0.622 3947.74 2.553 4028.62 1.082 4110.60 0.539 4191.68 0,363 4271.78 0.397 4352.79 Continued... 26 August, 1999 - 14:04 - 4 - DrlllQuest Sperry-Sun Drilling Services Survey Report for 1Co26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July,' 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7098.64 59.800 130.480 4667.40 4761.40 7190.52 59.450 130.640 4713.86 4807.86 7285.77 59.180 130.540 4762.46 4856.46 7379.31 58.880 131.090 4810.60 4904.60 7471.69 58.540 131.470 4858.58 4952.58 7565.28 58.190 131.740 4907.67 5001.67 7657.80 57.970 131.900 4956.58 '5050.58 7751.77 59.100 130.400 5005.64 5099.64 7847.01 59.470 129.350 5054.28 5148.28 7939.93 59.080 129.720 5101.76 5195.76 8032.93 58.810 129.410 5149.73 5243.73 8125.03 58.520 129.520 5197.63 5291.63 8218.71 58.300 129.270 5246.70 5340.70 8312.46 58.140 129.450 5296.08 5390.08 8406.61 57.980 129.990 5345.88 5439.88 8500.66 57.730 129.680 5395.92 5489.92 8592.96 57.190 129.910 5445.57 5539.57 8687.74 58.380 127.590 5496.10 5590.10 8779.78 58.390 126.540 5544.35 5638.35 8873.25 57.580 126.400 5593.90 5687.90 8967.81 58.320 126.820 5644.08 5738.08 9060.95 58.070 127.750 5693.17 5787.17 9153.20 58.170 128.340 5741.89 5835.89 9246.51 58.400 127.640 5790.94 5884.94 9341.55 58,270 127.910 5840.84 5934.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2926.78 S 3393.55 E 5965639.59 N 565765.67 E 2978.32 S 3453.77 E 5965588.55 N 565826.32 E 3031.62 S 3515.97 E 5965535.78 N 565888.96 E 3084.04 S 3576.68 E 5965483.86 N 565950.10 E 3136.12 S 3636.00 E 5965432.27 N 566009.85 E 3189.03 S 3695.58 E 5965379.86 N 566069.87 E 3241.40 S 3754.11 E 5965327.99 N 566128.83 E 3294.13 S 3814,46 E 5965275.75 N 566189.62 E 3346.62 S 3877.30 E 5965223.79 N 566252.89 E 3397.47 S 3938.90 E 5965173.45 N 566314.91 E 3448.21S 4000.32 E 5965123.22 N 566376.75 E 3498.22 S 4061.05 E 5965073.73 N 566437.90 E 3548.86 S 4122.72 E 5965023.59 N 566499.98 E 3599.40 S 4184.34 E 5964973.57 N 566562.02 E 3650.46 S 4245.79 E 5964923.02 N 566623.89 E 3701.47 S 4306.94 E 5964872.52 N 566685.47 E 3751.27 S 4366.73 E 5964823.22 N 566745.66 E 3801.45 S 4429.26 E 5964773.56 N 566808.61 E 3848.69 S 4491.80 E 5964726.84 N 566871.55 E 3895.80 S 4555.54 E 5964680.27 N 566935.67 E 3943,59 S 4619.87 E 5964633.01 N 567000.40 E 3991.54 S 4682.85 E 5964585.58 N 567063.77 E 4039.82 S 4744.54 E 5964537.82 N 567125.86 E 4088.68 S 4807.10 E 5964489.48 N 567188.82 E 4138.23 S 4871.04 E 5964440.47 N 567253.17 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.440 4434.10 0.409 4512.58 0.297 4593.67 0.598 4673.02 0.509 4751.03 0.447 4829.69 0.279 4907.18 1.816 4986,40 1.024 5067,59 0.542 5146.86 0.407 5225.92 0,331 5304.00 0.327 5383.21 0.236 5462.33 0.516 5541.58 0.385 5620.55 0.622 5697.72 2.422 5777.42 0,972 5855.54 0.876, 5934.60 0.868 6014,54 0.890 6093,41 0.554 6171.37 0.684 6250.38 0.278 6330.92 Continued... 26 August, 1999 - 14:04 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, t999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 9434.84 58.020 128.020 5890.07 5984.07 9527.05 57.970 127.540 5938.94 6032.94 9621.99 57.730 126.590 5989.46 6083.46 9715.19 59.080 124.830 6038.30 6132.30 9808.34 60.900 126.460 6084.88 6178.88 9902.95 62.270 127.390 6129.90 6223.90 9996.19 63.860 128.290 6172.14 '6266.14 10088.28 65.870 127.360 6211.25 6305.25 10183.94 67.270 124.360 6249.30 6343.30 10275.57 69.180 121.650 6283.29 6377.29 10369.96 72.150 120.060 6314.54 6408.54 10468.73 74.820 118.720 6342.62 6436.62 10502.24 75.820 117.440 6351.11 6445.11 10585.66 78.390 114.580 6369.73 6463.73 10617.89 81.230 116.080 6375.43 6469.43 10649.87 84.180 116.270 6379.49 6473.49 10681.69 84.630 115.740 6382.59 6476.59 10708.87 84.700 115.890 6385.12 6479.12 10740.76 84.690 115.980 6388.07 6482.07 10772.16 84.850 115.730 6390.93 6484.93 10804.60 83.760 114.730 6394.15 6488.15 10835.85 83.710 114.110 6397.56 6491.56 10869.94 82.650 114.200 6401.61 6495.61 10901.44 81.530 114.840 6405.94 6499.94 10934.63 81.500 115.250 6410.84 6504.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4186.97 S 4933.51E 5964392.24 N 567316.04 E 4234.88 S 4995.31E 5964344.85 N 567378.24 E 4283.33 S 5059.45 E 5964296.94 N 567442.78 E 4329.65 S 5123.91E 5964251.15 N 567507.62 E 4376.66 S 5189.44 E 5964204.69 N 567573.55 E 4426.65 S 5255.96 E 5964155.25 N 567640.48 E 4477.65 S 5321.60 E 5964104.80 N 567706.54 E 4528.77 S 5387.45 E 5964054.23 N 567772.81E 4580.17 S 5458.58 E 5964003.42 N 567844.37 E 4626.50 S 5529.94 E 5963957.69 N 567916.11E 4672.16 S 5606.39 E 5963912.66 N 567992.94 E 4718.62 S 5688.90 E 5963866.89 N 568075.82 E 4733.88 S 5717.49 E 5963851.87 N 568104.55 E 4769.52 S 5790.57 E 5963816.83 N 568177.91E 4783.09 S 5819.23 E 5963803.50 N 568206.69 E 4797.08 S 5847.70 E 5963789.75 N 568235.27 E 4810.97 S 5876.16 E 5963776.10 N 568263,85 E 4822.75 S 5900.52 E 5963764.52 N 568288.31E 4836.64 S 5929.08 E 5963750.87 N 568316.98 E 4850.28 S 5957.22 E 5963737.47 N 568345.23 E 4864.04 S 5986.42 E 5963723.95 N 568374.54 E 4876.88 S 6014.70 E 5963711.34 N 568402.93 E 4890.73 S 6045.58 E 5963697.75 N 568433.93 E 4903,68 S 6073.97 E 5963685.04 N 568462,42 E 4917:57 S 6103.71E 5963671.39 N 568492.28 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (fi) Comment 0.286 64O9.79 0.445 6487.65 0.884 6567.77 2.165 6647.02 2.472 6727.55 1.686 6810.50 1.910 6893.25 2.366 6976.25 3.228 7063.86 3.448 7148.93 3.525 7237.95 3.000 7332,50 4.750 7364.82 4.545 7445.60 9.931 7477.08 9.244 7508.60 2.179 7540.07 0.607 7566.95 0.283 7598.50 0.942 7629.56 4.550 7661.59 1.979 7692.34 3.120 7725.84 4.086 7756.74 1.225 7789.29 Continued... 26 August, 1999 - 14:04 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10965.48 81.580 114.940 6415.38 6509.38 10998.92 81.640 115.320 6420.26 6514.26 11031.69 81.710 115.920 6425.00 6519.00 11061.80 81.870 115.990 6429.30 6523.30 11094.86 81.420 116.090 6434.11 6528.11 11127.26 81.200 116.450 6439.00 6533.00 11157.65 81.770 115.230 6443.50 '6537.50 11190.06 83.530 114.540 6447.65 6541.65 11221.44 85.220 113.350 6450.72 6544.72 11252.43 85.450 113.320 6453.24 6547.24 11285.63 84.980 113.620 6456,01 6550.01 11320.07 85.800 113.290 6458.78 6552.78 11350.42 87.900 114.290 6460.45 6554.45 11384.68 87.220 113.610 6461.91 6555.91 11415.00 88.830 113.040 6462.95 6556.95 11446.05 90.710 116.010 6463.08 6557.08 11480.19 91.330 115.720 6462.47 6556.47 11509.95 91.300 114.350 6461.79 6555.79 11542.05 89.380 113.360 6461.60 6555.60 11574,25 87.010 112.600 6462.61 6556.61 11606.84 87.380 113.300 6464.21 6558.21 11637.90 86.980 113.440 6465.73 6559.73 11670.24 87.660 113.680 6467.25 6561.25 11702.97 88.730 114.710 6468.28 6562.28 11733.43 91.600 116.060 6468.19 6562.19 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4930.52 S 6131.34 E 5963658.68 N 568520.02 E 4944.56 S 6161.30 E 5963644.88 N 568550.08 E 4958.59 S 6190.53 E 5963631.10 N 568579.44 E 4971.63 S 6217.33 E 5963618.28 N 568606.34 E 4985.99 S 6246.72 E 5963604.17 N 568635.85 E 5000.16 S 6275.44 E 5963590.23 N 568664.68 E 5013.26 S 6302.49 E 5963577.35 N 568691.84 E 5026.79 S 6331.64 E 5963564.07 N 568721.11 E 5039.46 S 6360.18 E 5963551.64 N 568749.75 E 5051.70 S 6388.54 E 5963539.64 N 568778.22 E 5064.87 S 6418.89 E 5963526.71 N 568808.67 E 5078.54 S 6450.38 E 5963513.31 N 568840.27 E 5090.76 S 6478.11E 5963501.32 N 568868.10 E 5104.65 S 6509.39 E 5963487.69 N 568899.50 E 5116.65 S 6537.22 E 5963475.92 N 568927.42 E 5129.54 S 6565.46 E 5963463.27 N 568955.77 E 5144.43 S 6596.18 E 5963448.63 N 568986.61 E 5157.02 S 6623.13 E 5963436.27 N 569013.67 E 5170.00 S 6652.49 E 5963423.53 N 569043.13 E 5182.56 S 6682.11E 5963411.21N 569072.86 E 5195.26 $ 6712.09 E 5963398.77 N 569102.94 E 5207.56 S 6740.57 E 5963386.70 N 569131.52 E 5220.47 S 6770.18 E 5963374.04 N 569161.24 E 5233.88 S 6800.02 E 5963360.88 N 569191.19 E 5246.94 S 6827.53 E 5963348.05 N 569218.81 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (fi) Comment 1.027 7819.55 1.138 7852.37 1.824 7884.56 0.579 7914.17 1.394 7946.68 1.291 7978.52 4.391 8008.37 5.826 8040.23 6.576 8071.12 0.748 8101.62 1.678 8134.29 2.565 8168.20 7.662 8198.16 2.806 8232.01 5.633 8261.93 11.320 8292.67 2.005 8326.58 4.603 8356.09 6.730 8387.82 7.729 8419.57 2.427 8451.67 1.364 8482.30 2.230 8514.22 4.537 8546.59 10.412 8576.82 Continued... 26 August, 1999- 14:04 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, .1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11765.44 93.730 114.310 6466.70 6560.70 11797.49 93.890 112.420 6464.57 6558.57 11829.27 92.970 111.690 6462.67 6556.67 11862.70 92.400 110.410 6461.10 6555.10 11893.85 91.170 110.360 6460.13 6554.13 11925.94 89.080 108.710 6460.06 6554.06 11958.77 87.880 108.730 6460.93 '6554.93 11990.07 87.420 109.260 6462.22 6556..22 12021.57 86.740 108.800 6463.82 6557.82 12054.29 86.490 108.760 6465.75 6559.75 12085.97 86.370 108.830 6467.73 6561.73 12117.88 84.260 108.630 6470.33 6564.33 12150.85 83.070 108.810 6473.97 6567.97 12183.13 83.520 110.170 6477.74 6571.74 12213.54 84.390 109.740 6480.94 6574.94 12247.77 84.520 108.960 6484.25 6578.25 12279.99 84.270 108.820 6487.40 6581.40 12308.52 83.650 108.500 6490.40 6584.40 12344.05 83.410 108.980 6494.40 6588.40 12374.74 82.700 109.570 6498.11 6592.11 12409.78 82.500 109.680 6502.63 6596.63 12437.57 83.340 110.210 6506.05 6600.05 12470.18 86.000 109.520 6509.08 6603.08 12501.42 90.090 111.220 6510.15 6604.15 12533.19 93.670 111.190 6509.10 6603.10 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5260.54 S 6856.46 E 5963334.68 N 569247.85 E 5273.23 S 6885.82 E 5963322.25 N 569277.31 E 5285.14 S 6915.22 E 5963310.58 N 569306.81 E 5297.13 $ 6946.39 E 5963298.84 N 569338.08 E 5307.98 S 6975.57 E 5963288.24 N 569367.35 E 5318.71 S 7005.81 E 5963277.77 N 569397.68 E 5329.24 S 7036.89 E 5963267.49 N 569428.85 E 5339.42 S 7066.46 E 5963257.56 N 569458.50 E 5349.67 S . 7096.20 E 5963247.55 N 569488.32 E 5360.19 S 7127.13 E 5963237.29 N 569519.33 E 5370.38 S 7157.06 E 5963227.35 N 569549.35 E 5380.59 S 7187.18 E 5963217.39 N 569579.55 E 5391.11 S 7218.21 E 5963207.13 N 569610.67 E 5401.80 S 7248.43 E 5963196.69 N 569640.98 E 5412.12 S 7276.86 E 5963186.60 N 569669.49 E 5423.41S 7309.00 E 5963175.58 N 569701.73 E 5433.79 S 7339.34 E 5963165.45 N 569732.15 E 5442.87 S 7366.22 E 5963156.60 N 569759.11 E 5454.21 S 7399.65 E 5963145.54 N 569792.63 E 5464.27 S 7428.41 E 5963135.72 N 569821.47 E 5475.94 S 7461.14 E 5963124.32 N 569854.30 E 5485.35 S 7487.06 E 5963115.13 N 569880.30 E 5496.38 S 7517.60 E 5963104.35 N 569910.92 E 5507.24 S 7546.86 E 5963093.73 N 569940.27 E 5518.73 S 7576.46 E 5963082.49 N 569969.97 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Vertical Rate Section (°/lOOff) (ft) Comment 8.608 8608.53 5.905 8640.11 3.693 8671.31 4.188 8704.04 3.952 8734.49 8.298 8765.77 3.656 8797.65 2.241 8828.06 2.605 8858.66 0.774 8890.40 0.438 8921.12 6.642 8952.02 3.650 8983.85 4.410 9015.09 3.188 9044.61 2.300 9077.80 0.888 .9108.97 2.443 9136.52 1.503 9170.82 2.999 9200.48 0.650 9234.36 3.566 9261.29 8.425 9292.97 14.176 9323.49 11.269 9354.63 Continued... 26 August, 1999 - 14:04 - 8 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 Job No, AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12567.35 94.920 110.320 6506.55 6600.55 12595.66 94.470 111.030 6504.23 6598.23 12630.23 93.790 111.260 6501.74 6595.74 12662.50 93.110 111.410 6499.80 6593.80 12691.94 91.940 110.910 6498.50 6592.50 12726.01 88.400 110.410 6498.40 6592.40 12757.34 87.540 111.370 6499.51 '6593.51 12789.71 87.660 111.460 6500.86 6594.86 12818.91 88.250 111.690 6501.91 6595.91 12851.28 90.060 112.340 6502.38 6596.38 12881.96 90.250 112.590 6502.30 6596.30 12917.92 90.550 112.710 6502.05 6596.05 12949.64 90.710 112.710 6501.70 6595.70 12982.37 90.180 112.600 6501.45 6595.45 13014.49 89.570 112.600 6501.52 6595.52 13046.68 89.600 113.200 6501.75 6595.75 13078.44 89.720 113.280 6501.94 6595.94 13110.83 89.910 113.660 6502.04 6596.04 13142.83 90.000 114.080 6502.07 6596.07 13173.79 89.970 113.660 6502.08 6596.08 13206.53 89.080 112.910 6502.35 6596.35 13238.94 90.220 113.380 6502.55 6596.55 13268.69 90.740 113.370 6502.30 6596.30 13303.47 92.030 112.120 6501.46 6595.46 13335.22 93.020 111.910 6500.06 6594.06 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5530.80 S 7608.31 E 5963070.69 N 570001.92 E 5540.76 S 7634.71 E 5963060.94 N 570028.40 E 5553.20 S 7666.87 E 5963048.77 N 570060.66 E 5564.92 S 7696.87 E 5963037.30 N 570090.76 E 5575.53 S 7724.30 E 5963026.92 N 570118.27 E 5587.55 S 7756.17 E 5963015.16 N 570150.25 E 5598.72 S 7785.42 E 5963004.24 N 570179.59 E 5610.52 S 7815.53 E 5962992.68 N 570209.80 E 5621.26 S 7842.67 E 5962982.18 N 570237.02 E 5633.39 S 7872.67 E 5962970.30 N 570267.13 E 5645.11S 7901.02 E 5962958.81N 570295.57 E 5658.96 S 7934.21 E 5962945.24 N 570328.87 E 5671.20 S 7963.47 E 5962933.24 N 570358.23 E 5683.81S 7993.67 E 5962920.88 N 570388.54 E 5696.15 S 8023.33 E 5962908.78 N 570418.30 E 5708.68 S 8052.98 E 5962896.51N 570448.05 E 5721.21 S 8082.16 E 5962884.22 N 570477.34 E 5734.11 S 8111.87 E 5962871.56 N 570507.15 E 5747.06 S 8141.13 E 5962858.86 N 570536.52 E 5759.59 S 8169.45 E 5962846.57 N 570564.94 E 5772.53 S 8199.52 E 5962833.87 N 570595.11 E 5785.27 S 8229.32 E 5962821.38 N 570625.02 E 5797.07 S 8256.63 E 5962809.81 N 570652.42 E 5810.51 S 8288.69 E 5962796.63 N 570684.60 E 5822.40 S 8318.10 E 5962784.99 N 570714.10 E Alaska State Plane Zone 4 Kuparuk lC Dogleg Rate (°/~00ft) Vertical Section (ft) Comment 4.454 2.962 2.076 2.158 4.321 10.493 4.112 0.463 2.168 5.941 1.023 0.899 0.504 1.654 1.899 1.866 0.454 1.312 1.342 1.360 3.555 3.805 1.748 5.164 3.187 9387.99 9415.61 9449.42 9481.03 9509.87 9543.21 9573.89 9605.63 9634.29 9666.12 9696.33 9731.77 9763.03 9795.28 9826.93 9858.67 9890.02 9922.01 9953.65 9984.27 10016.59 10048.57 10077.94 10112.22 10143.41 Continued... 26 August, 1999 - 14:04 - 9 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 · Job No. AKMM90131, Surveyed: 27 July, '1999 · Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 13366.23 92,590 109,670 6498.54 6592.54 13398.75 89.290 106,850 6498.01 6592.01 13431.16 88,430 106,430 6498.65 6592.65 13462.11 88.120 106.140 6499.58 6593.58 13495.29 88,550 105,820 6500.55 6594.55 13526.14 90,520 106.140 6500.80 6594.80 13557.87 91.600 106.240 6500.21 '6594.21 13590.92 92.460 105.480 6499.04 6593.04 13623.07 92.280 104.360 6497.71 6591.71 13653.58 91.760 103.840 6496.63 6590.63 13685.57 91.110 103.230 6495.83 6589.83 13717.46 90.830 103.010 6495.29 6589.29 13748.48 90.650 102.420 6494.89 6588.89 13781.73 90.340 101.820 6494.61 6588.61 13813.88 90.150 102.130 6494.47 6588.47 13844.33 89.230 102.110 6494.63 6588.63 13874.44 89.260 102.420 6495.03 6589.03 13906.97 89.630 103.010 6495.34 6589.34 13936.86 91.050 102.750 6495.17 6589.17 13974.45 91.940 100.780 6494.19 6588.19 14006.81 90.710 99.700 6493.44 6587.44 14036.62 91.070 99.570 6492.98 6586.98 14070.16 89.750 99.130 6492.74 6586.74 14101.61 88.490 99.080 6493.22 6587.22 14137.14 86.740 98.720 6494.70 6588.70 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5833.40 S 8347.05 E 5962774.24 N 570743.15 E 5843.58 S 8377.92 E 5962764.31 N 570774.10 E 5852.86 S 8408.97 E 5962755.29 N 570805.22 E 5861.54 S 8438.66 E 5962746.86 N 570834.99 E 5870.67 S 8470.55 E 5962737.99 N 570866.95 E 5879.16 S 8500.20 E 5962729.75 N 570896.67 E 5888.00 S 8530.67 E 5962721.16 N 570927.21 E 5897.03 S 8562.44 E 5962712.39 N 570959.06 E 5905.30 S 8593.48 E 5962704.38 N 570990.16 E 5912.73 S 8623.05 E 5962697.20 N 571019.80 E 5920.21S 8654.14 E 5962689.97 N 571050.95 E 5927.45 S 8685.19 E 5962682.99 N 571082.06 E 5934.28 S 8715.45 E 5962676.42 N 571112.37 E 5941.26 S 8747.96 E 5962669.71 N 571144.94 E 5947.93 S 8779.41 E 5962663.30 N 571176.44 E 5954.32 S 8809.18 E 5962657.15 N 571206.27 E 5960.72 S 8838.60 E 5962651.00 N 571235.74 E 5967.88 S 8870.33 E 5962644.11 N 571267.53 E 5974.54 S 8899.47 E 5962637.69 N 571296.72 E 5982.20 S 8936.25 E 5962630.33 N 571333.57 E 5987.95 S 8968.09 E 5962624.84 N 571365.45 E 5992.94 S 8997.47 E 5962620.10 N 571394.87 E 5998.39 S 9030.57 E 5962614.93 N 571428.01E 6003.37 S 9061.62 E 5962610.21 N 571459.10 E 6008.86 S 9096.69 E 5962605.01N 571494.22 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100.) Vertical Section (ft) Comment 7.347 13.347 2.953 1.371 1.615 6.469 3.418 3.472 3.525 2.410 2.786 1.117 1.988 2.031 1.131 3.022 1.034 2.141 4.830 5.749 5.058 1.284 4.148 4.010 5.028 10173.74 10205.26 10236.43 10266.15 10297.95 10327.53 10357.99 10389.64 10420.27 10449.21 10479.46 10509.55 10538.75 10569.92 10600.04 10628.59 10656.85 10687.47 10715.63 10750.78 10780.73 10808.21 10839.06 10867.93 10900.47 Continued... 26 August, 1999- 14:04 - 10- DrlllQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 14167.38 85.850 99.050 6496.65 6590.65 6013.52 S 9126.50 E 5962600.60 N 571524.07 E 14198.21 85.290 99.450 6499.03 6593.03 6018.46 S 9156.84 E 5962595.91 N 571554.45 E 14228.40 85.720 99.190 6501.40 6595.40 6023.33 S 9186.54 E 5962591.28 N 571584.19 E 14248.84 87.170 99.720 6502.67 6596.67 6026.69 S 9206.66 E 5962588.10 N 571604.34 E 14279.52 87.200 99.040 6504.17 6598.17 6031.68 S 9236.89 E ' 5962583.35 N 571634.61 E 14323.54 87.510 99.670 6506.20 6600.20 6038.83 S 9280.28 E 5962576.57 N 571678.05 E 14354.94 87.380 99.540 6507.60 '6601.60 6044.06 S 9311.21 E 5962571.59 N 571709.03 E 14389.44 87.260 98.950 6509.22 6603.22 6049.60 S 9345.23 E 5962566.33 N 571743.09 E 14418.58 87.010 99.430 6510.67 6604.67 6054.25 S 9373.96 E 5962561.93 N 571771.85 E 14454.42 86.180 99.780 6512.80 6606.80 6060.22 S 9409.23 E 5962556.25 N 571807.18 E 14487.11 85.940 99.690 6515.05 6609.05 6065.73 S 9441.37 E 5962551.00 N 571839.36 E 14516.00 85.530 100.290 6517.20 6611.20 6070.73 S 9469.75 E 5962546.24 N 571867.78 E 14566.71 84.580 101.280 6521.57 6615.57 6080.18 S 9519.37 E 5962537.20 N 571917.48 E 14630.00 84.580 101.280 6527.55 6621.55 6092.51 S ' 9581.16 E 5962525.39 N 571979.37 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100fi) Vertical Section (ft) Comment 3.138 2.230 1.663 7.551 2.216 1.594 0.585 1.743 1.855 2.513 0.784 2.511 2.700 0.000 10928.13 10956.38 10984.06 11002.84 11031.03 11071.48 11100.38 11132.06 11158.79 11191.76 11221.85 11248.47 11295.42 11354.18 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 122.452° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14630.00ft., The Bottom Hole Displacement is 11354.18ft., in the Direction of 122.452° (True). Con#nue~.. 26 August, 1999 - 14:04 - 11 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July,'1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C Comments Measured Depth (ft) 14630.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6621.55 6092.51 S 9581.16 E Comment PROJECTED SURVEY 26 August, 1999- 14:04 - 12- DrillQuest Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C, Slot 1C-26 1C-26 Job No. AKMM90131, Surveyed: 27 July, 1999 SURVEY REPORT 26 August, 1999 Your Ref: API500292294400 Surface Coordinates: 5968538.08 N, 562347.92 E (70° 19' 28.4410" N, Kelly Bushing: 94.0Oft above Mean Sea Level 149 ° 29' 39. 9939" W) D,,R I L. L I N G I~ E R V I I: E S Survey Ref: svy8840 A tlALLIBURTON CON~PA~Y Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMMg0131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -94.00 0.00 189.24 0.340 16.710 95.24 189.24 290.21 0.100 45.890 196.21 290.21 374.41 1.120 174.630 280.40 374.40 462.47 2.210 179.390 368.42 462.42 556.27 3.830 192.510 462.09 556.09 647.46 5.570 179.820 552.97 646.97 737.31 6.390 177.770 642.33 736.33 824.27 6.110 177.320 728.78 822.78 915.40 6.530 176.830 819.35 913.35 1004.21 6.770 177.990 907.57 1001.57 1095.04 7.080 169.990 997.74 1091.74 1186.21 8.390 156.530 1088.08 1182.08 1279.14 9.300 146.910 1179.91 1273.91 1372.84 10.680 138.350 1272.19 1366.19 1465.87 12.890 128.850 i363.26 1457.26 1560.65 14.430 132.500 1455.36 1549.36 1654.45 17.350 137.220 1545.57 1639.57 1748.66 20.200 138.760 1634.76 1728.76 1844.92 22.320 134.670 1724.47 1818.47 1939.10 25.170 130.760 1810.67 1904.67 2032.17 28.430 130.540 1893.74 1987.74 2126.05 30.640 131.660 1975.41 2069.41 2220.05 33.500 132.480 2055.06 2149.06 2314.20 36.870 133.220 2132.00 2226.00 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5968538.08 N 562347.92 E 0.54 N 0.16 E 5968538.62 N 562348.08 E 0.89 N 0.31E 5968538.97 N 562348.22 E 0.12 N 0.44 E 5968538.20 N 562348.36 E 2.44 S 0.54 E 5968535.65 N 562348.48 E 7.30 S 0.12W 5968530.78 N 562347.86 E 14.70 S 0.77W 5968523.37 N 562347.28 E 24.06 S 0.56W 5968514.02 N 562347.56 E 33.52 S 0.15W 5968504.56 N 562348.05 E 43.54 S 0.36 E 5968494.55 N 562348.64 E 53.81 S 0.82 E 5968484.28 N 562349.19 E 64.67 S 1.98 E 5968473.42 N 562350.44 E 76.31S 5.61E 5968461.82 N 562354.16 E 88.82 S 12.41E 5968449.37 N 562361.07 E 101.65 S 22.31 E 5968436.62 N 562371.08 E 114.61S 36.13 E 5968423.78 N 562385.00 E 129.22 S 53.07 E 5968409.31 N 562402.06 E 147.38 S 71.19 E 5968391.29 N 562420.33 E 169.93 S 91.46 E 5968368.92 N 562440.79 E 195.28 S 115.42 E 5968343.77 N 562464.95 E 220.94 S 143.31E 5968318.34 N 562493.06 E 248.26 S 175.15 E 5968291.28 N 562525.12 E 278.70 S 210.01E 5968261.14 N 562560.24 E 312.14 S 247.04 E 5968228.00 N 562597.55 E 349.04S 286.80 E 5968191.43 N 562637.61E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100ft) (ft) Comment 0.00 0.180 -0.15 0.255 -0.21 1.408 0.31 1.247 1.76 1.867 3.82 2.212 7.24 0.943 12.44 0.327 17.86 0.465 23.67 0.310 29.57 1.114 36.38 2.443 45.68 1.865 58.13 2.160 73.38 3.154 91.98 1.861 114.12 3.402 139.16 3.070 168.36 2.687 202.18 3.456 239.48 3.504 281.01 2.426 326.76 3.078 375.96 3.608 ' 429.31 Continued... 26 August, 1999 - 14:04 - 2- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMMg0131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2408.16 40.060 133.520 2205.56 2299.56 2500.53 43.480 133.230 2274.44 2368.44 2599.32 46.350 132.750 2344.39 2438.39 2691.21 49.330 131.870 2406.06 2500.06 2786.52 52.500 131.730 2466.14 2560.14 2880.31 55.470 130.670 2521.29 2615.29 2972.48 58.420 130.010 2571.56 2665.56 3067.67 59.560 130.390 2620.60 2714.60 3163.01 58.780 130.390 2669.46 2763.46 3254.75 58.620 130.490 2717.12 2811.12 3350.44 58.780 130.060 2766.83 2860.83 3444.09 58.570 130.050 2815.52 2909.52 3534.85 60.130 129.370 2861.79 2955.79 3627.22 59.490 129.250 2908.24 3002.24 3720.52 59.250 129.950 2955.77 3049.77 3816.37 58.440 130.140 3005.36 3099.36 3910.09 59.460 130.520 3053.70 3147.70 4003.64 60.490 129.560 3100.51 3194.51 4096.26 59.440 130.290 3146.87 3240.87 4189.68 58.530 130.900 3195.00 3289.00 4281.92 58.620 129.280 3243.10 3337.10 4376.01 59.290 129.410 3291.62 3385.62 4469.72 60.130 129.100 3338.89 3432.89 4564.49 61.270 127.950 3385.26 3479.26 4656.08 60.410 127.970 3429.89 3523.89 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 389.18 S 329.28 E 5968151.65 N 562680.42 E 431.43 S 374.00 E 5968109.78 N 562725.49 E 478.98 S 425.02 E 5968062.65 N 562776.91E 524.81S 475.40 E 5968017.24 N 562827.66 E 574.11 S 530.54 E 5967968.39 N 562883.21 E 624.07 S 587.62 E 5967918.92 N 562940.71 E 674.06 S 646.50 E 5967869.41N 563000.00 E 726.72 S 708.81E 5967817.27 N 563062.75 E 779.77 S 771.17 E 5967764.74 N 563125.54 E 830.62 S 830.83 E 5967714.39 N 563185.62 E 883.48'S 893.21 E 5967662.06 N 563248.44 E 934.96 S 954.44 E 5967611.09 N 563310.10 E 984.84 S 1014.51 E 5967561.71 N 563370.58 E 1035.42 S 1076.28 E 5967511.64 N 563432.77 E 1086.59 S 1138.14 E 5967460.98 N 563495.05 E 1139.36 S 1200.94 E 5967408.73 N 563558.28 E 1191.33 S 1262.14 E 5967357.28 N 563619.92 E 1243.43 S 1324.15 E 5967305.69 N 563682.36 E 1294.89 S 1385.65 E 5967254.75 N 563744.28 E 1346.98 S 1446.44 E 5967203.16 N 563805.50 E 1397.67 S 1506.65 E 5967152.98 N 563866.13 E 1448.78S 1568.99 E 5967102.39 N 563928.90 E 1499.98 S 1631.65 E 5967051.71N 563991.98 E 1551.45 S 1696.31 E 5967000.78 N 564057.06 E 1600.65 S 1759.37 E 5966952.11N 564120.53 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 3.401 3.708 2.925 3.320 3.328 3.296 3.256 1.246 0.818 0.198 0.419 0.224 1.836 0.702 0.695 0.862 11142 1.415 1.323 1.123 1.502 0.722 0.941 1.602 0.939 486.69 547.10 615.66 682.77 755.76 830.73 907.24 988.08 1069.16 1146.79 1227.79 1307.09 1384.54 1463.81 1543.47 1624.77 1704.30 1784.59 1864.09 1943.35 2021.35 2101.38 2181.73 2263.91 2343.52 Continued... 26 August, 1999- 14:04 - 3- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 4752.20 59.950 125.850 3477.69 3571.69 4844.37 59.140 127.720 3524.41 3618.41 4938.01 58.780 127,840 3572.70 3666,70 5031.37 60.000 127.830 3620.24 3714.24 5124.57 59,010 127,980 3667.53 3761.53 5217.86 58.650 127.570 3715.82 3809.82 5310.90 59.820 126.510 3763.41 3857.41 5405.62 58.700 125.060 3811,82 3905.82 5498.87 57.790 126.060 3860.90 3954.90 5591.89 58.600 129,020 3909.93 4003.93 5686.22 57.970 129.890 3959.52 4053.52 5779.08 58.610 129.360 4008,33 4102.33 5872,17 58.520 131.280 4056.88 4150.88 5965.49 60,800 131.890 4104.02 4198,02 6061.04 61.640 130.550 4150.02 4244.02 6154.66 60,910 130.060 4195.02 4289.02 6247.50 60.440 130.030 4240.49 4334.49 6339.87 59.720 129.610 4286.56 4380.56 6422.89 59.150 129.480 4328.78 4422.78 6532.25 58.510 129.750 4385.38 4479,38 6626,93 60,690 130.960 4433.29 4527.29 6721.92 60.560 129.790 4479.88 4573.88 6815.94 60.350 130.320 4526.25 4620.25 6909.11 60.170 130.650 4572.46 4666.46 7003.62 59,900 130.950 4619.67 4713.67 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1650.73 S 1826.04 E 5966902.58 N 564187.61E 1698.30 S 1889.67 E 5966855.54 N 564251.64 E 1747.45 S 1953.08 E 5966806.92 N 564315.46 E 1796.73 S 2016.54 E 5966758.16 N 564379.32 E 1846.07 S 2079.91E 5966709.35 N 564443.09 E 1894.97 S 2143.00 E 5966660.98 N 564506.59 E 1943.12 S 2206.82 E 5966613.36 N 564570.80 E 1990.73 S 2272.85 E 5966566.31 N 564637.23 E 2036.83 S 2337.35 E 5966520.74 N 564702.12 E 2085.00 S 2400.02 E 5966473.09 N 564765.18 E 2135.99 S 2461.98 E 5966422.62 N 564827.56 E 2186.37 S 2522.83 E 5966372.75 N 564888.82 E 2237.76 S 2583.38 E 5966321.86 N 564949.80 E 2291.22 S 2643.61 E 5966268.91 N 565010.48 E 2346.40S 2706.61 E 5966214.25 N 565073.93 E 2399.50 S 2769.22 E 5966161.67 N 565136.98 E 2451.58 S 2831.18 E 5966110.11N 565199.37 E 2502.85 S 2892.67 E 5966059.35 N 565261.28 E 2548.36 S 2947.79 E 5966014.30 N 565316.78 E 2608.03 S 3019.88 E 5965955.24 N 565389.36 E 2660.91 S 3082.09 E 5965902.87 N 565452.02 E 2714.53 S 3145.15 E 5965849.78 N 565515.52 E 2767.16 S 3207.76 E 5965797.66 N 565578.56 E 2819.69 S 3269.29 E 5965745.65 N 565640.53 E 2873.19 S 3331.27 E 5965692.67 N 565702.95 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/100fi) (fi) Comment 1.972 2426.65 1.957 2505.87 0.400 2585.76 1.307 2665.75 1.071 2745.70 0.539 2825.17 1.594 2904.86 1.769 2986.13 1.336 3065.30 2.841 3144.03 1.030 3223.67 0.843 3302.05 1.762 3380.73 2.507 3460.24 1.511 3543.00 0.905 3624.33 0.507 3704.56 0.873 3783.96 0.700 3854.90 0.622 3947.74 2.553 4028.62 1.082 4110.60 0.539 4191.68 0.363 4271.78 0.397 4352.79 Continued... 26 August, 1999 - 14:04 - 4 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No, AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7098.64 59.800 130.480 4667.40 4761.40 7190.52 59.450 130.640 4713.86 4807.86 7285.77 59.180 130.540 4762.46 4856.46 7379.31 58.880 131.090 4810.60 4904.60 7471.69 58.540 131.470 4858.58 4952.58 7565.28 58.190 131.740 4907.67 5001.67 7657.80 57.970 131.900 4956.58 5050.58 7751.77 59.100 130.400 5005.64 5099.64 7847.01 59.470 129.350 5054.28 5148.28 7939.93 59.080 129.720 5101.76 5195.76 8032.93 58.810 129.410 5149.73 5243.73 8125.03 58.520 129.520 5197.63 5291.63 82i8.71 58.300 129.270 5246.70 5340.70 8312.46 58.140 129.450 5296.08 5390.08 8406.61 57.980 129.990 5345.88 5439.88 8500.66 57.730 129.680 5395.92 5489.92 8592.96 57.190 129.910 5445.57 5539.57 8687.74 58.380 127.590 5496.10 5590.10 8779.78 58.390 126.540 5544.35 5638.35 8873.25 57.580 126.400 5593.90 5687.90 8967.81 58.320 126.820 5644.08 5738.08 9060.95 58.070 127.750 5693.17 5787.17 9153.20 58.170 128.340 5741.89 5835.89 9246.51 58.400 127.640 5790.94 5884.94 9341.55 58.270 127.910 5840.84 5934.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2926.78 S 3393.55 E 5965639.59 N 565765.67 E 2978.32 S 3453.77 E 5965588.55 N 565826.32 E 3031.62 S 3515.97 E 5965535.78 N 565888.96 E 3084.04 S 3576.68 E 5965483.86 N 565950.10 E 3136.12 S 3636.00 E 5965432.27 N 566009.85 E 3189.03 S 3695.58 E 5965379.86 N 566069.87 E 3241.40 S 3754.11E 5965327.99 N 566128.83 E 3294.13 S 3814.46 E 5965275.75 N 566189.62 E 3346.62 S 3877.30 E 5965223.79 N 566252.89 E 3397.47 S 3938.90 E 5965173.45 N 566314.91E 3448.21'S 4000.32 E 5965123.22 N 566376.75 E 3498.22 S 4061.05 E 5965073.73 N 566437.90 E 3548.86 S 4122.72 E 5965023.59 N 566499.98 E 3599.40 S 4184.34 E 5964973.57 N 566562.02 E 3650.46 S 4245.79 E 5964923.02 N 566623.89 E 3701.47 S 4306.94 E 5964872.52 N 566685.47 E 3751.27 S 4366.73 E 5964823.22 N 566745.66 E 3801.45 S 4429.26 E 5964773.56 N 566808.61 E 3848.69 S 4491.80 E 5964726.84 N 566871.55 E 3895.80 S 4555.54 E 5964680.27 N 566935.67 E 3943.59 S 4619.87 E 5964633.01 N 567000.40 E 3991.54 S 4682.85 E 5964585.58 N 567063.77 E 4039.82 S 4744.54 E 5964537.82 N 567125.86 E 4088.68S 4807.10 E 5964489.48 N 567188.82 E 4138.23 S 4871.04 E 5964440.47 N 567253.17 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 0.440 4434.10 0.409 4512.58 0.297 4593.67 0.598 4673.02 0.509 4751.03 0.447 4829.69 0.279 4907.18 1.816 4986.40 1.024 5067.59 0.542 5146.86 0.407 5225.92 0.331 5304.00 0.327 5383.21 0.236 5462.33 0.516 5541.58 0.385 5620.55 0.622 5697.72 2.422 5777.42 0.972 5855.54 0.876 5934.60 0.868 6014.54 0.890 6093.41 0.554 6171.37 0.684 6250.38 0.278 6330.92 ContinUed... 26 August, 1999 - 14:04 - 5 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. 9434.84 58.020 9527.05 57.970 9621.99 57.730 9715.19 59.080 9808.34 60.900 9902.95 62.270 9996.19 63.860 10088.28 65.870 10183.94 67.270 10275.57 69.180 10369.96 72.15o 10468.73 74.820 10502.24 75.820 10585.66 78.390 10617.89 81.230 10649.87 84.180 10681.69 84.630 10708.87 84.700 10740.76 84.690 10772.16 84.850 10804.60 83.760 10835.85 83.710 10869.94 82.650 10901.44 81.530 10934.63 81.5o0 Azim. 128.o20 127.54o 126.59o 124.83o 126.46o 127.39o 128.290 127.360 124.360 121.650 12o.o60 118.72o 117.44o 114.58o 116.o8o 116.270 115.740 115.89o 115.980 115.730 114.730 114.11o 114.20o 114.84o 115.250 Sub-Sea Depth (ft) 5890.07 5938.94 5989.46 6038.30 6084.88 6129.90 6172.14 6211.25 6249.30 6283.29 6314.54 6342.62 6351.11 6369.73 6375.43 6379.49 6382.59 6385.12 6388.07 6390.93 6394.15 6397.56 6401.61 6405.94 6410.84 Vertical Depth (ft) 5984.07 6032.94 6083.46 6132.30 6178.88 6223.90 6266.14 6305.25 6343.30 6377.29 6408.54 6436.62 6445.11 6463.73 6469.43 6473.49 6476.59 6479.12 6482.07 6484.93 6488.15 6491.56 6495.61 6499.94 6504.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4186.97 S 4933.51 E 5964392.24 N 567316.04 E 4234.88 S 4995.31E 5964344.85 N 567378.24 E 4283.33 S 5059.45 E 5964296.94 N 567442.78 E 4329.65 S 5123.91E 5964251.15 N 567507.62 E 4376.66 S 5189.44 E 5964204.69 N 567573.55 E 4426.65 S 5255.96 E 5964155.25 N 567640.48 E 4477.65 $ 5321.60 E 5964104.80 N 567706.54 E 4528.77 S 5387.45 E 5964054.23 N 567772.81E 4580.17 S 5458.58 E 5964003.42 N 567844.37 E 4626.50 S 5529.94 E 5963957.69 N 567916.11 E 4672.16 S 5606.39 E 5963912.66 N 567992.94 E 4718.62 S 5688.90 E 5963866.89 N 568075.82 E 4733.88 S 5717.49 E 5963851.87 N 568104.55 E 4769.52 S 5790.57 E 5963816.83 N 568177.91E 4783.09 S 5819.23 E 5963803.50 N 568206.69 E 4797.08 S 5847.70 E 5963789.75 N 568235.27 E 4810.97 S 5876.16 E 5963776.10 N 568263.85 E 4822.75 S 5900.52 E 5963764.52 N 568288.31E 4836.64 S 5929.08 E 5963750.87 N 568316.98 E 4850.28 S 5957.22 E 5963737.47 N 568345.23 E 4864.04 S 5986.42 E 5963723.95 N 568374.54 E 4876.88 S 6014.70 E 5963711.34 N 568402.93 E 4890.73 S 6045.58 E 5963697.75 N 568433.93 E 4903.68 S 6073.97 E 5963685.04 N 568462.42 E 4917.57S 6103.71 E 5963671.39 N 568492.28 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (ft) Comment o.286 6409.79 0.445 6487.65 0.884 6567.77 2.165 6647.02 2.472 6727.55 1.686 6810.5o 1.910 6893.25 2.366 6976.25 3.228 7063.86 3.448 7148.93 3.525 7237.95 3.000 7332.50 4.750 7364.82 4.545 7445.60 9.931 7477.08 9.244 7508.60 2.179 7540.07 0.607 7566.95 0.283 7598.50 0.942 7629.56 4.550 7661.59 1.979 7692.34 3.12o 7725.84 4.o86 7756.74 1.225 7789.29 Continued... 26 August, 1999 - 14:04 - 6 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 10965.48 81.580 114.940 6415.38 6509.38 10998.92 81.640 115.320 6420.26 6514.26 11031.69 81.710 115.920 6425.00 6519.00 11061.80 81.870 115.990 6429.30 6523.30 11094.86 81.420 116.090 6434.11 6528.11 11127.26 81.200 116.450 6439.00 6533.00 11157.65 81.770 115.230 6443.50 6537.50 11190.06 83.530 114.540 6447.65 6541.65 11221.44 85.220 113.350 6450.72 6544.72 11252.43 85.450 113.320 6453.24 6547.24 11285.63 84.980 113.620 6456.01 6550.01 11320.07 85.800 113.290 6458.78 6552.78 11350.42 87.900 114.290 6460.45 6554.45 11384.68 87.220 113.610 6461.91 6555.91 11415.00 88.830 113.040 6462.95 6556.95 11446.05 90.710 116.010 6463.08 6557.08 11480.19 91.330 115.720 6462.47 6556.47 11509.95 91.300 114.350 6461.79 6555.79 11542.05 89.380 113.360 6461.60 6555.60 11574.25 ~ 87.010 112.600 6462.61 6556.61 11606.84 87.380 113.300 6464.21 6558.21 11637.90 86.980 113.440 6465.73 6559.73 11670.24 87.660 113.680 6467.25 6561.25 11702.97 88.730 114.710 6468.28 6562.28 11733.43 91.600 116.060 6468.19 6562.19 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4930.52 S 6131.34 E 5963658.68 N 568520.02 E 4944.56 S 6161.30 E 5963644.88 N 568550.08 E 4958.59 S 6190.53 E 5963631.10 N 568579.44 E 4971.63 S 6217.33 E 5963618.28 N 568606.34 E 4985.99 S 6246.72 E 5963604.17 N 568635.85 E 5000.16 S 6275.44 E 5963590.23 N 568664.68 E 5013.26 S 6302.49 E 5963577.35 N 568691.84 E 5026.79 S 6331.64 E 5963564.07 N 568721.11 E 5039.46 S 6360.18 E 5963551.64 N 568749.75 E 5051.70 S 6388.54 E 5963539.64 N 568778.22 E 5064.87 S 6418.89 E 5963526.71N 568808.67 E 5078.54 S 6450.38 E 5963513.31 N 568840.27 E 5090.76 S 6478.11E 5963501.32 N 568868.10 E 5104.65 S 6509.39 E 5963487.69 N 568899.50 E 5116.65 S 6537.22 E 5963475.92 N 568927.42 E 5129.54 S 6565.46 E 5963463.27 N 568955.77 E 5144.43 S 6596.18 E 5963448.63 N 568986.61E 5157.02 S 6623.13 E 5963436.27 N 569013.67 E 5170.00 S 6652.49 E 5963423.53 N 569043.13 E 5182.56 S 6682.11E 5963411.21N 569072.86 E 5195.26 S 6712.09 E 5963398.77 N 569102.94 E 5207.56 S 6740.57 E 5963386.70 N 569131.52 E 5220.47 S 6770.18 E 5963374.04 N 569161.24 E 5233.88 S 6800.02 E 5963360.88 N 569191.19 E 5246.94 S 6827.53 E 5963348.05 N 569218.81 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 1.027 1.138 1.824 0.579 1.394 1.291 4.391 5.826 6.576 0.748 1.678 2.565 7.662 2.806 5.633 11.320 2.005 4.603 6.730 7.729 2.427 1.364 2.230 4.537 10.412 7819.55 7852.37 7884.56 7914.17 7946.68 7978.52 8008.37 8040.23 8071.12 8101.62 8134.29 8168.20 8198.16 8232.01 8261.93 8292.67 8326.58 8356.09 8387.82 8419.57 8451.67 8482.30 8514.22 8546.59 8576.82 ContinUed... 26 August, 1999- 14:04 - 7- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11765.44 93.730 114.310 6466.70 6560.70 11797.49 93.890 112.420 6464.57 6558.57 11829.27 92.970 111.690 6462.67 6556.67 11862.70 92.400 110.410 6461.10 6555.10 11893.85 91.170 110.360 6460.13 6554.13 11925.94 89.080 108.710 6460.06 6554.06 11958.77 87.880 108.730 6460.93 6554.93 11990.07 87.420 109.260 6462.22 6556.22 12021.57 86.740 108.800 6463.82 6557.82 12054.29 86.490 108.760 6465.75 6559.75 12085.97 86.370 108.830 6467.73 6561.73 12117.88 84.260 108.630 6470.33 6564.33 12150.85 83.070 108.810 6473.97 6567.97 12183.13 83.520 110.170 6477.74 6571.74 12213.54 84.390 109.740 6480.94 6574.94 12247.77 84.520 108.960 6484.25 6578.25 12279.99 84.270 108.820 6487.40 6581.40 12308.52 83.650 108.500 6490.40 6584.40 12344.05 83.410 108.980 6494.40 6588.40 12374.74 82.700 109.570 6498.11 6592.11 12409.78 82.500 109.680 6502.63 6596.63 12437.57 83.340 110.210 6506.05 6600.05 12470.18 86.000 109.520 6509.08 6603.08 12501.42 90.090 111.220 6510.15 6604.15 12533.19 93.670 111.190 6509.10 6603.10 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5260.54 S 6856.46 E 5963334.68 N 569247.85 E 5273.23 S 6885.82 E 5963322.25 N 569277.31 E 5285.14 S 6915.22 E 5963310.58 N 569306.81E 5297.13 S 6946.39 E 5963298.84 N 569338.08 E 5307.98 S 6975.57E 5963288.24 N 569367.35 E 5318.71 S 7005.81 E 5963277.77 N 569397.68 E 5329.24 S 7036.89 E 5963267.49 N 569428.85 E 5339.42 S 7066.46 E 5963257.56 N 569458.50 E 5349.67 S 7096.20 E 5963247.55 N 569488.32 E 5360.19 S 7127.13 E 5963237.29 N 569519.33 E 5370.38 S 7157.06 E 5963227.35.N 569549.35 E 5380.59 S 7187.18 E 5963217.39 N 569579.55 E 5391.11 S 7218.21 E 5963207.13 N 569610.67 E 5401.80 S 7248.43 E 5963196.69 N 569640.98 E 5412.12 S 7276.86 E 5963186.60 N 569669.49 E 5423.41 S 7309.00 E 5963175.58 N 569701.73 E 5433.79 S 7339.34 E 5963165.45 N 569732.15 E 5442.87 S 7366.22 E 5963156.60 N 569759.11 E 5454.21 S 7399.65 E 5963145.54 N 569792.63 E 5464.27 S 7428.41 E 5963135.72 N 569821.47 E 5475.94 S 7461.14 E 5963124.32 N 569854.30 E 5485.35 S 7487.06 E 5963115.13 N 569880.30 E 5496.38 S 7517.60 E 5963104.35 N 569910.92 E 5507.24 S 7546.86 E 5963093.73 N 569940.27 E 5518.73 S 7576.46 E 5963082.49 N 569969.97 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100fi) Vertical Section (ft) Comment 8.608 5.905 3.693 4.188 3.952 8.298 3.656 2.241 2.605 0.774 0.438 6.642 3.650 4.410 3.188 2.300 0.888 2.443 1.503 2.999 0.650 3.566 8.425 14.176 11.269 8608.53 8640.11 8671.31 8704.04 8734.49 8765.77 8797.65 8828.06 8858.66 8890.40 8921.12 8952.02 8983.85 9015.09 9044.61 9077.80 9108.97 9136.52 9170.82 9200.48 9234.36 9261.29 9292.97 9323.49 9354.63 Continued... 26 August, 1999 - 14:04 - 8 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMMg0131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 12567.35 94.920 110.320 6506.55 6600.55 12595.66 94.470 111.030 6504.23 6598.23 12630.23 93.790 111.260 6501.74 6595.74 12662.50 93.110 111.410 6499.80 6593.80 12691.94 91.940 110.910 6498.50 6592.50 12726.01 88.400 110.410 6498.40 6592.40 12757.34 87.540 111.370 6499.51 6593.51 12789.71 87.660 111.460 6500.86 6594.86 12818.91 88.250 111.690 6501.91 6595.91 12851.28 90.060 112.340 6502.38 6596.38 12881.96 90.250 112.590 6502.30 6596.30 12917.92 90.550 112.710 6502.05 6596.05 12949.64 90.710 112.710 6501.70 6595.70 12982.37 90.180 112.600 6501.45 6595.45 13014.49 89.570 112.600 6501.52 6595.52 13046.68 89.600 113.200 6501.75 6595.75 13078.44 89.720 113.280 6501.94 6595.94 13110.83 89.910 113.660 6502.04 6596.04 13142.83 90.000 114.080 6502.07 6596.07 13173.79 89.970 113.660 6502.08 6596.08 13206.53 89.080 112.910 6502.35 6596.35 13238.94 90.220 113.380 6502.55 6596.55 13268.69 90.740 113.370 6502.30 6596.30 13303.47 92.030 112.120 6501.46 6595.46 13335.22 93.020 111.910 6500.06 6594.06 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5530.80 S 5540.76 S 5553.20 S 5564.92 S 5575.53 S 5587.55 S 5598.72 S 5610.52 S 5621.26 S 5633.39 S 5645.11S 5658.96 S 5671.20 S 5683.81S 5696.15 S 5708.68 S 5721.21 $ 5734.11S 5747.06 S 5759.59 S 5772.53 S 5785.27 S 5797.07 S 5810.51S 5822.40 S 7608.31 E 5963070.69 N 570001.92 E 7634.71E 5963060.94 N 570028.40 E 7666.87 E 5963048.77 N 570060.66 E 7696.87 E 5963037.30 N 570090.76 E 7724.30 E 5963026.92 N 570118.27 E 7756.17 E 5963015.16 N 570150.25 E 7785.42 E 5963004.24 N 570179.59 E 7815.53 E 5962992.68 N 570209.80 E 7842.67 E 5962982.18 N 570237.02 E 7872.67 E 5962970.30 N 570267.13 E 7901.02 E 5962958.81 N 570295.57 E 7934.21E 5962945.24 N 570328.87 E 7963.47 E 5962933.24 N 570358.23 E 7993.67 E 5962920.88 N 570388.54 E 8023.33 E 5962908.78 N 570418.30 E 8052.98 E 5962896.51N 570448.05 E 8082.16 E 5962884.22 N 570477.34 E 8111.87 E 5962871.56 N 570507.15 E 8141.13 E 5962858.86 N 570536.52 E 8169.45 E 5962846.57 N 570564.94 E 8199.52 E 5962833.87 N 570595.11E 8229.32 E 5962821.38 N 570625.02 E 8256.63 E 5962809.81 N 570652.42 E 8288.69 E 5962796.63 N 570684.60 E 8318.10 E 5962784.99 N 570714.10 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOft) (ft) Comment 4.454 9387.99 2.962 9415.61 2.076 9449.42 2.158 9481.03 4.321 9509.87 10.493 9543.21 4.112 9573.89 '0.463 9605.63 2.168 9634.29 5.941 9666.12 1.023 9696.33 0.899 9731.77 0.504 9763.03 1.654 9795.28 1.899 9826.93 1.866 9858.67 0.454 9890.02 1.312 9922.01 1.342 9953.65 1.360 9984.27 3.555 10016.59 3.805 10048.57 1.748 10077.94 5.164 10112.22 3.187 10143.41 Continue~.. 26 August, 1999 - 14:04 - 9 - DrillQuest Sperry-Sun Drilling Services Survey Report for lC-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 13366.23 92.590 109.670 6498.54 6592.54 13398.75 89.290 106.850 6498.01 6592.01 13431.16 88.430 106.430 6498.65 6592.65 13462.11 88.120 106.140 6499.58 6593.58 13495.29 88.550 105.820 6500.55 6594.55 13526.14 90.520 106.140 6500.80 6594.80 13557.87 91.600 106.240 6500.21 6594.21 13590.92 92.460 105.480 6499.04 6593.04 13623.07 92.280 104.360 6497.71 6591.71 13653.58 91.760 103.840 6496.63 6590.63 13685.57 91.110 103.230 6495.83 6589.83 13717.46 90.830 103.010 6495.29 6589.29 13748.48 90.650 102.420 6494.89 6588.89 13781.73 90.340 101.820 6494.61 6588.61 13813.88 90.150 102.130 6494.47 6588.47 13844.33 89.230 102.110 6494.63 6588.63 13874.44 89.260 102.420 6495.03 6589.03 13906.97 89.630 103.010 6495.34 6589.34 13936.86 91.050 102.750 6495.17 6589.17 13974.45 91.940 100.780 6494.19 6588.19 14006.81 90.710 99.700 6493.44 6587.44 14036.62 91.070 99.570 6492.98 6586.98 14070.16 89.750 99.130 6492.74 6586.74 14101.61 88.490 99.080 6493.22 6587.22 14137.14 86.740 98.720 6494.70 6588.70 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5833.40 S 8347.05 E 5962774.24 N 570743.15 E 5843.58 S 8377.92 E 5962764.31 N 570774.10 E 5852.86 S 8408.97 E 5962755.29 N 570805.22 E 5861.54 S 8438.66 E 5962746.86 N 570834.99 E 5870.67 S 8470.55 E 5962737.99 N 570866.95 E 5879.16 S 8500.20 E 5962729.75 N 570896.67 E 5888.00 S 8530.67 E 5962721.16 N 570927.21 E 5897.03 S 8562.44 E 5962712.39 N 570959.06 E 5905.30 S 8593.48 E 5962704.38 N 570990.16 E 5912.73 S 8623.05 E 5962697.20 N 571019.80 E 5920.21 S 8654.14 E 5962689.97 N 571050.95 E 5927.45 S 8685.19 E 5962682.99 N 571082.06 E 5934.28 S 8715.45 E 5962676.42 N 571112.37 E 5941.26 S 8747.96 E 5962669.71N 571144.94 E 5947.93 S 8779.41 E 5962663.30 N 571176.44 E 5954.32 S 8809.18 E 5962657.15 N 571206.27 E 5960.72 S 8838.60 E 5962651.00 N 571235.74 E 5967.88 S 8870.33 E 5962644.11 N 571267.53 E 5974.54 S 8899.47 E 5962637.69 N 571296.72 E 5982.20 S 8936.25 E 5962630.33 N 571333.57 E 5987.95 S 8968.09 E 5962624.84 N 571365.45 E 5992.94 S 8997.47 E 5962620.10 N 571394.87 E 5998.39 S 9030.57 E 5962614.93 N 571428.01 E 6003.37 S 9061.62 E 5962610.21 N 571459.10 E 6008.86 S 9096.69 E 5962605.01 N 571494.22 E Alaska State Plane Zone 4 Kuparuk 1C Dogleg Vertical Rate Section (°/lOOff) (ft) Comment 7.347 10173.74 13.347 10205.26 2.953 10236.43 1.371 10266.15 1.615 10297.95 6.469 10327.53 3.418 10357.99 3.472 10389.64 3.525 10420.27 2.410 10449.21 2.786 10479.46 1.117 10509.55 1.988 10538.75 2.031 10569.92 1.131 10600.04 3.022 10628.59 1.034 10656.85 2.141 10687.47 4.830 10715.63 5.749 10750.78 5.058 10780.73 1.284 10808.21 4.148 10839.06 4.010 10867.93 5.028 10900.47 Continued... 26 August, 1999- 14:04, - 10- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 14167.38 85.850 99.050 6496.65 6590.65 6013.52 S 9126.50 E 5962600.60 N 571524.07 E 14198.21 85.290 99.450 6499.03 6593.03 6018.46 S 9156.84 E 5962595.91 N 571554.45 E 14228.40 85.720 99.190 6501.40 6595.40 6023.33 S 9186.54 E 5962591.28 N 571584.19 E 14248.84 87.170 99.720 6502.67 6596.67 6026.69 S 9206.66 E 5962588.10 N 571604.34 E 14279.52 87.200 99.040 6504.17 6598.17 6031.68 S 9236.89 E 5962583.35 N 571634.61 E 14323.54 87.510 99.670 6506.20 6600.20 6038.83 S 9280.28 E 5962576.57 N 571678.05 E 14354.94 87.380 99.540 6507.60 6601.60 6044.06 S 9311.21 E 5962571.59 N 571709.03 E 14389.44 87.260 98.950 6509.22 6603.22 6049.60 S 9345.23 E 5962566.33 N 571743.09 E 14418.58 87.010 99.430 6510.67 6604.67 6054.25 S 9373.96 E 5962561.93 N 571771.85 E 14454.42 86.180 99.780 6512.80 6606.80 6060.22 S 9409.23 E 5962556.25 N 571807.18 E 14487.11 85.940 99.690 6515.05 6609.05 6065.73 S 9441.37 E 5962551.00 N 571839.36 E 14516.00 85.530 100.290 6517.20 6611.20 6070.73 S 9469.75 E 5962546.24 N 571867.78 E 14566.71 84.580 101.280 6521.57 6615.57 6080.18 S 9519.37 E 5962537.20 N 571917.48 E 14630.00 84.580 101.280 6527.55 6621.55 6092.51 S 9581.16 E 5962525.39 N 571979.37 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Alaska State Plane Zone 4 Kuparuk 1C Dogleg Rate (°/100fi) Vertical Section (ft) Comment 3.138 2.230 1.663 7.551 2.216 1.594 0.585 1.743 1.855 2.513 0.784 2.511 2.700 0.000 10928.13 10956.38 1O984.O6 11002.84 11031.03 11071.48 11100.38 11132.06 11158.79 11191.76 11221.85 11248.47 11295.42 11354.18 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 122.452° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14630.00ft., The Bottom Hole Displacement is 11354.18ft., in the Direction of 122.452° (True). Continued... 26 August, 1999- 14:04 - 11- DrillQuest Sperry-Sun Drilling Services Survey Report for 1C-26 Your Ref: API500292294400 Job No. AKMM90131, Surveyed: 27 July, 1999 Prudhoe Bay Unit Alaska State Plane Zone 4 Kuparuk 1C Comments Measured Depth (ft) 14630.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 6621.55 6092.51 S 9581.16 E Comment PROJECTED SURVEY 26 August, 1999- 14:04 - 12- DrillQuest Final Abandonment Report Subject: Final Abandonment Report Date: Fri, 12 Nov 1999 15:53:42 -0600 From: JGalvin~sperry-sun.com To: bob_crandall~admin, state, ak.us Bob, The attachment contains the final abandonment report submitted to the NRC for the radioactive source lost in the Kuparuk Field on well 1C-26. Both your office and the NRC granted approval to abandon the source. If you require futher information or supporting documentation I can be reached at the following numbers work: 273-3522 email: jgalvin@sperry-sun.com Jim Galvin Operations Supervisor ~_)Abandonment form 6 99.doc Name: Ab~ridc~r[ent form 6_99-2-6c Type: Microsoft Word (application/msword)] Encoding: x-uuencode Description: Unknown data type _ 1 of 1 11/15/99 8:14 AM Report of Incident Involving Radiation or Radioactive Materials INSTRUCTIONS: Complete all sections according to the Current Status selected below. DISTRIBUTION: After completion of report, save the report to your 'C' drive and e-mail the report to the affected Radiation Safety Officer*: Western Hemisphere: Well Logging - Dwaine Brown - dwain¢.brown~halliburton.com FAX 281-496-8394 Eastern Hemisphere: Well Logging - Jeff Pettigrew -j¢~.?¢ttig~¢w@hailiburton.com FAX 281-496-8394 Cementinq/Stimulation/NORM: Steve Woods - steve.woods@halliburton.corn FAX 580-251-3969 NOTE: Each change in incident status must be documented by a separate report. *If e-mail capability is not available, FAX the report to the affected RSO and notify the RSO by telephone that the report is enroute. Initial Report Stuck Other (Describe) Current Status Follow-Up Report Fishing Retrieved Closed Closure Report Abandoned Stuck/Fishing/Other Description of Status: One (1) 2.0 Ci Cs-137 source and two Cs-137 detector sources @ 0.5uCi and 1.5uCi respectively are stuck in the hole. Report Submitted By: Affected PSL: Other: Service Center: : Name: Other Management: Radiation Safety Officer Other: Date of This Report: Time of Incident: General Location: Date of Incident: Western Hemisphere Eastern Hemisphere Jim Galvin Name: Name: Name: Other: On Location Point of Contact: Report of Incident )lying Radiation or Radioac e Materials (cont.) Other Halliburton Employees on Location*: *Name/Title/Contact phone number Incident Location: Well Name: APl/OCS Number: Rig Name (Include OCS Description): Rig Phone Number: County/Parish: Company Man: Company Name: Company Address: Company City, State, ZIP: Drilling Company Name: Property Involved: SLD Detector Serial Number: Description: Sources of Radiation Involved: Source Serial Number: Paul Smith Kuparuk River Unit 1 C-26 50-029-22944-00 Pool 6 (907) 659-0545 North Slope Fred Herbert, Ray Springer Arco Alaska Inc. P.O. Box 10-3240 Anchorage, AK 99510-3240 Pool Arctic Alaska Near: MM-383 / Far: MM-345 Near: Isotope Products Model 3024 Cs-137 1.5uCi Far: Isotope Products Model 3024 Cs-137 0.5uCi Source Serial Number: List Other: Fishing Tool Company: Fishing Tool Company Contact: Address: City, State, Zip Code: Telephone Number: Time of Recovery: Leak Test Performed? Additional Comments: Retrieved Date of Recovery: , Abandoned Revision 6/99 Page 2 of 5 Report of Incident Ir qving Radiation or Radioac 'e Materials (cont.) Abandonment Plan Approved by List Names of Agencies Notified: Country: Date of Abandonment: Kickoff Device: Time of Abandonment: Describe Other Type of Kickoff Device: 13600 MD 6593 TVD 10451 MD 6432 TVD 14015 MD 6587 TVD 14541 MD 6613 TVD Retainer - Set at 14015 Feet MD Depth to Top of Cement Plug: If Deviated Depth of Top of Fish: If Deviated Depth to Bottom of Cement Plug: If Deviated Depth of Top Source: If Deviated Activity and Type of Source: Description of Other Type of Source: Activity: NA Depth of Bottom Source: NA MD If Deviated NA TVD Activity and Type of Source: Description of Other Type of Source: Activity: NA Isotope: NA Isotope: NA Depth of Bottom of Fish: 14605 MD If Deviated 6619.4 TVD Depth of Well: '14630 MD If Deviated 6621.9 TVD Drillpipe and Inflatable Describe: Closed/Other Resolution Revision 6/99 Page 3 of' 5 Report of Incident I! )lying Radiation or Radioa¢ 'e Materials (cont.) To Be Completed By Corporate Radiation Safety Officer Final Abandonment Plan Submitted to Customer Contact (if applicable): Name of Country: Abandonment Plaque Ordered Abandonment Plaque Shipped to: Date Plaque Shipped: Name: Company: Address: City, State, Zip Incident Closed: Radiation Safety Officer Date Revision 6/99 Page 4 of 5 Report of Incident I )lving Radiation or Radioa¢ 'e Materials (cont.) Revision 6/99 Page 5 of 5 Date 11/02/99 Well Na 1C-26 Service Type COILED TUBING Desc of Work PERFORATE Supervisor FERGUSON Complet [-~ Accident r- Injury l-- Spill l-- Summary Upcoming Job Num 0825990522.11 Unit UNIT #3 AFC AK0025 0 Prop 230D$10C Uploaded to Ser, Contractor Key Perso Successful r~ Initial Tbg Press 0 Initial Int Csg Press 325 Initial Out Csg Press 250 DS-NEWELL Final Tbg Press 0 Final Int Csg Press 325 Final Out Csg Press 250 PERFORATE 13350'-13370' USING 2" HSD POWER JETS / 6 SPF / 60 DEG PHASED / DEEP PENETRATING (Perf] Date printed: 11/04/99 at: 10:21:52 Date 11/01/99 Well Na 1C-26 Service Type COILED TUBING Upcoming Job Num 0825990522,11 Unit UNIT#3 Desc of Work PERFORATE Supervisor KRALICK Contractor Key Perso DS-JONES Complet F Successful r~ Accident F Initial Tbg Press 0 Injury I~ Initial Int Csg Press 325 Spill I-- Initial Out Csg Press 250 Summary AFC AK0025 1 Final Tbg Press 0 Final Iht Csg Press 325 Final Out Csg Press 250 Prop 230DS10C Uptoaded to Ser, PERFORATE 13410'-13370' USING 2" HSD POWER JETS / 6 SPF / 60 DEGREE PHASED / DEEP PENETRATING (Perf] Date printed: 11/04/99 at: 10:23:44 Date 10/31/99 Well Na 1C-26 Service Type COILED TUBING Desc of Work PERFORATE Supervisor KRALICK Complet ~-- Accident F- Injury F- Spill F- Summary Upcoming Job Num 0825990522,11 Unit UNIT#3 AFC AK0025 1 Prop 230DS10C Uploaded to Ser, Contractor Key Perso DS-JONES Successful l-- Initial Tbg Press 0 Initial Int Csg Press 375 Initial Out Csg Press 250 Final Tbg Press 0 Final Int Csg Press 375 Final Out Csg Press 250 PERF W/2" HSD POWER JETS / 6 SPF / 60 DEGREE PHASED / DP / FROM 13,450' - 13,410' MD (Per0 Date printed: 11/04/99 at: 10:21:36 ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ~' K1(1C-26(W4-6)) .. WELL JOB SCOPE JOB NUMBER 1 C-26 DRILLING SUPPORT-CAPITAL 0825990522.11 DATE DAILY WORK UNIT NUMBER 10/16/99 ABANDONMENT CEMENT SQUEEZE UNIT #3 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 8 YESI YES DS-N EWELL LIG ENZA FIELD AFC# Signed ESTIMATE AK0025 230DS10CG InitialTbgPress FinaITbgPress Initial lnner Ann Final lnner Ann I Initial Outer Ann I Final Outer Ann 1100 PSI 500 PSI 500 PSI 850 PSII 1250 PSI 300 PSI DAILY SUMMARY SET CEMENT RETAINER AT 14,015'. PUMP 90 BBLS OF RED CEMENT BELOW RETAINER. LAY IN RED CEMENT FROM RETAINER TO 13,361 '. ATTEMPT TO CLEAN OUT CEMENT TO 13,915'. UNABLE TO GET BACK DOWN.[Cement-Poly Squeeze] TIME LOG ENTRY 07:00 MIRU DOWELL/SCHLUMBERGER COIL TUBING UNIT. MAKE UP BAKER TOOL STRING TO BAKER COIL CONNECTOR THAT WAS INSTALLED AND TESTED AT THE END OF THE JOB YESTERDAY. TOTAL LENGTH OF TOOL STRING; 17.59'. 07:45 PRESSURE TEST LUBRICATOR AND SURFACE LINES TO 4,000 PSI. HOLD TAIL GATE SAFETY MEETING. DISCUSS JOB PLAN. WIND IS AT 23 MPH. TEMP AT 11 DEG. F. KEEP SURFACE LINES FREEZE PROTECTED. 10 PERSONNEL ON LOCATION. PAD ENTRANCE DESIGNATED MUSTER POINT. 08:10 RUN IN HOLE. WELL HEAD PRESSURE IS AT 1100 PSI. BLEED DOWN TO 200 PSI. 10:00 PICK UP WT AT 10,000' IS 13,000#. 10:10 SET DOWN AT CROSS OVER TO DRILL PIPE. ABLE TO PUMP DOWN THE BACK SIDE AND GET INTO PIPE. 11:10 SAW COLLAR JUST BEFORE FLAG. STOP AT 14,015'. 11:20 DROP 0.5" DELERON BALL. BEGIN PUMPING SEAWATER AT 1.0 BPM. 11:30 PRE JOB SAFETY MEETING. DISCUSS PUMP SCHEDULE. SAFETY CONTINGENCIES. 12:20 BALL ON SEAT. INITIATE PRESSURE STAGES TO SET RETAINER. 12:40 RETAINER SET AT 14,015'. BEGIN MIXING RED CEMENT. 13:00 PRESSURE TEST SURFACE LINES TO CEMENT MIXING VAN TO 4,000 PSI. 13:20 BEGIN PUMPING CEMENT AT 1 BPM. MAXIMUM PRESSURE PARAMETER OF 3400 PSIG. TIME LOG ENTRY 14:00 BACK PUMP RATE DOWN TO 0.5 BPM. COIL PRESSURE AT 1700 PSIG. 14:40 PUMP PRESSURE STEADY AT 2000 PSIG. 15:50 SWITCH TO FRESH WATER. 90.3 BBLS OF RED CEMENT PUMPED. 16:00 5 BBLS OF FRESH WATER PUMPED. SWITCH TO BIOZAN CONTAMINANT. 17:00 SHUT DOWN PUMP WITH 2 BBLS OF CEMENT IN COIL. BREAK OFF FROM CEMENT RETAINER. 17:25 UNABLE TO BREAK AWAY FROM CEMENT RETAINER. SPOTTING VALVE IS OPEN. DROP 0.75" BALL. 17:55 DISCONNECTED AT HYDRAULIC DISCONNECT. 18:20 PUMP 5 BBLS FRESH WATER, 5 BBLS RED CEMENT, 5 BBLS FRESH WATER AND 20 BBLS OF BIOZAN AT 1 BPM. 18:55 PUMP 1 BBL OF CEMENT OUT AT RETAINER. PULL UP AT 95 FPM LAYING IN REMAINDER OF CEMENT. STOP AT 13,350'. 19:45 MADE SEVERAL ATTEMPTS TO JET WITH BIOZAN TO 13,915'. UNABLE TO GET DOWN. LAST ATTEMPT GOT TO 13,238'. 22:00 ON SURFACE. CHANGE OUT BAKER TOOLS. PUT ON COLD ROLLED CONNECTOR, DUAL CHECKS, STINGER AND 2" SWIRL JET NOZZLE. 22:35 PRESSURE TEST LUBRICATOR AND LINES TO 4,000 PSI. TEST GOOD. RUN IN HOLE. 00:45 RUN DOWN TO 13,361'. STALL OUT. JET BIOZAN UP TO 12,300'. 01:10 RUN DOWN TO 12,658'. STALL OUT. JET BIOZA BACK UP TO 12,300'. 01:30 RUN DOWN TO 12,878'. STALL OUT. JET BIOZAN UP TO 12,300'. 01:45 RUN DOWN TO 12,873'. JET BIOZAN TO 12,300'. 02:00 PULL OUT OF HOLE. UNABLE TO GAIN ANY DEPTH. PUMPING SEAWATER AT 1.2 BPM. 04:30 ON SURFACE. FREEZE PROTECTED WITH DIESEL TO 2500'. RIG DOWN. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,~, WELL SERVICE REPORT ,~ K1(1C-26(W4-6)) WELL JOB SCOPE JOB NUMBER " 1 C-26 DRILLING SUPPORT-CAPITAL 0825990522.11 DATE DAILY WORK UNIT NUMBER 10/15/99 ABANDONMENT CEMENT SQUEEZE UNIT #3 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 7 NO YES DS-NEWELL LIGENZA FIELD AFC# CC# Signed ESTIMATE AK0025 230DS10CG InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 835 PSI 1600 PSI 450 PSI 650 PSII 1250 PSI 250 PSI DAILY SUMMARY TAGGED BRIDGE PLUG AND FLAGGED PIPE. PERFORMED INJECTIVITY TEST. WILL SET CEMENT RETAINER AND LAY IN CEMENT IN THE MORNING. [Cement-Poly Squeeze] TIME LOG ENTRY 07:00 RIG UP DOWELL / SCHLUMBERGER COIL TUBING UNIT. CHANGED PACK OFFS. INSPECTED CHAINS. MAKE UP 20' OVERALL LENGTH OF LUBRICATOR/BOPS. 09:00 PRESSURE TEST LUBRICATOR AND SURFACE LINES TO 4,000 PSIG. TAIL GATE SAFETY MEETING. THIS IS NOT OUR NORMAL UNIT. TAKE TIME TO GET FAMILIAR WITH EVERYTHING. WATCH OUT FOR SLIPS AND TRIPS IN FRESH SNOW. 09:35 RUN IN HOLE WITH 2.25 SJ NOZZLE, DUAL CHECKS AND COLD ROLLED COIL CONNECTOR. 12:00 TAG PLUG AT 14,004' CTM. CORRECT COUNTER DEPTH TO 14,068'. PULL UP HOLE TO 14,000'. PULL UP TO 13,885'. 12:10 BEGIN PUMPING SEA WATER AT 1 BPM. 1 BPM AT 2950 PSI. 1.25 BPM AT 3550. LINE UP TO PUMP DOWN BACKSIDE. TOTAL OF 53 BBLS PUMPED. AT 1.75 BBLS BPM, PRESSURE GRADUALLY INCREASED FROM 2800 PSI AND LEVELED OUT AT 3,700 PSI. 12:50 POH. FREEZE PROTECT COIL WITH DIESEL. 14:45 ON SURFACE. TEST BOPS. INSTALL BAKER COIL CONNECTOR. PULL TEST, PRESSURE TEST. 16:00 RIG DOWN FOR THE DAY. fla.. - Cl oq'Z Schlumberger NO. 12800 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1 C-26 99339 SCMT 990820 1 2A-02 LLt (--- INJECTION PROFILE 990822 I 1 2A-09 LEAK DETECTION LOG 990826 I 1 2A-10 PRODUCTION PROFILE 990830 I 1 2L-315 TEMPERATURE SURVEY 990910 I 1 2M-01 PRODUCTION PROFILE 990830 I 1 2N-325 ~ t C~ RST WATER FLOW LOG 990829 I 1 2N-325 '..~,-,- WARM BACK TEMP LOG 990908 I 1 2N-343 L~ C_ RST WATER FLOW LOG 990827 I 1 2N-343 ~ .wA'RM BACK TEMP LOG 990909 I 1 ,,, 2V-08A ~ ~ INJECTION PROFILE 990821 I I ... 3G-17 PRODUCTION PROFILE 990826 I 1 3M-02 L~(~. INJECTION PROFILE 990825 I 1 3M-10 U.I (-- INJECTION PROFILE 990906 I 1 i SIGNE ................................... DATE: ,,.~;:::' ,,- .... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. 9/17/99 Re: 1C..26 PTD 99-051 Subject: Re: 1C-26 PTD 99-051 Date: Thu, 02 Sep 1999 10:42:39-0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael R Niznik <MNIZNIK~mail.aai.arco.com> -- Mike, I also received the faxed schmetic, your proposal looks good. I do ask that your cap the retainer at 14,000' with at least 75' of cement. Good luck with the work. Let me know how it turns out. Do we have a CQL on the 7"? We need one to approve injection. Blair Wondzell, 9/2/99 Michael R Niznik wrote: Blair, I faxed over the schematic for lC-26, I hope a hand drawn picture is OK. Once you have a chance to look over the drawing I would like to discuss our next course of action. I propose setting a retainer at 14,000' and pumping ~100 bbls of Red Cement to isolate the BHA, we would lay some cement on top of the retainer. After WOC, we would attempt to isolate our injection interval because the drillpipe is in open hole and there is a fault that is capable of taking fluid in the vicinity. Our plan of action would consist of setting a CIBP at 12,100 , shooting sqz holes at 12,050 and setting a retainer at 12,000 . We would squeeze cement through the retainer and attempt to isolated the openhole and fault. The upper plugs and cement would be drilled out and the injection interval of 12,680' - 13,360' would be perforated. My number is 263-4561 and I look forward to speaking with you. Sincerely, Mike Ni znik 1 of 1 9/2/99 10:45 AM ARCO AleSka, Inc Instruclion$; 1 )Number Pages 2)Remove Staples 3)Use Only Black Ink 4)Use Only Clear/Defined Copies 5)Thank You For Your Cooperation [DATE TO '%-, LOCATION/ROOM COMPANY CITY STATE FAX # VERIFY # COMMENTS: COPIES TO; FROM BLDG/ROOM TELEPHONE NO, OF PAGES FOLLOWING COVER / ARCO Film Calculations Chart Sheet numl0er I ~ I I ~ | 159-5BB1 Re: 1 C'-'26 PTD 99-051 Subject: Re: 1C-26 PTD 99-051 Date: Thu, 2 Sep 1999 16:32:52-0900 From: "Michael R Niznik" <MNIZNIK@mail.aai.arco.com> To: Blair Wondzell <blair wondzell~admin.state.ak.us> Blair, I just got the CQL from Schlumberger. hrhat address do I send it to? Michael R. Niznik Blair Wondzell <blair wondzell@admin.state.ak.us> on 09/02/99 09:42:39 AM To: Michael R Niznik/AAI/ARCO CC: Subject: Re: 1C-26 PTD 99-051 Mike, I also received the faxed schmetic, your proposal looks good. I do ask that your cap the retainer at 14,000' with at least 75' of cement. Good luck with the work. Let me know how it turns out. Do we have a CQL on the 7"? We need one to approve injection. Blair Wondzell, 9/2/99 Michael R Niznik wrote: > Blair, > > I faxed over the schematic for 1C-26, I hope a hand drawn picture is OK. Once > you have a chance to look over the drawing I would like to discuss our next > course of action. I propose setting a retainer at 14,000' and pumping ~100 bbls > of Red Cement to isolate the BHA, we would lay some cement on top of the > retainer. After WOC, we would attempt to isolate our injection interval because > the drillpipe is in open hole and there is a fault that is capable of taking > fluid in the vicinity. Our plan of action would consist of setting a CIBP at > 12,100 , shooting sqz holes at 12,050 and setting a retainer at 12,000'. We > would squeeze cement through the retainer and attempt to isolated the openhole > and fault. The upper plugs and cement would be drilled out and the injection > interval of 12,680' - 13,360' would be perforated. > > My number is 263-4561 and I look forward to speaking with you. > > Sincerely, > Mike Niznik 1 of 1 9/8/99 8:48 AM 0 I:t I I_1_ I I~ G SIE I:lVI r' E S 26-Aug-99 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1C-26 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 14,630.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns/_,.L~ ~} ~e§ards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company August 1 O, 1999 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska, 99501 Plug and Abandonment and Completion Well 1C-26 Kuparuk Field Pool Rig 6 Dear Mr. Wondzell: Pool Rig 6 commenced drilling the referenced well on July 1, 1999. 9-5/8" Surface casing was set and cemented at 6496' MD (4455' TVD) and 7" 26# intermediate casing was set at 10,563' MD (6462' TVD). Wellbore angle at intermediate casing point is -87 degrees. From that point a 6-1/8" wellbore was horizontally drilled to a TD of 14630' in the Kuparuk C sand. Throughout the drilling of the production interval we had several instances of connection gas and had attempted to remain dynamically balanced as increased mud weights would result in loss of fluid to faulted intervals in the horizontal section. At TD, however, it became apparent that in order to run the 4-1/2" liner, the mud weight would have to be increased from 11.2 ppg to 11.6 ppg in order to avoid gas influx while out of the hole and running the liner. As the higher density fluid was circulated around, and just before a full annular column was achieved, the drillstring became differentially stuck at 14,090' (est.), despite pipe rotation and reciprocation during displacement. The stuck pipe incident occurred on July 27th at 6:30 p.m. and includes a BHA with a nuclear source (porosity) tool in the string at -q4,555' MD. Top of the BHA is at 14,130' MD. Since that time we have made numerous attempts at pipe recovery but have been unable to determine a free point or be able to cut the drill pipe in the horizontal interval, despite using both e-line and CTU options. We believe all reasonable attempts at pipe recovery have been prudently pursued and the only viable option that remains to salvage the well is to abandon the well above the BHA and complete the horizontal interval with drill pipe. We have perforated the drill pipe at 14,110' - 14108' with 18, 3.6 gram shots and, although unable to circulate to surface, have the capability to pump fluid away through the perforations. Our proposal to complete this well is to set a CTU conveyed retainer- type plug to a depth above the perforations that will allow the necessary isolation above the BHA and source, and squeeze cement into the perfs and void below the plug as the abandonment plug. Once the BHA is isolated and P&A'd the plan forward would be to back off the existing drilling jars at 10,386' and run in with a drill pipe cross over to a liner top packer and hanger with a tie-back sleeve. The packer/hanger would be installed on top of the drill pipe and 4-1/2" tubing would be run and stung into the PBR on tof'of the packer. The drilling rig would move off and CTU would perforate on either side of the proposed injection perforations and squeeze cement to obtain the necessary isolation of injection from faulted intervals in the reservoir. Uncertainty that remains around this proposal is identifying the type of retainer options available to be run concurrently through the 2.438" drill pipe ID tool joints and the 3.34" drill pipe tube in order to effect a cement squeeze into the perforations. In addition, the objective utility for this well is for water injection which brings into question the ramifications of cement bond logs, etc. Please advise as to AOGCC isolation requirements above the stuck BHA in terms of cement height, tagging requirements, minimum deflection material requirements, etc. Also, if you could please address the issues regarding use of this well with a drillpipe completion as an injection candidate. I can be reached at 265-6531. Sincerely William B. Lloyd Sr. Drilling Engineer - ARCO Alaska, Inc. Pool 6 '- E&A/Completion Proposal Subject: Pool 6 - P&A/Completion Proposal Date: Tue, 10 Aug 1999 13:31:12-0900 From: "William B Lloyd" <WLLOYD@mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us Blair, Per our conversation, I am sending you some information regarding our situation on Pool 6 and a potential completion plan. There are several "hurdles" to cross to achieve this completion - some of which we are still trying to figure out - that may cause us to continue fishing operations. We're thinking that even if we can do the attached program, we're still looking at another $1.5 MM but it would get us away cheaper. In any event, if it turns out this is something we can do, I'd like to get some of the details worked out from a regulatory standpoint. If you could please review the document and give me a call with any issues from your side of the table, I'd appreciate it. Thanks Bill (See attached file: lc26 completion proposal.doc) Name: lc26 comp'i'~{{~{"proposal.doc Type: Winword File (application/msword)] ~ lc26 completion proposal.doc Encoding: base64 Description: Mac Word 3.0 1 nf 1 g/10/90 ] :4c) PM MEMORANDUM TO: Robert Christenson~aska Chairman State of Alaska Oil and Gas Conservation Commission DATE: July 30, 1999 THRU: Blair Wondzell, ~~ ~/f~/~ FILE NO: P. I. Supervisor FROM: John H. Spaulding, ~ SUBJECT: Petroleum Inspector~ aa51g4gf, doc BOPE Test Pool 6 ARCO / KRU / 1C-26 PTD # 99-0051 July 30, 1999: I traveled to Arco's, KRU well 1C-26 being drilled by Pool Rig 6 and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report indicates, the test lasted 4 hours with 0 falures. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized allowing good access to the rig. Summary: I witnessed the initial BOPE test on Pool Rig 6 drilling Arco's 1C-26 Well. Pool 6, 7-30-99, Test time 4 hours, 0 failures Attachment: aa51g4gf, xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: lc-26 Casing Size: Test: Initial Workover: Pool Rig No. 6 PTD # 99-51 ARCO Rep,: 2N-309 Rig Rep.: Set @ Location: Sec. Weekly X Other DATE: 7/30/99 Rig Ph.# 659/7562 Fred Herbert D. Green 12 T. 11N R. 10E Meridian UM MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. OK ° FLOOR SAFETY VALVES: Upper Kelly/IBOP Lower Kelly/IBOP Ball Type Inside BOP Test Quart. Pressure P/F 1 250/3500 P I 250/3500 P 1 250/3500 p I 250/3500 P BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams 1 Blind Rams 1 Choke Ln. Valves 1 HCR Valves Kill Line Valves Check Valve ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Test Press, P/F 250/3500 250/3500 250/3500 250/3500 250/3500 2 250/3500 1 250/3500 N/A CHOKE MANIFOLD: No. Valves 15 No. Flanges 30 Manual Chokes 1 Hydraulic Chokes 2 Test Pressure P/F 250/3500! I P 250/35001 IP Functioned I P Functioned I P 3000 I P 1700 P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure ~ minutes 35 sec. Trip Tank OK OK System Pressure Attained 2 minutes 35 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: OK Remote: OK Flow Indicator OK OK Nitgn. Btl's: 6 @ 2100 Psi Meth Gas Detector OK OK . Psig. H2S Gas Detector OK OK Number of Failures: 0 ,Test Time: 4.0 Hours. Number of valves testea 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to me AOOCC Commission Office at: Fax NO. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I, Supervisor at 279-1433 REMARKS: Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: John H. Spaulding FI-021L (Rev.12/94) aa51g4gf, xls 1C-26 Shut-in c)9 Subject: 1C-26 Shut-in Date: Tue, 13 Jul 1999 10:22:26-0900 From: "Thomas A Brockway" <TBROCKW~mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us CC: "William B Lloyd" <WLLOYD~mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS@mail.aai.arco.com>, "Chip Alvord" <CALVORD~mail.aai.arco.com> Dear Mr. Wondzell, While circulating and conditioning the wellbore after reaching the intermediate hole section TD on KRU well 1C-26, the was shut-in with the rig BOPE for approximately 1/2 hour in response to a suspected fluid influx. After the well was shut-in wellbore pressures were monitored on the rig floor with no recordable pressure (0 psi) observed on either the annulus or the drillpipe. Following is a short synopsis of the events surrounding the shut-in: 7/12/99 03:30 - 10:00 Drill from 10063' - 10570'; no problems; MW=9.5 PPg 10:00 - 10:30 Pump HiVis/LoVis sweep 10:30 - 11:00 Methane gas alarm went off - check for flow at bell nipple. Well appeared to be flowing with bubbles at surface. Shut in well -- no pressure on DP or casing. Line up to pump through gas buster. pumps - 11:00 - 12:00 Open BOPE. Check for flow - no flow. Come up slow on hole packed off. No circulation. Work pipe off bottom. Upon opening the BOPE and attempting to resume circulation, it was discovered that the hole packed off, preventing circulation and severely limiting pipe movement. After jarring and working the pipe, circulation was reestablished. Currently the rig is circulating and conditioning the wellbore and subsequent flow checks have confirmed that the wellbore remains static at 9.5 ppg. The plan forward calls for weighting up the mud system from 9.5 ppg to 10.0 ppg in order to stabilize the Kalubik shales prior to running 7" intermediate casing. If you have any questions or require any further information, please contact Tom Brockway, Operations Drilling Engineer at (907) 263-4135 or Randy Thomas, Kuparuk Team Leader at (907) 265-6830. Sincerely, Thomas A. Brockway Operations Drilling Engineer 7/13/99 1:57 PM Re: 1C-26 Shut-in Subject: Re: 1C-26 Shut-in Date: Tue, 13 Jul 1999 14:03:48-0800 From: Blair Wondzell <Blair_Wondzell@admin.state.ak.us> To: Thomas A Brockway <TBROCKW~mail.aai.arco.com> CC: William B Lloyd <WLLOYD@mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS~mail.aai.arco.com>, Chip Alvord <CALVORD@mail.aai.arco.com>, John_Spaulding@admin. state.ak.us Thomas, Thanks for the information. I have no further questions. Blair Wondzell 7/13/99. Thomas A Brockway wrote: Dear Mr. Wondzell , While circulating and conditioning the wellbore after reaching the intermediate hole section TD on KRU well 1C-26, the was shut-in with the rig BOPE for approximately 1/2 hour in response to a suspected fluid influx. After the well was shut-in wellbore pressures were monitored on the rig floor with no recordable pressure (0 psi) observed on either the annulus or the drillpipe. Following is a short synopsis of the events surrounding the shut-in: 7/12/99 03:30 - 10:00 Drill from 10063' - 10570'; no problems; MW=9.5 PPg 10:00 - 10:30 Pump HiVis/LoVis sweep 10:30 - 11:00 Methane gas alarm went off - check for flow at bell nipple. Wel 1 appeared to be flowing with bubbles at surface. Shut in well -- no pressure on DP or casing. Line up to pump through gas buster. 11:00 - 12:00 Open BOPE. Check for flow - no flow. Come up slow on pumps - hole packed off. No circulation. Work pipe off bottom. Upon opening the BOPE and attempting to resume circulation, it was discovered that the hole packed off, preventing circulation and severely limiting pipe movement. After jarring and working the pipe, circulation was reestablished. Currently the rig is circulating and conditioning the wellbore and subsequent flow checks have confirmed that the wellbore remains static at 9.5 ppg. The plan forward calls for weighting up the mud system from 9.5 ppg to 10.0 ppg in order to stabilize the Kalubik shales prior to running 7" intermediate casing. If you have any questions or require any further information, please contact Tom Brockway, Operations Drilling Engineer at (907) 263-4135 or Randy Thomas, Kuparuk Team Leader at (907) 265-6830. Sincerely, Thomas A. Brockway Operations Drilling Engineer 1 of 1 7/13/99 2:05 PM - TONY KNOWLE$, GOVERNOR ALAS~ OIL AND GAS June 11. 199~2ONSERVATION COMMISSION Chip Alvord, Drilling Engineering Supvr ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kuparuk River Unit 1C-26 ARCO Alaska, Inc. Permit No: 99-51 Sur. Loc. 1702'FNL, 1339'FWL, Sec. 12, TllN, R10E, UM Btmhole Loc. 2377'FNL, 809'FWL, Sec. 17, TllN. RILE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integnts.' Test (FIT). Cementing records, FIT data. and anv CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Please note that an,,, disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site lC must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity. (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission max' witness the tests. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. ~~~l~obert N. Ctll~tenson. P.E. -- Chairman BY ORDER OF THE COMMISSION dlffEnclosure cc~ Department of Fish & Game, Habitat Section xxqo encl. Depamnent of Envirmunental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill [] Redrill [] lb. Type of well. Exploratory [] StratigraphicTest [] Development Oil[] Re-entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 95 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0361 ADL 28243 ALK 3814 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1702' FNL, 1339' FWL, Sec. 12, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1394' FNL, 2215' FWL, Sec. 18, T11N, R11E, UM lC-26 #U-630610 At total depth 9. Approximate spud date Amount 2377' FNL, 809' FWL, Sec. 17, T11N, R11E, UM June 12, 1999 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 809' @ TD feetI lC-01 25' @ 650' feet 2560 14728 ' MD / 6522 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 1200 MD Maximum hole angle 94 Maximum surface 2634 psig At total depth (TVD) 3126 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Weld 25' 95' 95' 120' 120' 9 cu yds High Early 12.25" 9.625" 40# L-80 BTC 6405' 95' 95' 6500' 4465' 790 sx AS III, 650 sx Class G 8.5" 7" 26# L-80 BTC-M 10468' 95' 95' 10563' 6547' 180 sx Class G 6.125" 4.5" 12.6# L-80 IBT-Mod 3865' 10413' 6422' 14278' 6522' 490 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: true measured vertical feet feet Plugs(measured, ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing' Length Size Cemented Measured depth True Vertical depth Conductor Surface Production RECEiV~E Liner Perforation depth: measured d U i'~ '-' ~' 1999 A~ 0il & Gas Cons, true vertical . A~ch0rage 20. Attachments Filing fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call William Lloyd265-653 Signed ~ ~,. Title: Ddlling Engineering Supervisor Chip Alvord 1~ Date Pm.n~ / Commission Use Onl~ PermitN~'~.~r ,~,//IAPlnumber I Approval_date Isee cover letter - 50- o z?- z z ? ¢" ¢' & ,-'//" Ifor other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required [] Yes ,j~ No Hydrogen sulfide measures [] Yes ,~' No Directionalsurvey required ~ Yes [] No for BOPE [] 2M; [] 3M; [] ~ [] 10M;• [] Required working pressure Other: by order of ORIGINAL SIGNED BY Commissioner the commission Date Approved by D .-. ~. .-. ,,+ ~ ~.~-,. ..... Form 10-401 Rev. 12/1/85 · Submit in triplicate · - ARCO Alaska, Inc. / Drill and Case Plan for :tC-26 Kuparuk ;[n jector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. Hove in / rig up drilling rig. Install diverter IA function test same. Spud and directionally drill 12 1/4" hole to the surface casing point at 6500' HD/4465' TVD. Run HWD logging tools in drill string as required for directional monitoring. Condition hole for casing, trip out. Run and cement 9 5/8" 40# L80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. · TAM Port Collar will be placed in the casing string at 1000' HD to be used in the event that cement does not reach the surface in the primary one stage job. Nipple down diverter, Install Gen V wellhead and nipple up BOP's. Test wellhead to 3500 psi and BOP's per AA[ Drilling policy. Notify AOGCC 24 hours before test Hake up 8 1/2" bit and BHA and R[H to top of float equipment · Pressure test casing to 3500 psi for 30 minutes · Record results and fax to town Drill float equipment and approximately 20' of new hole · Perform LOT · Record results and fax to town Drill 8 1/2" hole to Hid-HRZ at +9932' HD/6243' TVD · Perform a second LOT and determine an acceptable kick tolerance · ]:f kick tolerance is acceptable, 8 1/2" hole will be drilled into top of Kuparuk C · If kick tolerance is unacceptable, 7" casing will be run to base of HRZ. ::[0. Run and cement 7" 26# L80 BTC-Hod per plan 11. Hake up 6 1/8" bit and BHA and R]:H to top of float equipment · Pressure test casing to 3500 psi for 30 minutes · Record results and fax to town · Drill float equipment and displace drilling fluid to 10.5 ppg BaradrilN per plan. 12. Drill 6 1/8" horizontal wellbore to TD at 14728' HD/6522' TVD · Condition hole and mud for casing 13. Run 41/2'' 12.6# L80 [BT-Hod solid liner w/liner hanger and liner top packer. Cement entire length of liner interval. 14. POOH to above liner and displace well to 8.5 ppg seawater. Test LTP and monitor well for flow. POOH 15. Run and land 4 1/2" tubing completion with seal bore extension stung into LTP 16. Nipple down BOP's. Install production tree and pressure test same. . .. . . , , 17. Secure well, release rig ARCO Alaska, Inc. .... Drilling Area Risks: Drilling risks in the lC-26 area are surface interval hydrates, lost circulation and potential bore hole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM) Annular Pumping Operations: ]~ncidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class ]:! disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.~ The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The :!.C-26 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. Tf isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, a sundry notice requesting permission to annular inject into the :[C-26, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300- 500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by' Flax Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (4,465') + 1,500 psi Max Pressure - 4,286 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of :OD (ppf) Grade Range Type Collapse Collapse Burst Burst ~9-5/8" 40 L-80 3 BTC 3,090 psi NA 5,750 psi 4,888 psi I ,, 26 L-80 3 LTC-Mod 5,410 psi 4f599 psi 7,240 psi 6,154 psi 17 41/2''* 12.6 I..-80 2 B-I-C-Mod 7,500 psi 6,3?5 psi 8,440 psi 7,174 psi * if needed Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU :LC-26 Drillin.q Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel API Filtrate pH % Solids Spud to surface casing point 9.3-10.2 ppg 16-26 25-35 100 - 150' 10-20 15-40 7-15 9.5-10 +10% Drill out to Base HRZ 9.5 - 11.5 ppg 6-20 5-20 35-50 2-6 4-8 6- 15 9.0-10 <11% Horizontal Interval to TD 10.4- 12.5 ppg 5- 18 5 - 20 36 - 45 2-5 3-8 <5 9.0 - 9.5 <8% Drillinq Fluid System: ITriple Derrick Shale Shakers Desander, Desilter, IVlud Cleaner Centrifucle Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (HASP) while drilling the production hole is calculated using a surface casing leak-off of 13.5 ppg Et4W (0.70 psi/ft) and a gas gradient of 0.11 psi/ftI This shows that formation breakdown would occur at a surface pressure of 2,634 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. HASP = (4,465 ft)(0.70- 0.11) = 2,634 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1C pad are expected to be N3,365 psi (0.52 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.4 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6,500'. Target (Kuparuk C4) (3365+ 150)/(0.052'6500) = 10.4. Well Proximity Risks: The nearest well to 1C-26 is IC-01. The wells are 25' from each other at a depth of 650' HD. Gyro surveys are not required to validate survey integrity. Completed 1C-26 FMC Prudhoe Gen V 9-5/8 x 51/2 x 31/2 Base of permafrost at 1,853' MD / 1,820' TVD 12-1/4" Hole Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 9-5/8" 40 ppf L-80 BTC-Mod Surf. Csg. 6,500' MD / 4,465' TVD 81/2" Hole 4Y2" 12,6 ppf L-80 ABT-Mod w/15' seal bore extension tied into top of liner 7" 26 ppf L-80 BTC Intermediate. Csg. 10,563' MD / 6,547' TVD Baker 4.5" x 7" SLZXP LTP and tieback sleeve. TOL @ 10413' MD/6422' TVD 6-1/8" Hole 4.5" x 3.813" X nipple for SCSSV at 500' + MD Camco 4W'x 1" side pocket GLM Camco 4Y2" x 1" side pocket GLM 3.813" X nipple All Depths are RKB Pool Rig 6 1¢-26 Dri and set Casing FMC Prudhoe Gen V 9-5/8 x 7 9-5/8 Mandrel Hanger Base of permafrost at 1,853' MD / 1,820' TVD 12-1/4" Top of West Sak at 5,265' MD / 3,824' TVD Base of West Sak 6,115' MD / 4,265' TVD 9-5/8" 40 ppf L-80 BTC Surface Casing 6,500' MD / 4,465' TVD .:.'. 8-1/2" Hole Baker 4.5" x 7" SLZXP LTP and tieback sleeve and HMC Liner Hanger w/PBR @ 10413' MD Weatherford Gemoco 7" Float Collar and Float Shoe Baker 4-1/2" Guide Shoe .o, 16" Conductor Weatherford Gemoco 9-5/8" PORT Collar Standard Grade, BTC 1,001' MD / 1,000' TVD Mud Weight in Surface hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 9-5/8" Float Collar and Float Shoe Mud Weight in Intermediate Hole 8.6 to 12.5 ppg 7" 26 L-80 BTC Mod Csg i:i:i:i 10,563' MD / 6,547' TVD '. o. .. .o Mud Weight in Production hole 10.6 to 12.5 ppg 4-1/2"12.6#/ft L-80 ABT-Mod Solid Liner ARCO Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS L, J L ! 1 F- I I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom 3" 5,000 psi WP OCT ~---J MANUAL GATE VALVE '~ KILL LINE ~ 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / 1 I DSA 13-5/8" 5,000 psi WP .~.~'1 L x 11" 3,000 psi WP 3,, 5,000 psi wP Shaffer GATE VALVE ~/.hvdraulic actuator 13-5/8" 5,000 psi WP DRILLING SPOOL LI'~~ w/two 3" 5M psi WP outlets I J SINGLE 13-5/8" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams ARCO Alaska, Inc. Diverter Schematic Pool #6 21 ¼" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline I I I 21¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) Created by Dote plotted : 1-Jun-lggg Plot Rlflrlflcl ;I 26 VlrlJon ARCO Alaska, Inc. Structure : Pad 1C Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 600 1200 1800 2400 r- /5000 3600 '1~ 4200 (D 4800 J 54O0 6000 6600 7200 7800 ~lJ.%~n - 0.00 Inc, 0.00 Md, 0.00 Tvd, 0.00 V8 ~l.~n Directional Nudge 7915' (TO TARGET HEEL) . ~ off Pein[ - 5.00 Inc, 1100.00 Md, 1097.80 Tvd, ~4.65 Va 1 28 88 AZIMUTH i 1~3 DLS: 3.00 deg per 100 ft ***P~E OF PROPO~L,,, ~ ~ of Permafrost Top of West Sak ~ Base of West Sak ~ 9 5/B Casing Pt ...... I .... i ' i i i i i i i .... i' i i ' i i i i I i i i i i i i i i i ' 'l i i i i , i i l 0 600 1200 1800 2400 ~000 3600 4200 4800 5400 6000 6600 72~ Verflaal Seoflon (feet) -> Azimuth 128.88 with reference 0.00 N, 0.00 E from slot ~26 Created by rix~e Date plotted : 1-dun-lggg Plot Refmence ~1 25 Verllon ~7. Coord;nates are In feet reference Ilot d12~. I ~-~ ARCO Alaska, Inc. Structure : Pad lC Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 5200 5400 5600 5800 t~O(JU ,..~., ~- 6200 Q. 6400 '~ 6600 > Q~ 6800 F-. J 7000 7200 7400 '7800 - "1 ..... i ' i i 'l' I I I "i ! i i i i '1 [ i i i ! '1 i' i i'' ! '! i ! i [ ! i 'l ! ! i ! ! ! ! ! i 7400 7600 7800 8000 8200 8400 I~ 8800 9000 9200 9400 9600 9800 10000 10200 10400 10600 10600 11000 11200 11400 11600 Vertical Section (feet) -> Azimuth 128.88 wlth reference 0.00 N, 0.00 E from slot #26 Date plotted : 1-Jun-lggg / Plot Relerence Coordlnotea are ~n Vert;col ~pJh ...... f ARCO Alaska, Inc. Structure : Pad 1C Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska PROFILE COMMENT DATA .............. Point Begirt Directionol NuB EOC KOP Bose of Permofrost EOC Top of West Bose of West Sok 9 5/8 Cosing Pt C80 C60 C50 C4.0 C30 (K .... 2) Begin Build/Turn to (320 (t--tI:':~Z Midpoint) Bose HRZ K-1 i'7 Cosing Pt. '"l"op of' Kuporuk D ShoB Torget - Heel 1 Top of C4 EOC Heel 2/Begin Angle DB EOC 13egin Angle Build rob EOC Foult/Begin Angle Bu~ EOC "l"orget/Begin Build&TB EOC Begin Drop&Turn ]'or'get PostBF #2 EOC MD Inc Dir TVD North Eost V. Sect 300.00 0.00 180.00 500.00 0.00 0.00 0.00 655.55 5.00 180.00 652.91 - 14.54 0.00 9.12 1200.00 7.21 160.49 1197.24 -65.48 2.10 42.75 1855.00 25.88 155.21 1821.00 -206.65 117.30 221.01 2955.18 58.74 129.56 2625.22 -689.56 666.35 951.56 5265.42 58.74 129.56 5824.00 - 1941.90 2195.57 2926.57 6115.29 58.74 129.56 4265.00 -2402.61 2755.12 5652.85 6500.72 58.74 129.36 4465.00 -2611.54 5009.88 5982.32 6816.78 58.74 129.56 4629.00 -2782.87 5218.78 4252.48 7917.18 58.74 129.56 5200.00 -5379.38 3946.12 5195.11 8397.04 58.74 129.36 5449.00 -5639.50 4263.30 5603.50 8975.19 58.74 129.,56 5749.00 -3952.91 4645.44 6097.51 9668.97 58.74 129.36 6109.00 -4528,99 5104.01 6690.55 9817,61 58.74 129.56 6186.15 -4409.56 5202.26 6817.61 9932,15 61.72 127.58 6245.00 -4471.25 5280.22 6917.01 10164.53 67.84 123.68 6542.00 -4593.20 5451.27 7126.72 10555.13 72.92 120.89 6406.00 -4689.00 5603.01 7504.98 10565.50 78.50 118.01 6457.,58 -4788,07 5778.61 750,5.87 10665.30 81.20 116.67 6475.00 -4853.27 5866.05 7600.50 10989.17 90.00 112.40 6500.00 -4967.95 6161.29 7914.67 10989.19 90.00 112.40 6500,00 -4967.96 6161.51 7914.69 10990.96 90.00 112.45 6500.00 -4968.63 6162.94 7916.59 11985.54 90.00 112.45 6500.01 -5548.49 7082.12 8870.56 12078.58 85.,:36 112.81 6505.77 -5584.25 7167.90 8959.59 12294.59 85.36 112.81 6521.24 -5467.71 7366.37 9166.47 12387.50 90.00 112.55 6525.00 -5505.49 7452.00 9255.60 12815.55 90.00 112.55 6525.00 -5666.91 7845.46 9664.47 12852.75 90.58 112.56 6524.90 -5674.28 7863.19 9682.90 13521.03 90.58 112.56 6520.00 -5861.56 8314.10 10151.47 13405.76 93.50 109.49 6516.99 -5891.94 839,3.12 102,52.05 13458.19 93.50 109.49 6515.00 -5902.74 8423.65 10262.58 13438.24 93.50 109.49 6515.00 -5902.75 8423.68 10262.65 13780.60 89.27 96.46 6506.70 -5979.59 8756.42 10569.75 14117.19 89,27 96.4,6 6511.00 ........ 6017,25 9090.84 10853,1¢6 Deg/lO0 0.00 1 50 0 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00 3.00 3,00 3.00 3.00 0.00 5.00 0.00 5.00 0 O0 3 O0 0 O0 5 O0 0 O0 5 O0 4. O0 0 I.. 0(,,; 144.98.93 88.84 77.38 6517.36 -.5996.83 9470.21 11136.37 5.00 'l ,:'~ rcl et /E x tToe/7.0/C OS..B ..................... .!....4727:88 8_8__...5.,..4 Z7..~38. 6522.,...00 ............... ::,.5..9.46..,.8,0 96.95,59 __1__12Z8,.,.8,5 O. O0 Crsated by rtxse Dote plotlld: 1-dun-lggg PIo~. Relwren¢~ il 25 V~re~'on True Vert~col Deptha are releren¢o RKB (Pool 8). ARCO Alaska, Inc. Structure : Pad 1C Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 8400 go00 9600 10200 10800 11400 12000 12600 1 ~200 1,3800 I ! I I [ I I I I I I I I I I I I I I I I [ [ i I Begin D[rect~onol Nudge I SURFACE LOCATION: I 'KOP P]I'].~;~ of Permafrost 1702' FNL~ 133g' FWL SEC. 12, TllN. R10£ "~of West Sak "~se of West Sak 9 5/8 Casing Pt "~c6o .o ITARGET HEEL ~1: I ~ ~ _ oN _ I ~' FNL, ~ ~L I ~ ~°~o~ --~' I SEC. ~N, R~IE I v~ ~ ~. T~GET HEEL~2:I ,¢ 1775' FNL, 1799' FELI ~ - SEC. 17, T11N, R11E I TARGET~WNFAULT: I i I 2oe5' FNL, 1037' FEL T~? POST BF~2: SEC. ~. T~N..I~E , 2331 FNL. 461' FEL ITARGET POST BF, I: I SEC. 18, T11N, R11E , ~2~o' FNL, 570' FEL ' "T~ET p&~ ~F~3 SEC. 18. T11N. R11E I 2446* FNL, 206' FWL I ~ SEC. 17. TllN, R11E 1200 1800 2400 3000 0 38OO 4200 "~ 4800 5400 6000 6600 7200 7800 8400 ARCO Alaska, .... Sb'-,m~ure: Pad IC W~II: Fldd: Ir,,q~ruk R1~r Un~ ~: No~ ~ Fast (feet) -> 8O 60 4O 20 o 20 4O 6O 0 ~20 I 16O 2400 20O 220 2500 24O 260 280 300 ~ ~ t , 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 I I I I I I I I I I I I I I I I I I I I I I I t I I I I I I I 1400 ~-~ 500 /~-~'-~¢~---700 - ~ 21300 _.~ ~ .~- 1000 2100/ 15~ ,----, ~. 1800 200 700 ~'~ '"=_q~'O-- -- -'1000 J \ ~ 500~ ~ ~.oo ~ooi \ I ~7oo \ ~ 80O 20o0 1, ,oo 1000 t110o \.,,~300 ~ 22O0 \~, 14,00 20 0 20 4O 60 \ \ \%1500 ',, 1600 \~,,17O0 \ .% ..% \ \ \ \ \ 1900 \ \ \ \ 2 6 80 !CO ! 0 ','40 180 Easf (feel) -> 0 120 ~ 160 180 200 22O 24O 250 %2000 \ 280 ~ 300 IgO 200 >~C 240 ARCO Alaska, Inc. 0 looo I V ~1oo Ar, drl,~ ~1 ~: 1-J~-I~ J 2~ 1~ 0 o ,,~ ~"oo ..... ' ' ' ' ' ' ' ' ' '~;~ ' ' ' ' ' ' ' ' ' 2~ ~0 ( ~ 15~ ~ 16~ X 170O 2~2~C % 180O 2~0 X ~ 19~ 700 ~ %~21 O0 2700 ~0 28~ %~00 2900 ~0 3000 5~ % %2~0 5200 ~ 2~ 5500 5700 % ~2900 5800 39 O0 ~31 O0 12~ 4100 4200 ~00 1 ~0 4~0 45O0 4600 47~ ~00 1700 ~900 5O0O 1BO0 ~ 5100 ~J 200 ' :'3 O I O0 200 300 400 500 600 7~0 800 200 1000 11 Eosf (feet) -> lO0 7OO 1100 1200 1500 900 1800 1700 1500 1500 1400 ICteotl<l bX: Andre.~s lro~ BIL~ C)c~ I~ottld : l~Jun-I~ I P~Dt ~*fer~c~ b 2.8 Ve~ ~17. East (feet) -> 800 1200 1600 2000 2400 2800 5200 5600 4000 4-400 4800 5200 5600 60(X) 6400 6800 7200 40O 2800 5OO0 '~ 3000 3200 1200 x%5200 .~, 3400 5400 16oo 20OO '% 4000 5800 \ %4200 24O0 % 4400 x~,,4~oo 28OO ',. 480O ~ 5200 \%,5,000 ~ ~, 4400 ~ 5600 %5400 c- \ 4600 · 0- 'K 5600 0 4OOO 400G.[~] ~ 5800 (.~ /, 5600 5600.( ~ 5200 5200/ "' ,,.6000 I ./500o 5000/ V 44o0 / / % 6200 //2800 66J800~//~/""'x'28°° '' -.6~40o / 6200/ 2600~0 Target - 6500.00 Tvd, 4967.96 S, ,, 2~oo 6000../ _ ~oo ' - -. 5200 ._/ 58o0/ . ~.'-~,~2oo 5600 520o./ . ~ - -.Z~ '°.~.. ~,~oo r~ /~ ~ 5200 ~. 5200 .4 ~,"3000 / 3000 ~ ¢'2~oo .- ~8oo / / 2600 24-00 / '~3400 1200 1600 20OO 24OO 2800 0 52OO 56O0 64OO / "'3000 7200 "' --~2oo ~ ~ %00 F ~2oo 7500 t , , ~ , ; ~ ~ , , ~ ; : ; ~ ~ ~ , , , r ; ~ ~ ~ , , , J 7600 800 1200 1600 20C0 2400 2800 3200 3600 4000 4400 4800 5200 5800 5000 6400 6800 7200 East (feet) -> ARCO Alaska, I .nc.t SIn.,c, tv~: Pocl lC Wd: / 56O0 I V ~ East (feet) -> I~00 60(30 6400 6800 7200 7~00 ~IX)O 844)0 8800 g200 g~:X) 10000 10400 10000 11200 1 lEtO 12000 320028002400 m ~ I I t m m ~ ~, ~ s s , t e I x I ~ I m m I m ~ I ~ ~ ~ ~ ~20028002400 I ~ _,.~% 88OO 9200 1 0000 ) ......... , ~ ~ ~ , , 5600 6000 6400 6800 7200 7600 800~ 8400 8800 9200 96,30 10000 ! O~ 10800 I ! 2.% ! ! 600 Eosf (feel) -> I ~ V 7~ 84OO F , ; i 10000 1900 0 ARCO Alaska, Inc. Structure: Pad lC Field: Kuparuk River Unit Well : 26 Location : North Slope, Alaska 340 TRUE NORTH 50 0 10 20 lO0 40 3O0 310 5OO 50 60 290 7O 28O 8O 270 9O 260 1 O0 25O 110 240 120 250 130 220 210 200 190 180 140 150 160 170 Normc --.:-e Travelling Cylinder - ?eat Al! Ce2t~s shown are Measured deF,'.ns on Reference Well ARCO Alaska, Inc. Pad 1C 26 slot #26 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 26 Version #7 Our ref : prop3211 License : Date printed : 1-Jun-99 Date created : 25-Nov-98 Last revised : 1-Jun-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.433,w149 29 40.041 Slot Grid coordinates are N 5968537.231, E 562346.302 Slot local coordinates are 1702.00 S 1339.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North LL · ARCO Alaska. Inc. Pad 1C,26 Kuparuk River Unit,North Slope. Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 9500.00 58.74 129,36 6021.32 9668.97 58.74 129.36 6109.00 9817.61 58.74 129.36 6186.13 9900.00 60.88 127.92 6227.56 9932.15 61.72 127.38 6243.00 10000.00 63.50 126.26 6274.21 10100.00 66.13 124.67 6316.77 10164.53 67.84 123.68 6342.00 10200.00 68.78 123.15 6355.11 10300.00 71.44 121.68 6389.13 10355.13 72.92 120.89 6406.00 10400.00 74.12 120.26 6418.73 10500.00 76.80 118.87 6443.84 10563.30 78.50 118.01 6457.38 10600.00 79.49 117.51 6464.38 10663.30 81.20 116.67 6475.00 10700.00 82.19 116.18 6480~30 10800.00 84.89 114.86 6491.56 10900.00 87.59 113.56 6498.12 10989.17 90.00 112.40 6500.00 10989.19 90.00 112.40 6500.00 10990.96 90.00 112.45 6500.00 11000.00 90.00 112.45 6500.00 11500.00 90.00 112.45 6500.01 11985.54 90.00 112.45 6500.01 11985.56 90.00 112.45 6500.01 12000.00 89.28 112.51 6500.10 12078.58 85.36 112.81 6503.77 12294.59 85.36 112.81 6521.24 12300.00 85.63 112.79 6521.67 12387.50 90.00 112.55 6525.00 12500.00 90.00 112.55 6525.00 12813.55 90.00 112.55 6525.00 12813.57 90.00 112.55 6525.00 12832.75 90.58 112.56 6524.90 13000.00 90.58 112.56 6523.22 13321.03 90.58 112.56 6520.00 13321.05 90.58 112.56 6520.00 13400.00 93.30 109.70 6517.33 13405.76 93.50 109.49 6516,99 13438.19 93.50 109,49 6515.00 13438.24 93.50 109.49 6515.00 13438.26 93.50 109.49 6515.00 13500.00 92.74 107.14 6511.64 13600.00 91.51 103.33 6507.92 13700.00 90.27 99.52 6506,37 13780.60 89.27 96.46 6506.70 14000.00 89.27 96,46 6509.50 14117.19 89.27 96.46 6511.00 14117.21 89.27 96.46 6511.00 PROPOSAL LISTING Page 2 Your ref : 26 Version#7 Last revised : 1-Jun-99 R E C TAN G U LA R Dogleg Vert C 0 0 R B I N A T E S Deg/lOOft Sect 4237.39 S 4992.33 E 0.00 6546.12 4328.99S 5104.01 E 0.00 6690.55 C30 (K-2) 4409.56 S 5202.26 E 0.00 6817.61 Begin Build/Turn to Target 4454.02 S 5257.89 E 3.00 6888,82 4471,25 S 5280.22 E 3.00 6917.01 C20 (HRZ Midpoint) 4507.35 S 5328.44 E 3.00 6977.21 4559.84S 5402.14 E 3.00 7067.53 4593.20 S 5451.27 E 3.00 7126.72 Base HRZ 4611.35 S 5478.78 E 3.00 7159.53 4661.74S 5558.16 E 3,00 7252.95 4689.00 S 5603.01E 3.00 7304.98 K-1 4710.88, S 5640.06 E 3.00 7347,55 4758.63 S 5724.24 E 3.00 7443.06 4788.07 S 5778,61 E 3.00 7503.87 7' Casing Pt. 4804.85 S 5810.49 E 3.00 7539.21 4833.27 S 5866.05 E 3.00 7600.30 Top of Kuparuk D Shale 4849.43 S 5898.57 E 3,00 7635.76 4892.~ S 5988.23 E 3.00 7732.42 4933.15 S 6079.22 E 3.00 7828.94 4967.95S 6161.29 E 3.00 7914.67 Target - Heel I 4967.96 S 6161.31E 3.00 7914,69 1C-26 Heel1 28-May-99 4968.63 S 6162.94 E 3.00 7916.39 EOC 4972.09 S 6171.30 E 0.00 7925.06 5163.05 S 6633.39 E 0.00 8404.65 5348.49 S 7082.12 E 0.00 8870.36 Heel 2/Begin Angle Drop 5348.49 S 7082.13 E 0.00 8870.38 1C-26 Heel2 28-May-99 5354.01S 7095,48 E 5.00 8884.23 5384.25 S 7167.90 E 5.00 8959.59 EOC 5467.71S 7366.37 E 0.00 9166,47 Begin Angle Build to Fault Uplift 5469.80 S 7371.34 E 5.00 9171.65 5503.49 S 7452.00 E 5.00 9255.60 EOC 5546.64S 7555.89 E 0.00 9363.56 5666.91 S 7845.46 E 0.00 9664.47 Fault/Begin Angle Build 5666.92 S 7845.48 E 0.00 9664.49 1C-26 BtwnFault 24-May-99 5674.28 S 7863.19 E 3.00 9682.90 EOC 5738.43 S 8017.64 E 0.00 9843.39 5861.56 S 8314.10 E 0.00 10151.47 Target/Begin Build&Turn 5861.57 S 8314.12 E 0.00 10151.49 1C-26 PostBF#1 5890,01 S 8387.70 E 5,00 10226.62 5891.94S 8393.12 E 5.00 10232.05 EOC 5902.74 S 8423.63 E 0.00 10262.58 Begin Drop&Turn 5902.75S 8423.68 E 5.00 10262.63 Target PostBF #2 5902.76 S 8423.70 E 5.00 10262.65 1C-26 PostBF #2 24-May-99 5922,13 S 8482.22 E 4.00 10320.36 5948.38 S 8578.62 E 4.00 10411.88 5968.18 S 8676.61E 4.00 10500.59 5979.39 S 8756.42 E 4.00 10569.75 EOC 6004.07 S 8974.40 E 0.00 10754.94 6017,25 S 9090.84 E 0.00 10853,86 Target/Begin Build&Turn 6017,2~ S 9090.86 E 0.00 10853.87 1C-26 PostBF#3 24-May-99 All dat~ is in feet unless otherwise stated. Coordinates from slot #26 a"c TVD from RKB (Pool 6) (95.00 Ft above mean sea level). Bottom hole distance is 11372.35 on azimuth 121.53 degrees from wellhead. Total De, leg for wellpath is 142.75 degrees. Vertical sectic" is from wellhead on azimuth 128.88 degrees. Calculat-? uses the minimum curvature method. ?ssented by Baker Hughes iNTEQ ARCO Alaska. Inc. Pad 1C,26 Kuparuk Ri ver Unit. North S1 ope, A1 aska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 14200.00 89.17 92.32 6512.13 14300.00 89.05 87.32 6513.69 14400.00 88.94 82.32 6515.45 14498.93 88.84 77.38 6517.36 14500.00 88.84 77.38 6517.38 14727.88 88.84 77.38 6522.00 14727.90 88.84 77,38 6522.00 RECTANGULAR COORDINATES PROPOSAL LISTING Page 3 Your ref : 26 Version#7 Last revised : 1-Jun-99 Dogleg Vert Deg/lOOft Sect 6023.59 S 9173.38 E 5.00 10922.09 6023.28 S 9273.34 E 5.00 10999.71 6014.26 S 9372.88 E 5.00 11071.54 5996.83 S 9470,21 E 5,00 11136,37 EOC 5996.60 S 9471.26 E 0.00 11137.04 5946.80 S 9693.59 E 5946.80 S 9693.60 E 0.00 11278.85 Target/ExtToe/TD/Casing Pt 0.00 11278,87 1C-26 ExtndToe 4-Mar-99 All data is in feet unless otherwise stated. Coordinates from slot #26 and TVD from RKB (Pool 6) (95.00 Ft above mean sea level), Bottom hole distance is 11372.35 on azimuth 12i,53 degrees from wellhead. Total Dogleg for wellpa~h is 142.75 degrees. Vertical section is from wellhead on azimuth 128.88 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, :nc. Pad lC, 26 Kuparuk River Unit,North Slope, Alaska PROPOSAL LIST, ING Page 4 Your ref : 26 Version #7 Last revised: 1-Jun-99 Co~nts i n wel 1 path MD TVD Rectangul ar Coords, Co~ent 300.00 300.00 0,00 N 0.00 E Begin Directional Nudge 633,33 1200.00 1853.00 2955.18 5265.42 6115.29 6500.72 6816,78 7917.18 8397.04 8975.19 9668.97 9817.61 9932,15 10164,53 10355.13 10563,30 10663.30 10989.17 10989,19 10990.96 11985.54 11985.56 12078.58 12294,59 12387,50 12813.55 12813,57 12832,75 13321.03 13321,05 13405.76 13438.19 13438 24 13438 26 13780 60 14117 19 14117 21 14498 93 14727 88 14727 90 632,91 I4,54 S 0,00 E EOC 1197,24 65.48 S 2.10 E KOP 1821,00 206.63 S 117,30 E Base of Permafrost 2625.22 689.56 S 666,35 E EOC 3824.00 1941,90 S 2193,37 E Top of West Sak 4265,00 2~02.61S 2755,12 E Base of West Sak 4465.00 2611,54 S 3009,88 E 9 5/8" Casing Pt 4629.00 2782,87 S 3218,78 E C80 5200,00 3379,38 S 3946,12 E C60 5449,00 3639,50 S 4263,30 E C50 5749.00 395,2.91 S 4645,44 E C40 6109.00 4328,99 S 5104,01 E C30 (K-2) 6186,13 4409,56 S 5202,26 E Begin Build/Turn to Target 6243,00 4471,25 S 5280,22 E C20 (HRZ Midpoint) 6342.00 4593,20 S 5451,27 E Base HRZ 6406,00 4689.00 S 5603,01E K-1 6457.38 4788.07 S 5778,61 E 7' Casing Pt. 6475,00 4833.27 S 5866.05 E Top of Kuparuk D Shale 6500.00 4967.95 S 6161,29 E Target - Heel 1 6500.00 4967,96 S 6161,31 E 1C-26 Heel1 28-May-99 6500,00 4968.63 S 6162,94 E EOC 6500.01 5348.49 S 7082.12 E Heel 2/Begin Angle Drop 6500,01 5348,49 S 7082,13 E 1C-26 Heel2 28-May-99 6503,77 5384.25 S 7167,90 E EOC 6521,24 5467,71S 7366,37 E Begin Angle Build to Fault Upli~ 6525,00 5503.49 S 7452,00 EEOC 6525.00 5666,91 S 7845,46 E Fault/Begin Angle Build 6525.00 5666.92 S 7845.48 E 1C-26 BtwnFault 24-May-99 6524,90 5674,28 S 7863,19 E EOC 6520.00 5861.56 S 8314,10 E Target/Begin Build&Turn 6520.00 5861,57 S 8314,12 E 1C-26 PostBF #1 6516.99 5891.94 S 8393,12 E EOC 6515,00 5902.74 S 8423,63 E Begin Drop&Turn 6515.00 59~2,75 S 8423,68 E Target PostBF #2 6515.00 5902.76 S 8423,70 E 1C-26 PostBF #2 24-May-99 6506.70 5979.39 S 8756,42 E EOC 6511,00 6017,25 S 9090,84 E Target/Begin Build&Turn 6511.00 6017.25 S 9090,86 E 1C-26 PostBF#3 24-May-99 6517.36 5996.83 S 9470,21 EEOC 6522.00 5946.80 S 9693,59 E Target/ExtToe/TD/Casing Pt 6522,00 5946.80 S 9693,60 E 1C-26 ExtndToe 4-Mar-99 Casing positions in string 'A' Top MD Top IVD Rectangular Coords, Bot MD Bot TVD Rectangular Coords. Casing 0.00 0,00 O.OON O.OOE 6500,72 4465,00 2611,54S 3009,88E 9 5/8" Casing Pt 0.00 0,00 O,OON O,OOE 10563,30 6457,38 4788,07S 5778,61E 7" Casing 0.00 0,00 O.OON O,OOE 14727,80 6522,00 5946,82S 9693,51E 4 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Ccordinates Revised 1C-26 Heel1 28-May-9 562547.200,5963620.000,0.~000 6500.00 4967.96S 6161 31E 28-May-99 1C 26 Heel2 28-May-9 E.69471.000,5963247.000,0.0000 6500.01 5348.49S 7082 13E 28-May-99 1C 26 BtwnFault 24-M 6525.00 5666.92S 7845 48E 24-May-99 1C 26 PostBF #1 6520.00 586i.57S 8314 12E 24-May-99 1C 26 PostBF #2 24-M 6515.00 5902.76S ~A23 70E 24-May-99 1C 26 PostBF #3 24-M 6511.00 6017.25S 9090 $6E 24-May-99 lC 26 ExtndToe 4-Mar ~2087.000,5962670.000,0.S000 6522.00 5946.80S 9693.60E 6-May-99 ARCO Alaska. Inc, Pad 1C.26 Kuparuk River Unit. North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECT COOR 9500.00 58.74 129.36 6021.32 4237.39 9668.97 58.74 129.36 6109.00 4328.99 9817.61 58.74 129.36 6186.13 4409.56 9900.00 60.88 127,92 6227.56 4454.02 9932.15 61.72 127.38 6243.00 4471.25 10000.00 63.50 126.26 6274.21 4507.35 10100.00 66.13 124.67 6316.77 4559.84 10164.53 67.84 123.68 6342.00 4593.20 10200.00 68.78 123.15 6355.11 4611.35 10300.00 71.44 121.68 6389.13 4661.74 10355.13 72.92 120.89 6406.00 4689.00 10400.00 74.12 120.26 6418.73 4710.88 10500.00 76.80 118.87 6443.84 4758.63 10563.30 78.50 118.01 6457.38 4788.07 10600.00 79.49 117.51 6464.38 4804.85 10663.30 81.20 116.67 6475.00 4833.27 10700.00 82.19 116.18 6480.30 4849.43 10800.00 84.89 114.86 6491.56 4892.23 10900.00 87.59 113.56 6498.12 4933.15 10989.17 90,00 112.40 6500.00 4967.95 10989.19 90.00 112.40 6500.00 4967.96 10990.96 90.00 112.45 6500.00 4968.63 11000.00 90.00 112.45 6500.00 4972.09 11500.00 90.00 112.45 6500.01 5163,05 11985.54 90.00 112.45 6500.01 5348.49 11985.56 90.00 112.45 6500.01 5348.49 12000.00 89,28 112.51 6500.10 5354.01 12078.58 85.36 112.81 6503.77 5384.25 12294.59 85.36 112.81 6521.24 5467.71 12300.00 85.63 112.79 6521.67 5469.80 ANGULAR DINATES PROPOSAL LISTING Page 2 Your ref : 26 Version #7 Last revised : 1-$un-99 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. S 4992.33 E 6546.12 429.02 43.49 60.21 309.79 S 5104.01 E 6690.55 438.76 44.34 61.56 309.78 S 5202.26 E 6817.61 447.34 45.08 62.75 309.78 S 5257.89 E 6888.82 452.34 45,47 63.43 309.76 S 5280.22 E 6917.01 454.40 45.62 63.71 309.74 S 5328.44 E 6977.21 458.76 45,93 64.30 309.71 S 5402.14 E 7067.53 465.52 46.36 65.21 309.63 S 5451.27 E 7126.72 470.08 46.62 65.82 309.57 S 5478.78 E 7159.53 472.58 46.76 66.15 309.53 S 5558.16 E 7252.95 479.93 47.12 67.13 309.41 S 5603,01 E 7304.98 484.12 47.30 67.68 309.33 S 5640.06 E 7347.55 487.53 47.45 68.13 309.27 S 5724.24 E 7443,06 495.34 47.74 69.15 309.10 S 5778.61 E 7503,87 500.41 47.90 69.81 3D8.98 S 5810.49 E 7539.21 503.35 48.00 70.20 308.91 S 5866.05 E 7600.30 508.51 48.13 70.87 308.78 S 5898.57 E 7635.76 511.51 48.21 71.26 308.70 S 5988.23 E 7732.42 519.78 48.39 72.33 308.48 S 6079.22 E 7828.94 528.12 48.53 73.41 308.23 S 616i.29 E 7914.67 535.60 48.62 74.38 308.00 S 6161.31 E 7914.69 535.60 48,62 74.38 308.00 S 6162.94 E 7916.39 535.75 48.62 74.40 308.00 S 6171.30 E 7925.06 536,50 48.63 74.50 307.98 S 6633.39 E 8404.65 578.59 49.17 79,93 306.81 S 7082.12 E 8870.36 619.71 49.70 85.20 305.83 S 7082.13 E 8870.38 619.71 49.70 85.20 305.83 S 7095.48 E 8884.23 620.94 49.72 85.35 305.80 S 7167,90 E 8959.59 627.57 49.86 86.20 305.66 S 7366.37 E 9166.47 645.83 50.25 88.52 305.29 S 7371.34 E 9171.65 646.29 50.26 88.58 305.28 12387.50 90.00 112.55 6525.00 5503.49 S 7452.00 E 9255.60 653.74 50.36 89.53 305.13 12500.00 90.00 112.55 6525.00 5546.64 S 7555.89 E 9363.56 663,33 50,48 90.75 304.94 12813.55 90.00 112.55 6525.00 5666.91 S 7845.46 E 9664.47 690.10 50.83 94.14 304.45 12813.57 90.00 112.55 6525.00 5666.92 S 7845.48 E 9664.49 690.10 50.83 94.14 304.45 12832.75 90.58 112.56 6524.90 5674,28 S 7863.19 E 9682.90 691.74 50.85 94.35 304.42 13000.00 90.58 112.56 6523.22 5738.43 S 8017.64 E 9843.39 706.04 51.02 96.17 304.18 13321.03 90.58 112.56 6520.00 5861,56S 8314.10 E 10151.47 733,54 51.35 99.64 303.73 13321.05 90.58 112.56 6520.00 5861.57 S 8314.12 E 10151.49 733.54 51.35 99.64 303.73 13400.00 93.30 109.70 6517.33 5890.01 S 8387.70 E 10226.62 740.32 51.41 100.50 303,60 13405.76 93.50 109.49 6516.99 5891,94S 8393.12 E 10232.05 740.82 51.41 100.56 303.59 13438.19 93.50 109.49 6515.00 5902.74 S 8423.63 E 10262.58 743.61 51.44 100.91 303.54 13438.24 93.50 109.49 6515.00 5902.75S 8423.68 E 10262.63 743.61 51.44 100.91 303.54 13438.26 93.50 109.49 6515.00 5902.76 S 8423.70 E 10262.65 743.61 51.44 100.91 303.54 13500.00 92.74 107.14 6511.64 5922.13 S 8482.22 E 10320.36 748.93 51.49 101.58 303.41 13600.00 91.51 103.33 6507.92 5948.38 S 8578.62 E 10411.88 757.49 51.62 102.66 303.18 13700.00 90.27 99.52 6506.37 5968.18 S 8676.61 E 10500.59 765.95 51.78 103.75 302.90 13780.60 89.27 96.46 6506.70 5979.39 S 8756.42 E 10569.75 772.66 51.93 104.62 302.65 14000.00 89.27 96.46 6509.50 6004.07 S 8974.40 E 10754.94 790,99 52.36 106.99 301.99 14117.19 89.27 96.46 6511.00 6017.25 S 9090.84 E 10853.86 800.82 52.59 108.26 301.66 14117.21 89.27 96.46 6511,00 6017.25 S 9090.86 E 10853.87 800.82 52.59 108,26 301.66 All dat~ is in feet unless otherwise stated. Coordinates from slot #26 a~d TVD from RKB (Pool 6) (95.00 Ft above mean sea level), Bottom hole distance -s 11372.35 on azimuth 121.53 degrees from wellhead. Vertical sectic" is from wellhead on azimuth !28.88 degrees, Ca!cul~en uses the minimum curvature method. ?resented by Baker Hughes iNTEQ ARCO Alaska, Inc. Pad 1C. 26 Ku~ruk Ri ver Unit, North Slope. A1 aska PROPOSAL LISTING Page 3 Your ref : 26 Version #7 Last revised : 1-Jun-99 Measured Znclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 14200.00 89.17 92.32 6512.13 6023.59 S 9173.38 E 10922.09 807.56 52.77 109.16 301.39 14300.00 89,05 87.32 6513.69 6023.28 S 9273.34 E 10999.71 815.31 53.00 110.24 301,02 14400.00 88.94 82.32 6515.45 6014.26 S 9372.88 E 11071.54 822.57 53.26 111.32 300.61 14498.93 88.84 77.38 6517.36 5996.83 S 9470.21 E 11136.37 829.19 53.52 112.39 300.18 14500.00 88.84 77.38 6517.38 5996.60 S 9471.26 E 11137.04 829.26 53.53 112.40 300.18 14727.88 88.84 77.38 6522.00 5946.80 S 9693.59 E 11278.85 844.69 54.15 114.87 299,21 14727.90 88.84 77.38 6522.00 5946.80 S 9693.60 E 11278.87 844.69 54.15 114.87 299.21 POSITION UNCERT~,~FFY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 14728 ARCO (H.A, Mag) User specified 844.69 54.15 114.87 1. E11 ipse dimensions are hal f axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresl>~qding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. All data is in feet un!ess otherwise stated. Coordinates from slot #26 and TVD from RKB (xcel 6) (95.00 Ft above mean sea level). Bottom hole distance is 11372.35 on az-~h 121.53 degrees from wellhead. Vertical section is from wellheaz on azimuth 128,~ degrees. Calculation uses the minimum curvature method. Presented by Baker ~ghes iNTEQ ARCO Alaska, Inc. Pad 1C.26 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 4 Your ref : 26 Version #7 Last revised : 1-Ju~-99 Co~nents in wellpath MD TVD Rectangular Coords. Comment 300.00 633.33 1200.00 1853.00 2955.18 5265.42 6115 29 6500 72 6816 78 7917 18 8397 04 8975 19 9668 97 9817 61 9932 15 10164.53 10355.13 10563.30 10663.30 10989.17 10989.19 10990.96 11985.54 11985.56 12078.58 12294.59 12387.50 12813.55 12813,57 12832.75 13321.03 13321.05 13405 76 13438 19 13438 24 13438 26 13780 60 14117 19 14117 21 14498 93 14727 88 14727 90 300.00 632.91 1197.24 1821 O0 2625 22 3824 O0 4265 O0 4465 O0 4629 O0 5200 O0 5449 O0 5749 O0 6109 O0 6186 13 6243.00 6342.00 6406.00 6457.38 6475.00 6500.00 6500.00 6500.00 6500.01 6500.01 6503.77 6521.24 6525.00 6525.00 6525,00 6524.90 6520.00 6520 O0 6516 99 6515 O0 6515 O0 6515 O0 6506 70 6511 O0 6511 O0 6517 36 6522 O0 6522 O0 0.00 14.54 65.48 206 63 689 56 1941 90 2402 61 2611 54 2782 87 3379 38 3639 50 3952 91 4328.99 4409.56 4471.25 4593.20 4689.00 4788.07 4833.27 4967.95 4967.96 4968.63 5348.49 5348.49 5384.25 5467.71 5503.49 5666 91 5666 92 5674 28 5861 56 5861 57 5891 94 5902 74 5902 75 5902.76 5979.39 6017.25 6017.25 5996.83 5946.80 5946.80 0,00 0.00 2.10 117.30 666.35 2193.37 2755.12 3009.88 3218.78 3946 12 4263 30 4645 44 5104 01 5202 26 5280 22 5451 27 5603 01 5778.61 5866.05 6161.29 6161.31 6162.94 7082,12 7082.13 7167,90 7366.37 7452.00 7845.46 7845,48 7863.19 8314.10 8314.12 8393.12 8423 63 8423 68 8423 70 8756 42 9090 84 9090 86 9470 21 9693 59 9693 60 E Begin Directional Nudge EEOC E KOP E Base of Permafrost EEOC E Top of West Sak E Base of West Sak E 9 5/8" Casing Pt E C80 E C60 E C50 E C40 E C30 (K-2) E Begin Build/Turn to Target E C20 (HRZ Midpoint) E Base HRZ E K-1 E 7" Casing Pt. E Top of Kuparuk D Shale E Target- Heel 1 E 1C-26 Heel i 28-May-99 EEOC E Heel 2/Begin Angle Drop E 1C-26 Heel2 28-May-99 EEOC E Begin Angle Build to Fault Uplift EEOC E Fault/Begin Angle Build E 1C-26 BtwnFaul t 24-May- 99 EEOC E Target/Begin Build&Turn E 1C-26 PostBF #1 EEOC E Begin Drop&Turn E Target PostBF #2 E 1C-26 PostBF #2 24-May-99 EEOC E Target/Begin Build&Turn E 1C-26 PostBF #3 24-May-99 EEOC E Target/ExtToe/TD/Casing Pt E 1C-26 ExtndToe 4-Mar-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6500.72 4465.00 2611,54S 3009.88E 9 5/8' Casing Pt 0.00 0.00 O,OON O.OOE 10563.30 6457.38 4788.07S 5778.61E 7" Casing 0.00 0.00 O,OON O.OOE 14727.80 6522,00 5946.82S 9693.51E 4 1/2' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-26 Heell 28-May-9 568547.200,5963620.000.0.0000 6500.00 1C-26 Heel2 28-May-9 569471.000.5963247.000,0.0000 6500.01 1C-26 BtwnFault 24-M 6525.00 1C-26 PostBF #1 6520,00 1C-26 PostBF #2 24-M 6515,00 1C-26 PostBF #3 24-M 65t!.00 1C-26 ExtndToe 4-~iar 572087.0C~,5962670.000,0.0000 6522.00 4967.96S 6161.3iE 28-May-99 5348.49S 7082.!3E 28-May-99 5666.92S 7845.~E 24-May-99 5861.57S 8314.!2E 24-Hay-99 5902,76S 8423.7~£ 24-May-99 6017.25S 9090.E~E 24-May-99 5946.80S 9693.6CE 6-May-99 Presented by Baker Hughes INTEQ ~/ ARCO Alaska. Inc. Pad 1C,26 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 9500.00 58.74 129.36 6021.32 9668.97 58.74 129.36 6109.00 9817.61 58.74 129.36 6186.13 9900.00 60.88 127.92 6227.56 9932.15 61.72 127.38 6243.00 10000.00 63.50 126.26 6274.21 10100.00 66.13 124.67 6316.77 10164.53 67.84 123.68 6342.00 10200.00 68.78 123.15 6355.11 10300.00 71.44 121.68 6389.13 10355.13 72.92 120.89 6406.00 10400.00 74.12 120.26 6418.73 10500.00 76.80 118.87 6443.84 10563.30 78.50 118.01 6457.38 10600.00 79.49 117.51 6464.38 10663.30 81.20 116.67 6475.00 10700.00 82.19 116.18 6480.30 10800.00 84.89 114.86 6491.56 10900.00 87.59 113.56 6498.12 10989.17 90.00 112.40 6500.00 10989.19 90.00 112.40 6500.00 10990.96 90.00 112.45 6500.00 11000.00 90.00 112.45 6500.00 11500.00 90.00 112.45 6500.01 11985.54 90.00 112.45 6500.01 11985.56 90.00 112.45 6500.01 12000.00 89.28 112.51 6500.10 12078.58 85.36 112.81 6503.77 12294.59 85.36 112.81 6521.24 12300.00 85.63 112.79 6521.67 12387.50 90.00 112.55 6525.00 12500.00 90.00 112.55 6525.00 12813.55 90.00 112.55 6525.00 12813.57 90.00 112.55 6525.00 12832.75 90.58 112.56 6524.90 13000.00 90.58 112.56 6523.22 13321.03 90.58 112.56 6520.00 13321.05 90.58 112.56 6520.00 13400.00 93.30 109.70 6517.33 13405.76 93.50 109.49 6516.99 13438.19 93.50 109.49 6515.00 13438.24 93.50 109.49 6515.00 13438.26 93.50 109.49 6515.00 13500.00 92.74 107.14 6511.64 13600.00 91.51 103.33 6507.92 13700.00 90.27 99.52 6506.37 13780.60 89.27 96.46 6506.70 14000.00 89.27 96.46 6509.50 14117.19 89.27 96.46 6511.00 14117.21 89.27 96.46 6511.00 PROPOSAL LISTING Page2 Your ref : 26 Version #7 Last revised : 1-~un-99 Dogleg Vert G R I D C O0 R D S Deg/lOOft Sect Easting ~rthing 4237.39S 4992.33E 0.00 6546.12 4328.99S 5104.01E 0.00 6690.55 4409.56S 5202.26E 0.00 6817.61 4454.02S 5257.89E 3.00 6888.82 4471.25S 5280.22E 3.00 6917.01 4507.35S 5328.44E 3.00 6977 4559.84S 5402.14E 3.00 7067 4593.20S 5451.27E 3.00 7126 4611.35S 5478.78E 3.00 7159 4661.74S 5558.16E 3.00 7252 4689.00S 5603.01E 3.00 7304 4710.88S 5640.06E 3.00 7347 4758.63S 5724.24E 3.00 7443 4788.07S 5778.61E 3.00 7503 4804.85S 5810.49E 3.00 7539 567372.43 5964340.97 567484.85 59~250.29 567583.74 5964170.52 567639.72 5964126.53 567662.19 5964109.48 .21 567710.70 5964073.78 .53 567784.81 5964021.90 .72 567834.21 5963988.94 .53 567861.86 5963971.01 .95 567941.64 5963921.27 .98 567986.71 5963894.38 .55 568023.93 5963872.81 .06 568108.49 5963825.75 .87 568163.09 5963796.75 .21 568195.11 5963780.23 4833.27S 5866.05E 3.00 7600.30 4849.43S 5898~57E 3.00 7635.76 4892.23S 5988.23E 3.00 7732.42 4933.15S 6079.22E 3.00 7828.94 4967.95S 6161.29E 3.00 7914.67 4967.96S 6161.31E 3.00 7914 4968.63S 6162.94E 3.00 7916 4972.09S 6171.30E 0.00 7925 5163.05S 6633.39E 0.00 8404 5348.49S 7082.12E 0.00 8870 5348.49S 7082.13E 0.00 8870 5354.01S 7095.48E 5.00 8884 5384.25S 7167.90E 5.00 8959 5467.71S 7366.37E 0.00 9166 5469.80S 7371.34E 5.00 9171 5503.49S 7452.00E 5.00 9255 5546.64S 7555.89E 0.00 9363 5666.91S 7845.46E 0.00 9664 5666.92S 7845.48E 0.00 9664 5674.28S 7863.19E 3.00 9682 568250.89 5963752.27 568283.53 5963736.38 568373.53 5963694.31 568464.84 5963654.14 568547.19 5963620.01 .69 568547.20 5963620.00 .39 568548.84 5963619.34 .06 568557.23 5963615.95 .65 569020.81 5963428.77 .36 569470.98 5963247.01 .38 569471.00 5963247.00 .23 569484.39 5963241.59 .59 569557.05 5963211.95 .47 569756.17 5963130.11 .65 569761.16 5963128.06 .60 569842.08 5963095.03 .56 569946.31 5963052.73 .47 570236.82 5962934.83 .49 570236.84 5962934.82 .90 570254.61 5962927.61 5738.43S 8017.64E 0.00 9843.39 5861.56S 8314.10E 0.00 10151.47 5861.57S 8314.12E 0.00 10151.49 5890.01S 8387.70E 5.00 10226.62 5891.94S 8393.12E 5.00 10232.05 5902.74S 8423.63E 0.00 10262.58 5902.75S 8423.68E 5.00 10262.63 5902.76S 8423.70E 5.00 10262.65 5922.13S 8482.22E 4.00 10320.36 5948.38S 8578.62E 4.00 10411.88 570409.56 5962864.72 570706.98 5962744.01 570707.00 5962744.00 570780.81 5962716.17 570786.24 5962714.28 570816.83 5962703.73 570816.88 5962703.72 570816.90 5962703.71 570875.57 5962684.82 570972.18 5962659.36 5968.18S 8676.61E 4.00 10500.59 571070.31 5962640.35 5979.39S 8756.42E 4.00 10569.75 571150.20 5962629.80 6004.07S 8974.40E 0.00 10754.94 571368.36 5962606.89 6017.25S 9090.84E 0.00 10853.86 571484.89 5962594.66 6017.25S 9090.86E 0.00 10853.87 571484.90 5~2594.65 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #26 and TVD from RKB (Pool 6) (95.00 Ft above mean sea level). Bottom hole distance is 11372.35 on azimuth 121.53 degrees from wellhead. Total Dogleg for weilpath is i42.75 degrees. Vertical section is from wellhead on azimuth 128.88 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed usinG_ th~..~ Clarke - 1866 >pner~ .... Presented by Baker ~ughes INTEQ .... ARCO Alaska. Inc. Pad lC, 26 Kuparuk River Unit,North Slope. Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 14200.00 89.17 92.32 6512.13 14300.00 89.05 87.32 6513.69 14400.00 88.94 82.32 6515.45 14498.93 88.84 77,38 6517,36 14500.00 88.84 77.38 6517.38 14727.88 28.84 77.38 6522.00 14727.90 ~8.84 77,38 6522.00 PROPOSAL LISTING Page 3 Your ref : 26 Version #7 Last revised : 1-2un-99 R E C T A N G U L A R Dogleg Vert C 0 0 R D I N A T E S Deg/lOOft Sect 6023.59S 9173.38E 5.00 10922.09 6023.28S 9273.34E 5.00 10999.71 6014,26S 9372.88E 5.00 11071.54 5996.83S 9470.21E 5.00 11136.37 5996.60S 9471.26E 0.00 11137.04 5946.80S 9693.59E 0,00 11278.85 5946.80S 9693.60E 0.00 11278.87 GRID COORDS Easting Northing 571567.47 5962588.99 571667.41 5962590.11 571766.87 5962599.94 571864.05 5962618.16 571865.09 5962618.40 572086.98 5962670.00 572087.00 5962670.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #26 and TVD from RKB (tool 6) (95.00 Ft above mean sea level), Bottom hole distance is 11372.35 on azimuth 121.53 degrees from wellhead. Total Dogleg for wellpa~ is 142.75 degrees. Vertical section is from wel!heac on azimuth 128.88 degrees. Grid is alaska - Zone 4, Grid coordinates in FEET and computed ~sing the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1C.26 Kuparuk River Unit.North Slope, Alaska PROPOSAL LISTING Page 4 Your ref : 26 Version #7 Last revised : 1-Jun-99 Comments i n wel 1 path MD IVD Rectangul ar Coords. Comment 300 O0 300.00 O.OON O.OOE Begin Directional Nudge 633 33 1200 O0 1853 O0 2955 18 5265 42 6115 29 65O0.72 6816.78 7917.18 8397.04 8975.19 9668.97 9817,61 9932.15 10164.53 10355.13 10563.30 10663.30 10989.17 10989.19 10990.96 11985.54 11985.56 12078.58 12294 59 12387 50 12813 55 12813 57 12832 75 13321 03 13321 05 13405 76 13438 19 13438 24 13438 26 13780 60 14117 19 14117 21 14498 93 14727 88 14727 90 632.91 1197.24 1821.00 2625.22 3824.00 4265.00 4465.00 4629.00 5200.00 5449.00 5749.00 6109.00 6186.13 6243.00 6342.00 6406.00 6457.38 6475.00 6500.00 6500.00 650O.O0 6500.01 6500.01 6503.77 6521.24 6525.00 6525.00 6525.00 6524.90 6520 O0 6520 O0 6516 99 6515 O0 6515 O0 6515 O0 6506.70 6511,00 6511.00 6517.36 6522.00 6522.00 14 65 206 689 1941 2402 2611 2782 3379 3639 3952 4328 4409 4471 4593 4689 4788 4833 4967 4967 4968 5348 5348 5384 5467 5503 5666 5666 5674 5861 5861 5891 5902 5902 5902 5979 6017 6017 5996 5946 5946 .54S O.OOE EOC 48S 2.10E KOP 63S 117.30E Base of Permafrost 56S 666.35E EOC 90S 2193.37E Top of West Sak 61S 2755.12E Base of West Sak 54S 3009.88E 9 5/8" Casing Pt 87S 3218.78E C80 38S 3946.12E C60 50S 4263.30E C50 91S 4645,44E C40 99S 5104.01E C30 (K-2) 56S 5202,26E Begin Build/Turn to Target 25S 5280.22E C20 (HRZ Midpoint) 20S 5451.27E Base HRZ OOS 5603.01E K-1 07S 5778.61E 7" Casing Pt. 27S 5866.05E Top of Kuparuk D Shale 95S 6161.29E Target - Heel 1 96S 6161.31E 1C-26 Heel1 28-May-99 63S 6162.94E EOC 49S 7082.12E Heel 2/Begin Angle Drop 49S 7082.13E 1C-26 Heel2 28-May-99 25S 7167.90E EOC 71S 7366.37E Begin Angle Build to Fault Uplift 49S 7452.00E EOC 91S 7845.46E Fault/Begin Angle Build 92S 7845.48E 1C-26 BtwnFault 24-May-99 28S 7863.19E EOC 56S 8314.10E Target/Begin Build&Turn 57S 8314.12E 1C-26 PostBF #1 94S 8393.12E EOC 74S 8423.63E Begin Drop&Turn 75S 8423.68E Target PostBF#2 76S 8423.70E 1C-26 PostBF #2 24-May-99 39S 8756.42E EOC 25S 9090.84E Target/Begin Build&Turn 25S 9090.86E 1C-26 PostBF#3 24-May-99 .83S 9470.21E EOC .80S 9693.59E Target/ExtToe/TD/Casing Pt .80S 9693.60E 1C-26 ExtndToe 4-Mar-99 Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 O.OON O.OOE 6500.72 4465,00 2611.54S 3009.88E 9 5/8" Casing Pt 0.00 0.00 O,OON O,OOE 10563.30 6457.38 4788.07S 5778.61E 7" Casing 0.00 0.00 O.OON O.OOE 14727.80 6522.00 5946,82S 9693.51E 4 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1C-26 Heel2 28-May-g 569471.000,5963247.000,0.0000 6500 01 5348.49S 7082.13E 28-May-99 1C-26 BtwnFault 24-v 6525 O0 5666.92S 7845,48E 24-May-99 1C-26 PostBF #1 6520 O0 5861.57S 83!4.12E 24-May-99 1C-26 PostBF #2 24-" 6515 O0 5902.76S 8423.70E 24-May-99 1C-26 PostBF #3 24-" 65il O0 6017.25S 9090.86E 24-May-99 1C-26 ExtndToe 4-Y}~ 272087.000.5962670.000,0.0000 6522 O0 5946.80S 9693.60E 6-May-99 ARCO Alaska, Inc. Pad 1C 26 slot #26 Kuparuk River Unit North Slope, Alaska 3-D M I N I MUM D I STANC E CLEARANCE INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ REPORT Your ref : 26 Version #7 Our ref : prop3211 License : Date printed : 1-Jun-99 Date created : 25-Nov-98 Last revised : 1-Jun-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.433,w149 29 40.041 Slot Grid coordinates are N 5968537.231, E 562346.302 Slot local coordinates are 1702.00 S 1339.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wel 1 path PMSS <O-????'>,,25,Pad 1C 23 Version~5,,23,Pad 1C PMSS <1840 - ???'>,,23A,Pad 1C PMSS <O-???'>,,23,Pad 1C GMS <O-7615'>,,2,Pad 1C PMSS <0 - 8095'>,,18,Pad 1C PMSS <O-9390'>,,15,Pad 1C PMSS <0-10980'>,,14,Pad 1C 21 Version#5,,21,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C GMS <0-7575'>,,4,Pad lC 19 Version #1,,19,Pad 1C PMSS <0 - 10969'),,17,Pad 1C MSS <O-7000'>,,9GI,Pad 1C PGMS <0-9002'>,,lOGI,Pad 1C GMS <0-9600'>,,8,Pad 1C GMS <0-9784'>,,7,Pad 1C GMS <O-10243'>,,6,Pad 1C GMS <0-7753'>,,5,Pad 1C GHS <0-9700'>,,3,Pad 1C Closest approach with 3-D Last revised Distance M.D. 26-Apr-99 )14.7( 100.0 25-Mar-99 )73.2( 328.6 14727 19-May-99 )71.7( 400.0 14727 5-May-99 )71.7( 400.0 7720 18-Dec-98 )88.1( 357.1 357 22-Feb-99 )397.0( 300.0 300 17-Dec-98 )117.3( 514.3 12560 18-Mar-98 )219.2( 700.0 14272 4-Feb-99 )177.5( 328.6 328 8-Jan-99 )514.0( 720.0 14480 18-Dec-98 )327.1( 371.4 371 28-Dec-98 )359.5( 328.6 328 2-Dec-98 )833.8( 200.0 200 2-Jan-98 )853.9( 471.4 471 18-Dec-98 )627.5( 1344.4 5440 18-Dec-98 )809.6( 385.7 14309 18-Dec-98 )687.2( 37i.4 14500 18-Dec-98 )567.6( 371.4 371 18-Dec-98 )446.3( 385.7 385 18-Dec-98 )207.6( 371.4 13680 Minimum Distance method Diverging from M.D. 11680.0 .9 .9 .0 1 0 0 7 6 9 4 6 0 4 0 1 0 4 7 0 PMSS <0-8677'>..13.Pa.~C Unknown Data,,WS1.Pad 1C PMSS <0-11300'>,,11.Pad lC 24 Version #1.,24,Pad 1C MMS <6948-7570'>.,WS~24.Pad 1C PMSS <0-17089'>..12,Pad 1C GMS <O-7780'>..1,Pad 1C 27 Version #11,,27,Pad 1C PMSS <O-???>,.27,Pad 1C 1-Dec-98 2-Nov-98 19-Mar-97 28-Dec-98 17-Dec-97 7-Jan-98 11-Mar-99 27-Apr-99 1-Jun-99 )544.5( )7753.2( )845.9( )57.9( )8577.3( )419.0( )18.5( )13.2( )15.1( 342.~_~y 328. 328.6 371.4 7960.0 3560.0 680.0 414.3 100.0 342.9 328.6 14471.9 371.4 14727.9 14727.9 680.0 14727.9 11420.0 ARCO Alaska, Inc. Pad 1C 26 slot #26 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 26 Version #7 Our ref : prop3211 License : Date printed : 1-Jun-99 Date created : 25-Nov-98 Last revised : 1-Jun-99 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 28.433,w149 29 40.041 Slot Grid coordinates are N 5968537.231, E 562346.302 Slot local coordinates are 1702.00 S 1339.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-4590'>, PGMS <0-8850'> 28-May-81, PGMS <0-9783'> PMSS <0-4414'>, PMSS <0-4515'>, PMSS <0-5205'>, PMSS <0-4850'>, PMSS <0-5126'>, PMSS <381-6092'> PMSS <1957-5265'> PMSS <0-5015'>, PMSS <0-5047'>, Closest approach with 3-D Minimum Distance Iethod Last revised Distance .118,Pad 1D 2-Jun-98 MP I 17-II-II,Pad 1D 23-Apr-99 7063.2 2609.0 4-Aug-92 2212.1 2-Jun-98 8469.4 2-Jun-98 8387.2 2-Jun-98 6022.8 2-Jun-98 7149.8 2-Jun-98 5707.6 2-Jun-98 4174.4 2-Jun-98 8952.7 2-Jun-98 7471.2 2-Jun-98 8714.0 ,2,Pad 1D ,121.Pad 1D ,119,Pad 1D ~117,Pad ID ,109,Pad ID ~106,Pad 1D ,105,Pad 1D ,133,Pad 1D ~135,Pad 1D ,124,Pad 1D 21-May-98 10-Dec-97 13-Nov-97 13-Nov-97 6-Nov-97 29-Apr-98 28-Apr-98 2-Jun-98 2-Jun-98 4-Aug-92 2-Jun-98 13-Aug-98 2- Jun- 98 i-Jul -98 6- Jul - 98 8480.5 6272.4 6061 8 8691 6 9001 9 7282 5 7522 1 9022 6 8908.6 5756 0 8331 8 8389 7 7273 5 8938 9 8971 8 TOTCO Survey,,WS-8,Pad 1D PGMS <0-8365'>,,1,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <O-8610'>,,6,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <556-7024'>,,9,Pad 1D PMSS <0 - 7340'>,,lO,Pad 1D PMSS <O-5462'>,,129,Pad 1D PMSS <O-4778'>,,i30,Pad 1D PGMS <0-7502'>,,4,Pad 1D PMSS <O-5142'>,,115,Pad ZD PGMS <O-8070'>,,3,Pad iD PIdSS <0-4530'>,, 120.Pad ~ PMSS <0 - 6716'>,,126.Pad iD PMSS <0 - 7432'>,,127,Pad ID M.D. 5850.0 10991.0 8780.0 5550.0 5380.0 7220.0 4820,0 6040.0 6200.0 5140.0 8380.0 5120.0 7020,0 4980.0 10631.7 5640.0 5120.0 6180.0 10033.3 4740.0 5080.0 7640.0 4240.0 5120.0 7320.0 4950.0 4880.0 Diverging from M.D. 5850.0 13100.0 8780.0 6850.0 5380.0 7220.0 4820.0 6040.0 6200.0 10850.0 8380.0 6350.0 7020.0 4980.0 10631.7 6450.0 14327.3 6240.0 10033 10255 732C 7640 4240 875~ 732~ 13473 1206Z.! PMSS <0 - 6472'>..131. 1D PMSS <377 - 6224'>.,134,~r~ad 1D PMSS <467 - 5802'>,,132.Pad 1D PMSS <0 - 6580'>.,128,Pad 1D PMSS <291 - 5795'>,.125oPad 1D PMSS <0 - 5445'>,,122,Pad 1D PMSS <0 - 6270'>..114.Pad 1D PMSS<O-7045'>..111.Pad 1D GSS <0.173'>..123,Pad 1D PMSS <287-6055'>,,123,Pad 1D PMSS <293 - 6866'>,.113,Pad 1D GSS <0-175'>,,116,Pad 1D PMSS <290-6245'>,,116,Pad 1D PMSS <294 - 8250'>,,112,Pad 1D PMSS <256 - 5973'>,,1lO,Pad 1D PMSS <0 - 7150'>,.108,Pad 1D PMSS <O-????'>,,25,Pad 1C PMSS <1840 - ???'>,,23A,Pad 1C PMSS <O-???'>.,23,Pad 1C GMS <0-7615'>.,2.Pad 1C PMSS <0 - 8095'>,.18.Pad 1C PMSS <O-9390'>..15.Pad 1C PMSS <0-10980'>.,14,Pad 1C PMSS <0 - 11918'>,,16,Pad 1C GMS <0-7575'>.,4,Pad lC PMSS <0 - 10969')..17.Pad 1C MSS <0-7000'>..9GI,Pad 1C PGMS <O-9002'>,.lOGI.Pad 1C GMS <0-9600'>.,8,Pad 1C GMS <O-9784'>,,7,Pad lC GMS <0-10243'>,,6,Pad 1C G~LS <0-7753'>,.5,Pad 1C GMS <0-9700'>.,3,Pad 1C PMSS <O-8677'>.,13,Pad 1C Unknown Data.,WS1.Pad 1C PMSS <0-11300'>,,11,Pad 1C MMS <6948-7570'>..WS~24.Pad 1C PMSS <0-17089'>.,12,Pad 1C GMS <O-7780'>..1.Pad 1C PMSS <O-???>,,27,Pad 1C 23-2~i -98 3- Aug- 98 6-Au~-98 17-Aug- 98 19- ,Aug-98 29-A~- 98 2-Sep-98 3-Sep-98 4-Sep-98 13-Sep-g8 22- Sep- 98 8-Sep-98 17-Sep-98 21-Sep-98 5-0ct-98 28-0ct-98 26-Apr-99 19- May- 99 5- May- 99 18- Dec- 98 22- Feb- 99 17-Dec-98 18-Mar-98 8-Jan-99 18-Dec-98 2-Dec-98 2-Jan-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 18-Dec-98 1-Dec-98 2- Nov- 98 19-Mar-97 17- Dec- 97 7- Jan- 98 11-Mar-99 1-jun-99 9075.6 4600.~ 9077.5 5000.0'~J' 9091.5 4850.0 8903.2 4920.0 8829.7 4920.0 8746.7 4820.0 8031.0 3600.0 6979.0 2677.8 8981.1 4500.0 8863.4 4640.0 8015.5 2755.6 8866.7 4420.0 8593.1 4620.0 7183.3 2300.0 6826.6 3280.0 5680.7 2650.0 15.0 0.0 73.8 250.0 73.8 250.0 91.3 300.0 398.0 100.0 119.4 328.6 225.6 640.0 518.4 100.0 330.4 314.3 834.5 100.0 859.2 300.0 642.9 1322.2 811.3 0.0 690.4 300.0 570.8 300.O 449.9 350.0 210.8 300.0 546.2 314.3 7754.8 50.0 847.5 300.0 8959.1 7440.0 629.0 2766.7 25.0 650.0 15.3 0.0 10153.8 12000.0 12308.8 14336.4 14158.6 4820.0 14418.0 10588.9 4500.0 9800.0 2755.6 4420.0 13735.8 12560.0 11320.0 2650.0 0.0 14727.9 371.4 300.0 100.0 471.4 640.0 611.1 314.3 100.0 300.0 1322.2 14309.1 300.0 300.0 350.0 300.0 314.3 50.0 300.0 14727.9 14727.9 650.0 0.0 ARCO Alaska, Inc. Post Office Box 100~0 Anchorage, Alaska 99510-0360 June 2, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill: KRU 1C-26 Surface Location: 1702' FNL 1339' FWL Sec 12 TllN RIOEf Target Location: 1394' FNLf 2215' FWL Sec. 18~ TllN~ RllE~ UM Bottom Hole Location: 2377' FNL~ 809' FWL Sec. 17~ TllN, RllE~ UM Dear Commissioner Christenson, ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the Kuparuk interval from 1C pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and further develop the production potential of the Kuparuk sands in the vicinity of 1C pad. The well is designated as a horizontal injection well to the Kuparuk C4 zone using a 9 5/8" surface casing string, a 7" intermediate casing string to the top of the producing horizon, a 4-1/2" solid, cemented liner in the horizontal-reservoir section, and 4-1/2" production tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) 3) 4) 5) 6) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. ~ U l'l "" ~ ~cjc~ Gas Cons. 8) A copy of the proposed drilling program. Al~l!l, 0il& .... 9) ARCO does not anticipate the presence of H2S in the formation¢'~' All~h0ra0j~ be encountered in this well. However, H2S monitoring equipment will be functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. Robert Christenson Application for Permit to Drill - 1C-26 Page 2 10) Due to the large volume of regional information available, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type Icg generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Completion Report Technologist (20 AAC 25.070) Sharon AIIsup-Drake, Drilling 263-4612 2) Geologic Data and Logs Meg Kremer, Geologist (20 AAC 25.071) 265-6460 The anticipated spud date for this well is _June 12, 1999. If you have any questions or require further information, please contact Bill Lloyd at (907) 263-6531 or Chip Alvord at (907) 265-6120. Senior Drilling Engine¢ CC: Kuparuk :!.C-26 Well File Chip Alvord ATO-1200 M_] Loveland NSK6 Oil & Gas Cons, Anch0rago ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 CHECK NUMBER PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE' DRIVE 230096192 APRIL 3O, 1999 VOiD AFTER 90 DAYS 73-426 839 0997587 EXACTLY ******~***'100 DOLLARS AND 00 CENTs $***********100.00 The First National Bank of Chicago-0710 : Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 230096 192 WELL PERMIT CHECKLIST COMPANY .~/%- .~ WELL NAME /~.,~_---/ / C- ~ ~ PROGRAM: exp __ dev __ redrll__ serv ~ wellbore seg ann. disposal para req FIELD & POOL d/?~/~ INIT CLASS /- ~-.b,,~/,..-v~ ,~ ? ~ UNIT# ./.,/./_~:~ ON/OFF SHORE ADMINIS I I~ATION APPR DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to .~'OO('3 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. 31. 32. 34. GEOL AREA N N N Permit can be issued w/o hydrogen sulfide measures ..... ~YY N ~~ Data presented on potential overpressure zones ....... Y Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. / Contact name/phone for weekly progress reports [exploratory o~/] Y ANNULAR DISPOSAL 35. With proper cementing records, this plan APPR DATE (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGy.;, RPC~ ENGINEERING: UlC/Annular JDH' '..~..~.. COMMISSION: Comments/Instructions: RNa, ,, co uo c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Nov 11 14:58:47 1999 Reel Header Service name ............. LISTPE Date ..................... 99/11/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 99/11/11 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 KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 5 AK-MM-90131 B. HENNINGSE F. HERBERT 1C-26 500292294400 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES il-NOV-99 MWD RUN 7 AK-MM-90131 G. GRIFFIN R. SPRINGER MWD RUN 8 AK-MM-90131 G. GRIFFIN R. SPRINGER 12 lin 10E 1702 1339 .00 DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 94.00 60.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 115.0 12.250 9.625 6496.0 8.500 7.000 10556.0 6.125 14630.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 THROUGH 3 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUNS 4-5 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS. RUN 4 MADE NO FOOTAGE AND IS NOT PRESENTED. 4. MWD RUNS 6-8 ARE DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), STABILIZED LITHO-DENSITY (SLD), AND PRESSURE WHILE DRILLING (PWD). RUN 6 MADE NO FOOTAGE AND IS NOT PRESENTED. MWD RUN 8 BECAME STUCK AFTER TD OF WELL REACHED. THE TOOL STRING IS UNRECOVERED, AND ONLY REAL TIME DGR AND EWR4 DATA IS AVAILABLE. 5. NEAR DETECTOR PE DATA IS NOT PRESENTED DUE TO PROBABLE DECOUPLING OF THE PHOTOMULTIPLIER TUBE. 6. SLD SLIDE INTERVALS REFER TO SLD TOOL DEPTH WHILE NON-ROTARY DRILLING. 7. DEPTH CORRECTION OF MWD DATA IS WAIVED AS PER THE EMAIL FROM D. SCHWARTZ OF ARCO ALASKA, INC. ON 10/26/99. THIS DATA IS CONSIDERED PDC. 8. MWD RUNS 1-8 REPRESENT WELL 1C-26 WITH API%: 50-029-22944-00 . THIS WELL REACHED A TOTAL DEPTH (TD) OF 14630'MD, 6621'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED {LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). PARAMETERS USED IN DENSITY LOG PROCESSING: FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 6457 0 ROP 6507 0 FET 10546 0 RPD 10546 0 RPM 10546 RPS 10546 RPX 10546 DRHO 10563 RHOB 10563 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE ?BU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 14586 5 14629 5 14593 0 14593 0 11341 5 11341 5 11341 5 11313 0 11313 0 EQUIVALENT UNSHIFTED DEPTH -- BIT RUN NO MERGE TOP MERGE BASE 5 6507.0 10570.0 7 10570.0 11380.0 8 11380.0 14630.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type.. Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPD MWD OHMM 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 FET MWD HRS 4 1 68 RHOB MWD GM/C 4 1 68 DRHO MWD GM/C 4 1 68 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 Name DEPT GR ROP RPD RPX RPS RPM FET RHOB DRHO Min 6457 12.42 0 0.11 2 32 2 78 0 O5 0 32 1 88 -0 18 Max 14629.5 512.73 3241.41 2000 21.18 227.35 2000 160.27 3.23 0.4 Mean Nsam 10543.2 16346 116.166 16203 116.047 16246 14.3763 8095 4.06586 1592 4.85849 1592 29.249 1592 2.78479 8095 2.46507 1501 0.0671352 1501 First Reading 6457 6457 6507 10546 10546 10546 10546 10546 10563 10563 Last Reading 14629.5 14586.5 14629.5 14593 11341.5 11341.5 11341.5 14593 11313 11313 First Reading For Entire File .......... 6457 Last Reading For Entire File ........... 14629.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 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 ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6457.0 10519.0 ROP 6507.0 10569.5 $ LOG HEADER DATA DATE LOGGED: 12-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (PT): BIT ROTATING SPEED {RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 57.2 MAXIMUM ANGLE: 75.8 INSITE 3.2. (UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 10570.0 6507.0 10570.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ TOOL NUMBER P1306HGV6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE {IN): DRILLER'S CASING DEPTH (FT) : 8.500 8.5 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: LSND 9.00 42.0 9.0 35O 6.6 .000 .000 .000 .000 44.2 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 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 6457 10569.5 8513.25 8226 6457 GR 32.6 512.73 151.406 8125 6457 ROP 0 3241.41 146.411 8126 6507 Last Reading 10569.5 10519 10569.5 First Reading For Entire File .......... 6457 Last Reading For Entire File ........... 10569.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10519 5 FET 10546 0 RPD 10546 0 RPM 10546 0 RPS 10546 0 RPX 10546 0 DRHO 10563 0 RHOB 10563 0 ROP 10570 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ 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: STOP DEPTH 11335.0 11341.5 11341.5 11341 5 11341 5 11341 5 11313 0 11313 0 11377 5 20-JUL-99 INSITE 3.2. (UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 11380.0 10570.0 11380.0 ' 75.8 85.5 TOOL NUMBER P1322NLM4 P1322NLM4 P1322NLM4 6.130 6.1 LSND 10.80 54.0 8.5 400 4.0 2.100 1.138 2.700 3.100 51.1 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 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 7 FT/H 4 1 68 4 2 GR MWD 7 API 4 1 68 8 3 RPX MWD 7 OHMM 4 1 68 12 4 RPS MWD 7 OHMM 4 1 68 16 5 RPM MWD 7 OHMM 4 1 68 20 6 RPD MWD 7 OHMM 4 1 68 24 7 FET MWD 7 HOUR 4 1 68 28 8 RHOB MWD 7 G/CC 4 1 68 32 9 DRHO MWD 7 G/CC 4 1 68 36 10 Name DEPT ROP GR RPX RPS RPM RPD FET RHOB DRHO Min 10519.5 0 38 38 44 2 32 2 78 0 05 0 1t 0 65 1 88 -0 18 First Max Mean Nsam Reading 11377.5 10948.5 1717 10519.5 2281.64 66.8142 1616 10570 186.07 133.313 1632 10519.5 21.18 4. 06586 1592 10546 227.35 4. 85849 1592 10546 2000 29.249 1592 10546 2000 24.5612 1592 t0546 160.27 6.34966 1592 10546 3.23 2.46507 1501 10563 0.4 0.0671352 1501 10563 Last Reading 11377.5 11377.5 11335 11341.5 11341.5 11341.5 11341.5 11341.5 11313 11313 First Reading For Entire File .......... 10519.5 Last Reading For Entire File ........... 11377.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11340.5 14586.5 FET 11343.5 14593.0 RPD 11343.5 14593.0 ROP 11378.0 14629.5 $ 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 (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN $ 27-JUL-99 INSITE 3.2. (UPGRADE 3) CIM 5.46/ EWR 1.34/ SLD 10.87 MEMORY 14630.0 11380.0 14630.0 82.5 94.9 TOOL NUMBER P1322NLM4 P1322NLM4 P1322NLM4 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 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.130 6.1 LSND 11.10 50.0 8.5 7OO 11.4 1. 600 .733 1.900 2.000 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FET MWD 8 HOUR 4 1 68 4 2 GR MWD 8 API 4 1 68 8 3 ROP MWD 8 FT/H 4 1 68 12 4 RPD MWD 8 OHMM 4 1 68 16 5 60.7 First Name Min Max Mean Nsam Reading DEPT 11340.5 14629.5 12985 6579 11340.5 FET 0.32 22.91 1.90769 6500 11343.5 GR 12.42 178.92 67.4287 6436 11340.5 ROP 0.15 2814.8 90.343 6504 11378 RPD 2.85 38.63 11.8789 6500 11343.5 Last Reading 14629.5 14593 14586.5 14629.5 14593 First Reading For Entire File .......... 11340.5 Last Reading For Entire File ........... 14629.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 99/11/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 99/11/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 99/11/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
