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200-049
VTL 4/14/20 DSR-4/9/202DLB 04/09/2020 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� DATE: 10/10/19 P. I. Supervisor FROM: Matt Herrera SUBJECT: Surface Abandon Petroleum Inspector KRU 1D-139 PTD 2000490; Sundry 319-309 CPAI �o�, 444&--1 3— 10/10/19: 1 traveled to Kuparuk 1D -Pad and met up with CPAI rep Roger Mouser. Went over the paperwork and inspected the area where wellhead had been removed, casing cemented to top and cut off at required depth. Marker plate was ready to be installed and backfilled. No indication of wellbore leaking or subsidence however water evident in cellar area around casing sub from surrounding ground water. Vac truck on location to siphon water out. The marker plate had the correct information. Approved them to weld on marker plate and bury the abandoned well. Attachments: Photos (3) 2019-1010_Surface_Abandon_KRU_ 1D-139 mh.docx Page 1 of 3 Surface Abandonment — KRU 1 D-139 (PTD 2000490) Photos by AOGCC Inspector M. Herrera 10/10/2019 2019-1010_Surface_Abandon_KRU_1 D-139_mh.docx Page 2 of 3 ONock�,1 � t f 11 to Q 10 Ot C� WELL LOG TRANSMITTAL #905878731 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 1D-139 Run Date: 9/14/2019 200049 3 136 3 October 17, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-139 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-029-22958-00 OCT 22- 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: I OM//q Signed: WELL LOG TRANSMITTAL #905878731 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 1D-139 Run Date: 7/31/2019 200049 3 120 7 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-139 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22958-00 RECEIVED SEP 12 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: I K w/ Signed: THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Hanna Sylte Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1D-139 Permit to Drill Number: 200-049 Sundry Number: 319-309 Dear Ms. Sylte: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 W W W.aogcc.alaska.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. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this S day of July, 2019. RBDMS �JUL 0 8 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CFE IV1D JUN 2 7 2019 AOGCC 1. Type of Request: Abandon ID a Plug Perforations 10 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service p 200-049 3. Address: 6. API Number: t P. O. Box 100360, Anchorage, Alaska 99510 50-029-22958-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A t KRU 1D-139 Will planned perforations require a spacing exception? Yes ❑ No D 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25650 1 Kuparuk River Field / West Sak Oil Pool a 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): / 4,838' 4,276' 4739 4186 1500psi ✓ NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 110' 110' Production 4,001' 51/2 4,031' 3,594' Liner 964' 431/2 4,838' 4,275' Perforation Depth MD(ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4114-4490 3652.3962 3.500" L-80 3,876' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER SAB PRODUCTION PACKER 3874 MD and 3484 TVD SSSV - N/A N/A 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service [D 14. Estimated Date for 7/10/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ p WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ 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: Hanna Sylte Hanna Sylte Contac[ Name: Authorized Title: Wells Engineer Contact Email: Hanna.Sylte@cop.com Contact Phone: (907) 265.6342 Authorized p, Signature: Date::0 �-�" 1 1 I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity (� BOP Test ❑ Mechanical IntegrityTest ElLocation Clearance ' ®-� Other: Z d h4 ha m I ° r- i Y " 6 CG 1-5? f --n 5 � D "/-) ../. 7L SJ Post Initial Injection MIT Req'd? Yes El No I 1/RBDMS—11�JIUL 0 8 2019 Spacing Exception Required? Yes ❑ No Q/ Subsequent Form Required: / a — gQ APPROVED BY7 Approved by: COMMISSIONER THE COMMISSION Date: 3 l Y&-�-131/I vlfri-�Z'`y ORIGINAL Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Submit Form and ahme sin Duplicate 6 a C tB 617-8l19 KUP INJ WELLNAME 1D-139 WELLBORE 1D-139 r, -' ' Well Attributes Max Angle & MD TD CarocoPhill1ps WM Name iinn'QeRPVNW WelllorcS Ns ncll°I MOo%MBI Ac<Bbn XKB) Alaska, Ir1C. I WEST SAK ISON4JN5AOn IIN.I R so a n 1 a n caa n 09 1.139 1 Last Tag 'PossrM 'sompll Annotations Deptn( IS End DaM wNlosm 1 Ounib4By Last Tag: RKB 4,]03.0 1 WW2019 11D-,ur Izenrgtri 1 Last Rev Reason A.-Istum. EM Dane Welltwre IaatMW By Rev Reason'. Upltaletl Tag Da B Discovered Tbg Impingement liviner,ri iu-"u Izemi rp,HGER.flI Casing Sfrings oairp DeacNpnbn OD(1n) ID(m) TOp (MIn DepXI"[s... wuLen n_ Gr,ae Top Tnread Isar CONDUCTOR 16 15.06 31.0 1109 1100 0258 H40 WELDED Calnp Descnptton ODlin) ID gp Top(XXB) Sat Depth RMB) Bet Della lrvTH WNLen IL.. Grade Top IDread PROpUCTION 5112 6.95 30.5 4,031.1 3,5937 15.50 LSO LTC -M00 CCri10BLTOli al O11P0 Casing OescNdion .r (in) 113 pal Top(M(B) IRPHIARIVIRKIR last Depth (INIMLen p.. Grade Top Thmd LINER 31)2 999 3,8745 4,838.0 9.30 L-80 FOIS Liner Details TUBING IMPINGEMENT; lass Top Xxa Toplrvbn%Xel Top mH l°I gum Des noun, rvominH lO pnl 3,874.5 J, 8M Z 45.]8 PACKER BAKER'S.. -3' PRODl1CTION PACKER TUBING IMPINGEMENT, 350.0 Tubing Strings TubinO Description 3teing Ma... IDIIn) TOp (XK81 Set Cepth lX.. Si Depot IND/ I... WtIINXI GeMe Tap LOnneclion TUBING 31/2 299 29.3 3.8]6.9 3,485.9 9.30 L-80 EUEB Zd Completion Details WBnST;3712a Top TVD) Top -I NOT" .1 Top mKBI pmts) I°1 sem N. cam ID lip 293 29.3 0.06 HANGER VETCO-GRAY TUBING HANGER 3500 3,8133 3,4418 4555 NIPPLE CAMCO'DS'IANDING NIPPLE M2.813 NO GO PROFILE 2.813 NIPPLE 3.0137 3852.1 3,468.6 45. 74 1 LOCATOR BAKER KBH-22 LOCATOR 2.992 3,8525 3,468.9 45.74 PER BAKER4 5 SPECIAL CLEARANCE PBR 9958 3876.2 34854 45.78 ANCHOR BAKER KBH-22 ANCHORAGE A55EMBLY 2958 IL 11 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Irv01 TopmH PBR:385J5 Topl%KBI IXKRI I') Des Com Run Date I ID lint 150.0 150.0 0.49 T 8 TUBING IMPINGEMEN 1 (an passwil Il bore 6)612019 2.250 IMPINGEMENT short gauge ring, but not with king assemblies) AKLHORI arri , 3500 350.0 2.03 TUBING IMPINGE ' (an pass wil UII ore IMPINGEMENT shop gauge ring, but not ank ong assemblies) 61612019 9250 4,200.0 3.7164 39.22 CSG PATH T9"EXTERNALPRODUCTION AIN A 1 5.500 FROM MANDREL HANGER TO 7 5- NO 6 Perforations & Slots shot Dens Top IXKa BM Top ITVS Sup NVDI IboWL I ME) MIKE) (MR) HnFedlane Dane ) Type Con 4,1160 4,182.0 ,52.3 368]5 WS D, 10-139 6130/2000 4.0 IPERF 60 DEG PH 2S HSDDP 4,200.0 4,246.0 3,]16.4 3)52.] WS B, D 139 6/3012000 4.0 IPERF 60 DEG PH 25" HSD DP 4,258.0 4,28. 3762.4 3,]81.1 WS A41D-139 6130/2000 4.0 IPERF BO DEG PH 205 HSDDP PRODUCTORsits4,GX.1 4.310.0 4,318. 3805.1 3,811.8 W A,1 139 6/30/2000 401PERF 60 DEG PH 2.5- HSD UP 4,329.0 4 0. 3821.1 3,830.4 WS A3 10.139 6/302000 4.6 IPERF 60 DEG PH 25° HSD DP 4,345.0 7355.0 3,834.7 3843.2 WSA31D139 029200 4.01PERF 60 DEG PH 2.6 HSD DP /PERE', 4,114,OAJIz.o� 4,3690 775.0 38492 3860.4 WS A3, 1D-139 ti129IMW 4. IPERF WDEG PH25HSD DP 4,3930 4, 3,8]6.1 3.91.3 WSA2.1D-139 6/2912000 4. ERF 60 DEG PH 2.5"HSD DP 6680.0 4,490.0 3,952.8 3,961] WS A2, 1D-139 629/2000 4. IPERF 60 DEG PH 95' HSD UP IPERPAabou.G460 CapPATCH/ 4X00 Co. SOz;A MO must _ Cement Squeezes Topml(el arm al Top lrvDl Mi(lames Bion ri Dea sunt Dao Gom 42000 4,2 3716.4 3,]52.] GELSOZ 102016 PUMP L AL SEAL MBE TREATMENT PLACING 1040# 1-24 CS BEHIND PIPE LEAVING 6 BBLS UNDER -DISPLACED IN TUBING. WELL FREEZE PROTECTED W/ 20 BBLS IPSRF: 4,JBa.w,mt0� DIESEL(1,100 lbs Crystal Seal Pumi BSAND PERFINTERVAL Mandrel Inserts BI IPERF.43m0 .3130 X Top(XKB) TOInKB1PIr) MaM Mo41 ODlln) 9ery Type pass PoBNrt Be TRO�R13un Run Oane Com 1 3.]62.5 3,4058 CAMCO KB 2- 1 Gas LIP GLV INT 0. 0.0 61 20DD IPERF; <,3A 04.340.0 g Notes: General a Safety IPERF, A34eG6,355,0� EnE DNe Annouffion 11512009 NOTE: VIew SCM1ematic w/aaska SLM1ematic90 IPERF:0.342.M,Xralt � IPERF', 4.39004,440,0 IPERF:0.4E0M,I900 LINER. AME-i.BM0 Completion Post Tubing Punch F 1 D-139 Plug and Abandon PTD # 200-049 L16", 62.5#, H-40 Conductor to 110' KB 5.5", 15.5#, L-80 Surface Casing to 4031' KB 3.5", 9.3#, L-80 Tubing & Liner to 4838' KB 3.5" Tubing restrictions exist at —150' and —350' KB Cannot pass BHA's bigger than 3' OAL x 2.19" OD Tbg & IA Diesel Filled with Diesel GLM w/DV at 3,762' KB Proposed Tubing Punches at 3787' KB 2.812" DS Nipple at 3,813' KB Seal Assembly at 3,852' KB Peds Open: WS D 4114'-4162' KB WS B 4200'-4246' KB WS A4 4258'-4281' KB WS A3 4310'-4318' KB WS A3 4329'-4340' KB WS A3 4345'-4355' KB WS A3 4362'-4375' KB WS A2 4393'-4440' KB WS A2 4480'-4490' KB 3.5", 9.3#, L-80 Liner 3874'- 4838' KB Proposed P&A OA Cement Top Job Cement Plug #2, 15.8# Class G, C to 0' KB in Tbg & IA iment Plug #1, 5.8# Class G, Ball at 3838' KB, Is Cement in Liner DY - 3838' KB, bbls Cement in Parts HIS 6125/19 Proposed Procedure for 1D-139 Plug & Abandonment to Surface It is proposed that 1D-139 well work be performed to cement squeeze the perforations. The cement squeeze would be followed by a CMIT to verify that the formation is isolated. 1D-139 would then be filled with cement stage #2 to surface. The wellhead would also be removed, and a well ID plate would be welded onto the casing before 1D-139 is backfilled and buried. Well History: 1D-139 West Sak injector was drilled and completed in June 2000 as a single casing well with 5.5", 15.5#, L-80 Surface casing to 4031' RKB. The tubing is 3.5", 9.3#, L-80 to 3876' RKB where seals are stabbed into a 4" ID sealbore extension. The liner is 3.5", 9.3#, L-80 which extends from a production packer at 3874' RKB to 4838' RKB (4275' TVD). This well has a proactive surface casing patch welded on the surface casing in 2006. In 2005 a B sand MBE was discovered communicating to 1D-102. A casing patch was set across the B sand perfs in 2005 but later failed and was pulled in 2006. In 2013 a crystal seal MBE treatment was pumped which held until 2015. In 2016 a second crystal seal job was pumped but did not hold. The offset 1 D-102 producer has been shut in since 2016 due to solids production. 1D-139 is currently on injection at —220 BWPD, —760 WHIP to West Sak A2, A3, B, and D sands. 2n_6/6/19 a subsidence drift was performed, which determined the lar est secure plug that could be set is 2.19" plug past an obstruction at 150' nc 350, RKB. Slickline tagged TD at 4,703' , a perforations appear to be o n 1 D-139 passed an MIT -IA to 2,000 psi. Due to the tubing restrictions at 150' and 350' RKB, a decision has been made to proceed to Plug and Abandon 1 D-139. This proposal places cement across the West Sak A, B and D sand perforations from 4,490' MD to 4,114' MD. 1D-139 Proposed P&A Procedure Job Objective: Plug & Abandon 1 D-139 with cement to surface. Cut casing and tubing strings below grade and remove the wellhead, then weld on an ID plate and bury the well. Volume of 3.5" Tubing to TOF: (.0087 x 4,703' RKB) = 40.9 Volume of 5.5" x 3.5" IA: (.0119) x (3,876' RKB) = 46.1 bbis IA FP to 2000' TVD; 2002' RKB (.0119) x (2,002' RKB) = 23.8 bbis. Tbg FP to 2000' TVD; 2002' RKB = (.0087) x (2,002' RKB) = 17.4 bbls P&A Procedure Per correspondence with AOGCC re: 1D-120 P&A, AOGCC requests a State Witnessed PT to be performed on a 'reservoir plug'. Per AOGCC, a sand plug placement across the open perfs (rather than cement) did not satisfy P&A regulations as per: 20 AAC 25.112. Thus, this procedure calls for first placing a cement volume through the perforations from 4,490' RKB — 4,114' RKB. Prior to pumping fullbore cement plug #1, confirm passing MIT -IA has been achieved and tubing has been punched at 4,870' RKB. Fullbore Cement P&A - Cement Plug #1: Objectives: Fullbore 14 bbls Cement to put 6.5 bbis of cement into open perfs above TOF at 4703' RKB, and leave 7.5 bbls Cement under -displaced in 3.5" liner to leave a cement top at 3838' RKB. WOC and obtain an AOGCC witnessed CMIT of this bottom cement plug that isolates the reservoir per 20 AAC 25.112. 2.992" ID Tubing and Liner 3.5" x 5.5" IA Volume Volumes to fill with Cement: In perforations above TD at 4703' RKB In 3.5" Liner above TD at 4703' RKB Total 15.8 ppg Class 'G' Cement = 0.0087 bbl/ft _ .0119 bbl/ft = Total squeeze volume = 6.5 bbls _ (4703'- 3838')(0.0087) = 7.5 bbls = 14 bbls 1. Schedule pilot testing of P&A cement design. Cement job requires 14 bbls of pumpable 15.8 ppg Class 'G' Cement 2. MIRU Cement Van. Conduct PJSM. Inspect location for pre-existing conditions. Mitigate hazards. Mitigate personnel exposure for PT, and then PT equipment. 3. Pump Stage #1 Cement job as follows: Tubing Volume to Circ Holes at 3787' RKB = (.0087)(3787) = 32.9 bbls. Tubing + Liner Volume to first open D Sand perfs = (.0087)(4114) = 35.8 bbls. Tubing + Liner Volume to TD = (.0087)(4703) = 40.9 bbls. One barrel in 3.5" tubing fills —115' tubing. a) Open IA to tanks and circulate 120 bbls of Lead Freshwater down tubing through tubing punches at 3787' RKB and up IA at max rate up to 3 bpm to circulate all Diesel FP from tubing & IA to tanks to prepare well for cement job. As soon as good circulation is confirmed at circ rates of at least 1 bpm, start mixing 15.8 ppg Class 'G' Cement to provide a 14 bbl 'pumpable' batch of cement to be ready to pump immediately after the 120 bbl circ volume has been pumped away. As approaching 120 bbls of Lead Freshwater pumped away, leave IA open and adjust pump rate to 1 bpm, then swap to b) 14 bbls of 15.8 ppg Class 'G' Cement down tubing (Cum Vol = 14), followed by c) Foam Wiper Ball for 3.5" Tubing (Cum— Vol still 14), d) 5 bbls Freshwater Tail Spacer (Cum Vol = 19), followed by e) 5 bbls Biozan Cement Contaminant stage (Cum—Vol = 24), followed by f) 6 bbls Diesel FP (Cum—Vol = 30), followed by g) Close IA to halt returns. This enables us to start squeezing cement to the open perforations without getting cement into the lA as cement begins to pass the open circ holes at 3787' RKB (which starts to occur at Cum Vol = 32.9 bbls away). Note, we want to close IA --2.9 bbis before lead cement is due to arrive at circ holes to be safe in avoiding any cement getting circulated through the circ holes.). h) With IA closed, resume pumping an additional 17.4 bbls Diesel FP down tubing at rate that can be achieved up to maximum of 1200 psi WHIP, or at least to a minimum rate of 0.25 bpm to slowly squeeze cement away to open perfs. After all 17.4 bbls of Diesel is pumped away (Cum—Vol = 47.4), then Shutdown. Do Not Overdisplace Cement. Close Tubing & hold pressure At Shutdown, Cum Vol pumped = 47.4 bbls away, so Wiper Ball (if it was pumped) should be displaced with 33.4 bbls of fluid to put it at 33.4 bbls x 115 fllbbl = 3838' RKB = 51' below the circ holes at 3787' RKB. This means 6.5 bbls Cement was squeezed to perfs and —7.5 bbls of cement remains in 3.5" liner across perfs that were squeezed. However, at this point we only have 23.4 bbls of Diesel in Tubing and no Diesel yet in IA, so we need to get Diesel into IA by performing step j (below) to complete the job. j) Slightly crack open IA to take returns from IA on choke while bringing up the pump to pump another 17.8 bbls of Diesel down Tubing at slow rate to hold tubing & IA pressure constant as we had on tubing at SD in step 'i' (above). Objective here is to try to get the Diesel FP needed into the well while holding squeeze pressure constant as possible on the cement job, so we don't over - displace the cement job or allow it flow back up hole. We want to keep the cement job static as possible until it sets up. After 17.8 bbls of Diesel has been pumped away, k) Shutdown pumping and close IA & tubing to hold the final squeeze pressure on the well. Do not bleed off any final pressure from the well. 1) Jumper the Tbg to IA together to let Diesel FP U-tube and fully equalize from tubing to IA. Allow sufficient time for Diesel FP to equalize between IA and tubing. With U -tubing we also get fluid flow through the punches at 3787' RKB to ensure that we have removed any cement over the circ holes before it sets. With total of 41.2 bbls Diesel fully equalized we get /A & Tbg FP to 2000' TVD. m) Rig Down & MOL. n) WOC at least 24 hours before performing SL work. Slickline / Little Red Objectives: Tag TOC, State Witnessed CMIT, Combo DDT of Tbg / IA 1. WOC per Schlumberger UCA data (minimum 24 hrs) before performing tag & CMIT. 2. Notify AOGCC Inspector in advance regarding timing of Cement Plug #1 tag and MIT. 3. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 4. RU SL. PT equipment as required. �� r� Y° 5. RIH & tag TOC in tubing at —3838' RKB. Tag must be AOGCC witnessed. Record j{4 results. 6. RU LRS. PT Surface Equipment as required. 7. Perform CMIT to 1500 psi AOGCC witnessed. Record Results. Z 8. Perform Combo DDT on Tubing & IA. Record Results, 9. If the CMIT or DDT fails, contact engineer to discuss the possible need to pump another Cement Plug #1 job. 10. If CMIT passed, we will next perform a Cement Plug #2 placement, but first verify that we still have ability to circulate through the circ holes in tubing at 3787' RKB at sufficient rate to place Cement Plug #2. a) Perform step rate circulation test at different circ rates pumping Diesel down tubing while taking returns from IA. Record the injection rates & circ pressures in WSR. Do not exceed 3 bpm circ rate or 1500 psi max circ pressure during circulation test. b) Since Diesel was displaced from the IA during the circ test, jumper Tbg to IA together to let Diesel in well U-tube and fully equalize from tubing to IA. Allow sufficient time for Diesel FP to equalize between IA and tubing. EI 11. If we determine that inadequate circ rates exist for pumping a Cement Plug #2 job, contact engineer, to discuss where to shoot new circ holes in tubing. 12. RD & MOL. Fullbore Cement P&A - Cement Plug #2: Objective: Fullbore cement down Tubing and up IA to cement fill the tubing and IA to surface. 2.992" ID Tubing and Liner 4.950" ID Csg x 3.5" OD Tbg (IA) Volumes to fill with Cement: In 3.5" Tbg & 3.5" Liner In 4.950" ID Csg x 3.5" OD Tbg (IA) Plus —10% excess Total 15.8 ppg Class 'G' Cement = 0.0087 bbl/ft = 0.0119 bbl/ft = (3838'- 0')(0.0087) = 33.4 bbls = (3876'- 0')(0.0119) = 46.1 bbls = 8.0 bbls = 87.5 bbls Note, we're only pumping 15.8 ppg Class 'G' Cement. The tubing restriction at 150' and 350' RKB creates unacceptable risk in trying to attempt a Cement Plug #3 ArcticSet job across permafrost, so we won't perform a Cement Plug #3. 1. Verify with engineer, that circulation testing results (per step 10a) look good to perform a P&A before starting work on the cement job. 2. Schedule pilot testing of P&A cement design. The cement job requires 87.5 bbls of pumpable 15.8 ppg Class 'G' Cement. 3. Order 1 full 290 bbl Freshwater transport. If the cement P&A to surface goes as planned, we will leave 1 D-139 cemented to surface, so there is no need for Diesel FP in the well. Order a Diesel transport if needed for any purpose other than FP in well. 4. MIRU Cement Van. Conduct PJSM. 5. Inspect wellhead and location for pre-existing conditions. Mitigate hazards. Establish site control. Do Not Mix any Cement until requested (below). Ensure hardline is rigged up to pump down tubing and to take returns to tanks from IA. Ensure full opening returns from 2" hardline. Prepare for fluids and cement to exit a downspout on wellhead into drum and have a Vac truck on location to manage fluids. 5 Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen to surface. 6. Mitigate personnel exposure for PT, and then PT equipment as needed. 7. Circulate 150 bbls (-1.5 wellbore volumes) of Lead Freshwater down tubing through tubing punches and up IA to return tanks at max rate up to 3 bpm or 1500 psi max circ pressure to begin pumping. This pumping displaces all Diesel (contaminant to cement) from wellbore to tanks. When it is verified that good return rates are being observed from IA to tanks during Lead Freshwater pumping, start mixing 87.5 bbls of 'pumpable' 15.8 ppg Cl 'G' Cement while pumping away the Freshwater stage. After the Freshwater stage is pumped away, be ready to swap to fullbore pumping Cement down tubing. 8. Pump 87.5 bbls of 15.8 ppg Class 'G' Cement down tubing and up IA at rate of at least 1 bpm to provide good sweep, until the cement arrives back to surface from the IA, which should begin to occur at —80 bbls of cement is pumped away (assuming no cement losses to formation). 9. Monitor returns on surface and take samples to check pH and density. Once good cement returns are verified on surface using mud scale for cement density measurements, shut down pumping and open up the surface bypass line to flush all lines with water from the Freshwater transport. 10. Wash up SLB cement pumps 11. RDMO. 12. WOC 48 hrs. 13. Perform drawdown test on tubing, IA, and OA. Proceed to Wellhead Excavation and Final P&A work steps (next page). C8 Wellhead Excavation / Final P&A: 14. Remove Well House (if still installed). 15. Bleed off T/I/O to ensure all pressure is bled off the system. 16. Remove production tree, in preparation for excavation and casing cut. 17. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 18. Cut off wellhead and all casing strings at 4 feet below original ground level. 19. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 20. Send the casing head w/ stub to materials shop. Photo document. 21. Weld'W thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC Witness Required. ConocoPhillips KRU 1 D-139 PTD #: 200-049 API #: 50-029-22958-00 22. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 23. Obtain site clearance approval from AOGCC. RDMO. 24. Report the Final P&A has been completed to the AOGCC, and any other agencies required. Photo document final location condition after all work is completed. 7 • 40 211 3 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. April 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 _ DATA LOGGED RECEIV M.K BENDER APR 2 9 2016 RE: Injection Profile : 1D-139 100CC Run Date: 1/20/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-139 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22958-00 Injection Profile Log 1 Color Log 50-029-22958-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. %ON Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / vaLos i L. / `E:le:e"-C RECEIVED STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMAION JAN 19 2016 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate E Pull Tubing E s• a down Performed: Suspend E Perforate E Other Stimulate Alter Casing E Change Approved Program E Plug for Red rill 1 Perforate New Pool fl Repair Well IT Re-enter Susp Well IT Other:Crystal Seal MBE F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory fl 200-049 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-22958-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25650 \4'Q-k.3 WSAK1D-139 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): n/a Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 4838 feet Plugs(measured) None true vertical 4276 feet Junk(measured) None Effective Depth measured 4739 feet Packer(measured) 0 true vertical 4186 feet (true vertical) 0 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110 110 0 0 PRODUCTION 4001 5.5 4031 3594 0 0 LINER 964 4.54 4838 4275 0 0 Perforation depth: Measured depth: 4114-4490 ���mgi® >� 61�r�i`� True Vertical Depth: 3652-3962 Tubing(size,grade,MD,and ND) 3.5, L-80, 3876 MD,3485 TVD Packers&SSSV(type,MD,and ND) SSSV-NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation 199 1293 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory Development r Service 1', Stratigraphic I- Copies of Logs and Surveys Run I— 16.Well Status after work: Oil IIT Gas IT WDSPL Printed and Electronic Fracture Stimulation Data IT GSTOR WINJ F WAG r GINJ SUSP SPLUG IT 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-708 Contact John Peirce@265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date /. /5.9/16 7. 4c. /J�l��-tom'� J- ►v7`t z/14I i RBDMS Lk- JAN 2 1 2016 Form 10-404 Revised 5/20151/47/‘ Submit Original Only KUP 1D-139 ConocoPhilhps Well Attribut Max Angl D TD - Alaska..Irc. Wellbore APVUWI Field Name t Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Can3ro3hiNips 500292295800 WEST SAK INJ 46.59 3,091 38 4,838.0 ... A�° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 12-139,1/16/20162.28:42 PM SSSV:NONE Last WO 31.09 5/15/2000 Vertical schematic.(,aolual)... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 4,595.0 10/6/2013 Rev Reason:MBE CRYSTAL SEAL pproven 1/18/2016 - TREATMENT ®yah Casing Strings 'll Il Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread la-..................wa,u..,,..,....,,,.,,,.,.. CONDUCTOR 16 15.062 31.0 110.0 110.0 62.58 H-40 WELDED HANGER-29.3 ) ma.. Cas ng Descnption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 30.5 4,031.1 3,593.7 15.50 L-80 LTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread 4tT` LINER 31/2 2.992 3,874.5 4,838.0 9.30 L-80 FL4S Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com lin) -"-ti CONDUCTOR;31.D-1100~" I : 3,874 5 3,484.2 45.78 PACKER BAKER'SAB-3'PRODUCTION PACKER 2.750 I Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 29.3 3,876.9 3,485.9 9.30 L-80 EUE8rdMOD GAS LIFT;3,782.5 I Completion Details I Nominal ID Top IftK01 Top(TVD)(ftKB) lop Ind(°) Item Des Com (in) 29.3 29.3- 0.06 HANGER VETCO-GRAY TUBING HANGER 3.500 II3,813.7 3.441.8 45.55 NIPPLE CAMCO'DS'LANDING NIPPLE w/2.813 NO GO 2.813 PROFILE NIPPLE',3,8137 3,852.1 3,468.6 45.74 LOCATOR BAKER KBH-22 LOCATOR 2.992 3,852.5 3,468.9 45.74 PBR BAKER 40-45 SPECIAL CLEARANCE PBR 2.958 3,876.2 3,485.4 45.78 ANCHOR BAKER KBH-22 ANCHORAGE ASSEMBLY 2.958 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) r Top(TVD) Top Incl Top(ftKB) (ftKB) (°) Des Corn Run Date ID(in) PBR;3,852.5 f--( 4,200.0 3,716.4 39.22 CSG PATCH 7'9"EXTERNAL PRODUCTION CASING PATCH 11/15/2006 5.500 FROM MANDREL HANGER TO 7'5"MD MP Perforations&Slots 1 liElf Shot ANCHOR;3,876.2 Dens Top(TM Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com fd _t 4,114.0 4,162.0 3,652.3 3,687.5 WS D,10- 6/30/2000 4.0 IPERF 60 DEG PH 2.5"HSD am 139 DP 4,200.0 4,246.0 3,716.4 3,752.7 WS B,10- 6/30/2000 4.0 IPERF 60 DEG PH 2.5"HSD 139 DP 4,258.0 4,281.0 3,762.4 3,781.1 WS A4,10- 6/30/2000 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP 4,310.0 4,318.0 3,805.1 3,811.8 WS A3,1D- 6/30/2000 4.0 IPERF 60 DEG PH 2.5"HSD 139 DP 4,329.0' 4,340.0 3,821.1 3,830.4 WS A3,10- 6/30/2000 4.0 IPERF 60 DEG PH 2.5"HSD 139 DP 4,345.0 4,355.0 3,834.7 3,843.2 WS A3,10- 6/29/2000 4.0 IPERF 60 DEG PH 2.5"HSD PRODUCTION;30.5-4.031.1 ! 139 DP 4,362.0 4,375.0 3,849.2 3,860.4 WS A3,10- 6/29/2000 4.0 (PERF 60 DEG PH 2.5"HSD - I- 139 DP (PERF;4,114.0-4,162.0 - - y 4,393.0 4,440.0 3,876.1 3,917.3 WS A2,10- 6/29/2000 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP CSG PATCH;4,2000 4,480.0 4,490.0 3,952.8 3,961.7 WS A2,10- 6/29/2000 4.0'IPERF 60 DEG PH 2.5"HSD IPERF;4,200.0-4,248.01 j F r 139 DP Cement Squeezes Top(TVD) Btm(TVD) IPERF;4,258.04,281 0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 4,200.0 4,246.0 3,716.4 3,752.7'GEL SQZ 1/9/2016 PUMPED FULLBORE CRYSTAL SEAL MBE TREATMENT PLACING 10408 1-2-4 CS BEHIND PIPE LEAVING 6 BBLS UNDER-DISPLACED IN TUBING.WELL FREEZE PROTECTED WI 20 BBLS IPERF;4,310.04,318.0 DIESEL.(1100 lbs Crystal Seal Pumped)B-SAND PERF INTERVAL Mandrel Inserts IPERF;4,329.04,340.0 St ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn - IPERF;4,345.0-4,355.0 1_ 3,762.5 3,405.8 CAMCO KBG-2- 1 Gas Lift GLV INT 0.000 0.0 6/13/2000 9 Notes:General&Safety End Date Annotation IPERF;4,362 0-4,375 1/5/2009 NOTE View Schematic w/Alaska Schematic9.0 IPERF;4,393.04,440.0 IPERF,4.480.0-4,490 0 LINER,3 874.5-4,838.0 Ua • 1D-139 DTTM JOBTYP SUMMARYOPS START 1/9/16 SLICKLINE PUMPED FULLBORE CRYSTAL SEAL MBE TREATMENT PLACING 1040# 1-2-4 CS BEHIND PIPE MISC, LEAVING 6 BBLS UNDER-DISPLACED IN TUBING. WELL FREEZE PROTECTED W/20 BBLS DRIFT, TAG, DIESEL. ETC. 1/12/16 MECH ZONE Perform FCO down to TD at 4,733'. Crystal Seal first hit at 4,235' and broke through eventually and MOD only hit several bridges thereafter moderate amounts of Crystal Seal product brought back to surface.Maintained better than 1:1's throughout job. Well Freeze protected and ready to BOL. ***Job Complete***. OF 71,7 • THE STATE Alaska Oil and Gas 0,0h 7,4 oALASKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ��' LAgY+P Fax: 907.276.7542 www.aogcc.alaska.gov SC r► E John Peirce DE 0 3P015 Wells Engineer ConocoPhillips Alaska, Inc. L P.O. Box 100360 Li Anchorage, AK 99510 Re: Kuparuk River Field, Wesk Sak Oil Pool, KRU 1D-139 Sundry Number: 315-708 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner 5'7z- DATED DATED this I day of December, 2015 Encl. RBDMS DEC 0 22015 s • STATE OF ALASKA Jr1i \� RECEIVED • NOV 19 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdowns Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Crystal Seal MBED ‘ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory ❑ Development ❑ 200-049 3,Address. Stratigraphic CI Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22958-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? none KRU 1D-139 ' Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL25650 - Kuparuk River Field/West Sak 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): 4,838' - . 4,276' 4739'• 4186 1554 none Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 110' 110' Surface n/a n/a n/a n/a Intermediate n/a n/a n/a n/a Production 4,001' 5 1/2" 4,031' 3594' Liner 964' 4" 4838' 4,275' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4114'-4490' ' 3652'-3962' 3.5 L-80 3877' Packers and SSSV Type: No Packers Packers and SSSV MD(ft)and TVD(ft): No Packers Nipple-CAMCO DS Landing Nipple 'Nipple 3814=MD,3442=TVD 12.Attachments: Proposal Summary LI Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 2 ' 14. Estimated Date for 12/5/2015 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ 2 , WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce Email John.W.Peirce(a�conocophillips.com Printed Name John Peirce @ 265-6471 Title Wells Engineer /� � . 11Ii Ii5 Signature / .r--- Phone Date / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3!6 - --10 ? Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No V Subsequent Form Required: /O— L.,,/ 4' / APPROVEDLBY Approved by: COMMISSIONER THE COMMISSION Date: ti �21m� � � � Form 10-403 Revised 11/2015 0 RIG I44tAilIid for•4 months nc !from the date of approval. 1 Ak6 • to 4. KUP INJ • 1D-139 iv CQt 3QC0 Yillips °$ „, Well Attributes Max Angle&MD TD Ala ,Inc. I Wellbore API/UWI Field Name Wellbore Status ncl(°I MD(ftKB) Act Btm(ftKB) whord4xisps -•: 500292295800 WEST SAK INJ 46.59 3,091 38 4,838.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1D-139,10/14/20137:37:16 AM SSSV:NONE Last WO: 31.09 5/15/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag-SLM 4,595.0 10/6/2013 Rev Reason:TAB osbod 10/14/2013 Casing Strings W Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 3 z .,..,CONDUCTOR 16 15.062 31.0 110.0 110.0 62.58 H-40 WELDED 01 glit Casing DescriptionOD(in) ID(in To ftK8 Set Depth(ftKB) Set Depth(TVD)... WtlLen Grade Thread HANGER;29.3 ) P( ) (... Top PRODUCTION 51/2 4.950 30.5 4,031.1 3,593.7 15.50 L-80 LTC-MOD Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) 'Set Depth(TVD)... WtlLen(I...Grade Top Thread LINER 31/2 2.992 3,874.5 4,838.0 9.30 L-80 FL4S Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (in) GAJ cCAISUaTOR,31.611e0 \A.n. - 3,874 5 3,484.2 45.78 PACKER 'BAKER'SAB-3'PRODUCTION PACKER 2.750 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/it) Grade Top Connection TUBING 31/2 2.992 29.3 3,876.9 3,485.9 9.30 L-80 EUE8rdMOD GAS LIFT;3,7625 Completion Details Nominal ID III in Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 29.3 29.3 0.06 HANGER VETCO-GRAY TUBING HANGER 3.500 3,813.7 3,441.8 45.55 NIPPLE CAMCO'DS'LANDING NIPPLE w/2.813 NO GO 2.813 PROFILE NIPPLE;3,813.7 •+t9R 3,852.1 3,468.6 45.74 LOCATOR BAKER KBH-22 LOCATOR 2.992 fII it 3,852.5 3,468.9 45.74 PBR BAKER 40-45 SPECIAL CLEARANCE PBR 2.958 3,876.2 3,485.4 45.78 ANCHOR BAKER KBH-22 ANCHORAGE ASSEMBLY 2.958 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ® Top(N II r Top MKS)) (ftKB)D) Top(3Incl Des Com Run Date ID(in) PBR;3852.5 f CSG PATCH 7'9"EXTERNAL PRODUCTION CASING PATCH 7' 1t 11/15/2006 5.500 If FROM MANDREL HANGER TO 5"MD Perforations&Slots Shot 7_1 I I Dens ANCHOR;3,876.2 Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) _ (ftKB) (ftKB) Zone Date t) Type Com 4,114.0 4,162.0 3,652.3 3,687.5 WS D,1D-139 6/30/2000 4.0 (PERF 60 DEG PH 2.5"HSD DP 4,200.0 4,246.0 3,716.4 3,752.7 WS B,1D-139 6/30/2000 4.0 (PERF 60 DEG PH 2.5"HSD DP 4,258.0 4,281.0 3,762.4 3,781.1 WS A4,1D- 6/30/2000 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP 4,310.0 4,318.0 3,805.1 3,811.8 WS A3,1D- 6/30/2000 4.0 IPERF 60 DEG PH 2.5"HSD 139 DP 4,329.0 4,340.0 3,821.1 3,830.4 WS A3,10- 6/30/2000 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP 4,345.0 4,355.0 3,8347 3,843.2 WS A3,10. 6/29/2000 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP PRODUCTION;30.5-4,031.1 4 4,362.0 4,375.0 3,849.2 3,860.4 WS A3,10- 6/29/2000 - 4.0 (PERF 60 DEG PH 2.5"HSD 139 DP IPERF;4,114.0-4,162.0 4,393.0 4,440.0 3,876.1 3,917.3 WS A2,10. 6/29/2000 4.0 IPERF 60 DEG PH 2.5"HSD / _ 139 DP $W % p Cement Squeezes 4,490.0 3,952.8 3,961.7 WS A2,10. 6/29/2000 4.0 (PERF 60 DEG PH 2.5"HSD GEL SQZ;4,200.0 139 DP (PERF;4. 0-4.246.0• Top(ND) Btm(ND) ////i Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com (PERF;4,258.0-4,281.0 =(q 4,200.0 4,246.0 3,716.4 3,752.7 GEL SQZ 8/8/2013 PROFILE MODIFICATION-PUMPED 1045#(4MM) t CRYSTAL SEAL IN MBE @ 4210' Mandrel Inserts (PERF;4,310.0- l ,r,.‘" St4,310.0 Mj C - on Top(TVD) Valve Latch Port Size TRO Run 0 NO Top(ftKB) (8KB) _ Make Model OD(in) Sery Type Type (in) (psi) Run Date m 1 3,762.5 3,405.8 CAMCO KBG-2-9 1 Gas Lift GLV INT 0.000 0.0 6/13/2000 IPERF;4,329.0-4,340.0 _, Notes:General&Safety - End Date Annotation 1/5/2009 NOTE:View Schematic w/Alaska Schematic9.0 IPERF,4,345.0-4,355.0 IPERF,4,362.0-4,375.0 - IPERF,4,393.0-44400 - IPERF;4,490.0-4,490.0 - LINER;3.874.5-4,8380 1 S 1D-139 to 1D-102 B MBE Retreatment with Crystal Seal Proposal 1D-139 injector originally had an MBE occur on 4/25/04 to 1D-102 producer. A 3/17/05 IPROF in 1D-139 confirmed that a B sand MBE existed at 4210' MD. On 8/8/13, the B MBE was treated by fullbore pumping 1,035 lbs of 4 mm mesh synthetic crosslinked granular water swellable polymer (aka Crystal Seal) as a slurry to seal the MBE off in the B sand. A CT FCO removed excess Crystal Seal from the well, and then a post-treatment (PROF on 10/11/13 verified that the B MBE was indeed sealed. 1 D-139 was returned to PWI to D, B, and A sands. In September 2015, qualitative indications were noted that the B MBE treatment had gradually broke down causing a CPF1 upset. A 1D-139 IPROF ran on 11/05/15 shows 100% of PWI (at 740 BWPD / 500 psi WHIP) being injecting below 4200' MD to B &/or A sand perfs. Currently the B perf interval is partially covered by fill and all of the A sand perf intervals are covered. This indicates that the B MBE is likely open again and taking all PWI. It is proposed that the B MBE be retreated with Crystal Seal slurry fullbore pumped into 1D-139./The objective is to enable the return of 1 D-139 to West Sak A, B, and D sand PWI service to support 1D-102. Procedure: Slickline: 1. Bail -42' fill from 3.5" liner to 4255' RKB to uncover the entire B sand perf interval at 4200 - 4246' RKB in preparation for a Crystal Seal retreatment of the B MBE. Pumping: 2. Fullbore a Step Rate Injection Test (SRIT) with Seawater (10 to 20 bbls) down tubing to verify rates vs. WHIP's before the Crystal Seal retreatment to seal the B MBE. Immediately after SRIT and determination of preferable constant pump rate, continue pumping Seawater with 0.25 ppg of 1,2,4 mm mesh Crystal Seal down tubing at an established constant rate (-1 bpm is expected based on the 2013 treatment). Pump slurry until achieving 1000 psi WHIP (near frac pressure), and then call Flush of 15 bbls of Seawater, followed by 20 bbls of Diesel, followed by Shutdown. RD. Coil Tubing: 3) RIH with Jet Swirl Nozzle to perform a Crystal Seal & fill cleanout. Perform cleanout jetting Seawater with FR to as deep as possible. FP well with 20 bbls Diesel. RD CTU. Return 1D-139 to PWI service to West Sak D, B, and A sands.. JWP 11/18/2015 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) [] Two-Sided RESCAN rnjor items: Grayscale items: Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No Other No/Type TOTAL PAGES: ~fq NOTES: ORGANIZED BY: I~,EVERLY BREN ~ SHERYL MARIA LOWELL OVERSIZED (Scannable) Maos: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Oth er Project Proofing PROOFED BY: BEVERLY BR~HERYL MARIA LOWELL [] Staff Proof By: Date: PAGES: ~¢ (at the time of scanning) SCANNED BY~ BEVERLY ~ VINCENT SHERYL MARIA LOWELL ReScanned (do.e) IIIIIIIIIIIIIIIIIII RESCA.NEO.¥: BEVE.,v V,NOENTS,E,YLMA, IA '/ ,s, General Notes or Comments about this file: PAGES: ¢¢ Quality Checked (done) Rev1 NOTScanned,wpd 1., 0 �j- s9 THE STATE Alaska Oil and Gas °f l lLl l Conservation Commission G OVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John Peirce Wells Engineer 00 _ot-bq ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D -139 Sundry Number: 312 -490 Pi 16 2O '13 SCANNED Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Qtr orman Co ssioner DATED this 3 day of January, 2013. Encl. STATE OF ALASKA ALQA OIL AND GAS CONSERVATION COM•OION ' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 ®° Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re - enter Susp. Well r Stimulate r Alter casing r Other:Crystal Seal MBE Treatmenp`• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fl Exploratory r 200 -049 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22958 - 00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes fl No Ic 1 D - 139 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25650 - Kuparuk River Field / West Sak Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 4838 • 4276. 4739' 4186' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 110' 110' PRODUCTION 4001 5.5 4031' 3594' LINER 964 3.5 4838' 4276' RECEIVED DEC .?8g1? AC G Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9 intervals from 4114' - 4490'4 3654' - 3962' 3.5 L - 3877 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER SAB -3 MD =3875 ND =3485' SSSV - CAMCO DS NIPPLE MD =3814 TVD =3442• 12. Attachments: Description Summary of Roposal 17 • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development " Service r' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/10/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ P • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce © 265 -6471 Email: John .W.PeirceCcaconocoohillips.com Printed Name John Peirce Title: Wells Engineer Signature W, ,�•.._,�^ Phone: 265 -6471 Date laI2'r /1,2, Commission Use Only Sundry Number: � 2 - Conditions of approval: Notify Commission so that a representative may witness ✓ ✓ / v Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No ft Subsequent Form Required: / (' yo y APPROVED BY Approved by: Oil COMMISSIONER THE COMMISSION Date: ' � �� ////���1 (t ' • • • - • g is val • f• 12 months from the date of approval. O NA I L .: 0 Rl.rI 0t D 2013 Submit Form and Attachments in Duplicate � � — '/2 ‘ . • 1D-139 to 1D-102 B MBE Crystal Seal Treatment An MBE occurred between 1D-139 injector and 1D-102 producer on 4- 25 -04. A 3 -17 -05 IPROF in 1D-139 confirmed the B sand perf interval at 4200 - 4246' RKB was a thief zone with an MBE communicating to 1D-102. A plug was set between the D and B perf intervals so that 1D-139 could be returned to D sand only PWI. ID -139 was on D sand only PWI until June 2010 then became shut -in until the present. On 9- 20 -12, the plug set between the D and B sand perfs was pulled. On 9- 23 -12, a PBTD tag at 4217' RKB showed 273' of fill exists up into the B sand perfs. Per this procedure, the B MBE will be sealed with Crystal Seal full -bore pumped down 1D-139. The objective is to enable return of 1D-139 to West Sak A, B, and D sand PWI service. Procedure: Slickline 1. RIH to bail 42' fill from 3.5" liner to 4255' RKB. Cap TOF with 5' of 100 mesh CaCO3. Pumping 2. FB a Step Rate Injection Test with Seawater at 0.5 & 1.0 bpm to verify good injectivity. 3. FB pump Crystal Seal treatment to seal the B sand MBE. Initiate pumping with 36 bbls Seawater down tubing to determine optimal steady rate to pump Crystal Seal slurry. Immediately after Seawater pumping and constant pump rate determination, continue pumping Seawater with 0.05 ppg of 4 mm Crystal Seal down tubing at established rate. Volume of this stage (and all subsequent stages) is TBD during pumping based on treating pressure responses seen during pumping. Ramp stages as called at 0.10, 0.15, 0.20 and 0.25 ppg 4 mm Crystal Seal at the established rate, else swap to pumping Flush when we see signs of a screen out. If screenout indication has been seen, attempt to pump 35 bbls of Diesel down tubing to displace all Crystal Seal from the tubing to the MBE. With a sudden screenout, it may not be possible to get away 35 bbls of Diesel. This may result in an ice plug formation in tubing we will remove with coil tubing later. Underdisplace Crystal Seal from tubing by —1.5 barrels to leave the B MBE channel Crystal Sealed to the wellbore. If screenout has not been seen, but we decide to call Flush, pump 35 bbls of Diesel to displace Crystal Seal from the tubing at stable established rate, then SD. RD. Coil Tubing: 4) RIH with Jet Swirl Nozzle to perform a Crystal Seal & fill cleanout. Perform cleanout jetting Seawater with FR to as deep as possible. FP well with 20 bbls Diesel. RD CTU. Pumping (optional): 5) Pump an injection test into 1D-139 with Diesel down tubing to verify acceptable injection rate before attempting to return to PWI. Return 1D-139 to PWI. JWP 12/27/2012 • KUP 1D-139 • Conoc ill Well Attributes Max Angle & MD TD Inc Welibore API /UWI Field Name Well Status Inc! (1 MD (ttKB) Act Btm (ftKB) " • 500292295800 WESTSAK INJ 46.59 3,091.38 4,838.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (R) Rig Release Date ••• Well Canfig' - 10.139, 10/6/2012 10.26:18 AM SSSV: NONE Last WO: 31.09 5/15/2000 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date • . Last Tag: SLM 4,192.0 9/23/2012 Rev Reason: PULL PLUG, TAG ninam 10/6/2012 Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 CONDUCTOR 16 15.062 31.0 110.0 110.0 62.58 H - 40 WELDED .:. / Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.950 30.5 4,031.1 3,593.7 15.50 L - 80 LTC - MOD HANGER, 29 ', "'. Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 31/2 2.992 3,874.5 4,838.0 9.30 L -80 FL4S Liner Details ii . Top Depth (TVD) Top Inc! Nomi... Top (RKB) (RKB) (°) Item Description Comment ID (in) 3,874.5 3,484.5 45.96 PACKER BAKER 'SAB - 3' PRODUCTION PACKER 2.750 CONDUCTOR. 3 1-110 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (N0) ... String Wt... String ... String Top Thrd I l i TUBING 31/2 2.992 29.3 3,876.9 3,486.1 930 L -80 EUE8rdMOD Completion Details GAS LIFT. Top Depth 3,762 (ND) Top Ind Nomi... Top (8858) (RKB) (°) Item Description Comment ID (In) 29.3 29.3 -0.43 HANGER VETCO-GRAY TUBING HANGER 3.500 I. 3,813.7 3,441.9 45.82 NIPPLE CAMCO 'DS' LANDING NIPPLE w/2.813 NO GO PROFILE 2.813 NIPPLE. 3814 3,852.1 3,468.6 45.80 LOCATOR BAKER KBH-22 LOCATOR 2.992 EDP. 3 552 3,85Z5 3,468.9 4580 PBR BAKER 40-45 SPECIAL CLEARANCE PBR 2.958 3,876.2 3,485.6 45.95 ANCHOR BAKER KBH -22 ANCHORAGE ASSEMBLY 2.958 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Inc! Top (RKB) (RKB) (1 Description Perforations & Slots Comment Run Date ID (in) CSG PATCH T 9" EXTERNAL PRODUCTION CASING PATCH FROM 11/15/2006 5.500 MANDREL HANGER TO 7 5" MD I Shot Top (ND) Btm (ND) Dens 20C1,3a. 7111 Top(ftKB) Btm(RKB) OMB) (ftKB) Zone Date (oh -- Type Comment 4,114 4,162 3,654.4 3,687.8 WS D, 1D-139 6/30/2003 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,200 4,246 3,716.4 3,753.3 WS B, 10.139 6/30/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,258 4,281 3,762.7 3,781.1 WS A4, 1D- 139 6/30/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,310 4,318 3,805.3 3,812.0 WS A3, 1D-139 6/30/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,329 4,340 3,821.2 3,830.5 WS A3, 10.139 6/30/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,345 4,355 3,834.7 3,843.3 WS A3, 1D- 139 6/29/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,362 4,375 3,849.2 3,860.4 WS A3, 1D- 139 6/29/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,393 4,440 3,876.1 3,917.5 WS A2, 10.139 6/29/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP 4,480 4,490 3,952.8 3,961.9 WS A2, 1D- 139 6/29/2000 4.0 IPERF 60 DEG PH 2.5" HSD DP Notes: General & Safety PRODUCTION, End Date Annotation 314,031 1/5/2009 NOTE View Schematic w/ Alaska Schematic9.0 IPERF, 4,1144,162 IPERF, 4.2004,246 IPERF, • 4.258 -4,281 IPERF, 4,310 -4.318 IPERF, 4,3294,340 IPERF, 4,3454,355 IPERF, 4,3624,375 IPERF, 4,3934.440 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(RKB) (MB) r) Make Model (in) se, Type Type (in) (psi) Run Date Com._ 4.4eo44.490 aso 1 3,762.5 3,405.8 45.31 CAMCO KBG 1 Gas Lift DMY INT 0.000 0.0 6/13/2000 LINER, 3,874 -4838\ ■ TD, 4.838 MEMORANDUM TO: Jim Regg P.I. Supervisor ~~~1c1 ~~ZC<,~tc~? FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-]39 KUPARUK RIV U WSAK 1D-]39 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1 D-139 Insp Num: mitRCN100718145654 Rel Insp Num: API Well Number: 50-029-22958-00-00 permit Number: 200-049-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1Da39 ,Type Inj. i N TVD 3483 ~ IA 280 1770 ~ 1710 1690 ~ P.T.D zoooa9o TypeTest ~ S? J Test psi ]~~o ~~ OA Interval a~TST p/F' P ~ Tubing 6so 650 650 6so Notes: ~,; ,1 ~~ Thursday, July 22, 2010 Page 1 of 1 • ~ ; ~:~- ~:`" ~ ~ ~~ ~ • Ta: ~10GCC Christine Mahnken 333 West 7th Avenue Suit~ 100 Anchorage, Alaska 99501 [907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection[Caliper / MlT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal (etter to the following : PraActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Raad Suite C Anchora~, AK 99518 ~~;~~'~~~,~,~ ~,i~jiz,,, ~ ~ ~~~~ Fa~c (907) 245-8952 1 ~ Caliper Report 01-JuE09 ~ 2~ Caliper Report 01 1 Q137 1 Report / EOE 1 D-139 1 Repor~ / EDE ~: ~'- ~ - c~/'~ ! ~~~ 3 ~ ~Zc ~~ -c~'(~ t ~ 2'~ ~/ ~ , ~~ ~ Signed : Print Name: 50~029-22956-00 50-029-22958-00 Date : _ PROACTIVE DlAGNOSTIC SERVICES, INC., 1S0 W. (NTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHOntE: ~907)24$-8959 FAx: (907)245-88952 E-MF11L : ~_ __.__ _ -._ ~ _. ~_ ° - .. _. A__ VUEBSITE . _ ..._ , _ _ . __ _ .___., ~ ~ C~~~Documen~ and Settings\OwnerlDesk[op\T[ansmit_Conoco.docx ~ Memor°y MultirFinger Caliper Log Resuits Summary Company: ConocoPhillips Aiaska, Inc. Well: 1D-139 Log Date: July 1, 2009 field: West Sak Log No. : 7343 S#ate: Alaska Run Na.: 2(MIT) API No.: 50-029-22958-00 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD-MOD Top Log Intvll.: 22 Ft. (MD) Pipe1 Use: Tubing and Liner Bot. Log Iniv11.: 3,966 Ft. (MD) )nspection Type : Buckiing & Corrosive & Mechanicai Damage Inspection COMMENTS : This caliper data is 6ed into tf-e DS Nlpple ~ 3,844' {Driller's Depth). This iog was run to assess the condition of the tubing and liner with respect to subsidence induced buckling and corrosive and mechanical damage. The caliper recordings indicate the 3.5" twbing and liner logged a~e in good to poor condition, with a maximum recorded wall penetration of 56% recorded in a line of corrosion in joint 713 (3,557'). Recorded damage appears as isolated pitting, shallow corrosion, a line of pits from -2,750' ta -2,810', and line corrosion from ~2,810' to 3,966 (E~L). No significant areas of cross-sectianal wall loss or I.D. restrictions are recorded throughout the tubing and liner logged. The caliper recordings indicate buckling from ~160' to ~200', ~260' to ~290', and ~350' to -380'. A 3-D log plot of the centered and off-centered caliper recordings from surface to 1,000' is included in this report. This is the second time a PDS caliper has been run in this well and the 3.5" tubing and liner have been logged. A comparison of the cuRent and previous log (July 27, 2005) indicates no change in corrosive damage during the time between logs. A graph illustrating the difference in maximum recflrded penetrations on a joint-by joint basis between the current and previous log is included in this report. ,' 3.5" TUBING ~ LINER - MAXIMUM RECORDED WALL PENETRATIONS: Line corrosion ( 56%) Jt. 113 (~ 3,557 Ft. (MD) ' Line coROSion ( 55%) Jt. 129 ~ Line corrosion ( 55%) Jt. 116 ~ 3,824 Ft. (MD) 3,652 Ft. (MD) Line coROSion ( 50%) Jt. 104 {c,~ 3,274 Ft. (MD) Line corrosion ( 48%) Jt. 123 @ 3,922 Ft. (MD) I 3.5" TUBING $ LINER - MAXIMUM RECORDED CROSS-~ECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing and liner logged. 3.5" TUBING ~ LINER - MAXIMUM RECORDED ID RESTRICTIONS: No significant l.D. restrictions are recorded througMout the tubing and liner logged. Field Engineer: Wm. McCrossan Analyst: HY. Yang Witness: J. Rowell ProActive Diaqnostic Services, Inc. J P.O. 6ok 1369, Stafford, TX 7?497 Phone: t281) or (888) 565-9085 Fax: (2S1) 565-13b9 E-mail: PQS~,a~memorylog.com Prudhoe Bay Field O~fice PhonE: (907} 659-2307 Fax: (90?) 659-231~} vz ~ aoU - cxr~ r~s a~~~ PDS Mu~ftifin er Cali er 3D Log PI~ ~~~ g P ~~ Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 1D-139 Date : July 1, 2009 Description : Detail of Centered and Off-Center Caliper Recordings from Surface to 1,000' Cormients Depth Max ID (1/1000 in.) -J 1ft:750ft 2500 3500 Min ID (1N000 in.~ 2500 3500 Nominal ID (1N000 in.) :.............................................. 2500 3500 Tree Pup Jts. 50 .Ioint 1 Joint 2 100 Joint 3 ~ doint 4 150 _ ~- Joint 5 Buckling 2~~ Joint 6 Joint 7 250 Joint 8 -t Buckling ~ 300 Joint 9 Joint 10 350 Joint 11 Buckling i Joint 12 ,400 Joint 13 450 Joint 14 260° 0° 90° 180° 270° 0° 0° 90° 180° 270° 0°~ "` ;x..,.,,,e~~,---- - ~ _ .~ ~....rr~"=.__ _ : ~ - ~. .~ ~~ ~ -.~r:~m: ~~.~ Y *~~. ~~ ~~. .,~;;k:;, ~ „~y~;,. ~. ,....tc~.+~.,,,,. ~"~.`. ~~ ,,,~ ~,..~ - ~. ..:3cuii~'iF~.~:':~ °°~e-..._ ~ - s~~u....,.~ o~nt 500 Joint 16 + .loint 17 550 Joint 18 00 ~ f- Joint 19 Joint 20 650 Joint 21 ' ~ - Joint 22 7~0 Joint 23 -~ T50 Jant 24 i Joint 25 Isolated pitting 23% Wall Pen. 800 I~ Joint 26 850 Joint 27 _ Joint 28 i 900 Joint 29 Jant 30 950 Joint 31 Nominal ID (111000 in.) :.......................................... . 2500 3500 Min ID (7/1000 in.) 250~ 3500 Cornments Depth Max ID (1/1000 in.) ~.._ __~_. 1ft:750ft 2500 3500 r~ - ~~~ ,~-.-. ..... iter~ 3-0 ~ 260° ~: (~ff-Center) Image Map (centerea~ m~age nnap 0° 90° 180° 270° 0° 0° 90° 180° 270° 0° orrelation~of Recorded Dama e to BorehoTe Profile C g ~ Pipe 7 3.5 in (22.9' - 3949.9') Well: 1 D-139 Field: West Sak Cornpany: ConocoPhiilips Alaska, Inc. Country: USA Survey Date: July 1, 2009 ^ A pprox. T ool Deviation ^ A pprox. B orehol e Profil e 39 320 633 944 1255 1563 ~ ~ 1876 ;; ~ c t 2185 a a~ ~ 2500 2813 3126 3435 GLM 1 3784 124 3950 0 5 0 1 00 Da mage Profile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 124 1 10 20 30 40 50 ~ 60 ~ E ~ Z 70 ~ ~ o 80 ,.. , ~*~ 90 ~~ 100 I ( 110 I 120 ~ • • ~ Maximum Recorded Penetration ~. ~ -.--~ Comparison To Previous Well: 1D-139 Survey Date: July 1, 2009 Field: West SAk Prev Date: July 27, Z005 Company: ConowPhillips Alaska, Inc. Tool: UW MFC 24 No. 218370 Country: USA Tubirig: 3.5" 9.2 Ib L-80 EUE8rdMOD Overlay 0 5 Maar. R 0 10 ec. Pen 0 15 . (mis) 0 20 0 25 0 0.1 8 18 28 38 48 ~ 58 E a Z 68 ~ 0 78 88 98 108 118 121 ^~~ yi,2o o9 ^l~ yz~,2 oos Difference Diff. in Max. Pen (mis) -100 -50 0 50 100 ~ E e Z S I -2 ~ 5 -1 3 0 1 3 2 5 Ap~x ox Corros ion Rate ( mpy) 8 18 28 38 4$_ 58 , 78 88 9 108 1 ~?~ • • PDS Report Overview Body Region Analysis Well: 1 D-139 Survey Date: July 1, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 92 f L-80 EUESrdMOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°/a wall) ~ penetration body ~ metal loss body 100 80 60 40 20 ~ 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 132) pene. 0 8 73 40 11 0 loss 43 89 0 0 0 0 Damage Configuration ( body ) 40~ 30 ~ 2(1 10 ~ isola[ed general line ` ring hole / poss pitting corrosion corrosion corrosion ible hole Number of'oints dama ed total = 78 36 2 40 0 0 Damage Profile (% wall) ~ penetration body ~ metal loss body 0 50 100 0 48 i ' i ( 1 ~ 9~3 ~ I ~ I ~` ~ ~ I _ ~ GLM 1 ~ ~ { _ ~ ~-~ f - Bottom of Survey = 124 Analysis Overview page 2 PDS •ORT JOINT TABULATION S~Ef Pipe: 3.5 in 9.2 ppf L-80 EUE8rdMOD Well: 1 D-139 Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 1, 2009 Joint No. Jt. Depth (Ft,) I'c~n. Upset (Ins.) Pen. Body (Ins.) Pen. % Metal Loss %> Min. I.D. (Ins.) Comments Damage Profile (% wall) 0 50 100 .1 23 0 0.03 12 1 2.96 PUP .2 27 0 0.03 10 2 2.89 PUP 3 33 0 0.03 10 1 2.90 PUP 1 39 0 0.03 12 6 2.98 2 71 0 0.03 12 2 2.95 3 102 U 0.03 12 1 2.93 4 134 O 0.04 17 2 2.94 Isolated ittin . 5 165 ll 0.03 11 1 2.90 Bucklin . 6 196 (1 0.03 11 2 2.94 7 226 t) 0.03 11 2 2.94 8 258 0 0.03 13 7 2.96 Bucklin . Isolated ittin . 9 289 0 0.04 15 1 2.94 Isolated ittin . 10 320 (1 0.03 13 1 2.94 Isolated ittin . 11 352 0 0.03 13 2 2.87 Bucklin . 12 382 0 0.03 13 1 2.96 Isolated ittin . 13 414 l) 0.04 14 1 2.94 Isolated ittin . 14 445 l) 0.03 11 1 2.98 Isolated ittin . 15 477 0 0.04 15 1 2.94 Line of its. 16 508 0 0.04 17 3 2.96 Line of its. 17 539 0 0.03 12 2 2.94 18 570 (1 0.04 16 1 2.95 Isolated ittin . 19 602 U 0.04 14 1 2.95 Isolated ittin . 20 633 0 0.03 13 2 2.95 Isolated ittin . 21 664 U 0.04 15 2 2.94 Isolated ittin . 22 695 0 0.03 12 i 2.98 23 727 0 0.03 12 ; 2.93 Isolated ittin . 24 758 (1 0.03 12 1 2.95 Isolated ittin . 25 790 (1 0.06 23 2 2.95 Isolated ittin . 26 821 t~ 0.03 12 2 2.96 27 851 l~ 0.03 12 1 2.94 28 883 U 0.03 10 l) 2.93 29 914 O 0.03 12 1 2.94 Isolated ittin . 30 944 U 0.03 12 0 2.92 31 975 O 0.03 11 0 2.94 32 1004 0 0.03 12 1 2.96 33 1036 0 0.03 10 2 2.95 34 1067 U 0.03 12 2 2.94 35 1098 l1 0.03 12 1 2.94 Isolated ittin . 36 1129 U 0.04 17 1 2.96 Isolated ittin . 37 1161 ll 0.03 1 1 1 2.94 38 1192 l1 0.03 12 1 2.94 39 1224 ~1 0.03 12 0 2.94 40 1255 U 0.03 12 4 2.95 41 1287 t) 0.03 13 1 2.96 42 1318 0 0.03 11 2 2.94 43 1349 U 0.04 16 2 2.93 Isolated ittin . 44 1380 cl 0.03 11 2 2.95 45 1411 t) 0.04 17 5 2.91 Shallow corrosion. 46 1439 t) 0.03 10 1 2.95 47 1470 (~ 0.05 19 0 2.94 Isolated ittin . _ Pen~tration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION S~ET Pipe: 3.5 in 9.2 ppf L-80 EUE8rdMOD Well: 1 U-139 Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. fVominal I.D.: 2.992 in Country: USA Survey Date: July 1, 2009 Joint No. Jt. Deptfi (Ft.) Pc~n. Upset (Ins.1 Pen. Body (Ins.) Pen. % Metal I_oss °io Min. I.D. (Ins.) Comments 0 Damage Profile (%wall) 50 100 48 1500 c) 0.03 12 7 2.98 49 1532 0 0.03 12 1 2.95 50 1563 0 0.04 16 3 2.94 Shallow corrosion. 51 1593 0 0.03 11 2 2.96 52 1624 0 0.03 11 2 2.95 53 1656 0 0.03 11 4 2.97 54 1687 0 0.05 19 3 2.95 Isolated ittin . 55 1719 0 0.02 9 2 2.96 56 1750 t) 0.03 11 3 2.96 57 1782 O 0.05 19 9 2.99 Isolated ittin . 58 1813 0 0.03 1 1 1 2.95 59 1845 0 0.03 12 1 2.95 60 1876 O 0.03 11 2 2.95 61 1908 0 0.03 10 2 2.94 62 1936 0 0.03 12 4 2.96 63 1968 t) 0.03 11 2 2.96 64 1999 c) 0.03 10 2 2.94 65 2031 0 0.03 12 1 2.99 66 2062 0 0.03 12 2 2.96 67 2093 0 0.03 12 Z 2.96 68 2124 0 0.03 11 1 2.95 69 2154 0 0.06 22 1 2.96 Isolated ittin . 70 2185 (~ 0.03 11 2 2.95 71 2217 (1 OA5 21 1 2.99 Isolated ittin . 72 2248 0 0.03 11 2 2.95 73 2280 O 0.03 13 1 2.9 74 2312 (~ 0.03 12 1 2.96 75 2343 0 0.04 16 1 2.96 Isolated ittin . 76 2375 O 0.03 12 Z 2.95 77 2406 O 0.03 12 2 2.95 78 2437 U 0.05 20 2 2.95 Isolated ittin . 79 2468 0 0.03 12 2 2.96 80 2500 0 0.07 26 1 2.96 Isolated ittin . 81 2531 (1 0.05 20 2 2.94 Isolated ittin . 82 2562 l1 0.03 12 1 2.96 83 2594 U 0.07 27 1 2.95 Isolated ittin . 84 2625 U 0.10 39 3 2.93 Isolated ittin . 85 2656 (1 0.09 35 3 2.95 Isolated ittin . 86 2688 (1 0.08 32 3 2.95 Isolated ittin . 87 2719 0 0.09 34 2 2.94 Isolated ittin . 88 2751 ll 0.07 'L9 2 2.94 Line of its. 89 2782 0 0.07 26 2 2.95 Line of its. 90 2813 U 0.09 35 4 2.96 Line corrosion. 91 2844 tl 0.11 44 2 2.96 Line corrosion. 92 2876 0 0.07 28 2 2.95 Line corrosion. 93 2907 0 0.09 37 3 2.95 Line corrosion. 94 2938 0 0.08 32 3 2.96 Line corrosion. 95 2970 0 0.08 32 4 2.95 Line corrosion. 96 3001 0 0.09 36 2 2.96 Line corrosion. 97 3032 l1 0.09 37 3 2.96 Line corrosion. _ Penetration Body Metal Loss Body Page 2 PDS ~PORT JOINT TABULATION S~Ef Pipe: 3.5 in 9.2 ppf L-80 EUE8rdMOD Well: 1 D-139 Body Wall: 0.254 in Field: West Sak Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: July 1, 2009 Joint No. )t. Depth (Ft.) I'c~n. UF,sc~t (Ins.) Pen. Body (Ins.) Pen. % Metal Loss °i~, Min. I.D. (Ins.) Comments 0 Damage Profile (%wall) 50 100 98 3063 O 0.09 35 3 2.96 Line corrosion. 99 3095 0 0.06 22 1 2.94 Line corrosion. 100 3126 0 0.10 39 2 2.95 Line corrosion. 101 3158 0 0.11 43 2 2.96 Line corrosion. 102 3189 0 0.06 25 3 2.96 Line corrosion. 103 3221 0 0.08 31 3 2.95 Line corrosion. 104 3251 0 0.1 50 4 2.95 Line corrosion. 105 3282 U 0.11 44 4 2.96 Line corrosion. 106 3312 0 0.08 32 2 2.95 Line co~rosion. 107 3344 0 0.09 35 2 2.94 Line corrosion. 108 3374 0 0.11 45 3 2.96 Line corrosion. 109 3405 U 0.07 29 2 2.95 Line corrosion. 11 D 3435 0 0.10 41 3 2.96_ Line corrosion. 111 3466 O 0.08 31 1 2.95 Line corrosion. 112 3497 (1 0.08 32 2 2.94 Line corrosion. 113 3529 (1 0.14 56 3 2.94 Line corrosion. 114 3560 (1 0.07 27 2 2.96 Line corrosion. 115 3591 0 0.11 42 2 2.96 Line corrosion. 116 3623 0 0.14 55 3 2.95 Line corrosion. 117 3654 (~.06 0.09 34 3 2.96 Line corrosion. 118 3686 l) 0.09 34 3 2.96 Line corrosion. 119 3717 0 0.09 36 Z 2.95 Line corrosion. 119.1 3748 0 0.10 39 2 2.93 PUP Line corrosion. 119.2 3763 U 0 0 0 N A GLM 1 Latch ~ 11:30 1193 3772 0 0.06 25 1 2.98 PUP Line corrosion. 120 3784 0 0.10 38 3 2.91 Line corrosion. 120.1 3814 0 0 0 0 .81 Camco DS Landin Ni e NO GO 121 3816 0 0.14 55 7 2.93 Line corrosion. 121.1 3847 0 0.08 31 3 2.96 PUP Line corrosion. 121.2 3852 0 0 0 0 N A Baker PBR w Seal assembl 1213 3868 0 0.10 38 3 2.95 PUP Line corrosion. 121.4 3877 l) 0 0 (1 N A Baker KBH-22 Anchora e Assembl 121.5 3883 l) 0.10 38 3 2.96 PUP Line corrosion. To of liner. 122 3888 U 0.10 39 4 2.98 Line corrosion. 123 3918 (1 0.12 48 7 2.98 Line corrosion. 124 3950 O 0.08 31 3 2.97 Line corrosion. _ Penetration Body Metal Loss Body Page 3 ~ ~~ PDS Report Cross Sections ~~ Well; 1 D-139 Survey Date: )uly 1, 2009 Field; West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.2 f L-80 EUE8rdMOD Anal st: HY. Yan Cross Section for )oint 113 at depth 3557.433 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 97 % Tool deviation = 49 ° Finger 12 Penetration = 0.142 ins Line Corrosion 0.14 ins. = 56% Wall Penetration HIGH SIDE = UP ~ • Cross Sections page 1 ~ PDS Report Cross Sections ~ Well: 1D-139 Survey Date: July 1, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.2 f L-80 EUE8rdMOD Anal sr. HY. Yan Cross Section for Joint 121 at depth 3823.723 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviation = 48 ° Finger 5 Penetration = 0.14 ins Line Corrosion 0.14 ins. = 55%Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ' ~ r ~ ~ ~ ~ i ~ i • Cross Sections page 2 KUP 1 D-139 . ~Of IOCO~II~~IpS etl Amibutes A le 3 Nro TD c#Dac MW WI Fldd Name We0 9~us PfoNMM ( 1 ~(~) AU etrn p11~) ;~l.iti..: ~~ I, 500292295800 WESTSAK INJ PWI 46.59 3,D97.38 4,838.0 '~COnunert _--- H2S~ppe~ Dfe Amotdbn OMDae KBd'.rA~lq Rf9RNeaseDad "' ___- 'SSSV:NONE LaslWO: 31.09 5/15/2000 n - + W --~mt- io w ta t. __ Pdu91 IlmotaUOn D~ph IRI~) BM Ufe l lmotetla~ Bitl Date LastTag: ELMD 4,738.0 3I6I2005 R ev Reason: FORMAT UPDATE ~~5~2009 Casin Strin s ~ DeSt11p11m SMn90._ StNng _. TuPI I SetDeptlllT._ SetDeptl~l~wl._ ~~9WL.. Stfln9-. ~~9TOpMA CONDUCTOR 16 15.062 0.0 110.0 110.0 62.58 H-00 WELDED G~9 DesMpMOn ealM O._ ~ StrM91D ~. Top (N(B) Set Depth (f... Set DeP~ ('~1._ ShMg WC.. StM9... 9fring Top MA SURFACE 5112 4.950 0.0 4.031.0 '~ 3,593.7 15.50 L-80 BTCM PATQi.i m O_ 8t~1n0 ... IJNER 3 1/2 2.992 WI 1 3,974 5 ~mm~r_. 4.838.0 sN _ smnyw~. 9.30 sm~y... L-80 s~m~9rq,mra EUE8rd LinerDetails _. ~~p~ (T`/~) Top hKi ____ ___ - ' m TW Im~l m~~ 1'1 Ram oesaW on Commmt ___ ~ 1~' r i ~,874.5 3,484.5 45.96 PACKER BAKFA'SAB-3' PRODUCTION PACKER 2J5 CONWGTOR. 417o ~ I~ t .~ TYIDIII StIII1 $ 7UDhg Oeacrbtlon 91~hg 0... St~In91D _. Top (1118) 8et Deqth (f... SR Cep1h (Nq ... eMng Wt... Sring... StrlnO 7ap Mtl TUBING 31/2 2.992 0.0 3,876.9 3,486.1 9.30 L-80 EUEBrdMOD - Completion Detalis cns ~Fr. S,7s2 rop oepm (TVD) Top Illcl Top (ftlB) ~~) (') kem Descrlptlm Comment ~ (~ 29.3 29.3 -0.43 HANGER VETCOGRATUBI G ANGER 3.5f - 3,813.7 3,441.9 45.82 NIPPLE G~NiCO'D5lANDING NIPPLE w/2.813 NO GO PROFILE 2.81 rviaine.3eia 3.852.1 3,468.6 45.80 LOCATOR BAKER KBH-22 LOCATOR 2-~ 3. 2. 3. 6.9 5.80 AK IAL C P 2.9E 3.8762 ~ 3.485.6 45.95 ANCHOR BAKER- KBH~2 ANCHORAGE ASSEMBLY 2.9' Other In Hole Wiroiine retrievabl~ lu valves u s flsh ete. ~n mv+ (Tw) Top Incl PeR.3.e52 TuP(ftlm) IRlm) ('1 Dexhptlm CommerR Ru~DMe Dp~ 1.0 1.0 -0.65 PATCH 7' 9" EXTERNAL PRODUCTION CASING PATCH FROM 11f1 5.5( MANDREL HANGER T0 7' 5' MD 4,185.0 3.704.9 40.04 PLUC WEATHERFOR 3.5' WRPSET ~ MID~IEMENTTO 7/18/'ZOOG ISOLATEWESTSAKASlWDSBBSANDS FROM D-SANDS 7/t82006 suaF:~. aa.as~ IPE{iF, I,itN,iGl PLUG. d.165 IPERF, 4.2fiUd.X6 IPEl2F, ~.Z58d.281 IPERF. 4,3164 318 IPERF, A 329-6.340 IPERF, 4.345-4.355 IPERF 4 382-0 375 Valve Latch gpV lypa T/pe IPERF, 4.393-4 440 Jun 14 09 07'11p PDS Inc ~ P'3aiiiips tklas#:a inc. ~..x_:.u.`....t 1tH.~nii.~- t?G~I.AnW Pn~~i/~n~~ 907 6592314 p21 ~ ~ TUBIt~G Tefbint7 Or Liner D~SCriPiion W~LL_ 9 Q-139 OA7E: 5It5100 1 t'~F 1 ~AGES ~ ITEMS COMPLETE DESCRIls7'liJF' QF k''QlJ1i~A~t~i7 Rlfi S LI~NG"I~t !'~PTN NORDIG R1G #3 RT ta LD5 ~9-Z' Vetco-Gray Th .~3an sr W! 3.5° Ell~ 8~d Pup 3.80' & Hanrer 1.40' +~.80 29.27 3d.07 pups 3.5" 9.3# l.-BO EUE Srl~ PAOd Pups fi.06 & 6.i0 1~.11i 34.07 ~ J#. #3-12'1 3.5" 9.3# L-8(} EUE 8rd Mod tbg_ 37t7t ti4 46.23 Pup ~ 3.~" 9.3t`r {.~S{1 EUE $M Mvd Pup XO Buti mod X Eue 80x 14.&i 3747.83 ~ GLME 3.5" X t" C~nico 7iBG-2-9' wl DCK-3 Dump lCi1! Valvn BaE'om Latc 6.~~ 375?_4~ Petp 3.S" 9.~ L-80 EUE &Q Mod ~sp XO Butt mod X Eue Pin 9~1.1:3 3769.18 .fl. #2 3.5' 9_3# L-80 Etire 8 rt! Mod tbg_ 34.33 3783.36 3.5" Camco 'DS` i.and'e nippEe 2.$13 no-go profFte .95 3813.69 JL ~I'1 S.a" 9.3# 1-60 EUE 8rd Mod thg. 31.3~3 3618.64 Pup 3.5" 9.3# l-St~ ~UE 8rid INod P[~ 6.Ot, 3846.a2 ~.ocatof Baicer KSti-22 Lc~ator Spot~ed 1' up .~0 ~..._ 3852.07 SA S~l assembi FS 11.55 -7ap oF '45-40' SBE ~a 384B' ~852_47 3852.$7 PBR Baker '45-40' Speciaf ciaarance PBft 13.62 3852.47 Pup 3.5" 9.3~ L-80 EUE 8rei i~lod pt~ tU.10 `s8fi6.Q9 Anchar Saker'K@f~i-Z2` Anc~or assembdy .6B 33?S-t9 38~6_87 _. ...~. _.~.__.__. ~ rtemarxs: su~i~ wrignrs wan ~cs: vur«r ~r,vu r~ u~~, Eunr~ u~ocK~- K3R SJV jC7r1IF• (~E ~J~IIf'i~l l~7UCM7~ Vl.lYISS{ Q 71~Il~d{ ~-1ili G.WI' ~JIC~SU4 1alllJli~ VJP1A l4YUb 1+19YG ~'v F X #tvead cor,ipour~d an aii connections, Tubing is r.oa~-coai~_ -- Nal~iC ftiy #3 t~ritliru~ 5uperv~sor• M C. Netm ._._. . • ~~ `~ " ~-_ ..~~ r {~~o~a~~ ~iAyn~sric S~a~enc~s, l~vc. To: AOGCC ~hristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTt) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmitta! letter to the tollowing : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 ~j 1) MTf Report 1&Jun-09 1 D-139 ~ r 2j 1 Report 50-029-22958-00 ~ ~f'~~~~ ~ ~ ~~ ' $ ~jU~ K ~ 2~D~ ~zc ~~~~ Signed : ~ Print Name: Date : PROACTIVE DIAGNOSTIC SERV~CES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 F~c: (907)245-88952 E-MAIL : -: WEBSITE : ( E ~ ~ `~Documents and Settings\Ocmer~Desktop\"Craz~smit_Conoco.docx • • ~1 S Nlemory Magnetic Thickness Tool 1 Log Resul~s ~ummar~y Company: . ConocaPhillips Alaska, lr~c. _ Well: 1D-139 Log Date: June 18, 2009 Field: Kuparuk Log No. : 9Q5S5 State: Alaska RUn NO.: 3(2"d MTT) API ~10.: 50-029-2~958-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 214 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 fb L-80 BTCM 7op ~og Intv1.: Sur€ace Pipe2 Use: Produdion Casing Bot. Log Intv1.: 214 Ft. (MD) Pipe3 Desc,: 16" 62.58 Ib. H-40 Welded Top Log Intvt.: Surtace Pipe3 Use: Conductar Pipe Bot. Log Intvl.: 110 Ft. (MD) tnspection Type : Com~sive &,Mechanical Damage lnspection COMMENTS : - This MTT daia is tied into the Mandre/ Hanger @ D' Depth. '' This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of inetal of the 3.5° tubing and 5.5" production casing, as well as influence from the 16" conductor pipe. ' Passes at SHz, 8Nz, 10Hz and 12Hz were made at 20 fpm, with the 5Hz and 10Mz passes selected for analysis in this repo~t. ~, COMPARISON TO PREVIOUS MTT LOG RESULTS : A comparison of the current 10Hz pass to the previous 10Hz pass (September 26, 2006) indicates no significant change in metal thickness during the time between logs. Indications of a significant increase in '' metal volume are indicated over the interval (0' - 9'j. This increase in metal volume is believed to be associated with the Vecto-Gray tubing hanger installed since the previous M7T log (September 26, 2006). A log plot overlay of the average metal thicknesses recorded by the MT7 for the current and previous tog is ~ included in this repo~t and the most significant areas of ine#al (oss indicated in #he current and previous logs are iisted in the tabl~ below. Maximum Metal Loss Depth Description ', ~ 2009 Z006 _ 30' - 36' 7% 8% Gcneral circumferencial metal loss I 110' -121' S% 5% Generat circumferencia) metat loss ' S3' - 58' 3% 896 General circumferencial metsl loss 40' - 45' 3% 5% General circumferencial metal loss ,. 74' - 76' 3°r6 3% General circumferencial metal loss ',I' In the 2006 log, a single calibration taken within the conductor pipe was apptied to the entire iog interval. This resulted in an indication of less metal betow the conductor, relative #o the interval including the conductor. The current data set was processed using calibtations from both Zones, eliminating the appearance of inetal loss below the conductor pipe. fn order to support a more consistent comparison ' ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffard, TX 77~97 ' Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDSC~memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 fax: (90') 659-2314 I ' ' vrt ~- aoc~- c~y ~ , 1 ~ s between the current and previous log, the previous data set has been re-processed to include a calib~ation ' reference from the zone below the conductor pipe. , A much steadier logging speed (20 fipm) is observed in the current log than the previous log, enhancing the stability of the toot response to the metal volume surrounding it. The adcled s#ability and reliability of the data ' recorded at steady 20 fpm is believed to be the cause for some of the slight variance b~tween the 2006 and current log results. tNTERPRETATION OF MTT LOG RESUtTS : ~ The MTT log results cover the intetval from surface to 214'. Changes in metal volume are relative to the calibration points at 7Q' and 180', where the readings are assumed to represent undamaged pipe. All other ,' readings 2~re relative to these reference points, which include influences from the 3.5° tubing, 5.5" casing, and 16" cvnductor pipe. Log plots of the entire 5Hz and 10Hz passes and an overlay plot of the av~rage metal #hickness recorded by ' the MTT for the 5, 8, 10 and 12Hz passes are included in this report. A maximum overaA metal volume loss of 7% is indicated in tubing 7 joint 1(30' - 36'} in the 10Hz pass. ' The percent circumferential metal loss expressed in this summary is a percentage of the total metat that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the S.5° production casing, the percent metal loss from that pipe alone is probabty higher than the ' numbers expressed. Some of the metal toss indicated could be from either the 3.5" tubing or 16" conductor. ' ' ,' Field Engineer: G. Etherton Analyst: HY. Yang & J_ Burton ~tness: R. Ober ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone; (281) ar (888) 565-9085 Fax: (281) 565-1369 E-mail: ?DSrg`memarylog.com Prudhoe Bay Field Office Phone: (9Q7) 659-2307 Fax: (907} 659-2314 , , ' • Comparison to Previous M~ogs Overlay 1D-139 ~~ ao.q~,r~ sE~~, ~. June 18, 2009 and September 26, 2006 Database File: d:lwarriorldatal1d-1391comp1.db Dataset Pathname: 1!1l1/comp Presentation Format: comparis Dataset Creation: Thu Jun ~5 09:50:43 2009 Charted by: Depth in Feet scaled 1:150 0 Line Speed ~009 (ft/min) 100 -50 Delta Metal Thickness 2009 (1~Hz) (%) 50 Q Line Speed 2006 (ft/min) -100 -50 Delta Metal Thickness ~006 (10Hz) (%) 50 0 ~-DMT 2006 (10Hz) , MT 2009 (10Hz)~- ~ i S ~a ~ so of ~~,. so ~ 100 120 140 160 180 ~QO 2006 (1 ~009 0 Line Speed 2009 (ft/min) 100 ~-50 Detta Metal Thickness 2009 (10Hz) (%} 50 0 Line Speed 2006 (ft/min) -100 I-50 Delta Metal Thickness 2006 (10Hz) (%) 50 ~1 D-139 Recorded Magnetic Thickn~Log Data - 5Hz Pass {Surface to 214') June 18, 2009 PwAc~tve DlwqnaaTic Se~Aca, Inc. Database File: 1d-139.db Dataset Pathname: 5HzPas.1 Presentation Format: 1.4 scale Dataset Creation: Wed Jun 2418:03:08 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -5Q Delta Metal Thickness (%} 50 1.4 M7T Phase Shift - Sensor 01 (5 Hz) (rad) 11.4 0 LSPD (ftlmin) 200 -7.4 MTf Phase Shift - Sensor 12 (5Hz) (rad) 2.6 Pup ~~ 20 ~Ita Metal Thickness Tubir~ Jt. 1 Metal Loss 40 Metal Loss _Casinq Collar 60 Tubing Jt. 2 of 16" 80 Casing Coflar Tubing Jt. ~z, 8Hz, 10Hz and 12Hz Passes De~etal Thickness Overlay 1 D-139 June 18, 2009 ~~.,n~ o~~~ sE~~, i~. Database File: 1d-139.db Dataset Pathname: 1/111/overlay Presentation Format: comparis Dataset Creation: Thu Jun 25 09:14:07 ~009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2009 (12Hz) (%y 50 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness 2009 (8Hz) (%) 50 -50 Delta Metal Thickness 2009 (5Hz} (%} 50 0 Hanger. ~0 40 6Q t~ DMT (10Hz) of 16" 80 ~ 100 12d 140 160 180 200 -50 Delta Metal Thickness 2009 (12Hz) (%) 50 -50 Delta Metal Thickness ?009 (10Hz} (°/a) 50 --- - ---- -- --- __ --- -50 Delta Metal Thickness ~009 (8Hz) (%} 50 -50 Delta Metal Thickness ~009 (5Hz) (%) 50 ~ ConocoPhiliips ai.,~,., ;n: PATCM.1 Q7NIX1CfOR, 0.170 GPS LIFf. N WPLE. PBR. wEaF. ~.~iar.iss PLUG,d.i85 IPERF, <,20pd,M6 IPERF, 4.258d.26'I IPERF, a,310d,318 IPERF, 4 3294,310 KUP flell Attributes roat av xn naa Nane 500292295800 WESTSAK INJ 31.09 1 D-139 Last Tag: ELMD 4J38.0 3/fi12005 Rev Reason: FORMAT UPDATE 7/5/2009 Casi Strin s CasingDesaiptlon StringO... ID... uP DePUia-. fet ... StrfngYYt_ rtg_ Tap CONDUCTOR 16 15.062 0.0 110.0 110.0 62.58 H40 YVELDED BTCM HANGER T0 7' 5" MD IPEFF Jun 14 4~ D7:11p PDS Inc 907 2314 - - • ~ P21 Phi~iips ~tas~:a ir-c. Subsir~arv af A~antic Rid~eld Comuaav 7t~81 i~ G Tu~iirt~or Liner !J escn~og 1li!'~LL: t D 13~ DA`fE: 5/951OQ 9 £1F 1 #}AfiES # 17EtdtS CO~~TE DESCRiPT101~ OF EQli1PMEENT RUi! LENG~t ~PTFI idOi2DiC R!G #3 RT tct LDS 29.27 ~ Vetco-Gray Tbg. 3~an er W13.5° EL1E 8rd ~up 3.8~' ~ Hancer i.~' 4.80 29.27 34.0~ Pups 3.5" 9.3# L-BO EUE Srrt! Mod Pups &A& 8 6.1Q 12.iti 34,47 • Jt. #3-121 3.5' 9_3# L-86 EUE $rd Mod -b _ 37Q 1~iQ A~6.23 Pu~ 3.5" 9.3# l~~t1Q El1E 8rd Mod P=~p XO Butl mod X Eue Bcsx 14.6+3 ° 37~7_83 GL~d :3.,5" X 1" Can:co '1(BG•Z-9' wt DCK-3 Uump ~1! Valvc Bot'om L.a 6.F-.~ ' 3762.49 Pctp ~.5' 9_~ L-8~ EUE &ci Mad ~p XO Sutt moc! X Eue ~Pn i4.9 : 3~69.i8 T JL #2 3.5' ~.~ L-8Q Eue 8 rd Mod tbg_ 3f3.33 378~.36 3.S" Camco '~S" Land' ~ipple 2_813 r~o~4 pra~€te _~5 38f3.69 Jt. #-1 3_5" 9.3# C-SO EUE 8rd Mod tb . 31.3~3 387d.64 Pu 3_5" ~.3f1 L-8U EUE 8rd M+od Pup 6.0~~ 3845_0~ ~ocafor Baker iCBtt-22 ~acatcr SpotEed 1' op !:tf 3$52.07" SA Seal assemhE is 11.95 -Tap ot'4„5-40' SBE ~ 3$48' 3852.47 3852.47 PBR Baker'45-4~' Special c~earance PSiZ ~ '13.62 3852,47 Pup 3,5" 5.3~ L-80 EUE 8rd l+dod puss 10.1 ~J 3866.09 Anch~-r Baker 'K8H-?,~` Ar~c3~r assernbly ^ .66 38i8.19 3876.87 R(Gtlrst~ss: Stri~k,~ WCighis Wi1hs BIO~:kS: ~OK1t l3~-,Ob K# C3~~, 20K~ i3lOCk.r' F~an '130;o~Y~. ~f ts~birt a. - Ur~~ecs i~ba~g, c~Ms, t~ r~ger w~tn z.ast° plasuc rat~~t. usea t~r+c~~c c;raae ~ri n~qtyi~~ect roo ~eara thre~d compaarnd an atl connections. 7ubing is naii-cnated. Ntx'd~C Rig ~3 Drr3rir~g Supervisor.• M.G Heim y, Jun 14 d9 Q7:1ip PDS (nc~ Pn~fjips A~$srsa inG_ ~2~74 p.19 C/~+SfNC (JETt1tL 5-~f2" Ca~irttr tlescrip~ian iSRU 1G-939 DATE: 519d9/211dt3 1 dF 1 PAG~S ?€ f!"~AA3 COMRLETE DESGi21PT10N OF E(~IPMENI' R3''' _ _ - -- - l.ENGTH DEPT'N TGtt~S Landirt joint 6' abcve floQr ~ NORDiC RT TfJ U4t~WNG t2~+Ki 30.f~0 ~-4/Z" Gray Ca~ing hang~ wl pu~ 3_4J 30.50 Jt#A-94 5-112" 15,5#,1-80. LTGMod csg 3870.~6 3S.5tt ,~. #~ ~-uz x ov~~t ~-erz« ~rc-~,fld ~oY x arc ~~ ~s.7t~ ~a.a~ 5_5' Flaat Gcsilar 1~4 3943.ti6 jYs#1-2 5-ii2",15_5it, L-80lTG-ModCsg 85.16 394~4.50 _ ~~ 5.5" Ftoat Shoe . i~3 4029.66 __ 443T.Q9 Centraiizets 5-112" Run 5-tt2" X 7 718" Bawspr~ng GentraGzers 2~t far 5~7D' abov$ ~ Float cot~r. Stap rirg ~ middle ot jcdnt ietting csntrat~cer (loct between co ~r ' and stnp rirtg. 3oa~s 3 itw i 5. Place 1 Bovvs~ring every 3':ints . 18, 2t. 24. 27, 30, 33, 37. 40, 43, 47, 5~. 53. S7. 60, 63. 67, 70,'~3, 7G. 79, 82, $Sr 88, 9t Rer~a~tcs: ~#ma We~ahts wi#~ 8locks: ~tC# Un_ 5~ Dn_ 2t3[{~ Bloc:~. Rar- 9d ioH,ts ~,f 5.~i* casing. Drifi~ c~sin~. & i~ger with d.825' For 5.S" plast~ rabbit, lesed Arcfic Grade AF! AAOdi~c1 No Le~d lhre~d Carrys~und an aH coruiections. Tubing ;s ncx,-coa~ted. ` Norcf~o Ri~ #3 t7riN"ax,~ St+penrisor' ~C_ tiakt~ Jun 14 09 p7~11p PDS Inc ~ L.ti~lER D£TAIL Sinq,/e lniector ~'NtLUPS Aiaska, tnC. 947~14 ~.20 1NELL: tD-'t39 UA7E: 51~i 3J00 1 ~' 9 PACES # ITEMS CCIMPLETE O~SCi2tP'i'lC3N OF EQUIP`MEtdT RiI~T LENG i'H D~PTH - T'OPS -~2.5$ ~ ~. ~. _ ._._ _.,. _..__. ~ , - - ~ ~~~ - ~ _ " 2.58 -2.58 ~^ -2_5S 41 STC~.S, 2 7l8" ROH Qrili ~i~e=123 .1ts. 3874.;~8 2.58 R~nnir~ tool 2.7E. 3879 JO Packer Bake~ Iwodef "SRB-3" l~roduct~on packe~r ~rt d.51: 387d.4B Pup 31l2", ~.3Jt 1.-~, ?tt3-31 /210 rd gin X 3 4l2 FL4S Pin 5.8? 3879.02 ~`s 4- 30 ~ 3-112", &.3#, l-8p, FL45 L"mer _4t} 3.86~' iD 2.992° ~ 854.~5 3$SA.63 _ Bakec Type 'P Lansling cafler .9! ` 4739.06 ji ~i 3-i12", 9.3#. L-80, FL4.~'s Liner OD 3.86b" !~ 2.~J2" 37.&~ d739.~ 3-712° ~aker singte val+re Flaat eallar 9.'E!~ 47?1.59 jt's t&2 3-1J2". 9.3~, ~ 8~1, ~L4S Liner Ab 3.865' 1D 2~J2" 63.6i 4772_78 3-112" 8aker'Yvsct Shoe Special ctearance 1.B't 4836.39 -0R3ii.+1!1 Kerr'+~c5: b'tr~g vVetigCtts w+th tilOdcs: 1iUiVF Up, 4SK7~ Un, 2UtCt~ t3i4ck~,. Ran 3CI;~rts U~ tubing. Drifled lubing, with 2.867" pl~stic rabf~t. lJsed Fucf'~e Grac~e API hAnd~:d IVo LBacl ihread eo,wspourrd on atl eonnections. 7ubing is non-caated. Not~n: Rig ~!3 Oriltin~ Supert~i~r.- D~or~lc! t.. l+Vc+s3e~ - - - - -~__ , _ ~ . 'V/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 6 2007 ~ÐO -o~q Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water trom 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for 1H-Pad and December 28, 2006 for 1D-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cO~ Jerry Dethlefs ConocoPhillips Problem vVells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 1 93-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-401 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10' 9" 2.1 12" 12/16/2006 10.8 12/28/2006 1 0-11 0 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 10-120 197-221 13' 6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 10-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11'7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 D-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1D-140 200-136 29'9" 3.4 12" 12/16/2006 na na I ...... RECEIVED NO V 2 nØnZQ06 ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons C '. REPORT OF SUNDRY WELL OPERATIONS Anch' omm,ss,on . . STArE OF ALASKA oraoe 1. Qperations Performed: Abandon 0 RepaIrVVell . EI, Plug Perforations 0 Stimulate· 0 Other 0 Alter Casing D pullrubillg .. 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change.ApprovedProgram 0 0Perat. SlìutdownD Perforate 0 Re-enter Suspended Well 0 ... 2. Operator Name: 4. Currellt Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-049 1 .- 3. Address: Stratigraphic 0 Service D~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22958-00 .- ... . .. 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 10-139 , 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 4838' feet true vertical 4276' , feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet #REF! Casing Length Size MD TVD Burst Collapse Stru ctu ra I CONDUCTOR 110' 13-3/8" 110' 110' PRODUCTION 3930' 5-1/2" 4031' 3594' 5í ,';) \\ "'f .~ \/'J '\\ \'''''';> ~ LINER 964' 3-1/2" 4838' 4838' -h:...~ n,J "> ~\ ,-~~ Ie., S~~ \ 'Do~: a. .\. .-\ "-t: ~ 0 ~/l 111 D/. ~i-{) .- Perforation depth: Measured depth: 4114-4162, 4200-4246, 4258-4281, 4310-4318, 4329-4340, 4345-4355, 4362-4375, 4393-4440, 4480-4490' true vertical depth: 3653-3688, 3716-3753, 3763-3781, 3805-3812, 3822-3831, 3835-3844, 3850-3861, 3876-3918, 3953-3962' ?Dw, D í. f') 1 'I [ SCÁNNE9 L_\...' .:;J; ~'¡jü Tubing (size, grade, and measured depth) 3-1/2" , L-80, 3848' MD. Packers & SSSV (type & measured depth) Seal assembly 3848' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure TiJbinöPressure Prior to well operation . $ubsequentto operation . '. ...... . >14. 15,Wéll·plé!ss.aftétpróposedWork: Copies of Logs and Surveys ru.r\____ ExpIoratory>O .. D 0 . Development Service ... Daily. Report of WellOperatioOs_X 16.. \/\/ell$téltiJsafte¡r proposedwork: , IMr)SPLO .. ... .. ÒilD GasD WAG 0 GlNJD WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-224 Contact McConnell/Klein 659-7224 ... Printed Name Jerry Dethlefs Title Problem Well Supervisor Signature Phone 659-7224 Date 11/19/06 ~~O!-'M~ Drt. DEC 'i 4 2908 .0 l . Form 10"404 Revised 04/2004 OR I GI NAL );\;>1\4'"0(;, AÞ 12.. 17 " sU~i~1,9,'Y~Q;( , ¡... . 1 D-139 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 11/7/2006 Cut windows in Conductor, inspect Surface Casing. Remove 11 '9" of Conductor. T/I=OIO. Cut 24" x 14" windows at 3' & 9'. Removed 11'9" of conductor, chipped away cement and inspected SC. Found and marked some minor pittting for UT. Will need to make new conductor 11'2". Way forward with SC patch depends on UT results. Final T/I=OIO 11/15/2006 Patch weld on IA. T/I/= SI/O, Rigged up purge hoses and purged N2 out the hole in the IA. Welded two 6" wedding bands ( 51/2" x 15.5# L-80 ) on to the casing, (the top wedding band starts @ 9" from bottom of mandrel hanger). Seal welded 7' of 7" 26# .362 L-80 casing to wedding bands. Total patch lenth of 7' 5". 11/16/2006 MITIA - PASSED, (Post SC patch weld). T/I = SilO Installed VR plug in opposing IA. Pressured IA to 1800 psi with .5bbf diesel. T/I = SI/1800, started MITIA, 15 min. - T/I = S1/1800, 30 min - T/I = S1/1800, 45 min - T/I = S1/1800, 60 min - TII = S1/1800, Total loss of o psi. Bled fA. T/I = SI/O ", 11/18/2006 Installed new conductor. T/O = SilO, Assisted welders installing 11' 2" of 13 3/8" 68# .480 conductor. Wrapped top of conductor with cosmolien paper. /" ,¡ . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage. Alaska 99501 (907J 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 it): sf l'~~NEt ".;1 >.41. .. 1J 1 Report 10 - 136 MTT Report 2&Sep-06 U:r:c... 900 -o'-/b 2J 1 Report 1 0 - 137 MTT Report 26-Sep-06 U:I.C- d~ -ol.l-:¡' 3J 1 Report 1 0 - 138 MTT Report 26-Sep-06 U"J c- eoö - (f(o 2&Sep{Js0 aoo -~ 4J 1 Report 1 D - 139 MTT Report 5) ~ 6) RECEIVED 7) O,J0 SEP 2 9 2006 Signed: Date· . ~^ rì:')-t1 '^ Ç> rn,{)~ Ii\ t2 pJA ~ ÚII &, lias COliS. CUlllmI3SIO/) Print Name: Anchorage PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM D:\OO _ f'DSANC-2006\Z _ W ord\DislriblltionïrransnlÍflal_ Shccts\Translllil._ OriginaJ.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-139 Log Date: September 26, 2006 Field: Kuparuk Log No. : 8055 State: Alaska Run No.: 1 API No.: 50-029-22958-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 110 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-8D BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log Intvl.: 192 Ft. (MD) Pipe3 Desc.: 16" 62.58 lb. H-4D Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 192 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (70'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 192'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum of 16% circumferential metal loss is in the interval between 9' - 13'. A 15% circumferential metal loss is recorded in the interval between 3' - 5'. An 8% circumferential metal loss is recorded in the interval between 30' - 36' and 53' -58'. A 5% circumferential metal loss is recorded in the interval between 40' - 45'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5",5.5" and 13.375" pipe. If all ofthe metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey Analyst: M. Tahtouh & J. Burton Witness: J. Brake I 5651369 E-fI'rad: PDS(lÙrnefncrY!Og,J~ECEIVED 65~)'·2307 Fax: 659-2314 SEP 2 9 2006 u Ie-. 800- cYf1 Alaska 0/1 & Gas Cons. Commission Anchorage I I I I I I I I I I I I I <12 ~S. Magnetic Thickness Too g (10Hz Pass) PR<>AcrIvE DiAqNCl!i1lic SERvice¡;. INC. Database File: d\warrior\data\1 d-139\1 d-139, db Dataset Pathname: 10hzs.1 Presentation Format: 24SCAL -1 Dataset Creation: Thu Sep 2810:25:082006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 - -. -50 Delta Metal Thickness (%) 50 12.4 MTTP01 (rad) 12.4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3,6 ( I ~: ~ - Tree I "-.. T~ I Hanger 15% ,5" CollalPuP Ji. -- I S t-1 -rP" I Los s- ~-~--- Pup Jt t::16% M 3.5" Collar I I Loss I I I Pup Jt 3.5" Collar I 1 <- :: 20 - - ;::. ---- -- ~... ....- Line Speed f.--- __m - . . iíI\ 3.5" I--- ~ Joint 1 f-- _8% Metal ~ I ---- I Loss_ I ~ I _5% Metal 40 ~ -f-)- _Loss ---- -3.5" Collar I - f-8% Metal H - "- ---- - Loss - .-- ¡--- 60 --. - [I- I--- 3.5" --.......- .......- -- Joint 2 I I--- - Bottom of 16" Conductor- ~ It: Á. 3.5" Collar ~ ~ 1..."S'COlla 80 - e- -- .- -- { -- tl ~-- 1 1 <, " ~. .... ~ . ,£ " 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 .5" I.!~" nt3 u- .~ f-( ~_.. ~~ ~ 100 .... .- ~-' -. , -~ ~. \ - !~- "-. .~ . - -f--'~ ~. . ~'r-. ~- ~". .~ ~ I ~-+~~- "'- 3.5" Callar_ I -.~ "-+.- -.- ~ ~... - ,..-!--- -..- ~ -- ,~ '-.~ "-.~~. .~. ~.~ .~. '- _...~ .~_.- . ~"""'-5,5" Collar~~- ~~J~t~ f--~ ( , ~- I ~3.5" Collar -""-'- ~t-. -.,- ~~ -. -~. _.~~ -~ -.- '- ---~ ( \ . ~' M~ 3.5" Collar ( I I _I-- 5.5" Collar ~ -..- I .~ ( ._-~ ) f ~~__~£nd of Loa -50 Delta Metal Thickness (%) o Line Speed (ftlmìn) .~- 50 -200 3.5" JOint 4 140 3,5" Joint 5 160 - 180 3.5" JOint 6 '~m~~ ~ 1 f-~ I } 11 ¡..I I ,) 11 I---i .-- -. "- - ~ ~ ;p.,..~ ..~ ~ ... r ; .. ~ ii. :¡ ) ~ ..! -. < ,.. 120 ", ~~ - .. (- c--~ ¡ j "- I-- I-- -. I-- I-- .- I-- - -~ ,,~~ -I-- ~ C-'- -. f-- -- ~ tFt Þ' r : ~ I : ,- --c'- ~~ /---- ß.~ _ _~_ -~ '--- -- 4 .,~ j 5 ;; " "'\ i .. J 1--- - '",.. þ ...-- ;. - '¡,-~ -. þ ;. ~. -~ ~ ~- ? -- - ,-,,- , , , , '~'- ) , ~.. ~¡I Ji :=::,=d:?L.. MTTP01 (rad) MTTP12 (rad) -"-..- 2.4 --"----"" t--- .. ----- '-. -6.4 ~.. _ L._~_ 12.4 3.6 I I I I I I I I I I I I I I I I I I I cI? og (10Hz Pass) ·S. Magnetic Thickness To PROÁ.ciivE DiAqNCl51llc SERvice¡;, INC. Database File: d\warrior\data\ 1 d-139\anotation\ 1 d-139. db Dataset Pathname: 1 Ohzs. 1 Presentation Format: 24SCAL -1 Dataset Creation: Thu Sep 2810:25:082006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 160 -50 Delta Metal Thickness (%) 50 12.- MTTP01 (rad) 12.4 0 Line Speed (ftJmin) -200 -6.4 MTTP12 (rad) 3,6 - 1-- -,^--,^ Tree f--;;; I j Hanger ---' I I Pup Jt I ( .5" Collar e--15% Metal =~y, !-~ I 11_ Jf~- -~ - 1-=;;- Pup Ji. = f--. -..- f-- ~'". I~~'''~'' '" 3.5" Collar 16% Metal r , ¿'-I Los ,,~ I Pup Jt 3.5" Collar _"_m .-...- - .-.... -. - '--- -. --" I ~aKC ~ f-- ..~,*, ~!r. ~. -:; I"'" I ~ 20 , "..,¡ 'Š ;:" UH I þ.- "'" I r~ .::'$ F-- ;;. ;> ?- ~ I - :;::- ~ ~ ..,>- ;7" """'c "" .J! ÌI ¿ I~ i :I"" 50 :r~, \ ~ ~ "",. ~: , i' Line -...-! -~- . "- f'.- ';, . -- --.,~ ~. ....- :> - "'J 1*;,,. ~k. :" I ; , 3,5" « I .~ ~ ;: ~ ~ > I ~ ~=t ~ ¡'.... I", ? ? f JOjnt~_ I"", -50 Delta Metal Thickness (%) 50 2.4 MTTP01 (rad) 12,4 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 3.6 I I I I I I I I I I I I I I I I I I I - .r=) ~S. PROAcrivE DiAqN051'ic SERvices, INC. Magnetic Thickness Too og (10Hz Pass) Database File: Dataset Pathname: Presentation Format: Dataset Creation: Charted by: d \warrior\data \ 1 d-139\bottom anotation\ 1 d-139. db 10hzs.1 24SCAL -1 Thu Sep 2810:25:082006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 160 -50 Delta Metal Thickness (%) 50 !2.4 MTTP01 (rad) 0 Line Speed (ft/min) -200 -6.4 MTTP12 (rad) 1 I 1'\ '-~dfW-fm L~ Line Speed t' 3,5" <;¡ ~ ~ ' ._-.. - - - 1--- J.-.- c;: 1< Þ. ~ .,. Joint 1 II .; ~ ~ <¡ I-{ I .k j .; 8% Metal I Loss '"( --=;... - -I~I ~ -- -~ ~-- - I ~;,. ''0 - ^-----^ -- '-- ---- ¡,.~r~ 1.:1==. 40 ,. _5% Metal _~m ~ - Loss ,~-.- - ¡.-- ~.- I "- -- :>.¡; -1-:3.5" Collar J I I -'~ð: I I I I I I I 'B I 8% Metall.......¡.4 LosS'-f- ,-- f-- - ¡ ..,; ì ... . I ¡.... f-._. ,,- "-- ,,-- I~;- 60 ':i r-- ~ 5:' - - -'^- - _.~-- -- --. f--.- ._._ !t '" I -50 Delta Metal Thickness (%) 50 o Line Speed (ft/min) -200 " ^----.-- ¡~7 '.. 2.4 -6.4 MTTP01 (rad) MTTP12 (rad) f I., .- ~ -. "- ~ : j .í- i..=¡¡ - j ~-Io ; ~ f-- :;,. 1m1 ¡. " -( jt: '" < ~ :y,. ( " ",' 1 ¿;cs: ( .- , It'-:~ 12.4 3.6 12.4 3.6 F1 ~ ¡, ~. I III KRU 1D-139 I 11D439 API: 500292295800 Well Type: INJ Anqle IiiJ TS: deqliiJ TUBING SSSV Type: NONE Orlq Completion: 5/1512000 Angle @ TD: 25 de¡¡ IiiJ 4838 (0-3848, Annular Fluid: LastW/O: Rey Reason: Set WRP 00:3.500, Reference Lo¡¡: Ref l,o¡¡ Date: Last Update: 7/1912006 10:2992) Last T ªg: 4738 TD: 4838 ftK8 ~ Ie: Size TOD Bottom TVD Wt Grade Thread 'ROOUCllON CONDUCTOR 16,000 0 110 110 62.58 H-40 WELDED (0-4031, PRODUCTION 5.500 0 4031 3594 15.50 L-80 BTCM 00:5.500, LINER 3.500 3874 .~838 4838 9,30 L-80 _EUE 8RD Wt15.50) TubinQStrinQ..ALI. Gas Lift Size I TOD Bottom I TVD Wt Grade Thread I ndtelfOummy 3,500 0 3848 I ;;466 9,30 I L-80 !::UE!jHD Valve 1 (3758-3759, 00:4.725) Interval TVD Zona Status Ft SPF Date TVDa Comment 4114-4162 3653 - 3688 WSD 48 4 6/3012000 IPERF 60 DEG PH 2,5" HSD DP 4200 .. 4246 3716 - 3753 WSB 46 4 613012000 IPERF 60 DEG PH 2.5" HSD DP 4258 - 4281 3763 - 3781 WSM 23 4 6/3012000 IPERF 60 DEG PH 2,5" HSD DP 4310 - 4318 3805 - 3812 WSA3 8 4 6/3012000 IPERF 60 DEG PH 2.5" HSD DP 4329 - 4340 3822 - 3831 WSA3 11 4 6/3012000 IPERF 60 DEG PH 2.5" HSD DP 4345 - 4355 3835 - 3844 WSA3 10 4 6/2912000 IPERF 60 DEG PH 2,5" HSD DP 4362 - 4375 3850 - 3861 WSA3 13 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 4393 - 4440 3876 - 3918 WSA2 47 4 6/2912000 IPERF 60 DEG PH 2.5" HSD DP NIP ~-~~ 10 4 IPERF 60 DEG PH L,b H:S/J DP (3809-3810, 00:3.500) S frl Man Type I V Mfr I V Type I V 00 I latch I Port I mo I Date I VI" Run Cmnt ~ ~J .QMY I 1.0 IN' 0.000 I 0 6/1312000 I . c...: 3809 3438 NIP a DescriDtÎon 10 CAMCO DS NIPPLE 2.813 3848 3466 SEAL BAKER GBH-22 SEAL ASSY 3,000 4185 3705 PLUG WEATHERFORD 3.5" WRP SET @ MID-ELEMENT TO ISOLATE WEST SAK 0.000 A-SANDS & B-SANDS FROM D-SANDS 7/1812006 SEAL (3848-3849, OD:4000) '--. --. '- _. LINER (3874-4838, 00:3.500, Wt9.30) Perf -- I---- (4200-4246) "- 1--- Perf --- - (4258-4281) '- '-. -. _. Perf -.- -- (4310-4318) ._-. -. --- --. ~--- -- Perf _. --- (4329-4340) -- _m.. -- -- Perf --,- - (4345-4355) '-- - Perf -- ¡---.-. (4362-4375) -- f---- -- ¡---- - C'----- Perf -- --- (4393-4440) - --- Perf -- -- (4480-4490) -.. .-- - --- I I I I I I I I I I I I I I I I I MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ P.I. Supervisor !(J:?i'c; : '!~·r / ::-!ùeo DATE: Monday, July 31,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 10-13 9 KUPARUK RIV U WSAK 10-139 'dJJO' O~ FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: '~~~~ P.I. Suprv.. ...-'I Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-139 API Well Number 50-029-22958-00-00 Insp Num: miúCr060731102340 Permit Number: 200-049-0 Rei Insp Num Inspector Name: John Crisp Inspection Date: 7/29/2006 Packer Depth Pretest Initia I 15 Min. 30 Min. 45 Min. 60 Min. Well 1D-139 ¡Type Inj. I N ITVD 3466 I IA 0 1620 1590 1580 I --+-. 2000490 TypeTest I SPT I Test psi OA ~-...--:-- P.T. 1500 ~ , --+ Tubing ~-~~~-- Interval 4YRTST P/F P 300 250 250 250 .--L .L--__ Notes 1.2 bbl's pumped for test Monobore, no OA G (} j Monday, July 31, 2006 Page 1 of 1 - ~ ~=-=-"'J ~~..-=-=. ~ FRANK H. MURKOWSKI, GOVERNOR A."~A.SIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~ _::.;.J :..-: _-_-~ J en}' Dethlefs Problem Well Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 ~ÇA~NED '.JUN 2 9 2005 Re: Kuparuk River Field, West Sak Oil Pool 10-139 Sundry Number: 306-224 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ DATED this 'J,1d.ay of June, 2006 Encl. ';)t:D-d{~ -- '- y ConocoPhillips Alaska ._~ ·-Vi=- ~.~.- '.F l~.·· t: l' 4'\ KC.Vb~ .... _k#' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 JUf\\ _2 1 2006 ~~laska Œi & Gas Conso Gommission Anchorage June 19, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 1D-136 (PTD 2000460), ID-137 (PTD 2000470) and ID-139 (PTD 2000490). The approval requests regard potential repairs for surface casing corrosion. Please call MJ Loveland or me at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. Sincerely, ~--/c ~i:r Jerry Dethlefs Problem Well Supervisor Attachments IV 15 r Jt-r Ut '/¡ii( I.I~ b"1c. v¡ %- STATE OF ALASKA .-- ALASKA OIL AND GAS CONSERVATION COMMISSION £ ~l::l"I::IVt:U kfG¡ d~ JUN 2 1 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. CDfMlission Anchorage 1. Type of Request: Abandon Alter casing D D D 20 AAC 25.280 Suspend D Operational Shutdown D Repair well 0' Plug Perforations D Pull Tubing 0 Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic 0 Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 101' 8. Property Designation: Kuparuk River Unit Perforate 0 Waiver 0 Stimulate 0 Time Extension D Re-enter Suspended Well D Other D 5. Permit to Drill Number: 200-049 ' 6. API Number: 50-029-22958-00 9. Well Name and Number: 1 D-139 , Exploratory 0 Service 0. 10. Field/Pool(s): It Þ<... z. ~(..>O )b fø-1./·()1ø Kuparuk River Field / West Sak Oil Pool . PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 4838' 4276' . Casing Length Size CONDUCTOR 110' 16" PRODUCTION 3930' 5-1/2" LINER 964' 3-1/2" MD TVD Burst Collapse 110' 110 4031' 3594 4838' 4838 Perforation Depth MD (ft): 4114-4162, 4200-4246, 4258-4281, 431 0- 4318, 4329-4340, 4345~4355, 4362-4375, 4393-4440,4480-4490' Packers and SSSV Type: Seal assembly no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 14. Estimated Date for July 2006 Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name '" 'Dethlefs ~ _;, . Signature '7'''' I ~ ~ C, I ~~ ~mmisSion Use Only Packers and SSSV MD (ft) 3848' no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Perforation Depth TVD (ft): 3653-3688,3716-3753,3763-3781,3805-3812, 3822-3831, 3835-3844, 3850-3861, 3876-3918, 3953-3962' Date: Conditions of approval: Notify Commission so that a representative may witness Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 3848' Service 0 . Plugged 0 WINJ 0 . Abandoned 0 WDSPL 0 Contact: Title: McConnell/Klein 659-7224 Problem Well Supervisor Date ~//9A~ Phone 659-7043 Sundry Number: l~(o ..~.£f Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: <:.o~C\--¡:~~~-\m-~\'C\>I(C'~~~ \J\~~~'i ~\~ ~~~1è, { pw:> \-0 ~o L-'::' ~"'-- ~~ ~ ð-'&- 0.. C'-.'-\ ~ t: Date: ~ .. z, ';-~b ~ð ~..¿f.~ Subl]Jj in Duplicate ~ ~/k/AL' Approved by: APPROVED BY COMMISSIONER THE COMMISSION o RIG I N A L RBDMS BFL JUN 2 8 2006 "'-" ConocoPhillips Alaska, Inc. West Sak WelllD-139 (PTD 2000490) SUNDRY NOTICE 10-403 APPROVAL REQUEST 06/18/06 This application for Sundry approval for West Sak injection well1D-139 is for the proactive ." inspection and possible repair of the production casing. The well is to be excavated for an inspection of the near surface casing for damage due to corrosion observed on other similar wells in the West Sak field. The results of this inspection will help determine if similar actions should be performed on additional wells in the project area. The well is a 5-1/2" x 3-1/2" tapered casing completion that is designated as a water only injector, completed in May of2000. The well has a single casing string that is suspected of being subjected to accelerated corrosion processes. Mechanical Integrity Tests (MIT) have successfully passed on the casing and there are no known casing problems. However, the construction of this well is similar to those that have failed and a preventative inspection is warranted. With approval, inspection and repair of the casing will require the following general steps: 1. Notify AOGCC Field Inspector of inspection/repair plans for witnessing. 2. Safe-out the well with plugs and load the tubing and IA with water and diesel freeze protection cap. 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA and conductor so that hot work may be conducted in a safe manner. 5. Excavate around wellhead and install construction shoring box. 6. Cut away the conductor casing and remove cement from around casing for inspection. Approximately the top 5-10 feet of conductor will be removed to provide access to the casIng. 7. CP AI Mechanical Engineers will determine the appropriate patch and/or repairs to return the casing to operational integrity should damage be found. 8. QA/QC the repair and MIT -IA for a final integrity check (if repair was performed). 9. Install anti-corrosion coating to casing. 10. Replace the conductor and fill the void with material designed to seal out water and oxygen. 11. Backfill as needed with gravel around the wellhead. 12. Remove plugs and return the well to injection service. 13. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 6/18/2006 c~_ .:.:.:.:~.:.:.:.:.. .:::: "'~:~:::::::'~'::::::::" : t.¡¡¡¡.:·~ :(:(~i~¡~¡;¡~j;¡i¡¡¡!¡:. ConocoPhillips A 1..3.. :8. ... k8.,. ..:..1.:"... ...:C. .. +. . . "'-. '. 1D--139d :::.....:... API: 500292295800 SSSV Type: NONE TUBING (0-3848, 00:3.500, 10:2.992) "ROOUCTlON (0-4031, 00:5.500, Wt:15.50) NIP (3809-3810, 00:3.500) SEAL (3848-3849, 00:4.000) LINER (3874-4838, 00:3.500, Wt:9.30) PACKER (4191-4221, 00:3.500) Perf (4200-4246) PATCH (4221-4250, 00:3.000) I¡IJI¡¡¡¡@I¡¡]J¡¡ . ~ ~;~~l;l ~~~ ~~ ~~ ~~~;¡ i~ ~~;~ ;f~~ ~~~~~~ ~ . t ¡ PACKER (4250-4251, I 00:3.500) Perf j ~ (4258-4281 ) . Perf (4310-4318) Perf :1 , (4329-4340) :i Perf i (4345-4355) ~ Perf ~ (4362-4375) Perf , ( 4393-4440) Perf (4480-4490) ~ r-- Well Type: INJ Orig 5/15/2000 Completion: LastW/O: Ref Log Date: TD: 4838 ftKB Max Hole Angle: 47 deg @ 3091 CAMCO DS NIPPLE BAKER GBH-22 SEAL ASSY 3" ECLIPSE PACKER ASSEMBLY w/SPACER PIPE STUNG INTO TOP OF PATCH (OAL 30'9") set 4/17/2005 ECLIPSE PATCH (OAL29'4") set 4/17/2005 ECLIPSE PACKER set 4/1112005 Annular Fluid: Reference Log: Last Tag: 4738 Last Tag Date: 3/612005 Casing String-ALL··· Description CONDUCTOR PRODUCTION LINER Tubing String - ALL Size I Top 3.500 0 Perforations Summary Interval TVD 4114-4162 3653-3688 4200 - 4246 3716 - 3753 4258 - 4281 3763 - 3781 4310 - 4318 3805 - 3812 4329 - 4340 3822 - 3831 4345 - 4355 3835 - 3844 4362 - 4375 3850 - 3861 4393 - 4440 3876 - 3918 4480 - 4490 3953 - 3962 Gas Lift MandrelsNaIVE1$·· St MD TVD Man Man Type V Mfr Mfr 1 3758 3403 CAMCO KBG29 CAMCO Other. (pIUgs,eql.lÌl:L,. etc.) :"JEWBLRY Depth TVD Type 3809 3438 NIP 3848 3466 SEAL 4191 3710 PACKER Size 16.000 5.500 3.500 Zone WSD WSB WSA4 WSA3 WSA3 WSA3 WSA3 WSA2 WSA2 Status 4221 4250 3733 3757 PATCH PACKER ---- KRU 1 D-139 Angle @ TS: deg @ Angle @ TD: 25 deg @ 4838 Rev Reason: Set PATCH Last Update: 4/18/2005 Top o o 3874 Bottom TVD Wt Grade Thread 110 110 62.58 H-40 WELDED 4031 3594 15.50 L-80 BTCM 4838 4838 9.30 L-80 EUE8RD Grade Thread L-80 EUE8RD Ft SPF Date Type Comment 48 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 46 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 23 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 8 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 11 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 10 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 13 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 47 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 10 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP V Type DMY VOD latch Port TRO 1.0 INT 0.000 0 Description ID 2.813 3.000 1.812 Date Run 6/13/2000 Vlv Cmnt 1.750 1.812 L~ vvu. '-'UIIV""V~ 11111J.p~ .L.J^""U..U....lvJ..I """" 1.~"'P"·1..l .I. .I.'-'J""''''''''J ~-' -' Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 To: Lou Grimaldi <lou_grima1di@admin.state.ak.us>~ John Spaulding <john_spaulding@admin.state.ak.us>, John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones <jeffjones@admin.state.ak.us>, Chuck Scheve <chuc~scheve@admin.state.ak.us>, Jim Regg <jim -1egg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us NEÙ¿-weïT·...·integrl ty proj <N18 78@conocophillips. com> , aogcc prudhoe bay@adnlin.state.ak.us \\)-\~ \ J"C)\)~Ù'-\\ Subject: Date: From: To: CC: Tom: I don't remember how much of our plans we have shared with you on excavating and repairing wells at lC & ID pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to IIpro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know_ The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «IC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 1 C and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword 10f2 6/26/2006 7: 51 AM ). j: PRIORITY 1 2 3 4 5 6 7 8 9 10 11 ----'"l 12 ---=, 13 14 15 16 'd{JO-Q'-\ ~ ) ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates NAME 1 C-121 1 C-131 10-109 1 0-111 I 10-120 I. . '.. 'n......,...... : , 1[)~1'21 l. .._. .:., .......,..._...... .:......._~~.::...~.-'....... ..., ............. 1 ' .' :' " ", , tÐ~,t27 .. ..._.._..._...._.~....""--'----.-.~~_..._. ....,,-,--- 1 0-132 1 0-136 1 0-137 1 0-138 10-139 1 C-119 , In___~ ,..' ·"1:Ç=13~-· : .. .: 1 1..__·........-·..·, .".~.-'C..:.~~. ---.--.. ·······....····'-l· , . ..1 D-135 , .1 . ,·_~........·..·..·..·,..·~-_..·..".._·.,,.,.....--~···_·..··Î 1D..141 I TYPE INJ INJ INJ INJ INJ Gas Lift Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump ESP Gas Lift PTD# LEAK DEPTH (ft) - - -.._--- 201-080 4 -- --...'''.- 201-185 7 . ---..----..-.--.-- 197 -235 5* 198-166 5* --.. -.. --'-'. 197-221 7 197-181 None 198-109 None 198-121 5 200-046 None 200-047 None 200-048 8 200-049 None 201-139 16 201-220 None 197 -184 None 200-112 None COMMENTS I STATUS Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: \LaserFiche\CvrPgs _ Inserts\Microfilm_ Marker .doc Permit to Drill 2000490 DATA SUBMITTAL COMPLIANCE REPORT 9~6~2002 Well Name/No. KUPARUK RIV U WSAK 1D-139 Operator PHILLIPS ALASKA INC. MD 4838 'l-VD 4276 Completion Dat 6/29/2000-~'' Completion Statu 1WINJ Current Status IWINJ APl No. 50-029-22958-00-00 REQUIRED INFORMATION Mud Log No Sample No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital ype Media.._~ Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 9828 FINAL LIS Verification FINAL 2~ H ~,~ Temp/Press/Spin 5 FINAL Slim Cement Mapping 5 Tool SRVY RPT DGR/EWR-MD ' 2/5 FINAL DGR/EWR-'I-VD 2/5 FINAL MWD Formation Eval comp MWD LIS 72 4765 Case 2/22/2001 09828 72-4765 2/22/2001 9828 LIS Verification Digital Data 2/22/2001 LIS Verification Paper Copy 4060 4550 CH 1/2/2001 4060-4550 BL, Sepia 3637 4730 CH 1/4/2001 3637-4730 Color Print 0 4838 OH 5/18/2000 SPERRY 0-4838 110 4838 OH 10/12/2000 110-4838 5/8/00 THRUUIC 100 4275 OH 10/12/2000 100-4275 5/8/00 THRUUIC 72 4765 1/9/2001 72-4765 Digital Data 1/9/2001 Verification Listing Well Cores/Samples Information: Name Interval Start Stop Sent Dataset Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Analysis Daily History Received? ~' N Formation Tops ~)/N Comments: Permit to Drill 2000490 MD 4838 TVD DATA SUBMITTAL COMPLIANCE REPORT 9/612002 Well Name/No. KUPARUK RIV U WSAK 1D-139 Operator PHILLIPS ALASKA INC. 4276 Completion Dat 6/29/2000 Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22958-00-00 UIC Y Compliance Reviewed By: Date: Schh berger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1617 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 11/13/01 Well Job # Log Description Date BL Sepia CD Color :1A-13 / ~/--! ~' INJECTION PROFILE 10/15/01 I 1 1D-136 ~O~)-'~)qt~. INJECTION PROFILE 10/18/01 1 1 1D-139 :~O-~:::)L/~ PRESS/TEMP SURVEY 10/19/01 1 1 1F-10 / ~_/~:::) ~ INJECTION PROFILE 10/20/01 1 1 1H-07 / ~ -(::) ~,~ INJECTION PROFILE 10/24/01 1 1 1Q-13 !~.~-O~/~/ INJECTION PROFILE 10/20/01 I 1 2M-17 / ~/- O!~ INJECTION PROFILE 10/14/01 I 1 2N-321A /C/~_ ! "/:~ INJECTION PROFILE 10/26/01 I 1 '2X-17 / C/~_/.-~ ~ PRODUCTION PROFILE 10/25/01 1 1 :3C-04 / ~_/C~O PRODUCTION PROFILE 10/23/01 1 1 !3M-03 /~ 7~O/~/ PRODUCTION PROFILE 10/22/01 1 I RECEIVED DATE: I~C~, .. / nnn, I~uv I u[.U UI Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thar~l~l.0ii & Gas Cons. Commission An~orage WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 November 9, 2000 RE' MWD Formation Evaluation Logs 1D-139, AK-MM-00041 1 LDWG formatted Disc with verification listing. API//: 50-029-22958-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: Jqloi i ~ Schh berg r NO. 729 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Bird, 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 31-08 PRODUCTION PROFILE 001118 I 1 3K-25 INJECTION PROFILE 001117 I 1 1 D-136 INJECTION PROFILE 001119 I 1 1 D-137 INJECTION PROFILE 001119 I 1 1D-138 INJECTION PROFILE 001120 I 1 1 D-139 INJECTION PROFILE 001120 I I 11/28/00 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 11130100 Schlumberger NO. 746 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 ,, , 1D-136 20282 SCMT 000623 1 1D-139 20283 SCMT 000623 1 , , , , , , , ............... ..... .......... .................. ............. DATE= / 4h)/ -,-. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ORILLINB ~; I~ R ~./I C E ~=~ To: State of Alaska October 12, 2000 Attn.: Loft Taylor Anchorage, Alaska 99501 MWD-Fonnafion EvalUation-Log~-.. t.D4~:. AK-MM-00.041 The technical data listed below is being submitted herewith. Please address any problems or concems t.'tlma..~ion of.' L~,139: 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-2-2958-0~- · F~ueline Sepia Blueline D OCT 12 2000 Oil,& Ilas O~ns. Commission ~m0hora~ 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,.'SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ~] Gas [--1 Suspended F1 Abandoned FI Service J~J Water injector 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. '~~----,~ 200-049 3. Address~'"~;~' ~"~'"~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 5O-O29-22958-OO 4. Location of well at surface ~ ............. ,.,~ ,~.~ ......... ,~,~ ; ~-' 9. Unit or Lease Name 661' FNL, 602' FEL, Sec. 23, Tll N, R10E, UM (ASP: 560491,5959004)~__ ~--',L, __;~-'~';';: j Kuparuk River Unit At Top Producing Interval 10. Well Number 1930' FNL, 57' FWL, Sec. 24, T11 N, R10E, UM (ASP: 561160, 5957742) ;~ ~;~' ~;:~,,.~ ~ 1D-139 At Total Depth 11. Field ~nd Pool 2149' FNL, 156' FWL, Sec. 24, T11 N, R10E, UM (ASP: 561261, 5957524) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) [6. Lease Designation and Serial No. West Sak Oil Pool 30' RKB feet~ ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if o~hore 16. No. of Completions May 8, 2000 May 13, 2000~~0 ¢''~`t'~] ~A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey ~20. Depth where SSSV set 21. Thickness of Permafrost 4838' MD/4276'TVD 4739' MD/4186' TVD YES ~ No ~~ N/A feetMD 1634' 22. Type Electric or Other Logs Run GWPWD, GWReCNeu Dens 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE WT. PER ~. GRADE TOP BOSOM HOLE SIZE CEMENTING RECORD~ AMOUNT PULLED 13.375" 68¢ L-80 Sudace 110' 20" 7cu yds High Ear~ 5.5" x 15.5~ L-80 Su~ace 4031' 7.875" 380 sx AS III, 200 sx Class G 3.5" 9.3¢ L-80 3875' 4838' 4.75" 50 sx LiteCR~E 24. Perforations open to Production (MD + TVD of Top and BoSom and 125. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4480'-4490' MD 3953'-3962' TVD 4 spf 3.5" 3877' 3874' 4393'-4440' MD 3876'-3918' TVD 4 spf 4362'-4375' MD 3850'-3861' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4345'-4355' MD 3835'-3844' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4329'-4340' MD 3822'-3831' TVD 4 spf N/A 4310'-4318' MD 3805'-3812' TVD 4 spf 4114'-4162' MD & 4258'-4281' MD 3763'-3781' TVD 4 spf 3653'-3688' TVD & 4200'-4246' MD 3716'-3753' TVD 4 spf 4 spf 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas liE, etc.) Injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE [GAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fracture, apparent dips and pressence of oil, gas or water. Submit core chips. WA Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak D Base West Sak D West Sak Base GEOLOGIC MARKERS MEAS. DEPTH 4110' 4166' 4634' TRUE VERT. DEPTH 3649' 3690' 4091' 30. FO RMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 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. Signed ~~ Title Randy Thomas Kuparuk Drilling Team Leader Questions? Call Mark Chambers 265-1319 Date 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 pedinent 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: 08/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-139 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:05/08/00 START COMP: --_ RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22958-00 05/07/00 (D1) MW: 9.4 VISC: 250 PV/YP: 61/72 APIWL: 5.8 TD/TVD: 110/110 (110) CONTINUE REPAIRING AUGER. R/U SCHLUMBERGER, TAG UP 011 SUPV:DON WESTER & BRIAN NOEL Move rig from 1D-136 to 1D-139. Accept rig 0 1430 hrs. N/U diverter system and function test, OK. Make up BHA. 05/08/00 (D2) MW: 9.3 VISC: 237 PV/YP: 53/48 APIWL: 5.0 TD/TVD: 1195/1193 (1085) DRILL F/ 571' TO 1691' @ 0600 HRS. NOTE! RUNNING ON SUPV:DON WESTER & BRIAN NOEL Pre-spud meeting. Tag bottom 0 110' Spud 7-7/8" hole drilling from 110' to 295' Schlumberger run gyro. Drilling from 295' to 1195' 05/09/00 (D3) MW: 9.4 VISC: 255 PV/YP: 62/71 TD/TVD: 3040/2906 (1845) DRLG. ~ 3500' MD. SUPV:M.C. HEIM Drilling and surveys from 1195' to 3040' APIWL: 4.0 05/10/00 (D4) MW: 9.4 VISC: 280 PV/YP: 60/63 APIWL: 3.8 TD/TVD: 4041/3600 (1001) RIGGING UP TO RUN 5.5" CSG. SUPV:M.C. HEIM Drilling and surveys from 3040' to 4041' Pump sweep and circ bottoms up. Drop survey, POH to HWDP @ 821' Tight spot ~ 900'. RIH, work thru tight spot @ 900', tag bottom, no fill. Circ-cond hole for casing. 05/11/00 (D5) TD/TVD: 4041/3600 ( SUPV:M.C. HEIM MW: 9.3 VISC: 55 PV/YP: 23/15 0) TESTING CHOKE MANIFOLD APIWL: 5.0 Circ. condition mud for 5.5" casing. Wash and ream tight hole ~ 200'. Retrieve survey. PJSM. Run 5.5" casing. Safety meeting. Finish running 5.5" casing. Circ. condition mud & hole for cementing. PJSM. Pump cement. Bump plug. Check floats. 05/12/00 (D6) MW: 10.5 VISC: 57 PV/YP: 31/32 TD/TVD: 4041/3600 ( 0) DRLG. ~ 4070' SUPV:M.C. HEIM N/D diverter system. Test BOPE to 250/3000#. APIWL: 4.5 05/13/00 (D7) MW: 10.5 VISC: 52 PV/YP: 29/22 APIWL: 4.0 TD/TVD: 4838/4231 ( 797) RIG UP TO RUN 3 1/2" LINER. Tag @ 3939', drill plug, float collar, circ out wet cement Date: 08/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 to 4024'. Pump spacer pill, displace w/lsnd mud & survey. Drill float shoe and rathole to 4041' and new hole to 4061'. Circ condition hole, Run LOT @ 16#. Drilling from 4061' to 4127'. Drilling from 4127' to 4838' Checking well for hi pressures in each sand. CBU f/wiper trip. Check for flow, wiper trip to shoe 8 4031' and back to bottom, no problems. POH. 05/14/00 (D8) TD/TVD: 4838/4231 ( SUPV:M.C. HEIM MW: 8.3 VISC: 0 PV/YP: 0/ 0 0) SPACING OUT COMPLETION. APIWL: 0.0 POH. Run 3.5" liner. Circ condition hole & mud for cementing. Pump cement. Set packer. Displace well to water. Hold abandon rig drill. 05/15/00 (D9) TD/TVD: 4838/4231 ( SUPV:M.C. HEIM MW: 0.0 VISC: 0) ON NEW WELL 0 PV/YP: 0/ 0 APIWL: 0.0 Rig up to run 3.5" completion. Run 3.5" tubing and completion jewelry. ND BOPE, NU tree and test to 250/5000#. Freeze protect well. Set BPV. Secure cellar for rig move. Release rig ~ 1730 hrs. 5/15/00 PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-139(W4-6)) WELL 1D-139 JOB SCOPE DRILLING SUPPORT-CAPITAL JOB NUMBER 0602001838.5 DATE DALLY WORK UNIT NUMBER 06/29/00 PERFORATE 2145 KEY PERSON SWS-SPENCER DAY OPERATION COMPLETE I SUCCESSFUL 5 NO I NO InitialTbgPress [FinalTbgPress IlnitiallnnerAnn 75 PSI 30 PSI 0 PSI DAILY SUMMARY I PERFORATED SUPERVISOR KENNEDY Final lnner Ann IlnitialOuterAnn I Final Outer Ann 0 PSI 0 PSI 0 PSI (4480'-4490', 4393'-4440', 4362'- 4375', 4345'-4355') W/2 1/2" HSD UJ DP, 4 SPF, 60 DEGREE PHASING.[Perf] TIME LOG ENTRY 07:15 MIRU SWS 08:30 HOLD SAFETY MEETING BEFORE ARMING 1ST GUN 09:00 PFF LUBRICATOR TO 3K PSI 10:15 LOG TIE IN PASS ACROSS PERF INTERVALS UP ACROSS JEWELRY 10:40 LOG GUN #1 SHOOT PASS - GOOD INDICATION OF DETONATIONINTERVAL SHOT = 4480 - 4490 FT MD 11:15 GUN #1 AT SURFACE - CONFIRMED ALL SHOTS FIRED 11:30 RIH WITH GUN #2 12:05 LOG UP INTO SHOOT POSITION: NO SURFACE INDICATION OF DETONATION. 12:20 AFTER CHANGING OUT SURFACE SHOOTING ELECTRONICS, LOGED BACK INTO POSITION TO SHOOT GUN #2 - AGAIN, NO SURFACE INDICATION OF DETONATION. 12:50 GUN #2 AT SURFACE, CONFIRMED SHOTS DID NOT FIRE 13:10 TROUBLESHOOTING AT SURFACE INDICATES A BAD DETONATOR 13:30 GUN #2 IS REARMED AND RIH 14:30 LOG INTO POSITION AND SHOOT GUN #2 - POSITIVE SURFACE INDICATION 15:00 AT SURFACE, VISUAL CONFIRMATION ALL SHOTS FIRED 15:45 GUN #3 ARMED - BEGIN RIH 16:20 LOG UP INTO POSITION TO SHOOT GUN #3 - GOOD SURFACE INDICATION OF SHOT 16:50 AT SURFACE, VISU CONFIRMATION ALL SHOTS FIRED 17:00 GUN #4 ARMED - BEGIN RIH 17:30 LOG UP INTO POSITION TO SHOOT GUN #4 - GOOD SURFACE INDICATION OF SHOT 18:00 GUN #4 AT SURFACE - VISUAL CONFIRMATION ALL SHOTS FIRED 18:15 GUN #5 ARMED - BEGIN RIH 18:55 LOG UP INTO POSITION TO SHOOT GUN #5 - GOOD SURFACE INDICATION 19:20 AT SURFACE - CONFIRMED ALL SHOTS FIRED 20:30 SWS COMPLETED RIG DOWN - LEFT PAD PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-139(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-139 DRILLING SUPPORT-CAPITAL 0602001838.5 DATE DAILY WORK UNIT NUMBER 06/30/00 PERFORATE 2145 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 YES YES SWS-SPENCER KENNEDY Initial Tbg Press I Final Tbg Press1250 PSI 250 PSI Initial Inner Ann 0 PSI Final Inner Ann I 0 PSI I Initial Outer Ann I 0 PSI Final Outer Ann 0 PSI DALLY SUMMARY PERFORATED (4329'-4340', 4310'-4318', 4258'-4281', 4200'-4246', 4114'-4162') W/2 -1/2" HSD UJ DP, 4 SPF, 60 DEGREE PHASING.[Perf] TIME LOG ENTRY 07:30 MIRU SWS 08:00 SAFETY MEETING - ARM GUN #6 08:10 PT WELL TO 3 K - RIH 08:40 09:10 LOG UP INTO POSITION TO SHOOT GUN #6 ( 1ST OF THIS DAY) - GOOD INDICATION OF DETONATION AT SURFACE - CONFIRM ALL SHOTS FIRED 09:20 GUN #7 ARMED - RIH 10:00 LOG UP INTO POSITION - TO SHOOT GUN #7 - GOOD SURFACE INDICATION OF DETONATION 10:30 AT SURFACE - CONFORM ALL SHOTS FIRED 10:45 GUN #8 ARMED - RIH 11:20 LOG INTO POSITION AND SHOOT GUN #8 - GOOD INDICATION OF DETONATION 11:45 AT SURFACE - CONFIRMED ALL SHOTS FIRED 12:00 GUN #9 ARMED - RIH 12:35 LOG UP INTO POSITION TO SHOOT GUN #9 13:05 AT SURFACE - CONFIRMED ALL SHOTS FIRED 13:15 GUN #10 ARMED - RIH 13:40 LOG UP INTO POSITION TO SHOOT GUN #10 - GOOD DETONATION INDICATION 14:10 AT SURFACE - CONFIRMED ALL SHOTS FIRED 14:20 GUN #11 ARMED - RIH 14:45 LOG UP INTO POSITION TO SHOOT GUN #11 - GOOD INDICATION OF DETONATION 15:15 AT SURFACE - CONFIRMED ALL SHOTS FIRED 15:25 GUN #12 ARMED - RIH 15:50 LOG UP INTO POSITION TO SHOOT GUN #12 - GOOD INDICATION OF DETONATION 16:30 AT SURFACE - CONFIRMED ALL SHOTS FIRED 18:00 RIG DOWN COMPLETE - CALLED DSO - LEFT PAD PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 21, 2000 Mr. Daniel T. Seamount, Jr. Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Completion Report for 1D-139 (200-049) Dear Mr. Commissioner: Phillips Alaska, Inc. (formerly ARCO Alaska, Inc.) submits the attached Completion Report for the drilling operations on 1D-139. If you have any questions regarding this matter, please contact me at 265-6120 or Mark Chambers at 265-1319. Sincerely, Randy Thomas Kuparuk Drilling Team Leader PAI Drilling RT/skad 16-May-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-139 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 4,838.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-139 Surveyed: 13 May, 2000 OR!G NAL SURVEY REPORT 16 May, 2000 Your Ref: API-500292295800 Surface Coordinates: 5959003.94 N, 560490.58 E (70° 17' 54.8170" N, 149° 30' 36.4496" W) Kelly Bushing: 100.85ft above Mean Sea Level Survey Ref: s vy9211 North Slope Alaska Measured Depth (ft) Incl. Sperry-Sun Drilling Services ?~ i~ ~¥~ ~ ,~ ~, '% Survey Report for 1D- 139 ~: ........ ~ ~'~= ~r~=~ ~'~ Your Ref: API-500292295800 Surveyed: 13 May, 2000 Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (~) (") (~) (") (~) (") Dogleg Rate (°/100ft) Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) Comment 1D-139 Gyro o.oo o.ooo 11o.oo 0.220 14o.oo 0.460 17o.oo 0.560 200.00 o.71o 237.oo o.77o 329.00 1.62o 422.o0 3.450 475.00 4.41o 1D-139 514.63 608.63 700.43 795.15 859.32 955.29 lO52.71 1148.65 1246.96 1343.4o 4,740 5.560 6.12o 6.200 5.o3o 2.81o 1.14o o.78o 1.380 1.560 o.ooo 339.000 305.060 299.030 287.530 277.830 221.66o 21o.o4o 209.550 208.990 191.o6o 191.24o 192.76o 183.29o 16o.93o 126.25o 135.OLO lO5.56o 111.28o -100.85 0.00 0.00 N 0.00 E 5959003.94 N 560490.58 9.15 110.00 0.20 N 0.08W 5959004.14 N 560490.50 39.15 140.00 0.32 N 0.19W 5959004.26 N 560490.38 69.15 170.00 0.46 N 0.42W 5959004.40 N 560490.15 99.15 200.00 0.59 N 0.73W 5959004.52 N 560489.85 136.14 236.99 0.69 N 1.19W 5959004.62 N 560489.38 228.12 328.97 0.20 S 2.67W 5959003.72 N 560487.91 321.03 421.88 3.60 S 4.94W 5959000.30 N 560485.67 373.91 474.76 6.75 S 6.75W 5958997.13 N 560483.89 413.41 514.26 9.51S 8.29W 5958994.36 N 560482.36 507.03 607.88 17.38 S 11.05W 5958986.47 N 560479.67 598.36 699.21 26.54 S 12.86W 5958977.29 N 560477.94 692.53 793.38 36.48 S 14.97W 5958967.34 N 560475.91 756.39 857.24 42.67 S 15.90W 5958961.14 N 560475.03 852.14 952.99 49.10 S 15.37W 5958954.72 N 560475.61 949.50 1050.35 51.93 S 13.81W 5958951.90 N 560477.19 1045.43 1146.28 52.95 S 12.58W 5958950.89 N 560478.43 1143.72 1244.57 53.75 S 10.96W 5958950.11 N 560480.05 1240.13 1340.98 54.53 S 8.62W 5958949.34 N 560482.40 0.200 1.012 0.378 0.654 0.375 1.470 2.034 1.812 0.00 -0.21 -0.37 -0.60 -0.86 ~1.16 -1.06 0.90 2.87 E 0.840 4.59 E 1.911 10.29 E 0.610 17.58 E 0.192 25.41 E 2.320 30.47 E 2.767 36.41 E 2.034 39.64 E 0.404 41.12 E 0.813 42.57 E 0.241 44.35 RECEIVED MAY 18 2O00 Alaska 0il & Gas Co,,Is. Anchorage MWD Magnetic Continued... DrillQuest 1.05.05 16 Ma~ 2000-15:05 -2- Sperry-Sun Drilling Services Survey Report for 1D- 139 Your Ref: API-500292295800 Surveyed: 13 May, 2000 North Slope Alaska Measured Depth (ft) Incl. 1 8 2000 Sub-Sea Ve~ical Azim, Depth Depth (fi) (fi) Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 1D Dogleg Vertical Rate Section (°/100ft) (ft) Comment 1441.92 0.460 273.020 1338.64 1439.49 1538.13 0.430 300.840 1434.84 1535.69 1634.69 0.800 293.130 1531.40 .1632.25 1730.67 2.450 ' 178.940 1627.35 1728.20 1828.50 2.610 178.250 1725.08 1825.93 1925.50 6.380 169.640 1821.77 1922.62 2022.70 10.120 162.620 1917.95 2018.80 2119.90 13.310 148.560 2013.13 2113.98 2217.13 17.160 148.320 2106.93 2207.78 2314.98 20.990 149.250 2199.39 2300.24 2410.73 24.040 151.670 2287.83 2388.68 2507.59 27.510 150.640 2375.04 2475.89 2605.64 30.380 148.620 2460.84 2561.69 2702.96 34.010 149.090 2543.18 2644.03 2799.95 38.000 150.230 2621.63 2722.48 2897.32 40.020 152.620 2697.29 2798.14 2993.98 44.140 149.780 2769.02 2869.87 3091.38 46.590 149.240 2837.45 2938.30 3187.57 46.210 147.810 2903.78 3004.63 3284.25 45.830 148.160 2970.92 3071.77 3382.15 45.560 149.290 3039.30 3140.15 3477.42 45.890 148.600 3105.81 3206.66 3574.33 45.710 147.740 3173.37 3274.22 3671.81 45.690 150.520 3241.46 3342.31 3768.63 45.340 150.780 3309.30 3410.15 55.OO S 7.77 W 54.79 S 8.46 W 54.34 S 9.39 W 56.13 S 9.97 W 60.45 S 9.86 W 67.96 S 8.83 W 81.43 S 5.30 W 99.13 S ' 3.09 E 120.89 S 16.46 E 148.25 S 33.01 E 180.16 S 51.04 E 217.04 S 71.38 E 257.95 S 95.39 E 302.33 S 122.20 E 351.54 S 150.97 E 405.36 S 180.25 E 462.07 S 211.50 E 521.79 S 246.67 E 581.20 S 283.04 E 640.18 S 319.92 E 700.06 S 356.29 E 758.50 S 391.48 E 817.52 S 428.12 E 877.39 S 463.91 E 937.60 S 497.77 E 5958948.88 N 5958949.08 N 5958949.52 N 5958947.73 N 5958943.41N 5958935.91N 5958922.47 N 5958904.84 N 5958883.18 N 5958855.96 N 5958824.19 N 5958787.48 N 5958746.77 N 5958702.61N 5958653.63 N 5958600.04 N 5958543.58 N 5958484.15 N 5958425.04 N 5958366.35 N 5958306.77 N 5958248.62 N 5958189.89 N 5958130.31N 5958070.37 N 560483.26 E 2.032 45.16 560482.56 E 0.224 44.66 560481.63 E 0.392 43.83 560481.06 E 2.992 45.14 560481.20 E 0.166 49.02 560482.30 E 3.937 56.16 560485.93 E 3.978 69.73 560494.47 E 4.382 89.30 560508.02 E 3.960 114.79 560524.78 E 3.926 146.69 560543.07 E 3.329 183.33 560563.70 E 3.612 225.43 560588.05 E 3.092 272.81 560615.21 E 3.739 324.55 560644.37 E 4.171 381.49 560674.09 E 2.586 442.76 560705.80 E 4.694 507.49 560741.45 E 2.546 576.71 560778.29 E 1.147 646.20 560815.64 E 0.472 715.56 560852.50 E 0.871 785.47 560888.15 E 0.624 853.56 560925.27 E 0.663 922.84 560961.54 E 2.041 992.48 560995.88 E 0.409 1061.52 RECEIVED Continued... DrillQuest 1.05.05 16 Ma~ 2000-15:05 -3- North Slope Alaska Sperry-Sun Drilling Services ~, %1 ~ ~ # ~ ....... ?% Survey Report for 1D- 139 '~ ~=~' ~'~ ~? Your Ref: API-500292295800 Surveyed: 13 May, 2000 Alaska State Plane 4 Kuparuk 1D Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Local Coordinates Global Coordinates Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) Dogleg Vertical Rate Section (°/100ft) (ft) Comment 3863,22 45.790 153.380 3375,53 3476,38 997,27 S 529,38 E 5958010,96 N 561027,97 E 3962.62 45.720. 155,710 3444,89 3545,74 1061,56 $ 559,98 E 5957946,92 N 561059,09 E 3985,00 45,660 155,290 3460,52 3561,37 1076,13 S 566,63 E 5957932,40 N 561065.85 E 4011,19 45.400 155,240 3478,87 3579,72 1093,11 S 574,45 E 5957915,49 N 561073,81 E 4104.15 44.900 155,340 3544,43 3645,28 1152,98 S 602,00 E 5957855,85 N 561101,84 E 4198.64 39,290 151.720 3614,53 3715,38 1209,68 S 630,11 E 5957799,37 N 561130,41 E 4292,99 34.130 154,970 3690,15 3791,00 1260,01 S 655,48 E 5957749,24 N 561156,18 E 4387,63 29.530 154,590 3770,53 3871.38 1305,16 S 676,74 E 5957704,27 N 561177,80 E 4482,37 26.890 156.200 3854,01 3954,86 1345,86 S 695,40 E 5957663,72 N 561196.79 E 4576.33 26.080 155,250 3938,11 4038,96 1384,06 S 712,62 E 5957625,66 N 561214,32 E 4671,15 25.340 156.920 4023,55 4124,40 1421,66 S 729,31 E 5957588,20 N 561231,31 E 4766,97 25.120 154.830 4110,23 4211,08 1458,93 S 745,99 E 5957551,06 N 561248,29 E 4789,72 24.820 156,090 4130,85 4231,70 1467,66 S 749,98 E 5957542,36 N 561252.35 E 4838,00 24,820 156,090 4174,67 4275,52 1486,19 S 758,20 E 5957523,90 N 561260.72 E 2.019 1129.05 1.681 1200.19 1.369 1216.19 1.002 1234.85 0.543 1300.67 6.467 1363.96 5.842 1420.31 4.865 1470.17 2.900 1514.89 0.973 1556.72 1.092 1597.77 0.958 1638.53 2.684 1648.12 0.000 1668.35 Projected Survey 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. Magnetic Declination at Surface is 26.638° (06-May-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 152.430° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4838.00ft., The Bottom Hole Displacement is 1668.42ft., in the Direction of 152.971° (True). RECEIVED MAY !8 2000 ~.taska Oil & Gas Co.qs. Commissior, Continued... 16 May, 2000 - 15:05 - 4 - Anchorage OriliQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D- 139 Your Ref: API-500292295800 Surveyed: 13 May, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 4838.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4275.52 1486.19 S 758.20 E Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.oo 514.63 514.26 To Measured Vertical Depth Depth (ft) (ft) 514.63 514.26 4838.00 4275.52 Survey Tool Description AK-1 BP_HG MWD Magnetic 16 May, 2000 - 15:05 - 5 - DrillQuest 1.05.05 MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson,~J~J~) DATE: May 7, 2000 Chairman Cy! THRU: Blair Wondzell, P. I. Supervisor FROM: John Crisl~~x~v~ ~- SUBJECT: Petroleum't'nspector Diverter Inspection Nordic 3 AAI KRU 1 D-139 PTD 2O0049 May 7, 2000: I traveled to Arco Alaska's Kuparuk River Field to witness the Diverter function test on Nordic 3 drilling West Sak well 1 D-139. The Diverter System function tested without problems. The 16" diverter line was secured very well. Sign was placed @ Pad entrance indicating well was being drilled w/Diverter. Stay back 50' sign was placed on the end of diverter line. Rig & Location are in good shape. SUMMARY: I witnessed the Diverter function test & inspected the Diverter syatem on Nordic 3 drilling well 1D-139 for AAI in the KRU. Diverter Inspection, no failures. Attachments: Div. Insp. Nordic 3 5-7-00jc cc; NON-CONFIDENTIAL Div. Insp. Nordic 3 5-7-00jc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI,5,51ON Diverter Systems Inspection Report Operation: Drlg Contractor: Nordic Rig No. Operator: Arco Alaska Inc. Oper. Rep.: Well Name: 1D-139 Rig Rep.: Location: Sec. 29 T. 11N R. IOE Date: 5~7~00 Development X Exploratory: 3 PTD # 200-049 Rig Ph. # 659-7872 Don Wester Shane McGheehan Merdian Umiat MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: ok Well Sign: yes Systems Pressure: 3000 psig Housekeeping: ok (Gen.) Drlg. Rig: ok Pressure After Closure: 2050 psig Reserve Pit: na Flare Pit: na 200 psi Attained After Closure: min. 18 sec. Systems Pressure Attained: 1 min. 23 sec. Nitrogen Bottles: 4 @ 1 950 avg. DIVERTER SYSTEM INSPECTION: Diverter Size: Divert Valve(s) Full Opening: yes Valve(s) Auto & Simultaneous: yes Vent Line(s) Size: 1 6 Vent Line(s) Length: 85 Line(s) Bifurcated: na Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted / Long Radius: na 13 5/8" in. psig MUD SYSTEM INSPECTION: Light Alarm in. Trip Tank: ok ok ft. Mud Pits: ok ok Flow Monitor: ok ok GAS DETECTORS: Light Alarm Methane ok ok Hydrogen Sulfide: ok ok North wind direction Nordic 3 existing well houses 85'x 16"ventline with full opening automatic knife valve, 100 + feet from ignition source motors South Non Compliance Items Remarks: Repair Items Within Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c- Oper/Rep c - Database c - Trip Rpt File c- Inspector AOGCC REP.: JOIln CriSp OPERATOR REP.: Div.lnsp. Nordic 3 5-7-00jc DVTRINSP.XLT (REV. 1/94) Re:'l D-139 West Sak Injector (Top Set) - - PTD #20~-049 Subject: Re: 1D-139 West Sak Injector (Top Set) - - PTD #200-049 Date: Mon, 08 May 2000 12:27:03 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Mark A Chambers <MCHAMBE2~mail.aai.arco.com> CC: Sharon Allsup-Drake <SALLSUP~mail.aai.arco.com>, Chip Alvord <CALVORD~mail.aai.arco.com>, "Randy L. Thomas" <RLTHOMAS~mail.aai.arco.com> Mark, This is as we discussed on Thursday (May 4) and we accept this notice of the change as adequate. Thanks for the discussions and the schematics. Blair Wondzell Mark A Chambers wrote: Blair: Attached is letter we discussed concerning top set for well 1D-139. Any questions please call me ~ 265-1319. Thank you, Mark Chambers Drilling Engineer ARCO Alaska, Inc. (See attached file: AOGCC LetterlD139 50300.rtl)(See attached file: 1D-139 Completion Schematic. vsd) (See attached file: 1D-139 Top Set Completion Schema ti c. vsd) lYame : AOGCC LetterlD139 50300.rtf Type: En coding: Description: Name AOGCC LetterlD139 50300.rtl -- Rich Text Format (application~rtl) base64 Ri ch Text Format : 1D-139 Completion Schematic. vsd > 1D-139 Completion Schematic. vsd Type: application/x-unknown-content-type-vsd auto file > Encoding: base64 > Name: 1D-139 Top Set Completion Schema tic. vsd > 1D-139 Top Set Completion Schematic.vsd Type: application/x-unknown-content-type-vsd auto file -- __ > Encoding: base64 1 of 1 5/8/00 12:27 PM Teleld~,m ga~' May 03, 2000 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-139 West Sak Injector (Top Set) Permit # 200-49 Dear Blair, Per our conversation concerning the iD-139 West Sak Injector, I have attached a schematic of the original planned completion and a schematic showing the proposed top set completion. The original well plan called for Nordic 3 to drill 7-7/8" hole to TD at 4768' MD / 4187' TVD and run a typical 5-1/2" x 3-1/2" tapered string completion (see attached schematic #1). However, recent pressure information in the area indicates reservoir pressure may be as high as 2000 psi. 2000 psi ~ 3651' TVD (top D-Sand) = 11.1 ppg EMW with 100 psi overbalance Due to potentially high reservoir pressure the decision has been made to top this well. The current 1 D-139 Well Plan calls for Nordic 3 to drill 7-7/8" hole to the top of the D-Sand at 4143' MD / 3651' TVD and run 5- 1/2" casing. Nordic 3 will than drill 4-3/4" hole to TD at 4768' MD / 4187' TVD and run a 3-1/2" liner (see attached schematic #2). A LOT will be performed immediately above the top of the D-Sand prior to penetrating the top of the reservoir. This well is tentatively scheduled to spud May 07,00. Please call me at 265-1319 if you have any questions. Mark Chambers Drilling Engineer ARCO Alaska, Inc. Attachments: Well Schematic 1D-139 (Top Set) Completion Well Schematic 1D-139 Proposed Completion RECE!VED MAY 05 2000 Alaska Oi; & Gas Cons. Co~'nmjs,~jo~ Anchorage, May 0.3, 2000 Mr. Blair E. Wondze[l. P.E. SexfiJor la~.~trolcum [~gineet Alaaka Oil & Oa~ Con~ervafinn ~mmixslon 3001 Powupine Ddw Anchorage, ~aska 99501 Subject: ID., ! 39 West Salt Injector (Top Set) Permit ~ 200-49 Dear Blair, conversation concur/ling the ID- 139 W,.~t Sz& Injoctor. I have attach¢~l a su:hcmatic of the original The original w, II plan c~tlled for Nca-dlc 3 ta drill 7-718" bole to TD ~tt 4768'MD/41~7'TVD a~d run a typical 5-1/2" x 3-1/Z" tap,red strJng completion (~ attached gahema6~- $1). llowcv,~, recent pre~gtll'e informalt0li in 21300 p~i ~ 36.5 t 'TYD (lop D-Sallci) = It. I ppg fiMW with 100 p~i ovethalance Duo m pot,ntiall¥ high res~rvmr pressure tiao- dec|sion has b~fl made to top this well. Thc collcnt 1D-139 Well Plan ,ails for Nordic 3 I0 drill 7-7/11" lmle to Ih, tt~p of the D-Sand at 4143' MD 136,~ [' TVD a[d run 5- 1/2" caaing. Nordic 3 will than drill 4-314" hole t()TI)at 4768 qVID ! 418'/' TVD and run a 3-1f2" liner (~o at 'la*hod tab,matte #2). A LOT will be l~rform,d im,n¢diato, ly ah, ye the. tOD 1}1' die D-Sand prior to pon, trattng the top of M~ reservoir. This well Is t,ntat|v, ly .~cheduled to apad May 07,00. Pl~, ,all m~'- at, 265-1 .~ 19 if you have any que.~tions. Mark Chaml:~r~ 1)rillia~ Engineer ARCO Alaska, Inc. Attachments: Well Schematic I r>-139 .(?op 801) O. Oml.~l,-titm W~ll Schmmld= i D- 130 Propo~;ed Ccm~plelinn C /I #~[~L 9L~ LOB 1 D-139 West Sak Monobore Injector ,9-1/2" Top Set wi 3-'112" Unee Planned Completion 1~,~13" {tt~N L-i~O BI'~. G--'ondu~ar ~ ~' J TAM 6-1/a" Po~l Geller la-r(; tltox x Pin Sot @ +/- 1000' 'fVD Production asg, 5-1/2" t5.5~ L~o LTCM or BTOM SCl @ +I- 41)1tl3' MDI 3614"rv0 (50' MD / 07' TYD alive top o1' D-San~) D-E, mnd~ (piton t~ pefforetc Oft rig) a-,'ilar~$ (plan to peaoram oft MO) A-Sands (pltin to pedorate off ~Io) r~xluv~i~n L 3-tt2' vetco-Gfay Tubing Hangor w/~.~/~" r~uE SFiD-naOd pin clown, 3-1/~' @.B/f L-BO EUE t~RD M~d Tubing to ,surface, C,,mr-u 3,-11~" % 1" Model 'l,[Bl~-~-9' ~,LM w/~ · I~, ~-1/~" X 6' Ha~lt~ Pu~ Installed ~n I~p ~ ~t~m w/ B~M Pin ~ EU~ ~RO M~ BOX ~1;~1 I J01n! 3-1/2" 9.3# L.SC) EUE 8RD-Mod Tubing, 3-112' Camco ~s' Lant:llneJ Nipple w/2.81Z" NO.GO F'rOllla. JoiNt 8-1/~" 0.S& L-&O EUE/)RD,Mud Tubir,U. BIIii~ '4I~-4~I' l~l~eelel Clear,mix* PBR v~' 10' of effcclivc slrokc ~4.Bl~' UU, 4.0" ID Seal Bo~c. 3,0' ID Scala). Baker Um~ ~KBH' Anchor ..~e-I A,,semblV ir~taJIm:l ~n boltom (2.78' ID) and 6' L,80 lia~ldlin0 pup installed ~ top. DM(er a-l~Z" x 5" Mode] 'e~ABL~' la~llllBnl~i~ la11~ligr Iurl li15 a liner lO~ pacKor ~Z.TaO" mmlrnum ID ttwoUgll gel Pmnk~.r ~ ~- Rg4,? .Mr)~novidina t.~' of Linor iao_ ,q-iA~', S.~, L~, FL,N~ Tubing Irorn Ine LanUlng GOII~T I0 me Packer. I~aker 3-1/~' Landing Collar w/FL4S Box a Pin, 1 J, olnle 3-If2", 9,311, L-80, FL4~ Tubing. Baker 3r t/2" Fk~at Cnll-~ w/t-:L4S a~ x Pin. 2. ,7oint~ 3.1P2", 9.3~, L-BO, PLa.5 Tubing. BaJ(~r 3,1/2" FlOa[ Shoe w/FI_AS Box Up, 'ID ~ -~- '17~68' MD / 4187 TVD MAC; O&/O&,rO0 ~ /C #'~L 9L~ LOB ~3NI XV 1 D-139 West Sak Monobore Injector 13-3/~" 6g~ L-ElD g'l'lr3 G~nduolor ~ 8ff TAM 5-1/Z" Po~t Cell~r gTC Box x Pin ~,t i~ ~. lOOO' 'rvD 15.6# L-80 LTCM or I~TCM XO J ,~,~lg 1o e, urlaoe Se~ XO 1 SBE +/- ~00' ~ve top D-8~n~ (plan '0 perorate ~ rig) B-Sanda ~lan to perforate off da) A,~E~mdG (i~n in perforate alt' rig) rr0eu~on c~, 0.3# L-gO I::UI: laRD-Mod TO to xO / SBE J TD ~ 476B' MD / 4187' TVD L 3-1/'2' Vialoo-Gmy TL~drl~ Hangar w/<3.1/2' EUE aRD-MOCI pin QO~,nl. 3,1/2' 9.3~ L.~n I:U£ aRD ~ Tubing lc~ ~u~a. 3~1/~. x 1" C, am~ l(flfl-?-~ [ii M w~ DV & IBtCI1, ,3-112" )4 LT HanUIIng Pups Ins~lled on mp an~ botlo~n ~ B'TCM Pin x EUE 8RD Mo(I Box Special C~eatance Coupling&, 1J~,int 3-1J2" 13.3~ L.80 I~UI~ BRD.Mod Tubing, 3-1/2' Camco 'DS' LanOlng Nipple v~ 2,812" No-aa Profile, t Jaim 3-t/2' 9.3~ L-an gui; 8RD-blod Tubing. $-I/E' gal<ar Gi)H~.2 '80-40' Looabor 5eel ~aembl)' ~ 12' et Scale an~ ~ooalo, r g-lfZ' x 8' L-80 I'ianallng PuP Inatall~d on toD, EUE aRD-Moa Box up, Bakgr CarJng B,~;ia Rardll::ltlr'la F laake~' §-I.L~" XO / I-/,u"~..lifl,g Pup, ~ x LT.(:; '- I Baker XO Ooupling vd I~;~M~ shoulder, LTC I I~kcr 5" OD x 4" ID E)~I Bom Extcnoion ~ LBake( X0, SBE x 3-1/2' EUE 8RD 3-tjX' 9,3# L-80 EUE 8RD Mod Tubing from Landing Slccvc k~ 6BE, 3-1Y2" W~aB~erfnrd Landing e--Je~ve inelallad in lap af j,,i~d I Joins 5-1/~" 9.~ L~ EUE 8RD-Mad Turn9. 2 ~ ~-1~' ~.~ L~ EUESRD-MOd Tu~ng. S 1~" wcamcdom F~I SItOC ~ ~.1~' EUE 8~ BOX MAG 03/16/(X) ~ /g #'g~fiL 9Lg LOg TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COPlplISSION Chip Alvord Drilling Engineering Supervisor ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 3001 PORCUPINE DRIV[ ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: Kuparuk River Unit 1 D- 139 ARCO Alaska. Inc. Permit No: 200-049 Sur. Loc. 663'FNL, 598'FEL. Sec. 23, T1 IN, RIOE, UM Btmhole Loc. 2108~FNL. 155'FWL, Sec. 24, T1 IN, RIOE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No ID-139. Please note that any 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 ID 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 ,,'ear. The permit to drill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must bc 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 thc Commission may witness thc tests. Notice may be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF TH.~ikCOMMISSION DATED this {O t~-- day of April, 2000 dlf/Enclosures CC2 Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1;:T~p;o~woH(i Drill D Redriii D Jlb. Typ(;'of~ell. E)~l~lorai~ry D .... Stratigraphic'Test'O ~evei'°pmentOilD Re-entry D Deepen D I Service D Development Gas D Single Zone D M,Itiple Zone 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 101' above sea level 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 663' FNL, 598' FEL, Sec. 23, T11N, R10E, UM (ASP: 560493.6, 5959004) Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2021' FNL, 71' FWL, Sec. 24, T11N, R10E, U M (ASP: 561122.2, 5957855.9) 1 D-139 #U-630610 At total depth 9. Approximate spud date Amount 2108' FNL, 155' FWL, Sec. 24. T11N, R10E, UM (ASP: 561259.8, 5957564.58) April 16, 2000 $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) 2108' @ TD feetI 1D-134 31.7' @1054' MD feet 2560 4768 ' MD/4187 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 400' MD Maximum hole angle 48° Maximum surface 1390 psig At total depth (TVD) 1827 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of Cement Hole Casin~l Wei~lht Grade Coupling Len~lth MD TVD MD TVD (include stage data) 20" 13.375" 68¢ L-80 BTC 50' 30' 30' 80' 80' Pre-installed 7.875" 5.5"x 15.5# L-80 BTCM 3996' 30' 30' 4026' 3562' 380 sx Class G & 410 sx Class G 7.875" 3.5" 9.3# L-80 EUE 8rd M 742' 4026' 3562' 4768' 4187' (included in above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet 0RIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production " '~ ..... ~ ~ ~ ?' , ~ #REF! : ' ";. t'"', Perforation depth: measured true vertical --., ~,,.., ~u, ~.h;.;,., 2o. Attachments Fi,.g fee ID Prope,y P at ID BoP Sketch ID Dive.er Sketch E! Dri,ing program E] Drilling fluid program [~] Time vs depth Cot DRe~ractio. analysis D Seabed report I--I 2O AAC 25.O5O req.irements r'l 21. I hereby certify that the foregoing is true and correct to the best of my knowledg6 Questions? Call Mark Chambers 265-131(` Signed ~ ~'- ~4~ Title: Drilling Engineering Supervisor Date '~ IZ~ ~cO Chip Alvord pre~3~red hv .gharon AIl.~umDrak~ Commission Use Onl) PermitNumbe, APl number I Approva,~/~ ISee coverletter :2. co - ~.~ 5o- O ~ ¢'-- .2, 2.- '~' ,5"E' Ifor other requirements Conditions of approval Samples required D Yes ~ No Mud Icg required D Yes J~ No Hydrogen sulfidemeasures ~ Yes ~No_D(~ D irectionalsurveyrequired ]~ Yes D No Required working pressure for BOPE ['"]2M; [-i 5M; E] loM;r-i ['-I ~ ~1,.. Other: ORIGINAL SI(~N~J)By by order of Approved by' Robert N. ?hristen$on Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate 1 D-139 West Sak Monobore Injector 5-1/2" x 3-1/2" Tapered String Planned Completion 13-3/8" 68# L-80 BTC Conductor @ 80' '1 TAM 5-1/2" Port Collar BTC Box x Pin set @ +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 LTCM or BTCM XO / SBE to surface Set XO / SBE +/- 100' above top Perforation D-Sands (plan to perforate off rig) B-Sands (plan to perforate off rig) A-Sands (plan to perforate off rig) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod TD to XO / SBE 3-1/2" Vetco-Gray Tubing Hanger w/3-1/2" EUE 8RD-Mod pin down. 3-1/2" 9.3# L-80 EUE 8RD Mod Tubing to surface. 3-1/2" x 1" Camco 'KBG-2-9' GLM w/DV & latch, 3-1/2" x 6' Handling Pups installed on top and bottom w/BTCM Pin x EUE 8RD Mod Box Special Clearance Couplings. 1 Joint 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2" Camco 'DS' Landing Nipple w/2.812" No-Go Profile. 1 Joint 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2" Baker GBH-22 '80-40' Locator Seal Assembly w/12' of Seals and Locato.r 3-1/2" x 6' L-80 Handling Pup installed on top. EUE 8RD-Mod Box up. Baker Casing Bore Recepticle Assembly I!aker 5-1/2" XO / Handling Pup, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension 12' aker XO, SBE x 3-1/2" EUE 8RD 3-1/2" 9.3# L-80 EUE 8RD Mod Tubing from Landing Sleeve to SBE. 3-1/2" Weatherford Landing Sleeve installed in top of joint #3. 1 Joints 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2" Weatherford Float Collar w/3-1/2" EUE 8rd Box x Pin. 2 Joints 3-1/2" 9.3# L-80 EUE 8RD-Mod Tubing. 3-1/2" Weatherford Float Shoe w/3-1/2" EUE 8rd Box Up. TD @ 4768' MD / 4187' TVD MAC 03/15/00 Drill, Case and Completion Plan for West Sak 1 D-139 Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 13-3/8". Weld landing ring on conductor. MIRU Nordic Rig 3. Install diverter & function test same. Spud and directionally drill 7-7/8" hole to desired target through West Sak interval. Run MWD / LWD / PWD logging tools in drill string as required for directional monitoring and formation data gathering. Circulate and condition hole to run casing. POOH. Run and cement 3-1/2" 9.3# L-80 EUE 8rd x 5-1/2" 15.5# L-80 BTCM tapered casing string to surface. Displace cement with mud and perform stage job or top job if required. Note: 5-1/2" Port Collar to be installed @ +/- 1,000' TVD. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to brine. . , . , , . 8. 9. Sting into seal bore extension and space out. 10. With seal assembly unstung, freeze protect well with diesel 11. Sting into seal bore extension and land tubing. 12. Using diesel, pressure test tubing and annulus to 3,000 psi. Install back pressure valve. 13. Nipple down BOP stack. Install production tree and pressure test same. 14. Secure well and release rig. 16. Rig up E-line unit and RIH with CBL / CET. Run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 17. Rig up E-line unit and RIH with through-tubing perforating guns. 18. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 19. Install back pressure valve, shut in and secure well. MAC 3/28/OO 15. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1 D-139 Drilling Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: Drilling Fluid Properties Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.5 8-15 30-60 250 15-30 25-55 8-15 8-9 5-8 Spud to TD Final 9.4 - 9.6* 11-22 30-60 250 10-25 25-55 6 8-9 5-8 Drilling Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators * 9.8 ppg if hydrates are encountered. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface. A TAM Port Collar will be placed at approximately 1000 feet TVD. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1 D-139 well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled trom sudace through the West Sak pay zone can be safely drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.3 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,637'. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3972 ft)(0.46 - 0.11 psi/ft) -- 1390 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of 3,000 psi. The 5-1/2" 15.5# L-80 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-139 area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 9.8 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1 D-139. Well Proximity Risks: The nearest existing well to 1 D-139 is 1 D-134. The wells are 31.7' from each other at a depth of 1054' MD. Gyro Surveys will be required to validate survey integrity. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1 D-139 surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 16" DIVF TER SCHEMATIC- Nr .dic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 10" 150 ANSI Blanked Open r · To Accumulator I Closed ~' ~ ~ .... From Accumulator 3 Closed __..~ 3" Ball Valve Blanked Open Maintenance & Operation 1. Upon initial installation: . Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16"x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line - Nordic MAC 3/7/OO 5000 psi BOP Stac' Kuparuk River Unit West Sak Operations -Injector Wells 4 3 2 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine depth that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annular preventer, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" x 11" 5000 psi Double Studded Adapter/Spacer Spool 4. 11" 5000 psi Pipe Rams 5. 11" 5000 psi Drilling Spool with Choke and Kill Lines 6. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 7. 11" 5000 psi Annular Preventer MAC 3/28/00 1D-139 West Sak Injector Well Surface Cement loads and CemCADE* summary. Use 45 % excess below the Permafrost and 300 % above. Drilled with 7 7/8" bit. 5 V2", 15.5# X 31/2", 9.3# Tapered string. Crossover Joint @ 4008'(approximately 100' above the D Sands), TD @ 4768' MD. Top of Tail cement @ 3400' (minimum of 500' above the top of the crossover joint). Single Stage Design. Port Collar contingency at 1000' MD if no cement to surface. Base of the Permafrost at 1641' MD, Volume Calcs: Pump 20 bbls Arco Preflush, 50 bbls MUDPUSH XL @ 10.0 ppg. Cement from MD to 3400' with Class G + adds @15.8 ppg and from 4300' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.43 ft3/sk Above Permafrost: 5.5" x OH Below Permafrost: 5.5" x OH Total: 1136.9 ft3+ 441.8 ft3 = 1578.7 ft3/4.44 ft3/sk = (300% excess): (1641') x 0.1732 ft3/ft x 4 = (45% excess): (3400'-1641') x 0.1732 ft3/ft x 1.45 = 1136.9 ft3 441.8 ft3 1578.7 ft3 356 sks - Round up to 380 sks Have an additional 260 sks of lead on location for Top OU[/2nd stage, if necessary - enough cement to fill the annular space (300% excess) and the inside of the drill pipe from port collar to surface. Tail Slurry Requirements: 15.8 ppg Class G + 0.5%S1, 0.2%D46, 0.3%D65, 0.4%D167 - 1.17 ft3/sk Below Permafrost: 5.5" x OH (45% Excess): (4008'-3400') x 0.1732 ft3/ft x 1.45 = 3.5" x OH (45% Excess): (4768'-4008') x 0.2714 ft3/ft x 1.45 = 80' shoe joint: 80' x 0.04822 ft3/ft = Total: 152.7 ft3 299.1 ft3 3.9 ft3 152.7 ft3 + 299.1 ft3 + 3.9 = 455.7 ft3/1.17 ft3/sk = 455.7 ft3 390 sks - Round up to 410 sks BHST = 70F, BHCT = 65F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.0 ppg MUDPUSH XL, 356 sks (281 bbls) ASLite Lead, drop plug, 390 sks (81 bbls) Class G + adds Tail, drop plug, displace with rig. Circulation: Circulation at or less than 7 bpm is within safe ECD limits without breaking down the formation. Perform the designed cement job at a rate between 3 and 6 BPM for mud removal in Effective Laminar Flow. Drop the rate below 4 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 1300 psi at 4 bpm. At 7 bpm, expect 10 minutes of u-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 9.5 ppg or lower, Pv =15 to 20, Ty = 15 to 20 or lower - As thin and as light as possible to aid in the removal of mud during the cement job. This is the most important part of the cement job. James Franks can be reached at the Arco Tower, home or by cellular at the following numbers regarding this job or any other assistance: 265-6205(w), 248-3595(h), 223-5148(ce11). Jdf 3/24/00 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1 D-139 WPs 50O -- 1000 - 1500 -- 3500 - 2000 - '-~ 4000 - I DrillQuest' ~Start Dir @ 1.500°/100ft · 400.00ff MD, 400.00ft TVD o.o0 %~End Dir · 733.33fl MD, 732.91ff TVD ~Start Dir @ 1.500°/100ft: 833.33ft MD, 832.53ft TVD loo.oo ~End Dir' 1166.67ft MD, 1165.44ft TVD ~-o0Start Dir @ 3.500°/lOOff'1720.OOft MD, 1718.77ff 'I-VD 800.00 '000.00 100.00 Propoaal Data for 1D-139 WP1 Vortical Odgir~: 1D- 139 Hodzo~llaJ Origin: 1D-139 Measuren~lt Units: ~t North Reference: True North veD~leg sovedty: 15~.~ ..... ~cal Section Azimuth: Vertical Seclion DescdptJon: 1D-139 VerlJcal Section Odgin: 0.O0 N,0.00 E Nlea~ured Incl. Azlm. VerUcalNorthlng= EaetlngaV~tlcal Dogleg DeCth D~p01 Section Rate 0.00 0.0000.461 0.00 0.OO N 400.O00. O00 0.461 4O0. O0 00ON 0.181E 733.335.O0O23O. OOO 732.91 ').34 S 11.13 W3.13 1.5O0 833.335.000230.000832.53 14.95 S 17.81 W5.01 o(x81 1166.67 O.0~O0.461 1165.44 24.29 S 28.95 W8.1,1 1,5(X) 1720.00 O. OOO 0461 1718.77 24.29 S 28.*15 W 8.14 0.0{X) 3088.92 47.912 150. OO6 2933.64 491.78 S 24090 E547,433.500 3931.38 47.912 150.0063498.31 1033.25 S553.,15 E 1172,07 0.000 4315.91 35.000 155.8003786.(X) 1258.45 S67O. 52 E 1425.89 3.5(81 4767.77 19.185 155.7844187.OO 1445.55 S754.63 E 1630.67 3.5(X) Currant Wall Propertlea Well: 1 D- 139 WI I Horizontal Coordinate~: Rel. G[daal Coordinates: 59590O4.0 Roi. Well: 900.23 S, Roi. Geographical Coordinates: 70° ~ 7' 54. I RK~B E~e ...... North P~forence: Tree No,th I Unite: Feet 1D-139 WP8 5959004.01 N, 56O493.56 E 9OO.23 S, 2. t8 E 7O° IT $4.8175' N. 149°30'36.3627. W 95.001t above Moan Sea Level 95.o0ft above Well 250O - 6O0.00 700.00 8OO.OO · nd Dir: 3088.92ft MD, 2933.64ff TVD 3000 ..... 4O0.O0 500.00 o00.o0 7O0.O0 800.00 Start Dir @ 3.500°/100ff: 3931.38ft MD, 3498.31ft TVD to0.oo ......... iiiiii .................................................. ~~;; .............. 0.3637.00T~0 ......................................................................... ~:':" .............. B - 370].00 TVD 1D-l;~fl. TARGET o0'o0 .......................................................... ~~.~..~..!o .......... ~ ............ .......................................................... .~.o. t y. Lre. c. t.t, ?. ¢ .......... 5 7o"oi " 'A J- 3972.00 TVDNOt directl~ hit Total Depth :4767.77ft MD, 4187.00ft TVD I I I I 0 500 1000 1500 Scale: linch = 500ft Vertical Section Section Azimuth: 152.434° (True North) I DrillQuest North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1 D-139 WPs Proposal Data for 1D-139 WP1 1D-139 Vertical Origin: ~tD'139 Horizontal Origin: Moasurement Units: North Refereece: True No~lh E~xjk~j ~vedty: D~jr~a por 10Oft VeStal Section Azimuth: 152.434° VerlJcalSectJon DescripUon: 113-139 Vertical Section Origin: 0.130 N.O.00 E MeasuredIncl. Azlm. VerUcaJNorthlnga EaatlngaVertical Dogleg Depth D~pth glectlon Re1® 0.00 0.0000.461 0.00 0.00 N o(x) I'; 0.00 400.000.0000.461 400.00 1).00 N 0.{x} F, 0.(X) 0.00O 733.335,000230.000732.91 ').34 S 11.13 W3.13 1.500 833.335.000230.000832.53 14.95 S 17.111 W 5,01 0.18~1 1166.67 o.oo11 0.461 1165.44 24.29 S 28.95 W8.14 1.481 1720.00 O.OO00.461 1718.77 24.29 S 28.95 W8.14 o.o(x1 3088.92 47.912 150.0062933.64 491.78 S 240.90 F. 547.433.500 3931.38 47.912 150.0063498.31 1033.25 S553.45 E 1172.07 o.oo11 4315.91 35.000 155.8003786.00 1258.45 S670.52 E 1425.89 3.51X} 4767.77 19.185 155.7844187.00 1445.55 S754631'; 1630,67 3.500 __ -300 -- End Dir: 3( -600 - o Z -900 - o -1200 - II .-- ,,i-- Eastings Scale: linch = 30Oft 0 300 600 I I I art Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD nd Dir: 733.33ft MD, 732.91ft TVD rt Dir @ 1.500°/100ft: 833.33ft MD, 832.53ft TVD oo. d Dir: 1 166.67ft MD, 1 165.44ft TVD .oo '" Start Dir @ 3.500°/100ft: 1720.00ft MD, 1718. 700.00 800.00 . 85o.oo ,88.92 oft MD/T~li~o.oo 3tart Dir @ 3.500°/100ft' 3931.38ft MD, 1D-139 TARGET 3786.00 TVD 1358.45 S, 670.52 E13 Not directly hit Total Depth: 4767.77ft MD, I I I 0 300 600 Scale: linch = 300ft Eastings Current Well Propertlee Well: 1 D- 139 WI Horizo~tsl Coordinatos: Rof. Global Coonlinate8: 5959004.0 Rel. Well: 900.23 S,; Rel. Geo(j raphical Coordinatotl: 7O° 17' 54. RKi~ Bevalion: 95.0011 at;<) 95.00f1 ab( North Reference: True No~th Units: Foot --0 77ft TVD -- -300 -- -600 .-- o 1D-139 WPa 5959004.01 N, 56O493.56 E 9OO.23 gl, 2.18 E 7O° 1T54.8175' N, 149° 30' 363627" W 95.0011 alx)vo Mean Soa Lovol 95.00f1 above We, -1200 o° II - -900 Reference is True North Sperry-Sun Drilling Services Proposal Data- 1Do139 WPs- 1D-139 WP1 1720 000 401.000 180.019 16 March, 2000 - 15:11 - I - DrillQuest Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 0.00 0.000 0.000 -95.00 200.00 0.000 0.000 105.00 400.00 0.000 0.000 305.00 450.00 0.750 230.000 355.00 500.00 1.500 230.000 404.99 550.00 2.250 230.000 454.96 600.00 3.000 230.000 504.91 650.00 3.750 230.000 554.82 700.00 4.500 230.000 604.69 733.33 5.000 230.000 637.91 800.00 5.000 230.000 704.32 833.33 5.000 230.000 737.53 850.00 4.750 230.000 754.14 900.00 4.000 230.000 803.99 950.00 3.250 230.000 853.89 1000.00 2.500 230.000 903.83 1050.00 1.750 230.000 953.79 1100.00 1.000 230.000 1003.78 1150.00 0.250 230.000 1053.77 1166.67 0.000 0.000 1070.44 1200.00 0.000 0.000 1103.77 1400.00 0.000 0.000 1303.77 1600.00 0.000 0.000 1503.77 1720.00 0.000 0.000 1623.77 1750.00 1.050 150.006 1653.77 Ve~ical Local Coordinates Depth Northings Eastings (fi) (ft) (fi) 0.00 0.00 N 0.00 E 200.00 0.00 N 0.00 E 400.00 0.00 N 0.00 E 450.00 0.21 S 0.25W 499.99 0.84 S 1.00W 549.96 1.89 S 2.26W 599.91 3.36 S 4.01 W 649.82 5.26 S 6.26W 699.69 7.57 S 9.02W 732.91 9.34 S 11.13W 799.32 13.08 S 15.59W 832.53 14.95 S 17.81W 849.14 15.86 S 18.90W 898.99 18.31 S 21.82W 948.89 20.34 S 24.24W 998.83 21.95 S 26.16W 1048.79 23.14 S 27.58W 1098.78 23.91 S 28.50W 1148.77 24.26 S 28.92W 1165.44 24.29 S 28.95W 1198.77 24.29 S 28.95W 1398.77 24.29 S 28.95W 1598.77 24.29 S 28.95W 1718.77 24.29 S 28.95W 1748.77 24.53 S 28.81W Alaska State Plane 4 Kuparuk 1D Global Coordinates Dogleg Ve~ical Nothings Eastings Rate Section (fi) (fi) (°/100ft) (ft) 5959004.01N 560493.56 E 0.00 5959004.01 N 560493.56 E 0.000 0.00 5959004.01 N 560493.56 E 0.000 0.00 5959003.80 N 560493.31 E 1.500 0.07 5959003.16 N 560492.57 E 1.500 0.28 5959002.10 N 560491.32 E 1.500 0.63 5959000.61 N 560489.58 E 1.500 1.13 5958998.70 N 560487.34 E 1.500 1.76 5958996.37 N 560484.60 E 1.500 2.54 5958994.58 N 560482.50 E 1.500 3.13 5958990.81 N 560478.08 E 0.000 4.38 5958988.92 N 560475.87 E 0.000 5.01 5958988.00 N 560474.80 E 1.500 5.31 5958985.53 N 560471.89 E 1.500 6.13 5958983.48 N 560469.49 E 1.500 6.81 5958981.85 N 560467.58 E 1.500 7.35 5958980.65 N 560466.17 E 1.500 7.75 5958979.87 N 560465.26 E 1.500 8.01 5958979.51 N 560464.84 E 1.500 8.13 5958979.49 N 560464.81 E 1.500 8.14 5958979.49 N 560464.81 E 0.000 8.14 5958979.49 N 560464.81E 0.000 8.14 5958979.49 N 560464.81 E 0.000 8.14 5958979.49 N 560464.81 E 0.000 8.14 5958979.25 N 560464.95 E 3.500 8.41 Comment Start Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD End Dir: 733.33ft MD, 732.91fl TVD Start Dir @ 1.500°/100ft: 833.33ft MD, 832.53ft TVD End Dir: 1166.67ft MD, 1165.44ft TVD Start Dir @ 3.500°/100ft: 1720.00ft MD, 1718.77ft TVD Continued... 16 March, 2000 - 15:10 - I - DriliQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (fi) 1800.00 2.800 150.006 1703.74 1850.00 4.550 150.006 1753.64 1900.00 6.300 150.006 1803.41 1950.00 8.050 150.006 1853.02 2000.00 9.800 150.006 1902.41 2050.00 11.550 150.006 1951.54 2100.00 13.300 150.006 2000.37 2150.00 15.050 150.006 2048.85 2200.00 16.800 150,006 2096.93 2250.00 18.550 150,006 2144.56 2300.00 20.300 150.006 2191.72 2350.00 22.050 150.006 2238.34 2400.00 23.800 150.006 2284.39 2450.00 25.550 150.006 2329.82 2500.00 27.300 150.006 2374.59 2550.00 29.050 150.006 2418.67 2600.00 30.800 150.006 2462.00 2650.00 32.550 150.006 2504.55 2700.00 34.300 150.006 2546.28 2750.00 36.050 150.006 2587.15 2800.00 37.800 150.006 2627.12 2850.00 39.550 150.006 2666.15 2900.00 41.300 150.006 2704.21 2950.00 43.050 150.006 2741,26 3000.00 44.800 150.006 2777.28 VeHical Local Coordinates Depth Northings Eastings Nothings (fi) (ft) (fl) ~t) 1798.74 25.98 S 27.97W 5958977.81 N 1848.64 28.76 S 26.37W 5958975.04 N 1898.41 32.85 S 24,00W 5958970.97 N 1948.02 38.26 S 20.88W 5958965.58 N 1997.41 44.98 $ 17.00W 5958958.90 N 2046.54 53.00 S 12.37W 5958950.91 N 2095.37 62.31 S 7.00W 5958941.64 N 2143.85 72.92 S 0.88W 5958931,09 N 2191.93 84.80 S 5.98 E 5958919.26 N 2239.56 97.95 S 13.57 E 5958906.18 N 2286.72 112.35 S 21.88 E 5958891,84 N 2333.34 127.99 S 30.91 E 5958876.27 N 2379.39 144.86 S 40.65 E 5958859.49 N 2424.82 162.93 S 51.08 E 5958841.49 N 2469.59 182.21 S 62.21 E 5958822.31 N 2513.67 202.65 S 74.01 E 5958801.96 N 2557.00 224.25 S 86.48 E 5958780.46 N 2599.55 246.99 S 99.60 E 5958757.83 N 2641.28 270.84 S 113.37 E 5958734.09 N 2682.15 295.79 S 127.77 E 5958709.26 N 2722.12 321.80 S 142.79 E 5958683.37 N 2761.15 348.86 S 158.40 E 5958656.43 N 2799.21 376.94 S 174.61 E 5958628.49 N 2836.26 406.01S 191.39 E 5958599.55 N 2872.28 436.05 S 208.73 E 5958569.65 N Global Coordinates Eastings (It) 560465.80 E 560467.43 E 560469.82 E 560472.99 E 560476.92 E 560481.62 E 560487.07 E 560493.27 E 560500.23 E 560507.92 E 560516.35 E 560525.50 E 560535.38 E 560545.96 E 560557.23 E 560569.20 E 560581.84 E 560595.15 E 560609.11E 560623.71E 560638.93 E 560654.77 E 560671.20 E 560688.22 E 560705.80 E Dogleg Rate (°/100ft) 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 10.09 13.29 18.01 24.25 32.00 41.26 52.00 64.24 77.94 93.11 109.72 127.77 147.22 168.08 190.31 213.89 238.81 265.04 292.56 321.34 351.35 382.56 414.96 448.49 483.15 Comment Continued... 16 March, 2000- 15:10 - 2- DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 3050.00 46.550 150.006 2812.21 3088.92 47.912 150.006 2838.64 3200.00 47.912 150.006 2913.09 3400.00 47.912 150.006 3047.15 3600.00 47.912 150.006 3181.20 3800.00 47.912 150.006 3315.25 3931.38 47.912 150.006 3403.31 3950.00 47.281 150.226 3415.87 4000.00 45.589 150.842 3450.33 4050.00 43.900 151.494 3485.84 4100.00 42.216 152.188 3522.37 4126.32 41.330 152.571 3542.00 4150.00 40.535 152.927 3559.89 4200.00 38.860 153.720 3598.36 4209.79 38.533 153.882 3606.00 4250.00 37.191 154.572 3637.74 4300.00 35.528 155.492 3678.01 4315.91 35.000 155.800 3691.00 4350.00 33.807 155.799 3719.13 4400.00 32.057 155.798 3761.09 4450.00 30.307 155.797 3803.87 4500.00 28.557 155.796 3847.41 4533.50 27.384 155.795 3877.00 4550.00 26.807 155.794 3891.69 4600.00 25.057 155.792 3936.65 Ve~ical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (fi) (fl) (ft) 2907.21 467.03 S 226.61 E 5958538.82 N 560723.93 E 2933.64 491.78 S 240.90 E 5958514.19 N 560738.41 E 3008.09 563.17 S 282.11 E 5958443.13 N 560780.19 E 3142.15 691.72 S 356.31 E 5958315.18 N 560855.43 E 3276.20 820.26 S 430.51 E 5958187.24 N 560930.66 E 3410.25 948.81S 504.70 E 5958059.29 N 561005.89 E 3498.31 1033.25 S 553.45 E 5957975.25 N 561055.31 E 3510.87 1045.17 S 560.30 E 5957963.38 N 561062.25 E 3545.33 1076.71 S 578.12 E 5957931.99 N 561080.33 E 3580.84 1107.54 S 595.09 E 5957901.29 N 561097.55 E 3617.37 1137.64 S 611.21 E 5957871.33 N 561113.91 E 3637.00 1153.17 S 619.34 E 5957855.86 N 561122.16 E 3654.89 1166.97 S 626.44 E 5957842.13 N 561129.38 E 3693.36 1195.50 S 640.78 E 5957813.71 N 561143.95 E 3701.00 1200.99 S 643.48 E 5957808.24 N 561146.69 E 3732.74 1223.21 S 654.22 E 5957786.10 N 561157.60 E 3773.01 1250.08 S 666.73 E 5957759.34 N 561170.34E 3786.00 1258.45 S 670.52 E 5957751.00 N 561174.19 E 3814.13 1276.02 S 678.42 E 5957733.49 N 561182.23 E 3856.09 1300.81S 689.56 E 5957708.79 N 561193.57 E 3898.87 1324.42 S 700.17 E 5957685.27 N 561204.37 E 3942.41 1346.83 S 710.24 E 5957662.94 N 561214.63 E 3972.00 1361.16 S 716.69 E 5957648.66 N 561221.18 E 3986.69 1368.02 S 719.77E 5957641.83 N 561224.32 E 4031.65 1387.96 S 728.73 E 5957621.96N 561233.44 E Dogleg Rate (°/100ft) 3.500 3.500 0.000 0.000 0.000 0.000 0.000 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 3.500 Alaska State Plane 4 Kuparuk 1D Ve~ical Section (a) 518.88 547.43 629.79 778.08 926.37 1074.66 1172.07 1185.81 1222.02 1257.21 1291.34 1308.87 1324.39 1356.32 1362.44 1387.10 1416.71 1425.89 1445.11 1472.25 1498.09 1522.62 1538.30 1545.80 1567.63 Comment End Dir: 3088.92ft MD, 2933.64ft TVD Start Dir @ 3.500°/100fl: 3931.38ft MD, 3498.31ft TVD A3 A1 Continued,.. 16 March, 2000 - 15:10 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 4650.00 23.307 155.790 3982.26 4077.26 4700.00 21.557 155.788 4028.48 4123.48 4750.00 19.807 155.785 4075.25 4170.25 4767.77 19.185 155.784 4092.00 4187.00 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1406.64 S 737.13 E 5957603.35 N 561241.99 E 1424.04 S 744.95 E 5957586.02 N 561249.96 E 1440.14 S 752.20 E 5957569.97 N 561257.33 E 1445.55 S 754.63 E 5957564.58 N 561259.80 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-139. Northings and Eastings are relative to 1 D-139. Magnetic Declination at Surface is 26.703° (24-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1 D-139 and calculated along an Azimuth of 152.434° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 4767.77ft., The Bottom Hole Displacement is 1630.67ft., in the Direction of 152.434° (True). Dogleg Rate (°/100ft) 3.500 3.500 3.500 3.500 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 1588.08 1607.12 1624.75 1630.67 Comment Total Depth: 4767.77ft MD, 4187.00ft TVD 5 1/2" X 3 1/2" Liner Continued... 16 March, 2000 - 15:10 - 4 - DriflQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured S t a t i o n Depth TVD Northings (ft) (ft) (ft) 400.00 400.00 0.00 N 733.33 732.91 9.34 S 833.33 832.53 14.95 S 1166.67 1165.44 24.29 S 1720.00 1718.77 24.29 S 3088.92 2933.64 491.78 S 3931.38 3498.31 1033.25 S 4767.77 4187.00 1445.55 S Coordinates Eastings (ft) 0.00 E 11.13W 17.81 W 28.95 W 28.95 W 240.90 E 553.45 E 754.63 E Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) 4126.32 3637.00 3542.00 1153.17 S 4209.79 3701.00 3606,00 1200.99 S 4315.91 3786.00 3691,00 1258.45 S 4533.50 3972.00 3877.00 1361.16 S Comment Start Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD End Dir: 733.33ft MD, 732.91ft TVD Start Dir @ 1.500°/100ft: 833.33ft MD, 832.53ft TVD End Dir: 1166.67ft MD, 1165.44ft TVD Start Dir @ 3.500°/100ft: 1720.00ft MD, 1718.77ft TVD End Dir: 3088.92ft MD, 2933.64ft TVD Start Dir @ 3.500°/100ft: 3931.38ft MD, 3498.31ft TVD Total Depth: 4767.77fl MD, 4187.00ft TVD Eastings Formation Name (ft) 619.34 E D 643.48 E B 670.52 E A3 716.69 E A1 Continued... 16 March, 2000- 15:10 -5- DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-139 WPs - 1D-139 WP1 Revised: 16 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) <Surface> <Surface> 4767.77 Targets associated with this wellpath Target Name 1D-139 TARGET Vertical Depth Casing Detail (ft) 4187.00 5 1/2" X 3 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3786.00 1358.45 S 670.52 E 3691.00 5957651.00 N 561175.00 E 70°17'41.4556"N 149° 30'16.8179"W Target Target Shape Type Point 16 March, 2000 - 15:10 - 6 - DrillQuest 1.05.05 Sperry-Sun Alaska Anticollision Report 12:43:48 Page: 1 Well: 1D-139 WPs, True North , R~fer~¢e:: 1D-139WPs 95;0 above Mean Sea Level Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Definitive Plan Interpolation Method: MD Interval: 100.000 ft Error Model: ISCWSA Ellipse Depth Range: 0.000 to 6378.150 ft Scan Method: High Side + Azimuth MaximumRadius:10000.000 ft Error Surface: Ellipse Survey Program for Definitive Wellpath Date: 02/24/2000 Validated: No Version: 3 Planned From To Survey Toolcode ToolName ft ft 0.000 6030.060 Planned: 1D-139 WP1 Vl MWD MWD - Standard Summary !Cli No_Go Allowable Deviation Warning ft ft Kuparuk 1D Pad 1D-06 Kuparuk 1D Pad 1 D-07 Kuparuk 1D Pad 1D-08 Kuparuk 1D Pad 1D-10 Kuparuk 1D Pad 1D-11 Kuparuk 1D Pad 1 D-121 Kuparuk 1D Pad 1 D-127 Kuparuk 1 D Pad 1 D-128 Kuparuk 1D Pad 1 D-129 Kuparuk 1D Pad 1 D-130 Kuparuk 1D Pad 1 D-131 Kuparuk 1D Pad 1 D-132 Kuparuk 1D Pad 1D-133 Kuparuk 1D Pad 1D-133 Kuparuk 1D Pad 1 D-134 Kuparuk 1D Pad 1 D-135 Kuparuk 1D Pad 1 D-140 1 D-06 V2 1 D-07 V2 1 D-08 V12 1D-10 V2 1D-11 V4 1D-121 V2 1D-127 V2 1 D-128 V2 1D-129 V2 1D-130 V2 1D-131 V2 1D-132 V2 1 D-133 V2 1D-133PB1 V2 1 D-134 V2 1D-135 V2 4000.000 4000.000 199.049 106.785 92.264 Pass: Major Risk 1363.123 1300.000 104.097 31.749 72.348 Pass: Major Risk 1786.552 1800.000 84.738 33.130 51.608 Pass: Major Risk 578.661 600.000 98.250 9.947 88.303 Pass: Major Risk 682.683 700.000 70.344 11.511 58.833 Pass: Major Risk 2314.105 2500.000 421.112 42.449 378.663 Pass: Major Risk 817.775 900.000 304.709 23.174 281.535 Pass: Major Risk 1224.038 1300.000 252.468 31.459 221.009 Pass: Major Risk 919.173 1000.000 210.453 25.065 185.388 Pass: Major Risk 1430.833 1500.000 202.600 34.022 168.578 Pass: Major Risk 830.021 900.000 154.340 22.468 131.871 Pass: Major Risk 929.358 1000.000 92.803 24.530 68.273 Pass: Major Risk 1533.427 1600.000 60.661 33.677 26.985 Pass: Major Risk 1533.427 1600.000 60.661 33.677 26.985 Pass: Major Risk 1053.691 1100.000 31.730 23.771 7.959 Pass: Major Risk 481.611 500.000 135.738 6.945 128.793 Pass: Major Risk 1D-140 V5 Plan: 1D-140 490.431 500.000 283.512 7.397 276.115 Pass: Major Risk Site: Kuparuk 1D Pad Well: 1D-06 Rule Assigned: Major Risk Wellpath: 1D-06 V2 Inter-SiteError: 0.000 ft No-Go Allowable Distance Area Deviation Warning ; ff ft ft 90.000 90.000 100.000 100.000 0.000 0.000 -0.35 -0.35 189.998 189.998 200.000 199.998 0.051 0.000 -0.45 -0.45 289.995 289.995 300.000 299.995 0.157 0.224 -0.57 -0.57 389.994 389.994 400.000 399.994 0.270 0.661 359.36 359.36 485.705 485.697 500.000 499.994 0.325 0.881 -0.51 129.49 580.829 580.761 600.000 599.993 0.302 0.944 0.06 130.06 675.723 675.484 700.000 699.993 0.268 0.911 0.96 130.96 772.306 771.734 800.000 799.992 0.301 0.724 2.08 132.08 874.268 873.328 900.000 899.991 0.402 0.648 3.16 133.16 980.219 979.066 1000.000 999.987 0.523 0.816 4.01 134.01 1086.392 1085.172 1100.000 1099.929 0.631 0.953 4.73 134.73 1190.922 1189.695 1200.000 1199.695 0.652 1.210 5.52 5.52 1290.213 1288.987 1300.000 1298.987 0.717 1.600 6.90 6.90 1388.643 1387.417 1400.000 1397.417 0.797 1.969 9.09 9.09 1485.919 1484.692 1500.000 1494.692 0.882 2.342 12.14 12.14 1581.463 1580.237 1600.000 1590.237 0.971 2.756 16.48 16.48 1674.726 1673.500 1700.000 1683.500 1.061 3.214 22.80 22.80 1762.780 1761.549 1800.000 1774.118 1.134 3.704 31.98 241.97 1848.910 1847.551 1900.000 1861.883 1.153 4.209 43.53 253.52 1937.405 1935.540 2000.000 1947.144 1.134 4.678 56.29 266.28 2028.500 2025.451 2100.000 2029.799 1_131 5.132 69.32 279.30 2122.252 2116.990 2200.000 2109.523 1.225 5.643 81.77 291.76 300.482 0.000 300.557 Pass 300.807 1.577 299.230 Pass 300.933 4.068 296.865 Pass 300.775 7.216 293.558 Pass 301.093 9.479 291.617 Pass 303.077 11.027 292.051 Pass 306.901 12.248 294.690 Pass 312.571 13.234 299.443 Pass 318.538 14.842 303.871 Pass 322.111 17.300 305.034 Pass 321.669 19.627 302.283 Pass 316.674 22.028 294.899 Pass 307.668 24.871 283.031 Pass 294.377 27.664 266.920 Pass 276.944 30.440 246.669 Pass 255.470 33.284 222.287 Pass 231.390 36.253 195.199 Pass 209.162 39.343 169.991 Pass 194.152 42.167 152.079 Pass 186.825 44.876 142.017 Pass 186.605 47.668 138.989 Pass 193.710 51.003 142.867 Pass Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree No Cement to Surface Begin Primary One1 Stage Cement Job/ / / Cement / above Port / Collar / (1000' I"VD)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's If Top Job is ineffective or unacceptable to AOGCC Continue with Completion Cement to Surface Cement below Port Collar (1000' 'I'VD) ! Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion West Sak Monobore Iniector 5-1/2" TAM Port Collar The goal for using this tool is to eliminate use of a two stage cementing collar while still ensuring cement is successfully circulated to surface. This is yet another way to reduce rig time on West Sak wells while still providing operational integrity. This tool will only be opened if cement does not reach the surface with a single stage cement job and also is out of top job range. The decision to use the port collar will be made by the ARCO Drilling Foreman on location. This tool is basically a sliding sleeve which is opened with a "Combo Tool" that has packoffs on either side of 1" ports. The Combo Tool is run in on drillpipe until latching into a profile on the collar which places the ports on the combo tool across from the sliding sleeve of the port collar. Approximately 15,000 lbs. of weight is applied to shift the collar open. The packoffs ensure that cement is pumped out the ports into the annulus. When the cement job is complete, the Combo Tool is pulled out of the well. The port collar provides a full ID upon closing. Therefore no drill out is required after cementinq, If conditions indicate a good lob, the tubing should then be run without a cleanout run. Detailed operational procedures are enclosed. The Port Collar should be placed at approximately 1000' TVD. This depth was chosen because it is most likely out of top job range, but is still accessible with drillpipe in a reasonable time. Therefore it is recommended that if the Drilling Foreman believes that the top of cement is deeper than 1000' TVD the Port Collar should be used, otherwise a top job should be performed. An estimate of the top of cement can be made through the final slow circulating pressure before bumping the plug. In addition, a dye or a small amount of LCM should be mixed with the spacer to give an indication of top of cement. In order to facilitate a quick turn around should the Port Collar be used, it is also recommended that the Combo Tool be made up on a pup joint and be ready on the catwalk and approximately 12 stands of 3 1/2" tubing be racked back. As mentioned above, the tool does require approximately 15,000 lbs to open, therefore some heavy weight pipe may need to be run. A top job is the preferred remedial action to take if at all possible in the event cement does not reach the surface. The use of a Port Collar should be the last option for achieving cement to surface. The AOGCC must approve all top jobs in advance. Pre-approval should be considered since the time to make a decision whether to use the Port Collar or a Stage job will be small. Combo Tool and Port Collar Running Procedure 1. Check that all materials are at the rig site · ' 5 ~" TAM Combo Tool, with 2 7/8" EUE Box by Pin and 5 Y2" 15.5 ppf Packer Cups · 5 ~" TAM Port Collar with 5 ~" BTC Box x Pin Connections · 3 ~" Choke Sub with 2 7/8" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers 2. Ensure that all connections are compatible or there are appropriate crossovers available 3. Pick up and run 5 Y2" 15.5 ppf casing with Port Collar placed at 1000' TVD 4. If the Drilling Foreman determines that it is necessary to use the Port Collar, run in the hole with the 3 Y~" tubing as a workstring until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. · In order to trip in with the 3 Y~" work string and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. 5. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure 6. Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. 7. Establish circulation rate and pressure 8. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing 9. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar 10. Pressure up on workstring to confirm collar is closed 11. With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar 12. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub 13. Reverse out excess cement as required 14. Pull out of hole with tools Greater Kuparuk Area Casing Pressure Test Standard Draft 4 The AOGCC requires a 30 minute casing pressure test prior to drilling out the float equipment. Current AOGCC regulations require surface casings to be tested to 1500 psi or 0.25 psi/ft, whichever is greater. This test needs to be charted for the AOGCC. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Casing Test Procedure Pressure test the surface casing to the value specified in the well plan, above and below the stage collar, if one has been run. Hold each of these tests for 10 minutes to insure the stage collar is completely closed. The AOGCC does not require this test to be charted. Check the well plan for any site specific drill out details. 2. Run in hole to top of baffle plate or float collar, whichever occurs first. Establish circulation and insure well is stable for the 30 minute test. Pressure test surface casing to the value outlined in the well plan for 30 minutes. This test needs to be charted for the AOGCC. Pressure vs. volume needs to be plotted for AAI records and as a minimum volume line for the upcoming LOT/FIT. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record the pump pressure every two pump strokes until the pressure specified in the well plan is reached (this will insure enough data points on the LOT/FIT). Monitor shut in casing pressure for 30 minutes. Make sure test is being accurately recorded on a chart. Check surface equipment for leaks if pressure drops more than 10 percent in 30 minutes. If surface leaks are discovered repair them and do the casing test over. If no surface leaks are found and casing pressure continues to bleed off contact, the AAI Drilling Engineer assigned to the rig, prior to drilling out the casing float equipment. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 4. After achieving a successful casing test. Drill out remaining cement and all float equipment. Clean out any existing rat hole. Drill 20 feet of new hole. Perform a LOT/FITper the standard procedure that follows. RLM 7/31/98 Greater Kuparuk Area Leak-Off Test Standard Draft 4 There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW allows the wells to be permitted through AOGCC for annular injection and exceeds any known required mud weights to control the reservoir pressure. In some cases the AOGCC may require an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent from the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kupamk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 March 28, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: West Sak 1D-139 Surface Location: Target Location: Bottom Hole Location: 663' FNL, 598' FEL, Sec 23, T11 N, R10E 2021' FNL, 71' FWL, Sec. 24, T11 N, R10E 2108' FNL, 155' FWL, Sec. 24, T11N, R10E Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak Sands in the vicinity of 1 D Pad. The well is designated as a monobore injector using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. The well will be drilled and completed using Nordic Rig 3. 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) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore 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. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 10) 11) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is April 16, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Tom McKay at 265-6890 or Chip Alvord at 265-6120. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: cc: KRU 1 D-139 Well File Chip Alvord Tom McKay ATO-1 O3O ATO-1060 To the order of: Date 03-21-00 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 ********************* Amount Void after 90 days .O~T'w6..$18na~u re~ required for.~mOunts WELL PERMIT CHECKLIST COMPANY WELL NAME/Z)-'/,:~9 PROGRAM: exp ~ dev ~ redrll ~ serv ~ wellbore seg ~ ann. disposal para req ~ FIELD & POOL INIT CLASS / /- ,,,...,,.~ ,~ G )L AREA _/~?<:;r UNIT# ADMINI,~TRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 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 ................. ON/OFF SHORE 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 ........ ,., ....... ~'AJx~''~P~PR J~(~ 26. B OPE .ress rating appropriate; test to .~'~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ I]'"' 28. Work will occur without operation shutdown ........... I__ 29. ~-'EOLOGY ~ I1~ 31. 32. APPR ~TE 33. APPR DATE (A) will contain waste in a suitable receiving zone; ....... Y N (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 Is presence of H2S gas probable ................. 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) ............. Y N Contact name/phone for weekly progress reports [exploratory~dnly] With proper cementing records, this plan GEOLOGY: ENGINE.EF[ING: UlC/Annular COMMISSION: TEM -~-" I CO ~: Comments/Instructions: O Z O c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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. ,( ~ ;l 6 l}- Ó ~I q Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 27, 2005 6507 1 3.5" 9.3Ib. L-80 Tubing & Liner Well: 1D-139 Field: Kuparuk State: Alaska API No.: 50-029-22958-00 Top Log IntvI1.: Suñace Bot. Log IntvI1.: 3,920 Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 3,809' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damages. The condition of the 3.5" tubing and liner ranges from good to poor with respect to corrosive damage, with a maximum wall penetration of 65% in joint 121 (3,822'). The deeper penetrations are recorded in the interval between joints 80 and 123 (2,500' - 3,920'). Wall penetrations ranging from 20% to 65% are recorded in 49 of the 131 joints logged. The damage appears in the forms of corrosion with deeper isolated pitting, often appearing in a line. No significant areas of cross-sectional wall loss or ID restrictions are recorded throughout the tubing and liner logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Corrosion Isolated Pitting Isolated Pitting Corrosion Isolated Pitting ( 65%) ( 52%) ( 50%) ( 47%) ( 46%) Jt. Jt. Jt. Jt. Jt. 121 @ 113 @ 101 @ 116 @ 91 @ 3,813 Ft. (MD) 3,549 Ft. (MD) 3,175 Ft. (MD) 3,646 Ft. (MD) 2,845 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 7%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant J.D. restrictions are recorded. ,', ß " k 'i\~E""- I\u G ') "1 2 0 O¡::: ,~t;.f1.[\~h~ ~) h J ",) J.. d I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Ptìone: (907) 659-2307 Fax: (907) 659-2314 ck3s. Well: Field: Company: Country: 10-139 Kuparuk ConocoPhillips USA I Tubing: Weight 9.3 ppf Grade & Thread L-80 Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 150 ~ metal loss body 100 50 O _I o to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 131) pene. 0 7 75 38 11 0 loss 11 120 0 0 0 0 Damage Configuration ( body) 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 110) 78 32 0 0 0 PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 2.992 ins July 27,2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o o ~ ~ == ===- =::.- .!!5E:=- i ~ 48~ æ.. ===. ~ ~ ~ metal loss body 50 100 98 GLM 1 r -,r- Bottom of Survey = 123 Analysis Overview page 2 i( ( PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-139 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips NominaII.D.: 2.992 in Country: USA Survey Date: July 27, 2005 Joint Jt. Depth Pen. Pen. Pen. :\1\('1(11 Min. Damage Profile No. (Ft.) Upset Body % Loss 1.0. Com men ts (% wall) (Ills. ) (Ins.) 01<) (Ins.) 0 50 100 .1 25 0 0.02 9 1 2.95 PUP .2 29 () 0.03 13 2 2.92 PUP Shallow pitting. .3 36 () 0.04 16 2 2.94 PUP Shallow pitting. Lt. Deposits. 1 42 0 0.04 14 1 2.96 Shallow pitting. 2 73 0 0.04 17 2 2.95 Lt. Deposits. 3 105 () 0.03 10 2 2.98 4 136 0 0.04 14 2 2.97 Shallow pitting. 5 168 0 0.04 16 2 2.96 Shallow pitting. 6 199 0 0.03 10 2 2.96 7 229 0 0.03 12 :3 2.96 Shallow pitting. 8 260 0 0.03 13 " 2.98 Shallow pitting. ~) 9 292 0 0.04 15 2 2.97 Shallow pitting. 10 323 0 0.04 17 3 2.97 Shallow corrosion. 11 354 0 0.03 12 2 2.95 Shallow pitting. 12 384 0 0.03 11 2 2.98 13 416 () 0.03 11 2 2.96 14 447 0 0.04 17 3 2.97 Shallow corrosion. Lt. Deposits. 15 478 0 0.04 14 2 2.97 Shallow pitting. 16 509 0 0.04 17 2 2.96 Shallow corrosion. 17 541 0 0.03 13 2 2.94 Shallow corrosion. 18 572 0 0.03 10 2 2.96 19 603 0 0.03 13 2 2.94 Shallow pitting. 20 634 0 0.03 13 2 2.96 Shallow pitting. 21 665 0 0.03 11 3 2.97 22 696 0 0.05 19 2 2.95 Shallow corrosion. Lt. Deposits. 23 728 0 0.04 16 6 2.96 Shallow pitting. 24 759 0 0.04 17 :3 2.97 Shallow pitting. Lt. Deposits. 25 791 0 0.03 13 2 2.96 Shallow pitting. 26 822 0 0.03 12 3 2.95 27 852 0 0.03 12 2 2.94 Shallow pitting. 28 883 0 0.03 13 2 2.96 Shallow pitting. 29 914 0 0.04 15 6 2.95 Shallow pitting. 30 945 0 0.04 17 7 2.96 Shallow pitting. 31 975 0 0.03 10 3 2.97 32 1004 0 0.04 17 3 2.96 Shallow pitting. 33 1036 0 0.03 13 2 2.96 Shallow pitting. 34 1067 0 0.04 16 :3 2.97 Shallow pitting. 35 1098 0 0.02 9 4 2.97 36 1130 0 0.04 15 2 2.96 Shallow pitting. 37 1161 0 0.03 12 2 2.97 Shallow pitting. 38 1192 0 0.03 13 1 2.96 Shallow pitting. 39 1224 0 0.03 12 2 2.95 40 1255 0 0.03 12 6 2.95 41 1286 0 0.03 12 2 2.96 42 1318 0 0.04 17 2 2.96 Shallow pitting. 43 1349 0 0.04 17 3 2.94 Shallow pitting. 44 1380 0 0.03 13 4 2.94 Shallow pitting. 45 1411 0 0.05 18 6 2.95 Shallow corrosion. Lt. Deposits. 46 1439 0 0.03 11 1 2.96 47 1470 0 0.05 19 2 2.94 Shallow pitting. ~ Penetration Body !I:I] Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 1 D-139 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips NominaII.D.: 2.992 in Country: USA Survey Date: July 27, 2005 Joint Jt. Depth Pell. Pen. Pen. MC'lal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) 0; (Ins.) 0 50 100 /0 48 1500 () 0.04 18 2 2.94 Shallow pitting. Lt. Deposits. 49 1531 () 0.04 16 3 2.96 Shallow pitting. 50 1562 0 0.04 16 4 2.95 Shallow corrosion. Lt. Deposits. 51 1592 0 0.03 11 2 2.97 52 1624 0 0.03 12 2 2.97 53 1655 0 0.04 14 1 2.96 Shallow pitting. 54 1686 () 0.05 21 1 2.96 Isolated pitting. 55 1718 () 0.03 11 2 2.95 56 1749 0 0.04 15 2 2.96 Shallow corrosion. 57 1780 0 0.04 17 1 2.96 Shallow corrosion. 58 1812 0 0.03 12 2 2.96 59 1843 0 0.03 10 2 2.93 60 1874 0 0.03 11 2 2.93 61 1906 0 0.03 13 1 2.96 Shallow pitting. 62 1935 0 0.04 17 2 2.96 Shallow pitting. 63 1966 0 0.03 13 1 2.94 Shallow pitting. 64 1997 0 0.03 13 2 2.96 Shallow pitting. 65 2029 0 0.04 15 1 2.96 Shallow pitting. 66 2060 0 0.04 16 ') 2.94 Shallow corrosion. -) 67 2091 0 0~04 17 2 2.94 Shallow pitting. 68 2122 0 0.04 18 2 2.96 Shallow pitting. 69 2152 0 0.06 25 2 2.98 Isolated pitting. 70 2183 0 0.05 18 3 2.96 Shallow pitting. 71 2215 0 0.04 16 2 2.97 Shallow pitting. Lt. Deposits. 72 2246 0 0.03 13 2 2.96 Shallow pitting. 73 2278 0 0.04 15 2 2.98 Shallow corrosion. 74 2309 0 0.03 13 1 2.97 Shallow pitting. 75 2341 0 0.05 18 2 2.95 Shallow pitting. 76 2372 0 0.03 13 2 2.95 Shallow pitting. 77 2403 () 0.04 15 2 2.97 Shallow pitting. 78 2435 0 0.05 18 2 2.98 Shallow pitting. 79 2466 0 0.04 16 5 2.96 Shallow pitting. 80 2497 0 0.08 32 2 2.96 Isolated pitting. 81 2528 0 0.05 18 2 2.96 Shallow pitting. 82 2560 0 0.04 14 2 2.96 Shallow pitting. 83 2591 0 0.05 21 2 2.95 Isolated pitting. 84 2622 0 0.12 46 3 2.95 Isolated pitting. 85 2653 0 0.07 28 2 2.94 Isolated pitting. 86 2685 0 0.07 29 2 2.94 Isolated pitting. 87 2716 0 0.11 42 3 2.94 Isolated pitting. 88 2747 0 0.07 28 2 2.98 Isolated pitting. 89 2779 0 0.07 27 2 2.95 Isolated pitting. 90 2810 0 0.10 38 3 2.94 Corrosion. 91 2841 0 0.12 46 2 2.96 Isolated pitting. Lt. Deposits. 92 2872 0 0.07 26 2 2.94 Isolated pitting. 93 2904 0 0.08 31 2 2.95 Corrosion. 94 2935 0 0.07 28 2 2.95 Isolated pitting. 95 2966 0 0.06 24 3 2.94 Corrosion. 96 2997 0 0.10 37 3 2.94 Isolated pitting. Lt. Deposits. 97 3029 0 0.09 35 4 2.96 Corrosion. I Penetration Body Metal Loss Body Page 2 ~ PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-139 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips NominaII.D.: 2.992 in Country: USA Survey Date: July 27,2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss I.D. Comments (% wall) (Ins.) (Ins.) o¡;¡ (Ins.) 0 50 100 98 3059 0 0.07 29 2 2.92 Isolated pitting. 99 3091 0 0.07 29 2 2.88 Corrosion. Lt. Deposits. 100 3122 0 0.08 33 2 2.90 Isolated pitting. 101 3153 0 0.13 50 2 2.93 Isolated pitting. 102 3185 0 0.08 33 4 2.94 Isolated pitting. 103 3216 0 0.07 28 3 2.91 Corrosion. 104 3247 0 0.10 40 4 2.91 Corrosion. 105 3277 () 0.09 35 :3 2.93 Corrosion. Lt. Deposits. 106 3307 0 0.08 32 2 2.91 Corrosion. Lt. Deposits. 107 3339 0 0.09 34 :3 2.89 Isolated pitting. 108 3369 0 0.10 39 4 2.90 Corrosion. Lt. Deposits. 109 3400 0 0.08 33 2 2.92 Corrosion. 110 3431 0 0.10 41 4 2.92 Isolated pitting. 111 3461 0 0.08 30 2 2.91 Isolated pitting. 112 3492 0 0.10 40 3 2.91 Corrosion. 113 3524 0 0.13 52 3 2.91 Isolated pitting. 114 3555 0 0.07 29 3 2.94 Isolated pitting. 115 3586 0 0.11 44 :3 2.92 Corrosion. Lt. Deposits. 116 3618 0 0.12 47 4 2.93 Corrosion. Lt. Deposits. 117 3649 0 0.11 43 4 2.92 Corrosion. 118 3680 0 0.08 31 :3 2.91 Corrosion. 119 3712 0 0.09 35 4 2.93 Corrosion. 119.1 3743 0 0.06 24 (, 2.94 PUP Isolated pitting. 119.2 3758 () 0 0 0 N/A GLM (Latch @ 11 :30) 119.3 3764 0 0.09 35 2 2.95 PUP Isolated pitting. 120 3779 0 0.11 42 4 2.92 Corrosion. 120.1 3809 0 0 0 0 2.81 DS Nipple 121 3810 0 0.16 65 7 2.95 Corrosion. 121.1 3841 0 0.10 39 4 2.96 PUP Isolated pitting. 121.2 3848 0 0 0 0 3.00 SEAL ASSEMBLY 121.3 3862 0.05 0.08 32 4 2.95 PUP Isolated pitting. 121.4 3872 0 0 () 0 N/A HANGER 121.5 3878 0 0.08 33 2 2.97 PUP Isolated pitting. 122 3884 0 0.09 36 :3 2.93 Corrosion. Lt. Deposits.(l st Jt. of Liner) 123 3913 0 0.10 37 4 2.99 Isolated pitting. I Penetration Body Metal Loss Body Page 3 ... ·-~--'6 ~.. PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-13 9 Kuparuk ConocoPhillips USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 27,2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 121 at depth 3812.57 ft Toolspeed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 96 % Tool deviation = 62 0 Finger 7 Penetration = 0.164 ins Corrosion 0.16 ins = 65% Wall Penetration HIGH SIDE = UP Cross Sections page 1 - 1->. tS ~ .' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-13 9 Kuparuk ConocoPhillips USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 27,2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 113 at depth 3549.42 ft Tool speed = 49 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation = 59 0 Finger 15 Penetration = 0.132 ins Isolated Pitting 0.13 ins = 52% Wall Penetration HIGH SIDE = UP Cross Sections page 2 - - - -~, -." TUBING (0-3848, 00:3.500, 10:2.992) :>RooucnON (0-4031 , 00:5,500, Wt15.50) NIP (3809-3810, 00:3.500) SEAL (3848-3849, 00:4.000) LINER (3874-4838, 00:3.500, Wt9.30) PACKER (4191-4221, 00:3.500) Pelf (4200-4246) PATCH (4221-4250, 00:3.500) PACKER (4250-4251, 00:3.500) Pelf (4258-4281 ) Pelf (4310-4318) Pelf (4329-4340) Pelf (4345-4355) Pelf (4362-4375) Pelf (4393-4440) Pelf (4480-4490) ConocoPhillips Alaska, Inc. 1 0-139 --- Well Type: INJ Orig 5/15/2000 Completion: LastW/O: Ref Log Date: TD: 4838 ftKB Max Hole Angle: 47 deg @ 3091 CAMCO DS NIPPLE BAKER GBH-22 SEAL ASSY 3" ECLIPSE PACKER ASSEMBL Yw/SPACER PIPE STUNG INTO TOP OF PATCH (OAL 30'9") set 4/17/2005 ECLIPSE PATCH (OAL 29'4") set 4/17/2005 ECLIPSE PACKER set 4/11/2005 API: 500292295800 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: 4738 Last Tag Date: 3/612005 Casing String - ALL Description CONDUCTOR PRODUCTION LINER Tubing String - ALL Size I Top 3.500 0 Perforations Summary Interval TVD 4114 - 4162 3653 - 3688 4200 - 4246 3716 - 3753 4258 - 4281 3763 - 3781 4310 - 4318, 3805 - 3812 4329 - 4340 3822 - 3831 4345 - 4355 3835 - 3844 4362 - 4375 3850 - 3861 4393 - 4440 3876 - 3918 4480 - 4490 3953 - 3962 Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr Mfr 1 3758 3403 CAMCO KBG29 CAMCO Other ~plugs, equip., etc.) - JEWELRY Depth TVD Type 3809 3438 NIP 3848 3466 SEAL 4191 3710 PACKER Size 16.000 5.500 3.500 Bottom 3848 Zone WSD WSB WSA4 WSA3 WSA3 WSA3 WSA3 WSA2 WSA2 Status 4221 4250 3733 3757 PATCH PACKER KRU 1 D-139 Angle @ TS: deg @ Angle @ TD: 25 deg @ 4838 Rev Reason: Set PATCH Last Update: 4/18/2005 Top o o 3874 Bottom TVD Wt Grade Thread 110 110 62.58 H-40 WELDED 4031 3594 15.50 L-80 BTCM 4838 4838 9.30 L-80 EUE 8RD TVD Wt I Grade Thread 3466 9.30 L-80 EUE8RD Ft SPF Date Type Comment 48 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 46 4 6/30/2000 (PERF 60 DEG PH 2.5" HSD DP 23 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 8 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 11 4 6/30/2000 IPERF 60 DEG PH 2.5" HSD DP 10 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 13 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 47 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP 10 4 6/29/2000 IPERF 60 DEG PH 2.5" HSD DP V Type DMY VOD Latch Port TRO 1.0 INT 0.000 0 Description Date Run 6/13/2000 Vlv Cmnt ID 2.813 3.000 1.812 1.750 1.812 Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Nov 03 13:39:07 2000 Reel Header Service name .......... i...LISTPE Date ..................... 00/11/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previeus Reel Name ....... UNKNOWN Cemments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/11/03 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: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-00041 R. FRENCH D. WESTER 1ST STRING 1D-139 500292295800 Phillips Alaska, Inc. Sperry Sun 03-NOV-00 MWD RUN 2 AK-MM-00041 J. PANTER D. WESTER MWD RUN 99 AK-MM-00041 29 lin 10E 669 698 .00 101.22 70.90 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.875 13.375 110.0 2ND STRING 4.750 7.875 4041.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DSm) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER PHONE CONVERSATION BETWEEN M.WERNER OF PHILLIPS ALASKA, INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 5/02/00. MWD DATA ARE CONSIDERED PDC. 4. VERTICAL RESISTIVITY INVERSION (VRI) DATA IS PRESENTED AS A DEEP PHASE ENHANCED (RD) CURVE IN MWD MERGED DATA, AND AS 4 ENHANCED CURVES AND 4 MODELED CURVES IN THE FINAL RAW MWD FILE. THIS FINAL FILE SPANS PORTIONS OF MWD RUNS 1 AND 2. 5. MWD RUNS 1 AND 2 REPRESENT WELL 1D-139 WITH API%: 50-029-22958-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 4838'MD, 4275'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 RESISTIVIT (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. VEXP = INVERSION-DERIVED EXTRA SHALLOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALLOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED) . VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/03 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. .5000 DEPTH INCREMENT: FILE SUHMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP RD $ START DEPTH 72.5 100 0 100 0 100 0 100 0 100 0 115 5 3390 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH} BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 4765 0 4776 0 4776 0 4776 0 4776 0 4776 0 4838 5 4650 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 62.0 4042.0 2 4042.0 4838.0 99 3390.0 4650.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD RDVR MWD FT FT/H API OHMM OHMM OHMM OHMM HRS OHMM 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 1 68 0 4 8 12 16 20 24 28 32 Name Service Unit DEPT FT ROP MWD FT/H GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HRS RDVR MWD OHMM Min 72.5 0.33 14 82 0 19 0 21 0 22 0 03 0 21 0.1 Max 4838.5 1718.31 130.85 1644.44 2000 2000 2000 63.96 2000 Mean 2455.5 107.47 68.446 41.4145 79.512 109.284 130.888 1.15398 35.8859 Nsam 9533 9425 9386 9353 9353 9353 9353 9353 2521 First Reading 72.5 115.5 72.5 100 100 100 100 100 3390 Last Reading 4838.5 4838.5 4765 4776 4776 4776 4776 4776 4650 First Reading For Entire File .......... 72.5 Last Reading For Entire File ........... 4838.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/03 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 ....... 00/11/03 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: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 62.0 RPD 100.0 RPM 100.0 STOP DEPTH 3998.0 4O05.0 4005.0 RPS 100.0 RPX 100.0 FET 100.0 ROP 112.0 $ # 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: 4005.0 4005.0 4005.0 4041.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (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 Depth Units ....................... iO-MAY-O0 Insite 0.41 MEMORY 4042.0 .4 46.6 TOOL NUMBER PB01496FR3 PB01496FR3 7.875 110.0 LSND 9.40 255.0 8.5 400 4.0 2.700 2.390 3.500 3.000 72.0 82.2 72.0 72.0 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HRS 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 62 4041.5 2051.75 7960 62 ROP MWD010 FT/H 0 135730 161.118 7816 112 GR MWD010 API 15.07 199.39 87.061 7814 62 RPX MWD010 OHMM 0.19 1201.04 46.9003 7811 100 RPS MWD010 OHMM 0.21 2000 85.4661 7811 100 RPM MWD010 OHMM 0.22 2000 125.049 7811 100 RPD MWD010 OHMM 0.18 2000 152.47 7811 100 FET MWD010 HRS 0.21 1.9 0.565049 7811 100 Last Reading 4041.5 4041.5 3998 4005 4005 4005 4005 4005 First Reading For Entire File .......... 62 Last Reading For Entire File ........... 4041.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/03 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 ....... 00/11/03 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: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3998.5 4765.0 FET 4005.5 4776.0 RPD 4005.5 RPM 4005.5 RPS 4005.5 RPX 4005.5 ROP 4042.0 $ 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 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 4776.0 4776.0 4776.0 4776.0 4838.5 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: 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 14-MAY-00 Insite 0.41 MEMORY 4838.0 24.8 45.4 TOOL NUMBER pb0141496rf3 pb0141496rf3 4.750 4041.0 LSND 10.50 57.0 9.7 2OO 4.5 1.750 1.292 2.000 2.230 75.0 104.0 75.0 75.0 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPH RPD FET Service Order Units Size Nsam Rep FT 4 1 68 MWD020 FT/H 4 1 68 MWD020 API 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 OHMM 4 1 68 MWD020 HRS 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 3998.5 4838.5 ROP MWD020 FT/H 2.5 238.27 GR MWD020 API 42.35 130.85 RPX MWD020 OHMM 0.83 1644.44 RPS MWD020 OHMM 0.77 2000 RPM MWD020 OHMM 0.24 2000 RPD MWD020 OHMM 0.03 2000 FET MWD020 HRS 0.37 63.96 Mean 4418.5 116.442 82.4454 13.626 49.3514 29.4268 21.5641 4.13719 Nsam 1681 1594 1534 1542 1542 1542 1542 1542 First Reading 3998.5 4042 3998.5 4005.5 4005.5 4005.5 40O5.5 4005.5 Last Reading 4838.5 4838.5 4765 4776 4776 4776 4776 4776 First Reading For Entire File .......... 3998.5 Last Reading For Entire File ........... 4838.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/03 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 ....... 00/11/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW HWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 99 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MEMP 3390.0 4650.0 MESP 3390 0 HEXP 3390 0 VEDP 3390 0 VEHP 3390 0 VESP 3390 0 VEXP 3390 0 MEDP 3390 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: 4650 0 4650 0 4650 0 4650 0 4650 0 4650 0 4650 0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ 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 03-NOV-00 ITOL PROCESSED 3390.0 4650.0 TOOL NUMBER 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 RX MWD099 OHMM 4 1 68 4 2 RS MWD099 OHMM 4 1 68 8 3 RM MWD099 OHMM 4 1 68 12 4 RD MWD099 OHMM 4 1 68 16 5 MX MWD099 OHMM 4 1 68 20 6 MS MWD099 OHMM 4 1 68 24 7 MM MWD099 OHMM 4 1 68 28 8 MD MWD099 OHMM 4 1 68 32 9 Name Service Unit Min Max DEPT FT 3390 4650 RX MWD099 OHMM 0.1 2000 RS MWD099 OHMM 0.1 2000 RM MWD099 OHMM 0.1 2000 RD MWD099 OHMM 0.1 2000 MX MWD099 OHMM 0.435 166.821 MS MWD099 OHMM 0.467 2000 MM MWD099 OHMM 0.157 2000 MD MWD099 OHMM 0.094 69.578 Mean Nsam 4020 2521 21 5629 2521 43 39 35 10 22 16 10 5448 2521 0989 2521 8859 2521 4664 2521 0774 2521 1689 2521 2106 2521 First Reading 3390 3390 3390 3390 3390 3390 3390 3390 3390 Last Reading 4650 4650 4650 4650 4650 4650 4650 4650 4650 First Reading For Entire File .......... 3390 Last Reading For Entire File ........... 4650 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/11/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/11/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
