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Home My WebLink About200-046DSR-4/9/2020DLB 04/06/2020 VTL 4/14/20 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Teo IfInIc i DATE: 10/10/19 P. I. Supervisor FROM: Matt Herrera SUBJECT: P&A Site Clearance Petroleum Inspector KRU 1D-136 CPAI PTD 2000460 10/10/19: 1 traveled to Kuparuk 1 D -Pad and met up with CPAI rep Roger Mouser. KRU 1 D-136 was previously abandoned in July -August 2019. Site inspection after burial of the abandoned well shows no visible signs of leaks or subsidence. KRU 1 D - pad is has active production and injection wells. The location was verified by its position between wells KRU 1 D-08 and KRU 1 D-137, and by the drillsite map made available by Mr. Mouser. Attachments: Photos (2) 2019-1010_Location_KRU_1 D-136_mh.docx Page 1 of 2 6 ii La. j��T' .� .l ffi -� it �' � , _; � WELL LOG TRANSMITTAL #905876980 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-136 Run Date: 7/31/2019 200046 3 120 6 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-136 Digital Data in LAS format, Digital Log Image file RECEIVED 1 CD Rom 50-029-22955-00 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@haHiburton.com Date: f/I2/" '" l ! Signed: MEMORANDUM Founded on State of Alaska De th To MW Above Alaska Oil and Gas Conservation Commission TO: Jim Regg �.y, ��c� 5055 ft MD' DATE: July 24, 2019 6.9 ppg P.I. Supervisor I OA NA NA NA NA SUBJECT: Well Bore Plug & Abandonment KRU 1D-136 FROM: Austin McLeod CPAI Petroleum Inspector PTD 200-046; Sundry 319-311 Section: 23 Township: 11N Range: 10E - Meridian: Umiat- Drilling Rig: NA Rig Elevation: NA Total Depth: 5680 It MD Lease No.: ADL 25650 Operator Rep: Rory Ober Suspend: P&A: Yes Casing/Tubing Data (depths are MD): Casino Removal: Conductor: 13-3/8" O.D. Shoe@ 110 Feet Csg Cut@ NA Feet Surface: O.D. Shoe@ Feet Csg Cut@ NA Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ NA Feet Production: 5 1/2" O.D. Shoe@ 4952 Feet Csg Cut@ NA Feet Liner: 3 1/2" O.D. Shoe@ 5676 Feet Csg Cut@ NA Feet Tubing: 3 1/2" O.D. Tail@ 4938 Feet Tbg Cut@ NA Feet Plugging Data: Test Data Type Plug Founded on De th Btm De th To MW Above Verified Fullbore Bottom 5055 ft MD' 4600 ft MD ' 6.9 ppg Wireline tag OA NA NA NA NA Initial 15 min 3n min a5 min P.�'df Tubing 1700 1650 1620 1615 IA 30 30 30 30 P OA NA NA NA NA Remarks: On 7/24/19 I traveled to 1D-136, a single cased well, to witness the tag and pressure test of the bottom plug isolating the remaining 43' perforated interval. Fill was previously tagged at 5055', which is what the cement plug ended up being founded on. I was informed that on 7/18/19 1.5 barrels of 15.8 ppg cement was left inside the 3-1/2" to isolate the reservoir after 4 barrels of cement was squeezed into the perforations (top perforation -5012'). The planned top of the cement plug was •- 4887'. Running in the hole with a slickline assembly consisting of a 1-3/4" sample bailer, 1-1/2" weight bar and jars (- 175 lbs) they took weight at 4600' (inclination -44 degrees). Several tags were made -after picking up and tagging again several more times it was determined the top of cement was at 4600', 287' high (-2.4 barrels). Pulling the string to surface they then completed a passing pressure test against the plug with it taking 0.7 barrels to pressure with the same back once bled. Once unstung, they then broke i the tool string down and found cement in the bailer. Attachments: none rev. 11-28-18 2019-0724_Plug_Verification_KRU_1 D-1 36 -am 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-136 Permit to Drill Number: 200-046 Sundry Number: 319-311 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 .aogcc.olaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner rd DATED this i day of July, 2019. aBDMS 1W >U�- o B 1" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 JUN 2'1 2019 1. Type of Request: Abandon 0 Plug Perforations ❑ ' Fracture Stimulate ❑ Repair Well ❑ Operations shutdowrE] Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Strafigraphic ❑ Service Ei 200-046 r 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22955-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? /A KRU 1D-136 Will planned perforations require a spacing exception? Yes El No O 9. Property Designation (Lease Number): 10. Field/Pool(s): a 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: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,680' 4,255' 5680 4255 1500psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 133/6 110' 110' Production 5,646' 51/2 4,952' 3,653' Liner 724' 312 5,676' 4,252' Perforation Depth MD (1t) 113erforation Depth TVD (ft): ITubing Size: Tubing Grade: Tubing MD (ft): 5012-5059, 5094-5140, 5150- 3699-3736, 3764-3802, 3810- 3.500" L-80 4,938' 5173, 5201-5208, 5218-5266, 3830, 3853-3859, 3867-3908, 5287-5363 3926-3989 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - N/A N/A 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 Contact Name: Authorized Title: Wells Engineer Contact Email: Hanna.Sylte@cop.com Authorized Signature:Date: IO 2lD Contact Phone: (907) 265-6342 1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: q Plug Integrity Loj BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No 01< Spacing Exception Required? Yes ❑ No Subsequent Form Required: /D `4l% RBDMSl�W JUL 0 B 2019 &07� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: VTL-7/Z/!y ORIGINAL o 2� //IIIQI lRe /201 t 1 Subs in Form and Fonb&403 Revised a/2o3) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate , � `PO6 6-1,zsltg ConocoMillips Alaska, Inc. KUP INJ WELLNAME 1D-136 WELLBORE 1D-136 aid WD' +0.+36, Naval it ism AN Last Tag va'tial veweesexnnn Annopaon owdauv81 1 EMOaIe WellEore LaxiMM aY Last Tag: RKB dahm 43of Open Perls) I 5,055.0 lo2cui9 'll IzNpnladgj Last Rev Reason -.. __ ....................... Annolalion I End Oefe I WeIIWre I Leaw. ay Rev Reason'. Updated Tag Depth (Tubing Resbipeon) 6/22019 iD-136 Jumped Casing Strings HANDED xeJ casing DesuipeOn CONDUCTOR DD pp 1J 318 IG ImL rep MRel 12.51 310 see DePtn (rlAel se 110.0 110.0 Depin trvDl-. WULen O... code top Tnreaa 62.58 H-00 WELDED penes Daxalpbon PRODUCTION 5.5x3.5 OO (in) 51/2 Il iaP hated 4.95 30.0 ant Oepm peel sel 5,6]5.9 4,2519 Depth lrvol... WULen I1... Grade iopID 15.50 L-80 BTC -MOD 1EADOcPok: ai Ones ToStrings tubing 0. rdeon Stria 110 (1,) Top lXNel sin lxPLn lX.. sel Depth lrvol l... WlnIJ111 GRtle Top eonn6lion TUBING 31/2 2.99 26J d,951.8 3,fi529 930 L -BO EUEBRDMOD Tueyplyngen.nt.. Completion Details Top RVED mp Incl NID dial To, IhRS) mRe) In Imm Des coin tD linl 28.7 287 0.10 HAN ER VETCO GRAY HANGER 3.500 4.8996 3,610.4 43.50 NIPPLE 'AMC'DS NIPPLE 2813 4,938.1 3,642, 41.96 LOCATOR BAKER 80-00 eH-22LOCAme, 35W 4,939.9 3,6440 4190 SEAL ASSY SEALASSEMBLY 3500 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) IDP IrvD) Top Incl WS UFT: 4.NTs To(d al {XXB) C Oex Com ftun Dale +011nl 259.0 259.0 1.22 Tubing Tubing Impingement(largest secure plug Nal can 61212019 2120 Inpingement cunendy be set is 180' Hex Plug) CSG PATCH SURFACIECASINIGHPAICH'. PROACTIVETil 1091 5500 WELD ON IA. SEAL WELDED CASING AND 6 NIPPLE. a post 6- MANDREL HANGER. WELDED TWO 5" BANDS AND 56" SLEEVE ON IA CASING FOR A TOTAL PATCHED AREAOF61.5'. PUMPED GROUT INTO SLEEVE VOID AND SEAL WELDED THE PLUGS. 10/292006 Perforations & Slots snot Dene LOCATOR', da'A.1 Top Mae) Topa-I elm(Ma) mae 1 etm(Twl gl735 LNM1D Oace Ixnatxm 1 LN'RF Com 5,012.0 5,0590 3,698.] 3,735.6 IM RM 1D-136 &1I20D0 4.0 IPERF .5"H DUNE{et DP,W deg phasing IDEA. ASSY: 4.M 9- 5,094.0 5140.0 3.763.9 3,MT.T WS B. JD -136 8112000 d0 IPERF .5"H DUltraI DP, 60 deg phasing 5,1500 S, 1730 3,810.3 WSA4,10-136 8112000 40 IPERF5"H DUft -jeD deg Phasing 5,2010 52080 7853.1 ,850 WSA3,1D-136 ]!312000 4.0 IPERF 5'HDOPChgs,6 eg ph 5,2180 ON0 3,867.5 0]. WS A3, 1D-136 7131/2000 40 IPERF 2.5"HSD DP DID, eg Ph 5,287.0 5363.0 3,925.6 3.9699 WS A2. ID -1 36 0312000 1 40 on," 2.5"HSDDPChgs, ag IPERF', s,M305,019.0 1 Ph Mandrel Inserts sl xl an Tappets) lfll(el Tap(NOI laltal mala McdN OD PnI sery Valve TyPo Lake Type(In) Pod9b Tib Run 4.11 Bunoale Lom 11 4,8415 3.5]).2 CAM O 1 GASLIP' DMY INT 0.000 00161 00 9 1 Notes: General & Safety End Dah An.,00ken IPERP: E..Cg1.Oa,+ego 8202010 NOTE: View Schematic w/ Alaska SchemaRc90 IPERF: atSaOs,+Tap- IPERF: Is. Oa,yy.P- IPERF: Naa0. aim IPERF spur bases O0 ee- PROq.GTWN sYf 5', 300- 16sl sol Current Completion JI I I I L 1 D-136 Plug and Abandon PTD # 200-046 16", 62.5#, H-40 Conductor to 110' KE 5.5", 15.5#, L-80 Surface Casing to 4930' 3.5", 9.3#, L-80 Tubing & Liner to 5676' 3.5" Tubing restriction exists at —259' K Cannot pass BHA's bigger than 6' OAL x 1. Failed MIT -IA 6/25/19 Suspected shallow casing leak Tbg & IA Diesel Filled with Diesel GLM w/DV at 4,847' KB Tubing Punches at 4,870' KB 2.812" DS Nipple at 4,899' KB Seal Assembly at 4,939' KB Top of Fill tag at 5,055' KB (6/2/19) Paris Open: WS D 5012'-5059' KB WS B 5094-5140' KB WS A4 5150'-5173' KB WS A3 5201'-5208' KB WS A3 5218'-5266' KB WS A2 5287'-5363' KB 3.5", 9.3#, L-80 Liner 4930'- 5676' KB Proposed P&A A Cement Top Job lent Plug #2, f Arctic Set 1 Cement, 7KB in Tbg&IA gBB � t Plug #1, Class G, r at 4887' KB, 5 a Cement in ner 3887' KB, Ce in arfs 5051 HS 6/25/19 Proposed Procedure for 113-136 Plug & Abandonment to Surface It is proposed that 1 D-136 well work be performed to cement squeeze the perforations. The cement squeeze would be followed by a MIT -T to verify that the formation is isolated. The tubing would then be perforated to allow for circulation and 1 D-136 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 1 D-136 is backfilled and buried. Well History: 1 D-136 West Sak injector was drilled and completed in May 2000 as a single casing well with 5.5", 15.5#, L-80 Surface casing to 4930' RKB. The tubing is 3.5", 9.3#, L-80 to 4951' RKB where seals are stabbed into a 4" ID Sealbore Extension at XO in 5.5" x 3.5" Casing. The liner is 3.5", 9.3#, L-80 which extends from an XO at 4930' RKB to 5676' RKB. This well also has a proactive surface casing patch that was welded on the IA in 2006. 1 D-136 was on injection at —191 BWPD, —1100 WHIP to West Sak A2, A3, B, and D sands until 5/10/19. On 6/2/19 a subsidence drift was performed, which determined the largest secure plug that could be set is 1.8" HEX plug past an obstruction at 259' RKB. Fill was tagged at 5055' RKB towards the bottom of the D sand perfs (43' of perfs open). On 6/25/2019 an MIT -IA failed with a liquid leak rate of 9.66 gpm at 55 psi. Due to the tubing restriction at 259' RKB, a decision has been made to proceed to Plug and Abandon 1 - 36. This proposal is for well work to place cement into the formation through the perforations to be followed by an MIT -T to verify that isolation exists from formation. Next, the bottom of the tubing will be perforated to establish circulation and the wellbore will be filled with cement to surface, followed by removal of the wellhead. An ID plate will be welded onto the casing and then the well will be buried. Safe access with coil tubing or wireline tool strings bevond the tubing restriction at —259' RKB does not exist to remove fill from the B sand or A sand perf intervals covered by fill to enable a cement squeeze of these perf intervals. Thus, this procedure proposes cement squeezing only the perforation intervals that are open above top of fill at 5055' RKB. 113-136 Proposed P&A Procedure Job Objective: Plug & Abandon 1 D-136 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 Top of Fill (TOF): (.0087 x 5,055' RKB) = 44.0 bbls Volume of 5.5" x 3.5" IA: (0119) x (4,939' RKB) = 58.8 bbls IA FP to 2,000' TVD; 2,152' RKB (.0119) x (2,152' RKB) = 25.6 bbls. Tbg FP to 2,000' TVD; 2,152' RKB =18.7 bbls P&A Procedure This procedure calls for first placing a cement volume through the open perfs above TOF at 5055' RKB. Fill covers the A and B Sd perfs at 5,094' — 5,363' RKB, but the D Sd perfs at 5,012'— 5,055' RKB are uncovered. We should be able to get some cement squeezed into the open D pert interval. We do not currently have sufficient remaining access past the tubing restriction at —259' RKB to attempt to remove fill from the lower B and A sand pert intervals that are covered with fill to enable cementing these pert intervals. Thus, the procedure focuses on placing cement only into perforations that remain open above current top of fill at 5,055' RKB. Injectivity Test — Pumping: Objective: Verify sufficient injection rate into formation to place cement plug #1. 1. RU pumping unit. PT Surface Equipment as required. 2. Bullhead —100 bbls seawater (>2x wellbore volume) down tubing to displace diesel FP and any gas that may be in the tubing at a minimum of 1 bpm or max rate achievable below while staying below 1500 psi. 3. Perform step rate injectivity test with seawater for 2-3 flatlined rates. a. Do not exceed 1500 psi or 2bpm b. Record the injection rates & circ pressures in WSR 4. Pump 20 bbls of diesel to FP tubing (2152' MD x.0087 bbls/ft = 18.7 bbls). 5. Prior to pumping cement plug #1 confirm with engineer that sufficient injection rates have been established. Fullbore Cement P&A Plug #1 - Pumping: Objectives: Fullbore 5.5 bbls Cement to put —4 bbls of cement into open perfs above fill at 5055' RKB, and leave --1.5 bbls Cement under -displaced in 3.5" liner to leave a cement top at 4887' RKB (target) to isolate the reservoir with a cement plug, then WOC. Obtain AOGCC witnessed MIT -T of bottom cement plug that isolates the reservoir (as required per regulations: 20 AAC 25.112). 2.992" ID Tubing and Liner Volumes to fill with Cement: In perforations above TOF at 5055' RKB In 3.5" Liner above TOF at 5055' RKB = 0.0087 bbl/ft = Total squeeze volume = 4.04 bbls _ (5055'- 4887')(0.0087) = 1.46 bbls Total 15.8 ppg Class 'G' Cement = 5.5 bbls 6. Schedule pilot testing of P&A cement design. Cement job requires 5.5 bbls of pumpable 15.8 ppg Class 'G' Cement. MIRU Cement Van. Conduct PJSM. Inspect location for pre-existing conditions. Mitigate hazards. Mitigate personnel exposure for PT, and then PT equipment. 8. Pump Stage #1 Cement job as follows: Tubing + Liner Volume to first open D Sand perfs = (.0087)(5012) = 43.6 bbls. Tubing + Liner Volume to top of fill in D Sand perfs = (.0087)(5055) = 44.0 bbls. One barrel in 3.5" tubing fills -115' tubing. a) Pump 120 bbls of Lead Freshwater down tubing into the D sand perfs at lbpm or 1500 psi max pressure. This circulating displaces all Diesel FP from tubing and into formation to get the well ready for the cement job. This should displace any fluid from 3.5" tubing and liner that may contain hydrocarbons (cement contaminant) by injecting it through open perfs to formation. As soon as injection is confirmed at rates of at least 1 bpm, start mixing 15.8 ppg Class 'G' Cement to provide a 5.5 bbl 'pumpable' batch of cement to be ready to pump immediately after the 120 bbl lead volume has been pumped away. As we approach 120 bbls of Lead Freshwater pumped away, adjust pump rate to 1 bpm, and then set volume counter to zero and swap to b) 5.5 bbls of 15.8 ppg Class 'G' Cement down tubing (Cum_Vol = 5.5), followed by c) Foam Wiper Ball for 3.5" Tubing (Cum- Vol still 5.5), d) 5 bbls Freshwater Tail Spacer (Cum Vol = 10.5), followed by e) 5 bbls Biozan Cement Contaminant stage (Cum -Vol = 15.5), followed by f) 32.5 bbls Diesel FP (Cum Vol = 48) slowly decreasing rate during the last few bbis down to zero bpm at shutdown, then g) Shutdown. Do Not Overdisplace Cement. Close Tubing & hold pressure. Do not bleed off any final pressure from the well. At Shutdown, Cum Vol pumped = 48 bbls away, so Wiper Ball (if it was pumped) should be displaced with 42.5 bbls of fluid to put it at 42.5 bbls x 115 ft/bbl = 4887' RKB = 17' below the planned circ holes at 4870' RKB. This means -4.04 bbls Cement was squeezed to perfs and -1.46 bbls of cement remains in 3.5" liner across perfs that were squeezed. At this point we have 32.5 bbls of Diesel in the tubing which is sufficient volume to FP the well (18.7 bbls to 2000' TVD). h) Rig Down & MOL. i) WOC at least 72 hours before performing SL work. Tag TOC and Perform MIT -T & DDT - Slickline I Pumping: Objectives: Tag TOC, State Witnessed MIT, DDT of Tbg 9. WOC per Schlumberger UCA data (minimum 24 hrs) before performing tag & MIT. 10. Notify the AOGCC Inspector at least 24 hrs in advance to schedule Cement Plug #1 tag and pressure testing. 11. Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 12. RU SL. PT equipment as required. 1i 13. RIH & tag TOC in tubing at -4887' RKB. Tag must be AOGCC witnessed. Record results. 14. RU LRS. PT Surface Equipment as required. 15. Perform MIT -T to 1500 psi AOGCC witnessed. Record Results. 16. Perform DDT on Tubing. Record Results. 17. If the MIT -T or DDT fails, contact engineer, to discuss the possible need to pump another Cement Plug #1 job. 18. If MIT -T passed, we will punch holes in the tubing to establish circulation and pump Cement Plug #2 placement. 19. RD & MOL. Tubing Punch - Eline/DSL: Objective: Punch holes in 3.5" tubing to establish circulation prior to pumping cement plug #2. "Note - Depth of tubing punch below based on calculated TOC. Will adjust as necessary based on where top of cement is tagged 20. RU Eline. RIH with Dummy Tbg Punch Drift BHA of 1.375" max run OD. E -line Well Supervisor has discretion to alter drift BHA configuration if needed to further enhance ability to attain successful Dummy drift. If difficulty is encountered getting BHA past restricted tubing at -259, call engineer to determine path forward. RIH to Tubing Punch 'target' location at 4870' RKB. POOH with Dummy Drift BHA. 21. RIH with actual 1.375" max OD Tubing Puncher BHA configured to mimic Dummy Tubing Puncher Drift BHA that successfully drifted to target Punch location (step 20). Locate Puncher to shoot holes in Tubing at 4870' RKB to IA. Fire the Puncher. POOH with Puncher BHA. Verify ASF. 4 22. RU pumping unit. Pump a short (-10 bbls) step rate circulation test by pumping Diesel down Tubing while taking Diesel returns off IA to tanks, but do not exceed 1500 psi max WHIP. The overall volume is limited to —10 bbls due to the leak in the 5.5" casing. a. 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. This test is to determine if we have adequate circ rate vs. WHIP for a Cement P&A job, or do we need to shoot more punches. Ideally for the P&A it would be nice to see we have ability to circ to 2 bpm below 1500 psi. If we see an unacceptably low circ rate, we will need to shoot more punches. 23. 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. Fullbore Cement P&A Plug #2 - Pumping: Objective: Fuilbore cement down Tubing and up IA to cement fill the tubing and IA to surface. Note: 1 D-136 failed an MIT -IA on 6/25/2019. 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 15.7 ppg Arctic Set 1 Cement = 0.0087 bbl/ft = 0.0119 bbl/ft _ (4870'* - 0')(0.0087) = 42.4 bbls _ (4939'- 0')(0.0119) = 58.8 bbls = 10.1 bbls = 111.3 bbls Due to the leak in the 5.5" casing, Arctic Set 1 cement is being used instead of Class G. The shorter setting time will decrease the amount of cement lost to the casing leak which will decrease the likelihood of needing to perform a top job. *Note — tubing punch depth may change based on actual tagged TOC of plug #1 24. Verify with engineer that circulation testing results (per step 22) look good to perform a P&A before starting work on the cement job. 25. Schedule pilot testing P&A cement design. Cement job requires 111.3 bbls of pumpable 15.7 ppg Arctic Set 1 Cement. 26. MIRU Cement Van. Conduct PJSM. 27. 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. Tie in cement wash up lines, and isolation valves that will allow for surface lines to be flushed when cement is seen to surface. 28. Mitigate personnel exposure for PT, and then PT equipment as needed. 29. 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 111.3 bbls of'pumpable' 15.7 ppg Arctic Set 1 Cement while pumping away the Freshwater stage. After the Freshwater stage is pumped away, be ready to swap to fullbore pumping Cement down tubing. 30. Pump 111.3 bbls of 15.7 ppg Arctic Set 1 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 -100 bbls of cement is pumped away (assuming no cement losses to formation). 31. 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. a. Due to the 5.5" casing leak we may not see cement returns to surface; if cement returns are not seen to surface after complete cement volume is pumped: b. Close tubing c. Pump -10 bbls of 9.6 ppg NaCl brine down the IA. This will help ensure we have an adequate flow path through the casing leak (suspected to be around the subsided zone at -259) to pump a top job. 9.6 ppg brine is being pumped instead of freshwater to minimize risk of freezing in the formation outside the casing (TCT point of 9.6 ppg NaCl brine is -0°F). d. Pump 3.1 bbls (259' x .0019) of diesel down the IA to freeze protect down to suspected leak point. 32. Wash up SLB cement pumps. 33. RDMO. WOC 48 hrs. 34. Perform drawdown test on tubing, IA, and OA. Proceed to Wellhead Excavation and Final P&A work steps. Wellhead Excavation / Final P&A: 35. Remove Well House (if still installed). 36. Bleed off TWO to ensure all pressure is bled off the system. 37. Remove production tree, in preparation for excavation and casing cut. 38. If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent lose ground from falling into the excavation. 39. Cut off wellhead and all casing strings at 4 feet below original ground level. 40. Perform Top Job and verify that cement is at surface in all strings. AOGCC witness and photo document required. 41. Send the casing head w/ stub to materials shop. Photo document. 42. Weld ''/d' 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 1D-136 PTD #: 200-046 API #: 50-029-22955-00 43. Remove Cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 44. Obtain site clearance approval from AOGCC. RDMO. 45. 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 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPH &2 <n1617@conocophillips.com> Sent: Wednesday, June 26, 2019 5:46 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1D-136 (PTD 200-046) Report of failed MITIA Attachments: 1 D-136.pdf,, 1 D-136 90 day TIO trend 6.26.19.png Chris, KRU Injection well 113-136 (PTD 200-046) Failed a diagnostic MITIA yesterday. The well has been shut in since May 8, 2019. The diagnostic MITIA was for P&A preparation, which continues to be the current path for the well. Proper paperwork for the work will be submitted once the plan has been developed. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 ELLS TEAM WM cmWcolphMps U MEMORANDUM TO: Jim Regg ~--~ P.I. Supervisor ~ ~~ 7(~l ~O 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-136 KUPARUK RIV U WSAK 1D-136 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~"k-- Comm Well Name: KUPARUK RIV U WSAK 1D-136 Insp Num: mitRCN100718144333 Rel Insp Num: API Well Number: 50-029-22955-00-00 Permit Number: 200-046-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ ]D-736' Type Inj. I`I' TVD 3645 ~ IA 150 ~ 1720 1650 1640 ' ~ P. ~ zoooa6o' TypeTest SPT Test psi I~zo ' OA Interval a~TST p/F P ~ Tubing ~ sso s9o 900 900 Notes: ~dl~ rQy~~ ~~ 15tY>~.~ ~y (~}A ~ ..~p~y,ra hail /7j , Thursday, July 22, 2010 Page 1 of 1 -- ~ ~a~r~s~ ~sayrvmsa~c ~~~evic~, ~~. . • ~~ ~ ~~~ ~ To: AOGCC ~hristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Afaska 99501 (907) 659-5102 RE : Cased Hofe/Open Hole/Mechanical Logs and/orTubing 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 following : ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West Internatianal Airport Road Suite C Anchorage, AK 99518 Fa~c (907) 245-~952 ~ 1) Caliper Reporc 29-Jun-09 1 Q136 1 Repor~ / EDE 50-029-22955-0~~ 2) Caliper Report 30,Jun-09 1 Q111 1 Report / E~ 5Q-029-22911-00 UZ ~ ~°9~ - /G~~o j ~s2~<v v ~ ~ ~ o~ -0~6 l ~ ~ ~'~ Signed : ~ ~ Print Name: ..; ~. . ,. - ~~ Z~t~ ~~~~~~ :s~ ~~u~. ~ ~ E `~ Date : PROACTIVE DIAGNOSTIC SERVtCES, INC., 130 W. INTERNATlONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99598 PHONE: (907j245-8951 Fax: (907~245~8952 E-PAAIL : _ YVEBSITE : ~ C~,DocumenCs and Settings\Owner\DesktoplTransmit_Conoco.docx il ' ~'ll ~ I ~ ,, ~ i ~ Memory lVlulti-Finger Catiper Log Results Summary Company: ConocoPhillipsAlaska, Inc. Well: 1D-136 Log Da#e: June 29, 20Q9 Fieid: West Sak Log No. : 7339 State: Alaska Run No.: 2 API No.: 50-029-22955-00 Pipe1 Desc.: 3.5" 9_3 Ib. L-80 EUE 8RD Top Log Intv(1.: Surtace Pipe1 Use: Tubing and Liner Bot. Log Iritvl1.: 5,016 Ft. (MD) ~ Inspection Type : Buckling & Corrosive & Mechanical Damage lnspection ' COMMENTS : This caliper data is tied into the DS Nipple @ 4,9U0' (Driller's Depth). , This log 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" tubing and liner toggeci are in good to poor condition, v~th a maximum recorded walt penetration of 65% recorded in an area of corrosion in joint 143 (4,46T). Wall penetratiuns from 20% to 61% wall thickhess are recorded in 126 of the 163 joints ' logged. Recorded damage appears as a line of pits ftom ~950' to -1,310' and a line of corrosion from ~1,310' to ~4,000', eventually broadening into general corrosion irom ~4,000' to 5,016' (EOL). No significant areas of cross-sectional wall loss or t. D. restrictions are recorded #hroughout the tubing and liner logged. ~ The caliper recordings indicate no significant buckling throughout the 3.5" tubing and liner logged. A log plot of the centered and off-center 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 current and previous log (July 31, 2005) indicates no change in corrosive damaga during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by-joint basis beiween the current and previous log is included in this report. ,, 3.5" TUBING ~ LINER - MAXIMUM RECORDED WALL PENETRATIONS: ' Corrosion ( 65%) Jt. 143 @ 4,467 Ft. (MD) ', ~ Corrosion ( 61%) Jt. 145 ~ 4,552 Ft. (MD) Corrosion ( 57°r6) Jt_ 151 t~ 4,729 Ft. (MD) Corrosion { 57°~) Jt. 139 @ 4,351 Ft. (MD) Corrosion ( 57%} Jt. 141 @ 4,420 Ft. (MD) I~~' , 3.5" TUBING 8~ LINER - MAXIMUM REGORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded thraughout the tubing and liner iogged. ~ ~~ _ 3.5 I 1 TR 1 N: I TUB NG +& LINER MAXIMUM RECORDED D RES ICT Q S No significant I.D. restrictions are recorded throughout the tubing and liner logged. ' ~ ' ~ Field Engineer. Wm. McCrossan Analyst: C. Wa/drop Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. f P.~i. Box 1369, Stafford, TX 77497 Phone: (281) qr (888} 565-9085 Fax: (281} 565-13b9 E-mail: PDS;a~memorylog.com ' Prudhoe Bay Field Office Phane: (907) 659-2307 Fax; (90?) 659-2314 ~ ~ (~T ~ ~' p(~ -~~~o ~ '~c7~~" ' • • \.~~ PDS Multifinger Caliper 3D Log Plot I' Company : ConocoPhillips Alaska, Inc. Field : West Sak Well : 1D-136 Date : June 29, 2009 , Description : Detaif of Centered and Off-Center Caliper Recordings from Surface to 1,000' Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750R ~ 2500 3500 0° 90° 180° 270° 0° 0° 90° ~180° 270° 0° Min ID (1/1000 in.) 2500 3500 Nominal ID (1/1000 in.) ~ ................................................................. t 2500 3500 Tree 1 Pup Jt. _I „'~.~.~"` ~ ~ Joint 1 50 _. ~ ; I :i , ;~ . _ . ~,'.. ` `_ :. ~,w _ yW ;i Joint 2 , .'"~~~ S ~`, :,,-'~ _ ,~ 100 ~,~•.,.z„ ~ ~-6: _... - - ___ ~ _ ._ w._'~ , . ~ Joint 3 ~.._ ~ ~~ y `i Joint4 -~_ -- ~._. . ~,.. ~ ^,':,,.»~°`°'" ;~ 150 ,.,~~~-:: ~.._.._. ~ ~~. Joint 5 ' ~ - . s~ Joint 6 20Q '~ Joint 7 , __ - 250 i -' Joint 8 Joint 9 ' 300 Joint 10 -- ~ i 350 _ Joint 11 ~ - + , i ,_, , Joint 12 _. 400 ; - Joint 73 - - , --- h~ ~9 ,loint ~a 450 ~ ' ;~: ~ ' • • Joint 75 - ;s 500 _ ___ . Joint 16 -+ Joint 17 550 --t-- ~._.~,. :~ Joint 18 ~ 6~0 Joint 19 ~ ~ - Joint 20 -- - ~ - 5 6 0 ~ : ~ J i 1 L ' j o nt 2 ~ ? ~ 7 ~ .~~x:.,~ _ 's, Joint 22 0 y 1 Joint 23 - - _ ~.y.,_ . __ ~ Joint 24 75~ , - ~- ._...._ x. ~ - Joint 25 800 ~ _ - . i Joint 26 ° rr„w,,,,. ,. ~..~,,,,,;, ,, _ ~ ~ - _ ..,.,~ , ~. 850 _;_,_, ~ _. ~ ,..,4. Joint 27 ~ . ~ _,_ n ~ Joint 28 900 F Joint 29 - -~ l i 30 950 ~ . o nt y :t: :~ --- ,.,~ m.~.~---.. _ , Joint 31 . ~ ~:_ _. __;_ _; _.. '" ~ Joint 32 ~ Q~~ Nominal ID (1H000 in.) ... ............................................................ 2500 3500r Min ID (1/1000 in.) 2500 3500 Comments Depth Max ID (1N000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750ft 2500 3500 0° 90° .180° 270° 0° 0° 90° 180° 270° 0° • • Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (23.1' - 4992.7') Well: 1 D-136 Field: West Sak Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: June 29, 2009 ^ Approx. Tool Devia6on ^ A pprox. Borehol e Profil e 27 623 1247 1867 0 ~ 2492 ~ ~ L V a w ~ 3117 3743 4365 GLM 1 158 4993 0 S O 1 00 Da mage Profile (% wall) / 7001 D eviatio n (degr ees) Bottom of Survey = 158 1 20 40 ~ 60 ,~, a`, .n ~~ ~ ~ " ~ Z ~ ~ ~o ^ 100 120 140 :,: ~ ~ • ` Ma~cimum Recorded Penetration 1 `~- Comparison To Previous Well: 1 D-136 Survey Date: June 29, 2009 Field: West Sak Prev. Date: July 31, 2005 Company: ConocoPhillips Alaska, Inc Tool: UW MFC 24 No. 218370 Country: USA Tubing: 3.5° 93 Ib L-80 EUE 8RD Overla Max. Rec Pen. (mils) 0 50 100 150 200 250 0.1 70 20 30 40 50 60 70 ~ ~ 80 z E ~ 90 100 110 120 130 140 150 156 ~)une 29, 2009 ^July 31, 2005 nl{fP_I'Lt1C2 D -100 -5 iff. in Max 0 0 . Pen. (mils 5 ) 0 100 i 1Q i i 2~ ~ r 30 40 50 ~ i i s i ~ a ~ ~ 60 ~ 80 Z ~ c a 90 100 i 110 120 130 140 i 150 ! 156 ;c -1 ~ s ~ ~_ 1 ~',at~~ i 3 26 mpyl ~ • PDS Report Overview ~~ s. Body Region Analysis Well: 1 D-136 Survey Date: June 29, 2009 field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: U5A No. of Fingers; 24 Ana~ st: C. Waldro ~ Tubing: Nom.OD Weight Crade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-$0 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ;~ metal loss body 150 00 1'.' . 1 50 G~ .:. ~ 0 to 1 to 10 to 1% 10% 20% 20 to 40 to over 40% 85% 85% Number of 'oints anal se d total = 163 pene. 0 0 31 loss 23 140 0 34 98 0 0 0 0 Damage Configuration ( body ) 100 80 60 40 20 0 isOlated ~e~ncr.il linc~ rir~ hole / poss pitfing corrosion corrosion corrosion ib~e hole Number of ~oints dama ed total = 132 11 35 86 0 0 Damage Profile (% wall) ~ penetration body _;~y metal loss body 0 50 100 n GLM 1 Bottom of Survey = 158 Analysis Overview page 2 ~ PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEEf t Q136 West Sak ConocoPhillips Alaska, Inc USA June 29, 2009 Joint No. Jt. Depth (Ft.) I'~~n. U~~~~~i (In~.) Pen. Body (Ins.) I'~~n. ,~~ Gt~ i~~l lu~~ "~~~ Min. I.D. (InsJ Comments Damage Profile (%wall) 0 50 100 .1 23 ~? 0.03 I 3 ~ 2.94 PUP 1 27 ~~ 0.03 13 I 2.91 2 59 (~ 0.04 16 _' 2.91 3 90 ~~ 0.04 I(~ 292 4 122 ~~ 0.03 l i ' 2.91 5 153 ~! 0.03 1 I 2.90 6 184 ~~ 0.04 1 f, I 2.90 7 16 ~~ 0.03 1 I 2.92 8 247 t~ 0.04 I 4 I 2.92 9 279 U 0.04 1~ I 2.91 10 310 l~ 0.03 I-~ ' 2.91 11 341 U 0.04 15 I 2.93 12 373 c~ 0.04 1-1 I 2.92 13 403 ~~ 0.04 1 7 2.89 14 434 ~~ 0.04 I r, I 2.91 15 466 ~~ 0.03 1~I 2.92 16 497 ~~ 0.05 I~) ~ i 2.89 17 529 U 0.03 13 I 2.90 18 560 ~~ 0.0 15 I 2.92 19 592 l~ 0.03 11 ~~ 2.92 20 623 t) 0.03 13 ' 2.92 1 655 (~ 0.03 1 Z I 2.89 22 686 ~! 0.03 12 I 2.91 23 718 ~~ 0.04 1 a I 2.92 24 748 ~~ 0.04 1~~ I 2.92 25 779 ~~ 0.04 1; I 2.92 26 811 ~~ 0.04 14 I .92 27 842 ~~ 0.03 11 ~' 2. t 28 873 t~ 0.05 lt~ 1 .90 29 904 t? 0.06 <; ; 2.91 Isolated ittin . 30 935 ~~ 0.07 Z(~ 1 2.91 Line of its. 31 965 ~! 0.04 17 I 2.92 32 997 U 0.06 ~5 I 2.91 Vne of its. 33 102 7 i~ 0.05 1 ti I 2.91 34 1058 (~ 0.07 1~ I 2.92 Line of its. 35 1090 t~ 0.11 45 2.92 Line of its. 36 1121 t~ 0.07 ~~(> ? 2.92 Line of its. 37 1153 ~~ 0.08 i:~ Z 2.91 Line of its. 38 1184 t~ 0.12 45 > 2.91 Line of its. 39 1215 t~.(1- 0.10 a[) _' 2.91 Line of its. 40 1247 !~ .10 ~~> ' 2.92 Lin of its. 41 1278 t~ 0.11 ~35 ~' 292 Line of its. 42 1310 t~ 0.11 4;~ 2.91 Line corr sion. 43 1340 ~~ 0.10 a(1 ~' 2.91 Line corrosion. 44 1371 ~~ 0.10 ~~) i 2.91 Line corrosion. 45 1402 ~~ 0.11 43 .? 2.91 Line corrosion. 46 1434 ~~ 0.10 4l1 3 2.91 Line corrosion. 47 1464 (? 0.12 46 4 2.93 Line corrosion. 48 1495 U.U> 0.12 4(, ~ 2.93 Line corrosion. 49 1524 ~~ 0.11 -1.~ 2.90 Line corrosion. Lt. De >osits. Penetration Body Metal Loss Body Page 1 • PDS REPORT JOINT TABI, Pipe: 3.5 in 93 ppf L-80 EUE SRD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 D-136 West Sak ConocoPhillips Alaska, Inc. U SA )une 29, 2009 Joint No. Jt Depth (Ft.) I'r~n. U~,s~~l Ilii,.~ Pen. Body (Ins.) f'en. `%> ~1c1,a1 loss `i~, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 0 1555 ~) 0.13 5(1 4 2.92 Line corrosion. 51 1587 O 0.1 51 ~ 2.91 Line corrosion. 2 1618 U.Ub 0.12 ~1f1 , 2.92 Line or osion. Lt. De osits. 53 1648 ~~ 0.14 55 5 2.91 Line corrosion. 54 1679 ~? 0.14 55 i 2.92 Line corrosion. LL De osits. 55 1711 U 0.12 4b 2.90 L'ne corr sion. 56 1742 U 0.12 4i -1 2.91 Line corrosion. 57 1773 U 0.12 4t~ > 2.92 Line corrosion. 58 1804 l) 0.14 54 ~ 2.93 Line corrosion t. De sits. 59 1835 ~~ 0.12 47 ~l 2.92 Line corrosion. 60 1867 O 0.11 43 ; 2.93 Line corrosion. 61 1898 U 0.12 46 -1 2.92 Line corrosion. 62 1929 l?.0~~ 0.12 4~) 2.91 Line corrosion. 63 1959 (~ 0.11 4 i > 2.94 Line corrosion. 64 1991 ~~ 0.1 -1' 2 91 Line corrosion. 65 2022 ~~ 0.12 -1(, 2.93 Line corrosion. 66 2053 ~ ~ 0.11 4:; i 2.91 Line corrosion. 67 2084 ~~.~~~, 0.10 ~11 -1 2.92 I_ine cnrrosion. 8 2115 i 1 0.11 ~14 4 .91 Line cor osion. 69 2146 U 0.10 41 ~ 2.93 Line corrosion. 70 2178 ll 0.11 42 s 2.92 Line corrosion. 71 2209 ~1 0.13 50 ~~ 292 Line corrosion. 72 2241 ~~ 0.11 43 2.91 L'ne corrosion. 73 2272 u 0.11 ~5 2.91 Line corrosion. 74 2304 u 0.11 -i 1 2.93 Line corrosion. 75 2335 ~} 0.11 -1-1 1 2.91 Line corrosion. lt De sits. 76 2366 ~1 0.10 41 2.93 Line corrosion. 77 2398 i~ 0.11 4 s ; 2.93 Line corrosion. 78 2429 U 0.71 4~' 2.92 Line corrosion. 79 2461 U.U6 0.11 43 S 2.89 Line corrosion. 80 2492 (1 0.11 42 ~ 2.92 Line corrosion. 81 2523 c) 0.13 5~1 -1 2.93 Line corrosion. 82 2555 l1 0.11 4"i -1 2.93 Line corrosion. 83 2586 U 0.09 35 ~ 292 Line corrosion. 84 2617 U 0.09 37 s 2.9.3 Line rrosion. 85 2649 U 0.09 35 t 2.92 Line corrosion. 86 2680 u.(1; 0.13 51 ~ 2.92 'ne corrosi n. 87 2711 ~.05 0.11 42 ~~ 2.92 Line corrosion. 88 2742 U 0. 0 41 =1 2.91 L'ne co rosion. 89 2772 U 0.11 41 t 2.91 Line corrosion. 90 2803 c? 0.10 3~~ i 2.92 Line corrosio . 91 2835 U 0.1 l <12 ~ 2.92 Line corrosion. 92 2866 t? 0.09 i7 2.93 I.ine corrosion. 93 2897 ~~ 0.09 3 t S 2.92 Line corrosion 94 29 9 U 0.10 i~l 3 2.93 Line corrosion. 95 2960 U 0.11 ~-~ -J 2.92 Line corrosion. 96 2991 ~~ 0.09 ~4 -l 2.92 Line corro ion. 97 3023 ~~ 0.12 46 i 2.93 Line c.orrosion. 98 3054 (1 0.09 3i > 2.94 Line corrosion. 99 3086 ~) 0.11 45 t 2.91 Line c,orrosion. Penetration Body Metal Loss Body Page 2 ~ PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: . iLATION SHEEf 1 D-136 West Sak ConocoPhillips Alaska, Inc. USA )une 29, 2009 Joint No. Jt. Depth (Ft.) I'c~~i. ll~~,~~t Iln..) Pen. Body (Ins.) Pen. % ~~1~~t,~l Ic>~s °4, Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 100 3117 ~~ 0.09 37 S .93 ine corrosion. 1 1 3148 t) 0.11 42 ' 2.93 Line corrosion. 102 3180 t~ 0.08 32 ,' 2.91 Line corrosion. 103 321 1 i ~ 0.14 55 ~~ 2.93 Line corrosion. 104 3243 U 0.09 3? ' 2.93 Line corrosion. 105 3274 ~~ 0.11 45 ! 2.93 Line corrosion. 106 3304 u 0.08 32 ~,' 2.92 Line corrosion. 107 3336 ~~ 0.1 4i _' 2.92 Line orros'on. 108 3367 U 0.1 41 S 2.93 Line corrosion. 109 3398 U 0.10 41 > 2.93 Line rrosion. 110 3429 U 0.11 42 ~ .92 line co rosion. 111 3460 l1 0.12 ~l~) _' 2.92 Line corrosion. 11 3492 O 0.11 d_i _' 2.93 Line corrosion. 113 3523 U 0.11 44 ' 2.93 Line corrosion. 114 3555 l).U6 0.12 46 -1 2.92 Line corrosion. 115 3586 l~ 0.11 ~i:i ' 2.93 Line corrosion. 116 3618 U 0.08 t3 ~' 2.91 Line corrosio . 117 3649 ~~ 0.09 34 ' 2.90 Line cor osion. 118 3680 ~~ 0.11 44 2.94 Line corrosion. 119 371 1 U 0.10 -t1 2.93 Line corrosion. 120 3743 +? 0.10 3`J ~ .89 ~ine corrosion. 121 3774 ~~ 0.10 4U 2.93 Linc corrosion. 1 2 3805 u 0.09 37 2.93 Line corrosion. 123 3837 U 0.12 4b 2.93 Line corrosion. 1 4 386 ~~ 0.10 ~ti ; .8 Li corros~on 125 3899 t~ 0.11 44 > 2.93 Line corrosion. 126 3931 U 0.10 39 t 2.94 Line corrosion. 127 3962 ~~ 0.13 5 I i, 2.93 Line corrosion. 128 3994 U 0.11 ~~l ~, 2.92 Corrosion. 129 4025 U.~~(> 0.14 55 2.91 Corrosion. Lt. De osits. 13 4055 U.~15 0.11 ~l_i 2.93 Corrosion. Lt. De osits. 131 4085 ! 1 0.12 ~1t~ -1 292 Corrosion. 132 4117 ~~ 0.14 55 (~ 2.92 Corrosion. 133 4148 ~~ 0.12 4~3 ; 2.91 Corrosion. 134 4179 U 0.11 45 ~l 2.91 C rrosion. 135 4211 (> 0.12 46 4 2.91 Corrosion. 136 4240 O 0.12 4.5 ~i 2.91 Co rosion. 137 4271 U.u_; 0.12 ~~~ (~ 2.91 Corrosion. Lt. De osits. 138 4303 U.Ub 0.13 51 ~, 2.91 Corrosion. t. De osits. 139 4334 U.U6 0.14 S7 ~ 2.93 Corrosion. Lt. De osils. 1 4365 O.i)7 0.13 5) 4 2.92 Corrosion. . De osits. 141 4397 l~ 0.14 57 5 2.91 Corrosion. Lt. De osifs. 142 4428 U.~?' 0.14 5-~ 5 2.91 Corrosion. 143 44 9 {~ 0.17 (> i i 2.90 Corrosion. Lt. De osits. 144 4490 ~? 0.13 ~1 t~ 2.92 Corrosion. Lt. De osiLs. 145 4522 i~ 0.15 (i1 5 2.93 Corrosion. 146 4553 O 0.1 -~8 -l 2.92 Corrosion. Lt. De osits. 147 45$5 ~?.i ~6 0.13 i i 2.93 Corrosion. 148 4615 0.14 "~.1 2.92 Corrosion. Lt. De osits. 149 4646 0.13 2.94 Corrosion. Lt. De osits. Penetration Body Metal Loss Body Page 3 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: Body Walt: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEEf 1 D-136 West Sak ConocoPhillips Alaska, Inc. USA June 29, 2009 Joint No. Jt. Depth (Ft.) I'~~n. l1psE~t Itn,.) Pen. Body (Ins.) I'en. % :'vtct,il Loss ~~~~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 150 4677 U.US 0.12 4~~ 5 .92 C rr sion. t. De osits. 15 4709 t? 0.15 57 i 2.92 C rr sion. t. De o its. 15 4740 t~.ut3 0.13 51 (, 2.93 C rrosion. Lt. De osits. 153 4772 ~~.U£S 0.13 i1 !~ 2.92 C rr sion. . De o ils. 154 4802 ~~ 0.11 ~13 5 .93 C rrosion. 154.1 4833 ~~ 0.11 -l ~ ') 2.9 rros on. 154.2 4848 ~~ 0 t l ~ 1 N A M 1 L tch ~ 12 : 0 154. 4854 t~i 0.10 ~~~) £1 .95 PUP Corrosion. 155 4869 c1 0.11 ~35 6 2. Corro ion. 155.1 4900 (~ 0 0 U .81 Cam o DS-Ni 156 4902 t~.US 0.10 39 5 2.94 Corrosion. 156.1 493 O 0.1 4(i 3 2.88 PUP Corrosi n. 156.2 4938 ~? 0 U U 3.00 Baker GBH-22 Seal Assembl 156. 4950 ~~ 0 ~) ~! 3.00 Baker Seal Bore xtension 156.4 4952 u.tits 0.12 4~~ s .94 PUP To of 3.5" Li er. Corrosion. 157 4962 U 0.11 -1 i 5 2.89 Corros on. t De osits. 158 4993 ~).U(~ .10 3£i 6 2.90 Corrosion. t De o i. _ Penetration Body Metal Loss Body Page 4 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ PDS Report Cross Sections 1„ - ~~ „ Well: 1 D-136 Survey Date: June 29, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA \'o. of Fingers: 24 T~bina: 3.5 ins 9.3 ppf L-80 EUE 8RD Anaivst: C Waldrop Cross Section for )oint 143 at depth 4467.25 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 93 % Tool deviation = 60 ° Finger 19 Penetration = 0.165 ins Corrosion 0.17 ins = 65% Wall Penetration HIGH SIDE = UP ~ • Cross Sections page 1 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ! ~ ~~M ~ PDS Report Cross Sections ~ ,. Well: 1 D-13b Survey Date: June 29, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tooi Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 9.3 f L-80 EUE SRD Anal st: C. Waldro Cross Section for Joint 145 at depth 4552.46 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 98 % Tool deviaNon = 59 ° Finger 23 Penetration = 0.154 ins Corrosion 0.15 ins = 61% Wall PenetraNon H~GH SIDE = UP ~ i Cross Sections page 2 ~~ KUP ~ 1 D-136 ~OI'lOCO~'11~~IpS Weu Amibutea ~ wexeae ~ vwrw Rew neme wai seaais vromd wex iype ~~ f9 ~ I ~W T~ t~d M.- 50029229 5500 WESTSAK INJ PWI 61.85 3,085.37 5,680.0 Cammuil N (ppn) on e[e I~~GA (~q 9 Nmse e e on ~ .; ,5'~ „N ~ SSSV: NO NE 0 7f1l2008 Last WO: 31 40 517/2000 . .na .~ 1 tl ate n are LastTap: CTMD 5,500.0 11/7/2008 RevReasortFCO 11/8l2008 Casin Stri s caw,y o esapuon senn~ t~+1 o PN Top pncs~ sn I~el ~ P~1 P~q ~ aer~y r mra CONDUC OR 1 6 1.062 0.0 110.0 110.0 62.58 H-40 WELDED SURFACE 512 4.950 0.0 4,952.0 3,655.5 15.50 L~0 BTCM lJN R 311 2 2.992 4.948.0 5.676.0 4251.5 9.30 L-80 EUE 8RD Tubf Stri PATCH, 10 Q~ ~ D esalplon (N) M) Toph11C6) (~K6) (~B) pbNq fi'atl e SIMpT MO TUB NG 3 1! 2 2.992 0.0 4.941.0 3,648.0 9.30 L~0 EUE9rd Other t n Note A ll Jewei : Tubi Run & ReMevaW Flsh etc. CONWCOR, ~~ (1V~ TpP tto Top P~) kKIP) oesapwn Commet 1Unuate D 1 ~ . 10.0 70.0 0.03 PA CH URFACE CASING PATCH: PROACTIVE PATCH WEID 1029/2006 5.500 ~ ON IA SEAL WELDED CASING AND MANDREL HANGER. WELDED TWO 5" BAN0.S AND 56' SLEEVE ON IA CASING FOR A TOTAL PATCHED AREA OF 61.5'. PUMPED ~~s ~iFT. GROUT INTO SLEEVE VOID AND SEAL WELDED THE d,e°~ PlUGS. 10/29l2006 4.847.0 3,5782 4521 GAS LIFT CANICO G2•9l1lDMV/INT/// Comment STA 1 &132000 2.920 ~ ~~~ 4.900.0 3,614.9 43.32 NI lE CAAACO D NIPPLE 5(7f20 2.813 ` ' i~ 4.941.0 3,648.0 43_44 SEAL BAKER GBH-22 SE/1L ASS MBIY 5f)/2000 3.5~0 Perfora Aia~s NIPPLE.4900 Top~TVD) B~~TW) ~d ~ T !Un 1~01 l~N Zone D~ee l+h- Ca mie~t ~~ 5.012.0 5.059.0 3,698.9 3,734.9 WS D, iD-136 &7/2000 4.0 IPERF 2.5" FISD Ultrajet DP. 60 deg phasing ~ 5,094.0 5,140.0 3,763.7 3,802.O WSB,ID-136 &1Yt000 4.O IPERF 2.5"HSD N,aje P~9 tDP,60deg 5,150.0 5,173.0 3,810.4 3,829.7 WSM.1D-136 &1l2000 4.0 1 RF 2.5'HS UWajetDP.60deg s~.avni P~9 5,201.0 5,208.0 3,8532 3,859.0 A1, 10.136 7/31lZ000 4.0 IPERF 2.5" HSD D~ Chg s, 60 deg ph ,218.0 5,286.0 3,867.5 3.907.9 WS A1, 10.136 7/3112000 4.0 IPERF 2.5' HSD DP qg s, 60 deg ph ,287.0 5,363.0 3,925.6 ~,989.4 WS A2, 1D-136 713112000 4.0 IPERF 2.5" H50 DP Ch gs, 60 tleg ph SURFPCE, 4.851 IPERF, 5,072-5 O54 IPERF. 5.094-5.160 IPERF, 5,150-5,1]3 ! IPERF. ~ 5.201-5.108 ~ _~-. IGERF. 5,278-5 266 IPERF. 5.38]-5 363 LINER. 5 6]6 TD. 5 680 • , : ~~ ~~~ ~:._._ ~..~,~- .' ' ~~ ~~ ~~~~~ ~~oA,~~ ~iagn~sric S~a~mri~s, ~n~c_ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, A(aska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Se~vices, Inc. Attn: Robert A. Richey 130 West Internatianal Airport Raad Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1~ MTT Report 16,Jun-09 1 a136 1 Report 2] MTT Report 17,Jun-09 1 D~137 1 Report 50-029-22956-(]0 ~ % ~ '~ OC~ '~ _'---- o ~l~ ~~';i~'t!~~~`~% Ju~. s~ 2~C5 t~ 2 ~- a ~ Signed : Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 !N. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8959 ~Ax: (9075245-88852 E-MAIL : < :~: . . , :.: _ ,i , VNEBSITE : „ - . ~ C:~Documents and Settings\Owner\Desk[op\'Cransmit_Conow.docx ~ ~ ~ ,, Log Results Surnmar~ Company: ConocoPhillips Alaska, Inc. Well: 9D-'136 Log Date: June 16, 2009 Field: Kuparuk Log No. : 10562 State: Ataska RUn No.: 3(2"d MTT) API No.: 50-029-22955-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surtace Pipe1 Use: Tubing Bot. L.og tntvl,: 212 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvi.: Surface Pipe2 Use: Production Casing Bot. Log InNI.: 212 Ft. (MD) Pipe3 Desc.: 16" 62.5 tb. N-40 Welded Top Log Intv1.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 110 Ft. (MD Inspection Type : Corrosive 8 Mechanical Damage lnspection COMMENTS : This MTT data is tied into the Mandre/ Hanger @ 0' 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 thick~ess of ineta! of the 3.5" tubing and 5.5° production casing, as well as influence from the 16" eonductor pipe. Passes at SHz, 8Hz, 10Hz and 12Hz were made at 20 #pm, with the 5Hz and 10Hz passes seleeted for analysis in this report. COMPARISON TO PREVIOUS MTT LOG RESULTS : A comparison of the current 1QHz pass to the previous 10Hz pass (September 26, 2006) indicates no significant loss of inetal thickness during the time between logs. Indications of a significant increase in metal volume are indicated aver the interval (0' - 6'), and a sfight increase over the interval (6' -12'). This increase in metal volume correlates to the surface casing patch (0' -10') installed on October 29, 2006, following the previous MTT log (September 26, 20fJ6). A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log is included in this report, while the most significant areas of inetal loss indicated in the current and previous logs are (isted in the table belaw. Aepth 35' - 4Q' 192' -212' 23' - 32' 120' -146' 148' -189' IVlemory Magnetic Thickn~ss Tool Ma~timum Metal Loss 2009 ti006 6°r6 S% 4% 4% 4°~ 6°r6 Not Logged* 4°~ 4% 4% Descriptlon General Circumferencial metal loss ' General circumferenciaf inetal loss General circumferencial metal loss General aircumferencial metal loss General circumferencial me1a1 toss ' 2006 bg erMed at 192' In the 20061og, a single calibration taken within the conductor pipe was applied to the entire log interval. This resulted in an indication of less metal below the conductor, relative to the interval including the conductor. The current data set was processed using calibrations from both zones, eliminating the appearance of inetal loss below the canductor pipe. In order to support a more consistent comparison ProActive Diagnostic Services, Inc. J P.O. Bax 1369, Stafford, TX 77497 Phone. (281} or (&88) 565-9085 Fax: (281) 5fi5-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (90?) 659-2314 u-r ~ acx~ - vY~ , ~ ~ ',' between the current and previous fog, the previous data se# has been re-processed to include a calibration reference from the zane betow the conductor pipe. A much steadier logging speed (20 fpm) is observed in the current log than the previous log, enhances the ~I' stability of the tool response to the metal volume surrounding it. The added stability and reliabitity of the data ~ecorded at steady 20 fpm is believed to be the cause for some of the sligh# variance between the 2006 and ~ current log results. , INTERPRETATION OF MTT LOG R SULTS : ~ 7he MTT log results cover the interval from surface to 212'. Changes in metal volume are relative #o the calibration points at 50' and 147', where the readings are assumed to represent undamaged pipe. All other readings are rela#ive to these reference points, which include influences from the 3.5° tubing, 5.5" casing, ' and 16" conductor pipe. Log plots of the entire 5Hz and 10Hz passes are included in this report. A maximum overall metal volume loss of 6% is indicated in tubing joint 2(35' - 40') in the 10Hz pass. ' An overlay plot of the average meta! thickness recorded by the MTT far the 5, 8, 10 and 12Hz passes is included in this report. Near the end of the conductor, as much as 3°1o metal loss is indicated by the 12Hz ' pass, while only -1%, relative to the calibration point at 50', is indicated in fhe 5Hz pass. The spread in tool response at different logging frequencies over this interval suggests the metal loss is spatialty closer to the tool, influencing tMe higher frequency fogging passes more. The homogeneity of the tool response to metal loss over various frequencies in the remainder of the conductor pipe interval points to the likelihood that , remaining metal loss intervals may be more evenly distributed between the surtace casing and conductor PiPe. The percent circumferential metal loss expressed in this summary is a percentage of the tota! metal that the , tool is responding to, which includes influences firom the 3.5", 5.5" and 16" pipe. If aii of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than #he numbers expressed. Some of the metal loss indicated could be from either the 3.5° tubing or 16" conductor. ' ~ ~ ' ' Field Engineer: G. Etherton Analyst: HY. Yang & J_ 8urton Witness: R. Ober RroActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax; (281) 565-1369 E-mail: PDSCamemorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ' ' ~ Comparison to Previous M~..og Overlay 1 D-136 ~,~ o~,~~ sE~e, ~~. June 16, 2009 and September 26, 2006 Database File: 1d-136.db Dataset Pathname: 'I h /1 /comp Presentation Format: comparis Dataset Creation: Sun Jun 21 20:34:20 2009 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness ~009 (10Hz) (%) 50 -50 Delta Metal Thickness 2006 (10Hz) (%y 50 0 2009 ~006 Surtace Casi -T_.T.._-- T- -{Installed on ~0 4~ 60 Bottom of 16" 80 •D-136 Recorded Magnetic Thickne~og Data -10Hz Pass (Surface to 212') June 16, 2009 PaoAcilve DL~qnosdc Sewvlces, Inc. Database File: 1d-136.db Dataset Pathname: 10HzPas.1 Presentation Format: 3 scale Dataset Creation: Sat Jun 20 18:57:32 2009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (°/a} 50 3 MTTP01 (rad) 13 0 Line Speed (ftlmin) 200 -5.8 MTTP12 (rad) 4.2 5" 'ace Casing Patch Metal Thickness Tubing Jt. 1 ~0 Metal Loss ~ Metal Loss 4U -Fi.5" Casinc~ Collar Tubing Jt. 2 60 of the 16" Conc 80 Tubing Jt. 3 5" 13.5" 100 Tubing Jt. 4 120 5" 5" Casinq Collar 140 4% Metal Loss Tubing Jt. 5 ~ 5" Tubing Collar-#~ ~ ~~ 4% Metal Loss Tubing Jt. 6 .5° Casing Collar 180 3.5" Tubing Collar -}--~~ -- ° ~ I I t i~`> %o Metal Loss 200 nq Jt. 7 Delta Metal Thickness -5U Uelta Metal Thickness (%) 50 3 0 Line Speed (ft/min) ~00 -5.8 MTTPU1 (rad) M'iTP12 (rad) 13 4.2 •1 D-136 Recorded Magnetic Thickn~Log Data - 5Hz Pass (Surface to 212') June 16, 2009 PnoAe~hre DL~qwosric Seavlcr3„ Ine. Database File: 1d-136.db Dataset Pathname: 5HzPas.1 Presentation Format: 1.4 scale Dataset Creation: Sat Jun ~0 18:42:12 2409 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%} 50 1.4 MTT Phase Shift - Sensor 01 (5 Hz) (rad) 11.4 0 LSPD (ft/min) 200 -7.4 MTT Phase Shift - Sensor 12 (5Hz) (rad) 2.6 Tree Casinq Collar. Pup Patch Tubing Jt. 1 20 5" Metal Loss 4~ -5.5" Casing Collar Tubing Jt. ~ 6U of 16" Conduc sa Ti.ibin~ Jt. 3 ,~~ cas~ln9 I `~ Collar ~~ 100 Tubing Jt. 4 120 3.5" T i.5" C:asing C:olfar 140 Metal Loss Tubing Jt. 5 Metal Jt. 6 5" Casing Collar ~ 180 Metal Loss ~ 200 Metal Thickness I I ffubina Jt. 7 -50 Delta Metal Thickness (%} 50 0 LSPD (ft/min) 200 1.4 MTT Phase Shift - Sensor 01 (5 Hz) (rad) 11.4 -7.4 MTf Phase Shift - Sensor 12 (5Hz) (rad) ~.6 ~z, 8Hz, 10Hz and 12Hz Passes Del~etal Thickness Overlay 1 D-136 June 16, 2009 PROAe~tve Diwqna~srie Seavics, itie, Database File: 'Id-136.db Dataset Pathname: 1l1/1loverlay Presentation Format: comparis Dataset Creation: Sun Jun ~1 20:35:11 2009 Charted by: Depth in Feet scaled 1:154 -50 Delta Metal Thickness 2009 (12Hz) (%) 50 -50 Delta Metal Thickness 2009 (10Hz) (%) 50 -50 Delta Metal Thickness ~009 (8Hz} (%) 50 -50 Delta Metal Thickness 2009 (5Hz} (%) 50 0 Sitrf~re ~0 4~ ~c1 (1 i Bottom of 16" 80 • 100 124 140 160 180 2pQ -50 Delta Metal Thickness 2409 (12Hz) (%) -50 Delta Metai Thickness ~009 (10Hz) (%} -50 ~~' Delta Metal Thickness 2009 (8Hz} (%) -50 Delta Metai Thickness ~009 (5Hz) (%} 50 50 50 50 ~~ KUP ~ 1 D-136 ConoCO ~ Phillips w~n Att~+b~c~ ! wenu«e nrwwi Rda name wex sean,s rromry wex ifpe ma ~•~ no I rocel m Ime~q In... al,r;",' lii ~ 500292295500 WESTSAK INJ PNI 61.85 3.08537 5,680.0 - Conmat H2 (p SSSV: NONE pn) ~a[e [etlon de 0 7/1I2008 Last WO: 31.4q Rlg AeaseD3e 5f7/2000 - a ~,a. Mwtatlon Ce~M (~) E nA Dte DYe Last Ta : CTMD 5,500.0 1111R008 Rev Reason: FC0 l l/8/2008 Casin Sbin cas~ngoesarWon I~I 1~! Tua1~B1 s~c oe~m l~) ) G~ ID~9 tr+ ~ Tapmra CONDUCOR 1 15.062 0.0 110.0 110.0 62.58 H-40 WELDED SURFACE 51/ 2 4.950 0.0 4,952.0 3,655.5 15.50 L-80 BTCM LI ER 31f 2 2.992 4,948.0 5,676.0 4.251.5 930 L-80 EUE 8RD TUbI Strf PATCH, 10 ~~ ~ ~ n,anyoesa~pnon nn~ 1~1 rav1~1 nnW IKKeI 1~~9 crsae s~ TopMU TU&NG 31l 2 2.992 0.0 4,941.0 3,648.0 9.30 L-80 E EBrd Other i n Hole I Jawel : Tu Run S Retriev ~ish etc. CoNOUCOR. ~ RVq 7op ~~o TaPl~) ~a I~'IP) D esalp0on CammarR IMD~e Dh4 10.0 10.0 0.03 PAT CH SURFA E CASING PATCH: PROACTIVE PATCH W D 10l29/2006 5.500 ON IA. SEAL WELDED CASING AND MANDREL HANGER. WELDFD TWO 5" BAN0.5 AND 56° SLEEVE ON IA CASING FOR A TOTAI PATCHED AREA OF 61.5". PUMPED crs uFr. GROUT INTO SLEEVE VOID AND SEAL WELDED THE a.sa~ PLUGS. 10l29/2006 . 4.847.0 3.5782 4521 Gl1S L1FT CAAACO/KBG-2-9I1IDMYANT!// CamienC A 1 6113/Z000 2.920 . 4,900.0 3,614.9 43.32 NIP PLE CAMCO DS NIPPLE 5I7 0 2.813 ~ 4,941.0 3 648.0 43.M SE AL BAI~R GBH-22 SEAL ASSEMBLV 5/7 3.500 ~ Patorations NIPPLE.4,900 ~ rop (Nq Bhn (TVD) &IOf ~ T BUn (~B) I~d) Zone Date (+ti- Co mmevt : i 5,012.0 5,059.0 3,698.9 3,734.9 WS D, 1 D-136 8/1/2000 4.0 IPERF 2.5" HSD Ultra-j2 Ph~~9 t DP, 6U deg ~ ~ 5.094.0 ,140.0 3,763.7 3,802.0 WS B, 1D-136 8/1I2000 4.0 IPERF 2.~ FISD Ultraje P~~9 t DP, 60 deg 5.150.0 5.173.0 3,810.4 3,8 J WS A4, 1D-136 &12000 4.0 IPERF 2.5' D Ultraye t DP, 60 deg sex.a eai D~m9 5.201.0 5.208.0 3,8532 3,859.0 WS N, 1 D-136 7l31/2000 4.0 IPERF 2.5' HSD DP Ch gs. 60 deg pb 5,218A 5,266.0 3.867.5 3,907.9 WS A3, D-036 7l31 000 4.0 IPERF 2.5' HSD DP qg s, 60 deg ph 5,287.0 5.363.0 3,925.6 3,989.4 WSA2, 1D-136 7/31/2000 4.O IPERF 2. 'HSDDPCh gs,60degph SVRFACE. 4 95I IPERf. 5,0123,059 IPERF, 5,086-S,t4o IP€RF, S 150-5 7T3 IPERF, a q ' ~ ~ S,zoi-S,zoa S ~ ~ IPERF, S,I18 ~5 266 IPERF 5,29]5.3fi3 LINER, 5.616 TD, 5,680 Jun 14 09 07:14p FDS Inc • PhitIigs ~Iaslca lnc. s~i~arv oF af~c ~rc+,rrekr coa~arw 3U619UG Tubin~ ar Liner Desc,r~ptPr~n 947~Z314 p.'[8 ... 1IYEl.L: 1Q-'i36 na-rE: ~tsroo '1 OE= 1 PAG~3 3¢ iTEMS G~119PLET~ DESCRIPTlO~! OF ~QI~iPMENT R1'N l~~IGI'H D~PTti N~RDtC RIG #3 RT to L~3S ' 28_(35 Vstco-Gray Tbg. #ianger W/ 3.S" EUE 8rd pup xxx' & Nar.ger 4.5'I' 4_~'1 28,65 ~ Jf. #3-156 3.5" 9_3# t-~0 EUE $rd Pgod tb . 47~,&3 33.16 3_a° 9.3# L-80 EU~ Srd Mod Pup XO BuH mod X Eue Box 1 d.ti6 d832.T9 GLM 3.5" X 1" Camco'KB+G 2-9" w1 DCl43 latch ~.ff~ ! d~84T.4,S Pup 3.5° 9.3# !-8t~ EUE 8rd Mhd 3~tap Xt7 Buq m¢d X Eue Prn 14. I S ~4854.9 4 Jt ~2 3.5° 9.3# ~-SQ Eue 8 rd Mod tb . 3'i: i2 4868.32 3.5" Cam~'DS' Landir-g ni le 2.$i3 no-go proffle ~ _9:5 4$99 ~i4 .ft. #1 3.5" 9,3;i~ L-8(? EUE 8rd Adod tbg. 31.~ 49q0.59 Pup 3,5" 9.3# L-8t) EUE Srd Mqd ~t,rp 6.13 49Cii.95 ~ocator 8aker $0-4Q GBH-~Z i.aca0or Spetts~ 7` up 1. ~ T ~4938.0$ SA Se~t asseml3ly is 11.95 ~op of 84-4C1 SBE ~ d~4i' 11:35 ~939.85 4951,84 Remarks~ SKing Weights watit B1aCks: fi5K# i.lp. A5}C~ ~n, 24K# StoCk:', Ran 756; UistiS of t~n g. Drifted h~~a. GLMs_ & harruer with 2_867" ndastic rabbit~ tlsed Arclic +3r2de API M odifiet No L~ad ttrre~ti compourtC on ali conn~ctions. Tut~ing 'rs ~on-coated. Nt~rdic Rig #3 BriltvxJ SUpervisa:~ t}ons~kf L. vue:~ter Jun 14 0~ ;;?:'~p PDS Inc ~ c~s~~~ o~ ~ ~v~ 5-?/2"X 3-'f!2" Casit~g Oesc~t~art Phitii~s~ Alaska lnc. 9~7 6~4 ~.17 KRU 7 D-136 DA1`E: 5/05120tN'1 1 Qt= 1 PAG~S # f[E~dS ~O~+IPLET~ D~SCftiP'f14iV OF EQUIPNfEPi1' RilA1 I~EPiGTFi UEP7H ^ TDPS t Landing joint S` ab ~ve fionr ~ FtiDRD~C FiT ~'L~ tAAICNAiG R~NG 29.95 5-1t2" i's~y Casing hsm~er yvl pup 3.i:1 ~9.95 ~! 297-320 5-if2° iv-S#. [.-80, BTGtklod csg 975.&~ 33.1fi s-'[12" Tam Port Cc~ltar 2.~5 ){}Q9.Od jt 201-296 5-t12" 15.5f~. L-8U. $TGIViod csg 3~l8.+82 1d11_95 5-112" Baker Cr~sover pcap B_Dfl" flD. A.93T' 10 1ff.!37 493U_77 Baksr 92' SB~ w! §" {~O, 4" IQ 12.~5 +19A4.~84 3-112°,9.3#, L-84, EUe 8 rd Mod Pt~ ~ t0-il7' 4953.T1 3Ys #4 23 3-~I t2". ~.3#. L-80. Eue 8 r~t N4od Tbg 614,28 4~3.84 3-112° Weathe~ord land'mg ~ailar 55T8't0 jCs~f;# 3-11~`. 9.3(~. ~-80, ~ue 8 rti Moti1 31_58 5578.i0 ~-'t(2° YY~therfprd Fiaat coila[ Eue 8rd bex x~n ~ }. ~T ~09.68 'Cs #t 3 2 3-112", 9.~. L-$U. Elie 8 rd Mai Tbg fi3.80 561Q85 3-112" W~therforrl Ftnat shae Eue Srd bax_ 1,;'.Q ~74.65 567~.85 Nt~TE! Jofat #245, 212, Z14, 27~, 3a2 out ;aaEe Tsta1 ~epth S68Q.E1tI CentraiFzers 3-712" Run two 3-tI2" 5C 7-~18" ROTCt] Soiid Sp'Ka! Biade csen~~~s perl~t. Place stap ct~ar in the cer~ter of each jt. i.et centr~ize~ fio~# betwe.eEt ii and the cn~a:s Centraliaers 5-112" €~un ~-it2" X 7-7t8" 8ows~rir~g L:e17tr~izer8 2 pe~i fur 5fltl` ;.!aove cross~uer_ Sfog ring in middie of jdint iettirtg cenEr2li'ter ~t "~~sreen cotl ar ~d stop rireg. Joinhs 2{}1 Ehttj 212. P{ace 4 B~rspriru~ evB~Y 3 jott~ts _ Z1v~, 218, 227,2'24,aZ7,23a,233.236,239,242,245.24$,25'1.2:s4,257 26U.263.266.Z,~927~.27~278,2~@1,26r,287,29~.C~93,294), Z:~?,30D.303, 346,3a9,3t2 S 316 Rernarks: S~tirtn Weia~tt~ w+tl, Bfocks- xxKit llo_ YxIC# Dn_ 2UI4# Bloclcr•.. Rart i i5 ia irtts nf ~_5" and 29 its c~ 3.5" ca~n9. L}rifted casing. & h~ger Nnth 2.8fi7° For 3.5" & 4.S.GS' For 5.5° t~as~CC =~abo~t. Used P,~clic Gr~de AP1 N~dified No ledd tAread camjsaund cm a~ conri~tions. Tubing is Flcx'~. 1VOrdic Rig ~3 Dt~'lfrig Supervisor. E?onald L Wc~sler J . //I ~\ ~_~ i/ 01 /08/09 Schlumberger -DCS ~ ~ "' ° ` 2525 Gambell Street, Suite 400 t - Anchorage, AK 99503-2838 _.; . ~ E ~ P°' ~ t _, - ATTN: Beth i~X: ~ '~~ b ° ~-~"` Well Job # Log Description NO.5035 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . )¡r/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 Nlr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tl1 Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 6200? ~.oo~ot¡fp Dear Nlr. 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 0 f approximately 1.0 foot. The remaining vo lume 0 f annular void respectively was coated with a corrosion inhibiter, RG2401 that was engineered to prevent water ITom 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 IH-Pad and December 28, 2006 for ID-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, ~--/cD~ Jerry Dethlefs ConocoPhillips Problem \-Vells 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 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1 H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 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 1 0-120 197-221 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 1 0-132 198-121 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 10-136 200-046 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 10-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 10-139 200-049 11' 2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na · · RECENED NO\l 2 9 2006 commission A\aska Oil & Gas Cons. Anchorage PHilLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 26, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 , ·r: I:i,M""~~·)\·) ~,~'~~\;.w ,~~.~,..... ¡; ~:, 1;-.: :; ...... Re: 1D-136, 10-404 Production casing repair Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for Phillips Alaska, Inc.,well1D-136 (PTD #200-046, Sundry # 306-222) The 10-404 Sundry on 1D-136 was for the repair of damaged production casing. It was brought to our attention that in the original drilling logs, the conductor size was incorrectly stated and the 10-403 was filled out accordingly. This is a corrected 10-404 reflecting the correct conductor size. Please call MJ Loveland or Jerry Dethlefs @ at 659-7043 if you have any questions. ßII~ MJ Loveland ConocoPhillips Well Integrity Project Supervisor Sincerely, 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 101' . RECEIVED . NOV 2 9 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF S NDRY WELL OPERATIONS Alaska Oil & Gas Co Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Other Repair Well Pull Tubing Opera!. ShutdownO Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 200-046 1 . 6. API Number: 50-029-22955-00 Exploratory Service o 0. 9. Well Name and Number: 10-136 8. Property Designation: ¡.. Kuparuk River Unit ,AI>I- Z.S-(PÇ'o þÞ II·?··&> 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool , Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION LINER Perforation depth: measured 5680' feet true vertical 4255' feet measured 5680 feet true vertical 4255 feet Length Size MD 110' 133/8" 110' 4851' 5-1/2" 4952' 724' 3-1/2" 5676' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3653' 4252' Measured depth: 5012-5059, 5094-5140, 5150-5173,5201-5208,5218-5266, 5287-5363' true vertical depth: 3699-3736, 3764-3802, 3810-3830, 3853-3859, 3867-3908, 3926-3989' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4941' MD. Packers & SSSV (type & measured depth) Seal assembly 4941' no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 13. Oil-Bbl n/a n/a Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casin Pressure n/a n/a n/a n/a n/a n/a 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: OilO Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Tubin Pressure n/a n/a Daily Report of Well Operations _X Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-222 Printed Name Signature 659-7043 Title Phone Well Integrity Supervisor' Date~ ~ ORIGINAL 'RBDMS BFI. DEC 1 3 2 Þ /i, '1o.~ s~ O.riginal Only ~ Wcr/a6 1. Operations Performed: Abandon D ¡/I Repair Well 0 Alter Casing G ~ 1 Pull Tubing D Change Approved Program D Operat. ShutdownD 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 101' . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION {' , REPORT OF SUNDRY WELL OPERATIONS Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D Stimulate D Waiver D Time Exterßiorì Re-enter Suspended Well 5. Permit to Drill Number: D 0· Exploratory Service 200-046 1 6. API Number: 50-029-22955-00 9. Well Name and Number: 10-136 . 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION LINER Perforation depth: .,(1)<... Þ fl·1~ 10. Field/Pool(s): Kuparuk River Field IWest Sak Oil Pool Z$"G.C:;O measured 5680' feet true vertical 4255' feet measured 5680 feet true vertical 4255 feet Length Size MD 110' 16" 110' 4851' 5-1/2" 4952' 724' 3-1/2" 5676' Plugs (measured) Junk (measured) Burst Collapse TVD 110' 3653' 4252' Measured depth: 5012-5059, 5094-5140, 5150-5173,5201-5208,5218-5266, 5287-5363' true vertical depth: 3699-3736,3764-3802,3810-3830,3853-3859, 3867-3908, 3926-3989' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 4941' MD. Packers & SSSV (type & measured depth) Seal assembly 4941' 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-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation n/a n/a n/a nla n/a Subsequent to operation n/a n/a n/a n/a n/a 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0· Daily Report of Well Operations _X 16. Well Status after proposed work: oilD Gas D WAG D GINJ D WINJ 0 WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 306-222 Contact Printed Name Signature " Dethlefs/Loveland 659-7043 Jerr:::/ cCJ Title Phone Well Integrity Supervisor ~~'-?-.?ð '7/'3 Date 11/3/06 RBDMS BFt {, ~ 2006 .4D /1· 7·0t. ~;7~~ Form 10-404 Revised 04/2000 R \ G \ f~ A L · 1D-136 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/18/2006 Conductor removal. Removed 11' of conductor with the measurement starting from the top of ' the landing ring. Removed cement and buffed the IA casing for UT inspection. The casing appears to be in fairly good condition with no visible leaks. 10/29/2006 Proactive patch weld on IA. Rigged up purge hoses and purged 1 bottle of Argon. Switched over to N2 purge for remainder of job. Seal welded casing te mandrel hanger. Welded on two 5" bands on to casing. Welded on 56" sleeve. Total area of repair is 61.5". Pumped in grout behind sleeve and seal welded 3/4" plugs on sleeve. Sleeve material was of 7" 26# L-80 / .500" wall drill casing. 10/30/2006 Post IA Patch MITIA - passed, Initial T/I=SI/O, Pressured up the IA to 3000 psi. with 1 bbl. of diesel. T/I= SI/3000, 15 min. T/I= SI/2975, 30min. T/I=SI/2965 , 45 min. T/I= SI/2965, 60 min. T/I= SI/ 2965, Bled IA. Final T/I= SI/O 10/31/2006 Dense wrapped exposed casing, welded on 10' 2" conductor. T/I=SI/100. Bled IA to 0 psi. Re-installed VR plug on non-valve side and norma led up the IA jewelry on the valve. Wrapped all exposed casing with Dense tape. Welded 10' 2" conductor back on. Conductor is 16", 62.5# Grade B conductor material. Top of conductor is 11" below top of mandrel hanger. Wrapped top of conductor with cosmolene paper and installed cap on 4" cement circ port. . . 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 Holej Open Holej Mechanical Logs and j or Tubing Inspection(Caliper j MTT] 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 . . ....~\~«:;;,\) Ii'.'. :~. ~.. Ii''': ê: xc t,,,··· (~~~~(""" , ?); 1) 2) 3J 4) 5) 6) 7) 1 Report 1 D - 136 MIT Report 26-Sep-06 UXC- 900 -O'-/b 1 Report 1 D - 137 MIT Report ~ 26-Sep-06 U::r.C- ;)CtJ-o'-l""} 1 Report 1 D - 138 MIT Report 26-Sep-06 u:z ~ eoó - (ita 1 Report 1 D - 139 MIT Report 26-Sep-06 U:r. c. GOo - o'-{9 RECEIVED Print Name: o,J0 ~^ r~~tì \A Ç) ~,(\\^ III V {)JA SEP 2 9 2006 Date· . . ~ Oil & <.;as COliS. Culllml3Sl0l1 Anchorage Signed: 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 _ PDSANC-2006\Z _ W ord\DistributionlTransmillal _ ShcclslTransmit. Origina Ldoc 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: 10-136 Log Date: September 26, 2006 Field: Kuparuk Log No. : 8052 State: Alaska Run No.: 1 API No.: 50-029-22955-00 Pipe1 Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intv/.: Surface Pipe1 Use: Tubing Bot. Log InM: 110 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log InM: Surface Pipe2 Use: Production Casing Bot. Log InM: 190 Ft. (MD) Pipe3 Desc.: 16" 62.5 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intv/.: 190 Ft. (MD) Inspection Type: Assess External Co«osive 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 ofthe 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 (60'), 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 190'. 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 6% circumferential metal loss is recorded in the interval between 35' - 40' and 67' - 68. A 5% círcumferential metal loss is recorded directly below the mandrel hanger in the interval between 0' - l' and 67' - 68'. A 4% circumferential metal loss is recorded in the interval between 23' - 26' and 29' - 29'. A 3% circumferential metal loss is recorded in the interval between 12' -12.5' and 57' - 59'. 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 16" pipe. If all of the 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 Witness: J. Brake I RECEIVED Analyst: M. T ahtouh & J. Burton U I c...- a-OD - 04 to SEP 2 9 2006 Alaska 011 & Gas eons. eommlsslon Anch0fage I I I I I I I I I I I I I I I I I I I <!as. Magnetic Thickness To g (10Hz Pass) p~ DÎAq""""'ìc SER"¡CE5, INC. Database File: d\warrior\data\1 d-136\1 d-136. db Dataset Pathname: KuparukJ1 D-136/run1/P1 Ohz.1 Presentation Format: 26SCAl-1 Dataset Creation: Wed Sep 2708:49:542006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 -- - - -50 Delta Metal Thickness (%) 50 2.6 MTIP01 (rad) 12.6 0 line Speed (ftlmín) -200 -6.2 MTIP12 (rad) 3.8 ( !. I ( I I "__.n" ¡---.- c---- ---.^ " ) i Hanger Tree ~ \ A % Metal Pup Jt. .---<:; -Los ollar I - 3.5" Collar- -- - - --- 1--1 ~-,.,._- r- - \ ¡ ..... I --: -3% Metal -I+--Uìss-- - ---- ¡-- ----- ---- Ii'-- 3.5" ( 1 _ Joint 1 line Speed J I _ 20 ) ~ _4% Metal -.,111>%; ~ r-- -IHu¡sm I c-- -4% Metal -- f--- --¡--- ¡--. loss- '-- --~ C.5" Collar -6% retal..... ~ ~ LOSS 40 ¡-- 4t \ ¡-- >-- -- c--- ,--- _.'" -- -fE ~5 :;" Collar .......... -- - --- - 3.5" ~ Joint 2 - - - -- -- - - -- - ~ --- -- t -~ -3% Metal -'" -- --- -- - ) loss__ 60 - --"~ ~~(Metalg ----- ~3.5" Collar Loss f- - :] - f- ~ - 1-- ,","-Bottom of 16" Conductor -;;; p »'~" -'-"' I 80 .í~ [' -- f* 3.5" t ! f. I Joint 3 t I _7--- ~, --- -- -,- --- m -.- I': ~ ~. - - J \¡;;: - 1 ~~ I J [> -;~ :: I> .5" Collar - ~ - ') I"( "'¡...---- <~ ç "- ~ ",. '.. " "''It'1 '" "'-, I, --- I I I I I I I I I I I I I I I I I I I II I I J I _{I J II I "~- ~ "- ~L d.5"bol '- --- 100 f-- ~ I "- -- --" ¡,. , , ~ ~~ I 3.5" Joint 4 c"_" -" ~" --.-" --- -- -- -" ~ -- !--~ --- ""- ~"-"- --" --~ ~ ,---- -- -~ 120 ¡- , r---- ---- "-¡---- ~,-- ---- ;--- _m~ -- ~ -" - r- --- F'--- I I ¡- ä ~ - I..i.. I 3.5" Collar - f--- I i_ t ¡----- I ,? I? ~ -" ¡-- -- 5.5" COllar- -- I~--t"--- r- ~- ,- -. -- "'-,. ,---- -- F--- - -- -- r-- ¡-- 3, 140 r- ¡-- - -- -"- -- :--- "- +-~ -. -- -- I- i I 3.5" :-- - r- - ----- Joint 5 - c-- -- - - --"~- - - ( ~ --- -- ."- -- c---- - -- ¡------ -- ~- -- r--- -- - - I -- -- -- -- ... t--- - --. -- ~ ~ '--- A .....5" Collar 160 ~ ...- ..., - Ii f$ --- --- -- -- ~--" c---- -- 2 -ì- --- f------ --- -- -- L r ::t _'"n_ r----¡' -"'. - !---- '------ 3.5" ( ~ ~ --- t-- ~d- -= .-- 11 - --- -- ~ .-- -~"r------ -'-... Joint 6 \:::.- ç ;;;;:;;-5.5" Co I!a r- '--- -:- ~m .....~ - > ,----- r> - ;:=> ".- " 180 -- "--- -- . ~ .~- r------ - i- -"- , ~~rOf Log--- ~ ---: ~ V :c-- r----- T"-- --- - -50 Delta Metal Thickness (%) 50 26 MTTP01 (red) 126 0 Line Speed (ftlmìn) -200 -6.2 MTTP12 (rad) 3.8 I I I I I I I I I I I I I I I I I I I cJa~ Magnetic Thickness Too g (10Hz Pass) p~ DÎAq""""'lc SER"¡CE5, INC. Database File: d\warrior\data\1 d-136\top\ 1 d-136db Dataset Pathname: KuparukJ1 D-136/run1/P1 Ohz.1 Presentation Format: 26SCAL -1 Dataset Creation: Wed Sep 2708:49:542006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 175 - -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 line Speed (fUmin) -200 -6.2 MTTP12 (rad) 3.8 r I Tree r== - Hanger -5% Metal ~ 0 ~ / Loss I Pup Jt. 5" Collar fm-- ,~... -- I 3.5" Collar Þ ¡;... 1t :!>- '" - ~ =-- = ....: ..¡ f- >-- ;;,. I i1~ : I J ¡ I: ... I - , 3% Metal I" I ~ .:d -; ~~t I loss. I I ~ - ~. ~ I ì î J ! 3.5" I ..~ , line Speed Joint 1 -""--~- I ~ ~ ·d 20 ~~ ~ ~ I :ð"" ::- ~ ;, -- I"" ~ ~ ~ ._f-- --- ;- ~ _ 4% Metal .... ""¿J ... ..;, .è L1 Loss '".. 1J: =~ c ~ I "...' .~ -, -.------ .- -- - ~L ,.~ I :: ,,:¡ .., -4% Metal - 1+. ¡ Loss '" , ...ø I ~ /'" .5" Collar I ......1"" ) I ~ f- - t--- - .. _6% fetal ~ ~ ..- -"., ...- .- ~ 1\4 :~ !+ lOiS ~= - ~ -., ~ 2., 40 > , -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 line Speed (fUmin) -200 -6.2 MTTP12 (rad) 3.8 I £ .ç Magnetic Thickness To g (10Hz Pass) ...... ...I. I p~ Di",,""""'ic SER"¡CE5, INC. - Database File: d\warrior\data\ 1 d-136\bottom\ 1 d-136. db I Dataset Pathname: Kuparukl1 D-136/run1/P1 Ohz.1 Presentation Format: 26SCAL -1 Oataset Creation: Wed Sep 2708:49:542006 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 175 I -- -50 Delta Metal Thickness ('Yo) 50 2.6 MTTP01 (rad) 12.6 0 line Speed (ftImin) -200 -6.2 MTTP12 (rad) 3.8 I ~~]'collar -- -- li~ I ~- -I---~ ---; ~- '3 -- -----.-- - <: 't j sf¡ i _6% Metal -lIÞl' I I ) Loss I ~ I ~ 40 ~I > '" I --~-- - ^--" --*- ~ ~ i- ~'~.~'* ~ "'---', ~j I -- --- ~"I'-- I I p~ 1+1- 5.5" Collar 3.5" '::I V !J "Í I - Joint 2 - , ~ I :'" ---f-- ----- I I - ~ I . - I 1 I ,... 1--3'Y) Metal ;; "' - ~. ..; ~ I loss I) ,? ;'" 60 I ( ,... ? j - - i l- I I I I ' Collar I I _ºI~,,-Metal ~ - loss I I , ~ j;¡1- I I f I I - I ~--,- ¡:- ~ ~ J ~ j I -fW I .---- -~~ --- ------- ~~-- "--- Iii:' !w )+1- B~ttom of 16" Conductor ~ L -50 Delta Metal Thickness (%) 50 12-6 MTTP01 (rad) 12.6 I 0 line Speed (ft/min) -200 1-6 MTTP12 (rad) 3_8 I I I I I I I I I I I I I I I I I I I I - TUBING (0-4941, OD:3.500, ID:2.992) , RODUCTION (0-4952, OD:5 .500, Wt:15.50) Gas Lift I ndr,WDummy Valve 1 (4847-4848, OD:4.725) NIP (4900-4901, OD:3.500) SEAL (4941-4942, OD:5.500) Perf __n -.- (5012-5059) -- ---- '- -- --'- '---- ~_..- f-- Perf --- __n_ (5094-5140) -- ---- - -- ---,- ---_. ---- -,,- Perf '-- - (5150-5173) ---- 1---- - - - 1--- - f----- Perf '--- 1---- (5201-5208) - -_. -- 1----- "-- ¡----- "- 1------ Perf -- -- (5218-5266) ---- 1------- --- I--- ---- 1"--- -- -- Perf -. 1------- (5287-5363) ----- ¡-------. -- 1---- -- I---- IGål St MD NO ~a; Man Type V Mfr I V Type I V 00 ¡latch I Port I TRO I ~~~ I C~:t 1 4847 3577 CAMCO KBG29 CAMCO I DMY 1 1.0 INT I 0.000 I 0 IUJ '':>ILVVU rOther ()fU!:lSi9CiÜiD..eti .J" A;:\I\i¡;::r~v Deoth NO I Tvoe 4900 3615 NIP CAMCO DS NIPPLE 4941 3645 I SEAL BAKER GBH-22 SEAL ASSY 110-136 API: 500292295500 SSSV Type: NONE Annular Fluid: Reference Loa: Last Tag: 5040 Last 12125/2005 I-A!..!.. notion CONDUCTOR PRODUCTION LINER All Size I Top 3.500 I 0 interval NO 5012 - 5059 3699 - 3736 5094 - 5140 3764 - 3802 5150 - 5173 3810 - 3830 5201 - 5208 3853 - 3859 5218 - 5266 3867 - 3908 5287 - 5363 3926 - 3989 KRU 1 D-136 Well Type: INJ Orig 51712000 Completion: LastW/O: Anale @ TS: dea @ Angle @ TO: 33 deg @ 5680 Rev Reason: TAG 323' FILL OVER PERFS Last Update: 1213112005 Ref Loa Date: TO: 5680 ftKB Max Hole Angle: 62 deg @ 3085 Size Too Bottom NO Wt Grade Thread 16.000 0 110 110 62.58 H-40 WELDED 5.500 0 4952 3653 15.50 L-80 BTCM 3.500 4952 5676 4252 9.30 L-80 EUE 8RD I Bottom NO I Wt I Grade I Thread I 4941 1 3645 I 9.30 I L-80 I EUE 8RD Zone Statu," Ft SPF Date TVDe Comment WSD 47 4 81112000 IPERF 2.5" HSD Ultra-jet DP, 60 dea phasina WSB 46 4 8/1/2000 IPERF 2.5" HSD Ultra-jet DP, 60 deg phasina WSA4 23 4 8/1/2000 IPERF 2.5" HSD Ultra-jet DP, 60 deQ phasinq WSA3 7 4 7/31/2000 IPERF 2.5" HSD DP Chgs, 60 deg !ph WSA3 48 4 713112000 IPERF 2.5" HSD DP Chgs, 60 deg !ph WSA2 76 4 7/31/2000 IPERF 2.5" HSD DP Chgs, 60 deg :ph DescriDlion I ID I 2.813 I 3.500 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ I" /5:·V I '-.,c'/t-/ ?/- Jf ¿",-, DATE: Monday, July 31, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lD-136 KUPARUK RIV U WSAK lD-136 Jp(JJ O#; FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.l. Suprv,Jì3,2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-136 API Well Number 50-029-22955-00-00 Inspector Name: John Crisp Insp Num: mitJCr06073 I I 02045 Permit Number: 200-046-0 Inspection Date: 7/29/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I lD-136 IType Inj. I , 'l5šo Well . N iTVD 3645 i IA , 0 1610 1590 I i 2000460 iTypeTest I SPT : Test psi I I P.T. 1500 ¡ OA I ~al 4YRTST P/F P / .... Tubing! 600 675 675 I 675 - ,it,;A r,t\4 }::r :\, fI' J. ) --- 'J 'ir; 'J Notes 1.2 bbl's pumped for test Monobore, no OA ."...,. ,II 1,.;,,,,,,-..,,/ ~ 1 '"" i...1 ,,: ~~U Monday, July 31, 2006 Page I of 1 e e FRANK H. MURKOWSKI, GOVERNOR ALASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 ;...;$ '·.·'·"'-.·./fi¡,;¡»~\1.~Y~;J··1. ~;'\i4 ,"" ¡"",; \~!.i c· j, l, ;;¡ Re: Kuparuk River Field, West Sak Oil Pool 10-136 Sundry Number: 306-222 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 thisØday of June, 2006 Enc!. ~)lb '-U-[lp e ~ ConocoPhillips Alaska e P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 RECEIVED JUN 2 1 2006 Alaska Oil & Gas Cons. Commission Anchorage June 19,2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th 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), 1D-137 (PTD 2000470) and 1D-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, ý~c- ~ Jerry Dethlefs Problem Well Supervisor Attachments {}/f b/lt/7 C/4-~2I- O/þ. k RECEIVED e STATE OF ALASKA <ø b 'v ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 1 2006 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 MC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0' Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 200-046 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22955-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 10-136 8. Property Designation: 10. Field/Pool(s}: Kuparuk River Unit J' ì> '- t.~" >è> ,,1> Kuparuk River Field / West Sak Oil Pool 11. ,.~/·Þf:> PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5680' 4255' 5680 4255 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110 PRODUCTION 4851' 5-1/2" 4952' 3653 LINER 724' 3-1/2" 5676' 4252 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5012-5059, 5094-5140, 5150-5173,5201- 3699-3736, 3764-3802, 3810-3830, 3853-3859, 5208,5218-5266,5287-5363' 3867-3908,3926-3989' 3-1/2" L-80 4941' Packers and SSSV Type: Packers and SSSV MD (ft) Seal assembly 4941' no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for July 2006 15. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: McConnell/Klein, 659-7224 Printed Name Jerry Dethlefs 0 ~ - Title: Problem Well Supervisor Signature ¢~~ ê ~r~ Phone 659-7043 Date 4-ð~/rJ~ , ~ mmission Use Only sund~~er: Conditions of approval: Notify Commission so that a representative may witness l 'Ð·~ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: t.o~~\- L~L-\Ð\-'\o'-c~,""~~ '1\0 v\~w o..~ c..v-~\~ ~ ~~~~ S''''''''O"tFo"" RO";reðŒ ~, Æ , \ \'. a i.. c.. ""-1. "t!('ù. \. .- Y" - :í'-'-'-.)~~"" <J... 'ö t-. b'.Z¡"rP ~ ~ APPROVED BY Approved by: / \. COMMISSIONER THE COMMISSION Date: \.,../ lJ "- RBDMS BFl JUN 28 700p ~ ",¿¡.o~ . . Form 10-403 Revised 7/2005 ORIGINAL Submit In Duplicate ~ çµ~~ [Fwd: ConocoPhillips Excavation & Repair Project] e e 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 ÑSK-weTfIntegrlty--prõ-J---~Ni87-8@conocophillips. com> , aogcc prudhoe bay@a.dmin.state.a.k.us \\)-\~lp d.-OO--() '--\ ~ 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 "pro-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: applicationlvnd.ms-exce1 Content-Encoding: base64 SC Corrosion West Region 2006 Final.doc Content-Type: app1icationlmsword lof2 6/26/20067:51 AM e e ConocoPhiIlips Alaska, Inc. West Sak WelllD-136 (PTD 2000460) SUNDRY NOTICE 1 0-403 APPROVAL REQUEST 06/18/06 This application for Sundry approval for West Sak injection well1D-136 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 rrom around casing for inspection. Approximately the top 5-10 feet of conductor will be removed to provide access to the casmg. 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. Pile 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 6/18/2006 e e ConQcoPhiUipsAlaska, Inc. KRU 1 D-136 .. .. .. ...... .... .... ........... .......... ..... ........ .... ......... ... .... API: 500292295500 Well Tvpe: INJ Anole (ii) TS: deo (ii) TUBING > SSSV Type: NONE Orig 5f7!2000 Angle@TO: 33 deg @ 5680 (0-4941, OD.3.500, > Completion: ID:2.992) > Annular Fluid: LastW/O: Rev Reason: TAG 323' FILL OVER PERFS < Reference Loo: Ref Loa Date: Last Update: 12/31/2005 Last Tag: 5040 TO: 5680 ftKB 'ROOUCTION Max Hole Anole: 62 deg (ii) 3085 (0-4952, CasingSttin¡:- ALL 00:5.500, Wt:15.50) Description Size Top Bottom TVD Wt Grade Thread Gas Lift CONDUCTOR 16.000 0 110 110 62.58 H-40 WELDED ,ndrellDummy PRODUCTION 5.500 0 4952 3653 15.50 L-80 BTCM Valve 1 (4847-4848, LINER 3.500 4952 5676 4252 9.30 L-80 EUE 8RD 00:4.725) TubinaStrina-AlL Size I Top I Bottom I TVD I Wt I Grade I Thread 3.500 I 0 I 4941 I 3645 I 9.30 I L-80 I EUE8RD . ...... perfötâtionsSurnrnarv. Interval TVD Zone Status Ft SPF Date Type Comment ....... 5012 - 5059 3699 - 3736 WSD 47 4 8/1/2000 IPERF 2.5" HSD Ultra-jetDP, 60 deo phasino NIP 5094 - 5140 3764 - 3802 WSB 46 4 8/1/2000 IPERF 2.5" HSD Ultra-jet DP, 60 (4900-4901, deg phasino 00:3.500) 5150 - 5173 3810 - 3830 WSA4 23 4 8/1/2000 IPERF 2.5" HSD Ultra-jet DP, 60 deg phasino 5201 - 5208 3853 - 3859 WSA3 7 4 7/31/2000 IPERF 2.5" HSD DP Chgs, 60 deg ph 5218 - 5266 3867 - 3908 WSA3 48 4 7/31/2000 IPERF 2.5" HSD DP Chgs, 60 deg --- ¡ph 5287 - 5363 3926 - 3989 WSA2 76 4 7/31/2000 IPERF 2.5" HSD DP Chgs, 60 deg > ¡ph .< Gas Uft Mandl'elsNal'les < St I MD I TVD I Man I Man Type I V Mfr I V Type I V OD I Latch I Port I TRO I Date I Vlv Mfr Run Cmnt SEAL 1 I 48471 35771 CAMCO I KBG29 I CAMCO I DMY I 1.0 I INT I 0.000 I 0 16/13/2000 I (4941-4942, i········ »> Other pluas ,9QIJÌP.,. etc. )-JEWELRY 00:5.500) ......... Depth TVD I Type I Description I ID . 4900 3615 I NIP [CAMCO DS NIPPLE I 2.813 4941 3645 I SEAL I BAKER GBH-22 SEAL ASSY I 3.500 ....... >i>ii Perf - - (5012-5059) - - - - - - Perf - - (5094-5140) - - - - - - - - Perf - - (5150-5173) - - - - - - - - - - Perf - - (5201-5208) - - - - - - - - Perf - - (5218-5266) - - - - - - Perf - - (5287-5363) - - - - - - - - ConocoPhillips Alaska, Inc. 1 C and 1 D Surface Casing Corrosion Repair Candidates PRIORITY . NAME . ~--.~----.--1---- -.-.-----. 1 1C-121 2 1C-131 3 1 0-1 09 e 4 5 6 7 . ------.--...-.----- ifO:> - t)~ 10 8 ~9 ~ 10 -.'----_..,-_.------ e 11 12 13 14 15 16 --------.--------'- 1 0-111 10-120 1 C-119 TYPE -----_.._--_._-~--- INJ INJ INJ _._u..__., INJ INJ ---------.------------ Gas Lift Gas Lift INJ INJ INJ INJ -------- Jet Pump ---...---.---,------ ESP Gas Lift PTD# LEAK DEPTH (ft) ! -----------..------+..---- .- ---+------------ 201-080, 4 ! ---~------_. .l-----------.---+-----·· .- 201-185' 7 ! ------- .----- ---.----.- 197 -235 5* --------.--.'.----- 198-166 197-221 197-181 198-109 198-121 COMMENTS I STATUS ._~------_.-._.__..._---.._----_._....- --....-...----------." '----------- .-------- ------..---.. -- _____m______ __ -------- 5* ---------- -,---.--- --------- -----'- 7 - -.------ _0' __________..__ None Proactive dig Proactive dig -- ----- None -....--.--- - _____m____ --------------,. 5 --,-.,'---- ----~..- ------------ _______^ __ - ____._~.._.__________._____._.n___ 200-046 200-047 200-048 200-049 201-139 -- ------.--- 201-220 197-184 200-112 None None Proactive dig ----- ------...--."---....-------- - ----.-". -- Proactive dig _ _______·_w__._..___n.__,_______..______ --------- ------ 8 _______._._m_' - ----------- -- -----"._------- - None Proactive dig _..._._------~-----_.- 16 ----- _.__.________...._,,_________n____.____·_·_ Proactive dig None None None _...~---------_..-- ...._~-_._-- -- 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 1 C-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 MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg. ~~<. L/.'2l(Of' P.I. Supervisor ~ I DATE: Thursday, May 19,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC lD-136 KUPARUK RIV U WSAK lD-136 1J() ~·Olf~ FROM: J eff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK 10-136 API Well Number: 50-029-22955-00-00 Insp Num: mitJJ050518081646 Permit Number: 200-046-0 Rei Insp Num: Inspector Name: Jeff Jones Inspection Date: 5/17/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well lD-136 Type Ioj. W TVD 3645 IA 0 1710 1640 1630 P.T. 2000460 TypeTest SPT Test psi 911.25 OA Interval 4YRTST P/F P Tubing 1150 1150 1150 1150 Notes: "Monobore" type injector. 1 well house inspected; no exceptions noted. :~f"''[~ Ú\.'~,' ~~n~: r'\, 1\ ~J G... fL D,', "2' 0 q ì) ~,WU'U·t$Pl)J~t,,..J J''¡!~ I ~} tl _ .JwJ~. Thursday, May 19,2005 Page 1 of I .PHILLlPS AlasJa, Inc. , r:m A Subsidiary of PHilLIPS PETROLEUM COMPANY I I I ¡'1Ð~.136' I ", API: i 500292295500 i SSSV T ýpP.: I NONE I : Annular Fluid: II I Reference Log: ! Last Tag: /5493 I Last Tag Date: I 11/15/00 ; Casing String - ALL Description CONDUCTOR PRODUCTION LINER Ii Tubing $, t,ri'!;9, - ALL Size I Top 3.500 0 F'~ffQrätipris$Ümmary'· Interval TVD 5012 - 5059 3699 - 3736 TUBING (0-4941, 00:3.500, 10:2.992) PRODUCTION (0-4952, 00:5.500, Wt:15.50) Gas lift landrel/Dummy Valve 1 (4847-4848, 00:4.725) 5094 - 5140 3764 - 3802 \" ~ 5150-5173 3810 - 3830 5201 - 5208 3853 - 3859 5218 - 5266 3867 - 3908 5287 . 5363 3926 - 3989 NIP (4900-4901, OD:3.500) SEAL (4941-4942, 00:5.500) ."",..,",., ~:::: Perf (5012-5059) Perf (5094-5140) Perf (5150-5173) Perf (5201-5208) Perf I (5218-5266) I Perf I (5287-5363) I I L_ GásLiftMãtiëlrølslVål\i.es St MD TVD Man Mfr I 1 4847 35ìì CAMCO KBG29 CAMCO DMY 10 INT 0.000 ! Other (plugs, equip., etc.) - JEWELRY Depth TVD Type Description 4900 3615 NIP CAMCO OS NIPPLE 4941 3645 SEAL BAKER GBH-22 SEAL ASSY t\.Àu 1 D-136 Angle lãi TS:! deg @ Angle I~ TO: j 33 deg 'S;µ 5680 Rev Reason:, Add PERFS by ImO Last Update: ! 4/10/01 . I Size Top Bottom TVD Wt Grade Thread 16.000 0 110 110 62.58 H-40 WELDED 5.500 0 4952 3653 15.50 L-80 BTCM 3.500 4952 5676 4252 9.30 L-80 EUE 8RD Bottom TVD Wt Grade Thread 4941 3645 9.30 L-80 EUE8RD Zone Status Ft SPF Date Type Comment WSD 47 4 8/1/00 IPERF 2.5" HSD Ultra-jet DP, 60 de~ phasing WSB 46 4 8/1/00 IPERF 2.5" HSD Ultra-jet DP, 60 de~ phasing WSA4 23 4 8/1/00 IPERF 2.5" HSD Ultra-jet DP, 60 de~ phasing WSA3 7 4 7/31/00 ¡PERF 2.5" HSD DP Chgs, 60 deg ph WSA3 48 4 7/31/00 ¡PERF 2.5" HSD DP Chgs, 60 deg ph WSA2 76 4 7/31/00 ¡PERF 2.5" HSD DP Chgs, 60 deg o ID 2.813 3.500 F:\LaserFiche\CvrPgs _ Inserts\Microfilm_ Marker.doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ~;.~ Permit to Drill 2000460 MD 5680 TVD 4255 DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. KUPARUK RIV U WSAK 1D-136 Operator PHILLIPS ALASKA INC. Completion Dat 7/31/2000 ~ Completion Statu 1WINJ Current Status 1WINJ APl No. 50-029-22955-00-00 UIC Y REQUIRED INFORMATION Mud Log No Sample N._9 Directional Survey N_9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Name Scale Media Interval Run No Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments Well Cores/Samples Information: Name Start Interval Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ Analysis ~ R e.c.e, ive. d ? Daily History Received? Formation Tops {~N Comments: Compliance Reviewed By: ~L~'-'~ Date: /~J Sch berg r 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 Corem 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 ~OO--0~(., INJECTION PROFILE 10/18/01 I 1 1D-139 ~)-Oc/~ PRESS/TEMP SURVEY 10/19/01 I 1 1F-10 / ~".~_/(~ ~ INJECTION PROFILE 10/20/01 I 1 1H-07 / ~'c~-O ~.~ INJECTION pRoFILE 10/24/01 I 1 1Q-13 ! ~ S-O~'L/ INJECTION PROFILE 10/20/01 I 1 2M-17i~ I- Ol~ INJECTION PROFILE 10/14/01 I 1 2N-321A /c~ ~-_ I ~ INJECTION PROFILE 10/26/01 I 1 2X-17 / C~ ~_j~ I PRODUCTION PROFILE 10/25/01 I 1 3C-04 ! ~')~---/c~) PRODUCTION PROFILE 10/23/01 I I ... 3M-03 ]~7 7--O)~-~ PRODUCTION PROFILE 10/22/01 I I DATE: RECEIVED NOV i 6 2001 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Tha~Jl~.0ii & Gas Cons. Commission Anc~rage Schlumberger NO. 1178 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1B-01 I<~'()-~ LEAK DETECTION LOG 05/16101 1 1 1B-01 .~ LEAK DETECTION LOG 05118101 1 1B-11 I~!--I,..~ LEAK DETECTION LOG 05117101 1 1 1D-121 ~c~'7-1~! TEMPIPRESS/DENSITY SURVEY 05119101 I 1 1D'135~OD-~, TEMPIPRESSlDENSI~ SURVEY 05119/01 ~-~ ~-I~- ~ .~c~,o. ~o~ o~o~ 3F-2~ ~ ~D-~ PRESSURE SURVEY 0611 ~/01 1 1 1D-3~O~-~ ~, ~ 2~ 224 SCMT 04124101 2A-15/~-I~ 21223 USIT 04/23101 1 2P~17~/..,~ 21243 FRACADE ADVISOR 05112101 1 RECeiVI: SIGNED~~ ~ ~- .^~: JUN 0 1 D Alaska Oil & Gas Cons. Commjsdon Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ,~llC~lOf~e 5/30/2001 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 I 11/30/00 Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALAS~,J-~ OIL AND GAS CONSERVATION COMI~,.oSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well O,1 F~ Gas [~ Suspended Fl AbandonedE] Servicer'~]'t~ Waterlnjeotor 2. Name of Operator ; . ~ 7. Permit Number Phillips Alaska, Inc.t~."~~?'~'?'~'~~~,-~- ~ 200-046 a. ~ddmss t8 8. ~l ~umb~r ~. O. Box l ooa~o, ~nchora~o, ~K ~SlO-OaO0 ~, 50-02~-22~5S 4. kocation o~ woll at suvaco 616' FNL, 602' FEL Sec. 23, T11 N, R1OE, UM (ASP: 560491,5959049)~" ~"~"~';:' ;'':~ '}'';' ~" Kuparuk River Unit At Top Producing Inte~al ; . ~: ~[ ~.. ~ ~10. Well Number 2380' FNL, 2121' FWL, Sec. 24, T11N, R10E, UM (ASP: 563~8, 5957309) ~ ................... 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 ~and. ~15. Water Depth, if o~shore 16. No. of Completions April 30, 2000 May 4, 2000 ~0 ~. ~('~~ N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickne~ of Permafrost 5680' MD / 4255' TVD 5576' MD / 4168' TVD YES ~ No ~~ N/A feet MD 1690' 22. T~e Electric or Other Logs Run GR/PWD, GR/Res/Neu Dens, CCL 23. CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. G~DE TOP BO~OM HOLE SIZE CEME~ING RECORD~ AMOUNT PULLED 13.375" 68¢ L-80 Surface 110' 20" 7 cu yds High Ear~ 5.5" x 15.5¢ L-80 Surface 4952' 7.875" 520 sx AS III L, 390 sx Cla~ G 3.5" 9.3¢ L-80 4952' 5676' 7.875" (see ~ove) 24. Pedorations open to Produ~ion (MD + TVD of Top and Bo~om and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 4952' N/A 5287'-5363' MD 3926'-3990' ~D 4 SPF 5218'-5266' MD 3867'-3908' ~D 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5201'-5208' MD 3853'-3859' ~D 4 SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5150'-5173' MD 3810'-3830' ~D 4 SPF N/A 5094'-5140' MD 3764'-3802' ~D 4 SPF 5012'-5059' MD 3699'-3736'~D 4 SPF 27. PRODUCTION TEST Date First Produ~ion Method of Operation (Flowing, gas li~, etc.) INJECTOR Date of Test Hours Tested Production for OIL-BBL ~S-MCF WATER-BBL CHOKE SIZE ]GAS-OIL RATIO I Test Pedod > Flow Tubing ~Casing Pressure Calculated ~OIL-BBL ~S-MCF WATER-BBL OIL GRAVITY - APl (co~) pre~. psi 24-Hour Rate > 28. CORE DATA Brief description of litholo~, porosi~, fractures, ~parent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top West Sak D Base West Sak D West Sak Base MEAS. DEPTH 5010' 5064' 5540' TRUE VERT. DEPTH 3697' 3740' 4138' 30. FORMATION 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. Questions? Call Mark Chambers 265-1319 Signed ~~~l"~~le Kuparuk Drilling Team Leader Date Randy Thomas Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, 5... ¢~ ;~ ',,'~' ' i?"";~ Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/01/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:ID-136 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:04/30/00 START COMP: -- RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22955-00 04/29/00 (D1) TD/TVD: 110/110 SUPV:M.C. HEIM MW: 0.0 VISC: 0 PV/YP: 0/ 0 ( 110) RIGGING UP DIVERTER. Move rig off 1D-138 and move to 1D-136. APIWL: 0.0 04/30/00 (D2) TD/TVD: 451/451 SUPV:M.C. HEIM MW: 9.8 VISC: 262 PV/YP: 49/52 (341) DRLG. & SURVEYS ~ 700' APIWL: 5.2 Move rig over diverter on well 1D-136. Accept rig ~ 00:00 hrs. N/U diverter. Pre-spud meeting. Drilling-surveys and gyro surveys from 110' to 700' 05/01/00 (D3) MW: 9.6 VISC: 202 PV/YP: 58/36 TD/TVD: 2016/1902 (1565) SURVEY ~ 2466' RIG ON HI-LINE POWER SUPV:M.C. HEIM Drilling-surveys & gyro from 451' to 2016' APIWL: 4.4 (Diverter drill) 05/02/00 (D4) MW: 9.5 VISC: 240 PV/YP: 41/43 TD/TVD: 3152/2588 (1136) DRILLING ~ 3506' SUPV:DON WESTER APIWL: 4.5 Continue directional drilling 7-7/8" hole from 2016' to 2466'. Circ hole clean. Rotate and reciprocate. POOH. Started swabbing ~ 1079'. Back ream to surface. Wash and ream tight spots ~ 240', 270', 1650' & 1700'. Wash and ream 90' to bottom 50' fill ~ 2466'. Continue directional drilling 7-7/8" hole from 2466' to 3152' 05/03/00 (D5) TD/TVD: 4860/3582 SUPV:DON WESTER MW: 10.0 VISC: 242 PV/YP: 45/53 (1708) CONTINUE DRILLING ~ 5100' APIWL: 4.0 Continue directional drilling 7-7/8" hole from 3152' to 4860'. Raised mud weight from 9.5 to 10 ppg. 05/04/00 (D6) MW: 10.0 VISC: 258 PV/YP: 47/59 APIWL: 3.8 TD/TVD: 5680/4254 ( 820) L/D MOTOR, M/U HOLE OPENER. DOWN LOAD MWD & UP LOAD SA SUPV:DON WESTER Continue directional drilling 7-7/8" hole from 4860' to 5680' Circulate and condition hole. Rotate and reciprocate. Sperry-Sun dropped single shot survey for check shot. Monitor well, OK. POOH slowly. Date: 08/01/00 ARCO ALASKA INC. WELL SIZMMARY REPORT Page: 2 05/05/00 (D7) MW: 10.0 VISC: 230 PV/YP: 50/58 APIWL: 3.8 TD/TVD: 5680/4254 ( 0 LAND 5-1/2" CSG, R/U CEMENT HEAD SUPV:DON WESTER RIH with 7-7/8" hole opener. RIH to 2819' tight hole wash to bottom ~ 5680'. Rotate and reciprocate pipe while circ and condition mud. Pump liner pill. POOH. Safety meeting. RIH with 3.5" x 5.5" casing. 05/06/00 (D8) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 5680/4254 ( 0) RIH W/ 3.5" COMPLETION STRING, SPACE OUT & CIRC OUT PE SUPV:DON WESTER Continue RIH w/5.5" and 3.5" casing. PJSM. Pump cement job. Bump plug. Floats held, OK. N/D diverter. N/U BOP stack. Run 3.5" completion. 05/07/00 (Dg) TD/TVD: 5680/4254 ( SUPV:DON WESTER 0) MW: 8.3 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 Continue running completion 3.5" tubing. N/D BOP. N/U tree and test to 250/5000 psi. OK. Pump diesel down annulus. Secure well. Move off well. Released rig ~ 1400 hrs. 5/7/00. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-136(W4-6)) WELL 1D-136 JOB SCOPE DRILLING SUPPORT-CAPITAL DATE DAILY WORK 07/31/00 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL 5 YES I YES Init,alTbgPress IFinaITbgPress IIn,tiallnnerAnn 50 PSI 50 PSI 0 PSI DALLY SUMMARY KEY PERSON SWS-ELMORE JOB NUMBER 0512000814.1 UNIT NUMBER 2128 SUPERVISOR CHANEY Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSII 0 PSII 0 PSI IPERFORATED 5287'-5363', 5218'-5266', 5201'-5208'.1N 6 RUNS USING 2-1/2" HSD, DP CHGS,4 SPF, & 60 DEGREE PHASING. LOG JEWELRY LOG. TIME LOG ENTRY 07:30 MIRU SWS 2128, ELMORE, TGSM, PT 3000#. 09:40 RIH W/GUN 1,26' X 2.5" HSD, 4SPF, CCL. 10:05 TIE IN AT JEWELRY 5030'-4800'. RIH. 10:28 LOG JEWELRY LOG FROM 5450'-4800'. RIH. 10:55 LU SHOOT GUN 1 5337'-5363'. POOH. 11:30 RIH W/GUN 2, 26'. 11:58 RE-CK TIE IN LU SHOOT 5311'-5337'. 12:25 RIH W/GUN 3 24'.5. 12:50 RE-CK TIE IN LU TO SHOOT 5287'-5311'. POOH. 13:15 RIH W/GUN 4 26'. 13:50 RE-CK TIE IN LU SHOOT 5240'-5266'. 14:14 RIH W/GUN 5 22'.5 14:35 RE-CKTIE IN LU SHOOT 5218'-5240'. POOH. 15:03 RIH W/GUN 6 7'. 15:30 RE-CK TIE IN LU SHOOT 5201'-5208'. 15:55 BD, RD. 17:00 RDMO. PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-136(W4-6)) WELL 1 D-136 JOB SCOPE DRILLING SUPPORT-CAPITAL JOB NUMBER 0512000814.1 DATE DALLY WORK UNIT NUMBER 08/01/00 PERFORATE OPERATION COMPLETE SUCCESSFUL YES YES Initial Tbg Press I Final Tbg Press Initial Inner Ann 50 PSII 50 PSI 0 PSI DAY 6 KEY PERSON SWS-ELMORE Final Inner Ann I 0 PSI I DAILY SUMMARY SUPERVISOR FERGUSON Initial Outer Ann I Final Outer Ann 0 PSIJ 0 PSI I PERF 5012'-5059', 5094'-5140', 5150'-5173'. 2 1/2" HSD ULTRA-JET DP, 4 SPF, 60 DEG PHASING, TIME LOG ENTRY 07:30 MIRU SWS 2128 ELMORE, REBUILD WEAK POINT PRIOR TO 1ST GUN RUN. 09:30 RU GUN 1, PT 3000#. 09:40 RIH W/CCL, GUN 1,23'X 2.5" GUN, 4 SPF, D.P.,. 10:20 TIE IN AT JEWELRY AT 4900', RIH TO 5250'. 10:50 RE-CK TIE IN, LU SHOOT 5150'-5173'. POOH. 11:30 RIH W/GUN 2, 26'. 11:45 SAW A FALL-OFF OF TENSION AT 2850', FOR ABOUT 50' WHILE RIH. STOPPED PUH 200', RIH SLOWLY AGAIN. SAW SAME THING AGAIN. APPEARS TO BE POSSIBLE DEBRIS FROM GUNS LAYING IN TBG AT MAX DEVIATION AREA. CONTINUE RIH TO 5250' W/NO PROBLEM. 12:05 RE-CK TIE, LU SHOOT GUN 2 AT 5114'-5140'. POOH. 12:40 RIH W/GUN 3, 20'. 12:45 DIDN'T SEE ANYTHING AT 2850', SLOWED TO 10000 FPH, TO BE CAUTIOUS. CONTINUE RIH. 13:05 RE-CK TIE IN, LU SHOOT 5094'-5114'. POOH. 13:38 RIH W/GUN 4.26'. 14:02 RE-CK TIE IN, LU SHOOT 5033'-5059'. POOH. 14:30 RIH W/GUN 5, 21'. 14:57 RE-CK TIE IN, LU SHOOT 5012'-5033'. POOH. 15:30 AT SURFACE, RD. 16:45 RDMO. 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 23, 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-136 (200-046) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on 1 D-136. If you have any questions regarding this matter, please contact me at 265-6120 or Mark Chambers at 265-1319. Sincerely, Randy Thomas Kupamk Drilling Team Leader PA1 Drilling RT/skad WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June 22, 2000 1D-136, AK-MM-00032 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-136: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22955-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22955-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia REC£1 JUN 2 1 2000 Alaska Oil & Gas Cons. ~;a.~:-mssion Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska June 20, 2000 Alaska Oil and Gas Conservation Comm. Attn.: Ix)ri Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1D-136, AK-MM-00032 1 LDWG formatted Disc with verification listing. API#: 50-029-22955-00 PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING A. COPY OF THE TRANSMITYAL LETTER TO THE ATTENTION OF:- Sperry-Sun Drilling Service Attn:..Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: R. ECciVED JUN 21 2OOO Cobs. CommiSSlO~ Alaska 0il & Gas Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 16-May-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-136 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 5,680.00' 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-136 Surveyed: 4 May, 2000 SURVEY REPORT OS!6!NAL 16 May, 2000 Your Ref: AP1-500292295500 Surface Coordinates: 5959048.98 N, 560490.91 E (70° 17' 55.2600" N, 149° 30' 36.4295" W) Kelly Bushing: 101.22ft above Mean Sea Level DFIILLIN{] SE Ftb'l (~ E S Survey Ref: svy9207 A HA]~,]IfftJE~TO~N CO~,I~ANY North Slope Alaska Measured Depth (ft) Incl. Azim. 1D- 136 Gyro 0.00 0.000 120.00 0.400 150.00 0.500 180.00 0.700 210.00 1.100 230.00 1.100 260.00 1.220 290.00 1.450 320.00 1.260 350.00 0.830 380.00 0.620 410.00 0.500 440.00 0.440 480.00 0.680 0.000 3O2.980 304.950 3O3.34O 304.940 316.870 314.140 312.710 311.640 310.590 305.740 313.930 305.150 122.770 1D-136 518.72 546.73 577.55 611.20 641.73 2.120 2.50O 2.510 2.440 3.080 Sperry-Sun Drilling Services Sub-Sea Depth (ft) Survey Report for 1D- 136 Your Ref: AP1-$00292295500 Surveyed: 4 May, 2000 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) -101.22 18.78 48.78 78.78 108.77 128.77 158.76 188.75 218.75 248.74 278.74 308.74 338.74 378.74 0.00 120.00 150.00 180.00 209.99 229.99 259.98 289.97 319.97 349.96 379.96 409.96 439.96 479.96 0.00 N 0.00 E 0.23 N 0.35 W 0.36 N 0.55 W 0.54 N 0.81 W 0.80 N 1.20 W 1.05 N 1.48 W 1.48 N 1.91 W 1.96 N 2.42 W 2.44 N 2.94 W 2.80 N 3.36 W 3.04 N 3.65 W 3.22 N 3.88 W 3.38 N 4.07 W 3.34 N 3.99 W 132.990 417.44 518.66 2.73 N 3.28W 129.600 445.43 546.65 1.98 N 2.43W 129.350 476.22 577.44 1.13 N 1.39W 131.890 509.84 611.06 0.18 N 0.28W 129.170 540.33 641.55 0.77 S 0.84 E Alaska State Plane 4 Kuparuk 1D Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (ft) (°/100ft) (fi) 0.00 0.333 -0.42 0.337 -0.65 0.669 -0.97 1.336 -1.44 1.143 -1.82 0.440 -2.41 0.775 -3.10 0,639 -3.80 1.435 -4.34 0.729 -4.72 0.48O -5.01 0.312 -5.26 2.799 -5.17 3.760 -4.24 1.441 -3.12 0.048 -1.78 0.387 -0.34 2.139 1.12 5959048.98 N 560490.91 E 5959049.21N 560490.56 E 5959049.34 N 560490.36 E 5959049.51 N 560490.10 E 5959049.77 N 560489.71E 5959050.02 N 560489.42 E 5959050.45 N 560488.99 E 5959050.92 N 560488.48 E 5959051.40 N 560487.95 E 5959051.75 N 560487.53 E 5959051.99 N 560487.23 E 5959052.17 N 560487.01E 5959052.33 N 560486.82 E 5959052.29 N 560486.89 E 5959051.68 N 560487.61E 5959050.94 N 560488.47 E 5959050.10 N 560489.51 E 5959049.16 N 560490.63 E 5959048.22 N 560491.75 E Comment MWD Magnetic RECEIVED IVlAY 18 2000 Continued... 16 May, 2000 - 12:41 -2- Alaska Oil & Gas Cons. Commissior, Anchorage DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Az[m. Sub-Sea Depth (ft) Sperry-Sun Drilling Services Survey Report for 1D- 136 Your Ref: API-500292295500 Surveyed: 4 May, 2000 Vertical Local Coordinates Depth Northings Eastings (fi) (ft) (fi) 670.19 3.740 132.740 568.74 669.96 762.54 6.410 122,110 660.72 761.94 859.69 12.560 118.840 756.50 857.72 955.36 12,520 120.200 849.89 951.11 1051.57 13,610 118.590 943.61 1044.83 1149.28 13.900 121,300 1038.52 1139.74 1246.46 17.360 123.000 1132.09 1233.31 1343.45 21.700 123.520 1223.48 1324.70 1439.48 26.110 122.090 1311.25 1412.47 1537,56 26.560 122.970 1399.15 1500.37 1634.65 26.320 123.400 1486.08 1587.30 1730.58 30.510 126.220 1570.44 1671,66 1827.75 33.780 125.820 1652.71 1753.93 1924.73 37.940 126.850 1731.29 1832.51 2023,00 42,420 125.240 1806.35 1907.57 2119.77 45.040 122.580 1876.28 1977.50 2216.89 46.880 123.110 1943.79 2045.01 2313.80 50.630 122.030 2007.67 2108.89 2410.30 54.410 120.450 2066.38 2167.60 2505.05 53.620 125.270 2122.07 2223.29 2601.72 52.230 126.110 2180.35 2281.57 2697.59 51.570 127.380 2239.51 2340.73 2794.44 51.540 127.270 2299.72 2400.94 2891.70 55.390 126.740 2357.61 2458.83 2987.45 59.830 121.800 2408.91 2510.13 1.88 S 2.11E 6.67 S 8.69 E 14.65 S 22.55 E '24.89 S 40,63 E 35.55 S 59.58 E 47.15 S 79.70 E 61,11 S 101.84 E 78.90 S 128,94 E 99.94 S 161.66 E 123.34 S 198.34 E 147.00 S 234.52 E 173.11S 271.94 E 203.51S 313.75 E 237,18 S 359.49 E 274,44 S 410.76 E 311.72 S 466.28 E 349.59 S 524.93 E 388.79 S 586.34 E 428.47S 651.81E 470.04 S 716.19 E 515,03 S 778,83 E 560.16 S 839.29 E 606.15 S 899.61 E 653.17 S 962.01 E 698.59 S 1028,82 E Global Coordinates Northings Eastings (ft) , (ft) 5959047.11N 560493.04 E 5959042.38 N 560499.65 E 5959034.51 N 560513.58 E 5959024.42 N 560531.73 E 5959013.91N 560550.77 E 5959002.47 N 560570,99 E 5958988.69 N 560593.24 E 5958971.12 N 560620.48 E 5958950.34 N 560653.37 E 5958927.24 N 560690.24 E 5958903.87 N 560726.60 E 5958878.06 N 560764.23 E 5958848.01N 560806.29 E 5958814.70 N 560852,30 E 5958777.85 N 560903.87 E 5958741.02 N 560959.69 E 5958703.63 N 561018.64 E 5958664.92 N 561080.36 E 5958625,77 N 561146.15 E 5958584.72 N 561210.86 E 5958540.24 N 561273.86 E 5958495,60 N 561334.68 E 5958450.09 N 561395.37 E 5958403.58 N 561458.14 E 5958358.69 N 561525.32 E Alaska State Plane 4 Kuparuk 1D Dogleg Vertical Rate Section (°/lOOft) (ft) 2.435 2.80 3.053 10.93 6.352 26.89 0.311 47.61 1.194 69,30 0.723 92.49 3.591 118.66 4.478 151.07 4.631 189.97 0.607 233.47 0.316 276.70 4.585 322.32 3.372 373.96 4.334 430.68 4.679 494.00 3.307 560.88 1.935 630.68 3.959 703.53 4.127 780.03 4.199 856.65 1.596 933,72 1.249 1009.04 0.094 1084.72 3.983 1162.70 6.361 1243.49 Comment 16 May, 2000 - 12:41 -3- RECEIVED UAY 18 2000 _ Alaska 0il & Gas Cons. Commission Anchorage Continued... DrillQuest 1.05.05 North Slope Alaska Measured Depth (ft) Incl. Sperry-Sun Drilling Services Survey Report for 1D-136 Your Ref: API-500292295500 Surveyed: 4 May, 2000 Sub-Sea Vertical Azim. Depth Depth (ft) (ft) 3085.37 61.850 119,220 2456.63 2557.85 3183.31 59.290 119,200 2504.75 2605.97 3280.58 55,230 121.750 2557.35 2658.57 3377.84 54.990 123.260 2612.99 2714.21 3474.91 55.600 123.000 2668.25 2769.47 3573.18 56,560 123.230 2723.09 2824.31 3669.63 57.160 124.390 2775,82 2877.04 3766.15 53.980 122.510 2830.39 2931.61 3862.75 53.690 121.760 2887.39 2988.61 3960.53 53.070 122.210 2945.72 3046.94 4058.15 53.490 122.960 3004.09 3105.31 4155.67 54.130 122.210 3061.67 3162.89 4252.55 54.740 122.600 3118.02 3219.24 4349.94 55.170 123.130 3173.94 3275.16 4446.73 54.920 123.940 3229.40 3330.62 4543.04 55.480 123.560 3284.36 3385.58 4639.79 51.870 123.440 3341.66 3442.88 4736.44 50.820 123.620 3402.03 3503.25 4832.45 46.260 125.470 3465.59 3566.81 4931.10 42.210 123.370 3536.26 3637.48 5028.35 38.740 122.150 3610.22 3711.44 5125.29 33.520 120.410 3688.50 3789.72 5221.01 32.480 119.210 3768.77 3869.99 5316.43 32.850 119.980 3849.10 3950.32 5416.82 32.920 120.040 3933.41 4034.63 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 1 D Dogleg Vertical Rate Section (°/100ft) (ft) Comment 741.98 S 1102.49 E 783.61 S 1176.94 E 825.05 S 1247.45 E 867.92 S 1314.73 E 911.53 S 1381.55 E 956.08 S 1449.85 E 1001,02 S 1516.95 E 1044.92 S 1583.35 E 1086,40 S 1649.39 E 1127,97 S 1715.95 E 1170.11S 1781.88 E 1212.49 S 1848.20 E 1254.73 S 1914.73 E 1298.00 S 1981.71 E 1341.82 S 2047.83 E 1385.76 S 2113.59 E 1428.77 S 2178.58 E 1470.46 S 2241.49 E 1511.22 S 2300.76 E 1550.14 S 2357.48 E 1584.31S 2410.55 E 1614.02 S 2459.35 E 1639.95 S 2504.58 E 1665.38 S 2549.36 E 1692.64 S 2596.56 E 5958315.90 N 561599.34 E 5958274.87 N 561674.12 E 5958234.00 N 561744.96 E 5958191.67 N 561812.58 E 5958148.60 N 561879.76 E 5958104.60 N 561948.41 E 5958060.20 N 562015.87 E 5958016.84 N 562082.62 E 5957975.89 N 562148.99 E 5957934.86 N 562215.89 E 5957893.25 N 562282.15 E 5957851.40 N 562348.81 E 5957809.71N 562415.68 E 5957766.98 N 562483.00 E 5957723.69 N 562549.47 E 5957680.28 N 562615.58 E 5957637.79 N 562680.92 E 5957596.61 N 562744.17 E 5957556.33 N 562803.76 E 5957517.87 N 562860.80 E 5957484.12 N 562914.13 E 5957454.80 N 562963.17 E 5957429.25 N 563008.61 E 5957404.17 N 563053.59 E 5957377.29 N 563101.01 E 3.090 1328.87 2.614 1413.93 4.720 1495.61 1.297 1575.37 0.666 1655.17 0.996 1736.71 1.184 1817.47 3.665 1897.06 0.695 1975.03 0.734 2053.48 0.751 2131.72 0.903 2210.41 0.710 2289.21 0.627 2368.93 0.733 2448.26 0.666 2527.35 3.733 2605.28 1.096 2680.76 4.964 2752.67 4.365 2821.46 3.660 2884.57 5.487 2941.66 1.283 2993.68 0.583 3045.07 0.077 3099.47 RECEIVED MAY 18 2000 Continued,.. 16 May, 2000 - 12:41 -4- Alaska 0ii & Gas Co,qs. Oommissior~ DriliQuest 1.05.05 Anchorage Sperry-Sun Drilling Services Survey Report for 1D- 136 Your Ref: API-500292295500 Surveyed: 4 May, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 5513.97 33.010 118.720 4014.92 4116.14 1718.57 S 2642.62 E 5609.81 33.470 118.170 4095.07 4196.29 1743.60 S 2688.81 E 5680.00 33.470 118.170 4153.62 4254.84 1761.87 S 2722.93 E Alaska State Plane 4 Kuparuk 1D Global Coordinates Dogleg Vertical Northings Eastings Rate Section (ft) (fi) (°/100ft) (ft) 5957351.73 N 563147.27 E 5957327.08 N 563193.67 E 5957309.08 N 563227.94 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.645° (28-Apr-00) 0.745 3152.20 0.574 3204.53 0.000 3243.07 The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 123.470° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5680.00ft., The Bottom Hole Displacement is 3243.23ft., in the Direction of 122.905° (True). Comment Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 5680.00 4254.84 1761.87 s 2722.93 E Projected Survey RECEIVED MAY 1 8 2000 Alaska ":'u,, & ,~,,,,e~° P_.-~,'.ns. Anchorage Continued... 16 May, 2000 - 12:41 - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Survey Report for 1D-136 Your Ref: API-500292295500 Surveyed: 4 May, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 518.72 518.66 TO Measured Depth (ft) 518.72 5680.00 Vertical Depth (ft) 518.66 4254.84 Survey Tool Description AK-1 BP_HG MWD Magnetic 16 May, 2000- 12:41 -6- DrillQuest 1.05.05 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~I~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Supervisor ARCO Alaska. Inc. PO Box 100360 Anchorage. AK 9951 (t-0360 Re~ Kuparuk River Unit 1D-136 ARCO Alaska, Inc. Permit No: 200-046 Sur. Loc. 618' FNL. 598' FEL. Sec. 23. TllN, R10E, UM Btmhole Loc. 2362' FNL, 2038' FWL, Sec. 24. T11N, RIOE. UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The pernfit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Aamular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. ID-136. Please note that any disposal of fluids generated from this drilling operation which arc pumped down the sm'face/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pcrlnit to drill docs not authorize disposal of drilling waste in a volume greater than 35,000 barrels through thc annular space of a single well or to use that well for disposal purposes for a period longer than one year. The blowout prevention equiplnent (BOPE) must be tested in accordance with 20 AAC 25.035; and thc mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.(130(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 rcprcscntativc of thc Commission mav witness the tests. Notice max.' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Clu'istcnson. P.E. Chair BY ORDER OF THE ~OMMISSION DATED this { ~}a~ {lay of April, 2t}00 lit/Enclosures cc: Department of Fish & Game. Habitat Section w/o encl. Depamnent of Enviromncntal Conservation xv/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type ofwork: Drill ~] Redrill D '1 lb. Type ofwell. Exploratory D StratigraphicTest D Development Oil Re-entry D Deepe, OI Service r~ Developme,t Gas D Single Zone ~] Multiple 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) 618' FNL, 598' FEL, Sec. 23, T11N, R10E, UM (ASP: 560493.2, 5959049) Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2273' FNL, 1904' FWL, Sec. 24, T11N, R10E, UM (ASP: 563010, 5957414) 1 D-136 #U-630610 At total depth 9. Approximate spud date Amount 2362' FNL, 2038' FWL, Sec. 24. T11N, R10E, UM (ASP: 563144.6, 5957326.6) May 10, 2000 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 2362' @ TD feet 1D-08 15.6' @ 600' MD feet 2560 5643 ' MD/4248 ' 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 55° Maximum surface 1416 psig At total depth (TVD) 1862 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of Cement Hole Casin~l Wei~lht Grade Couplin~l Length 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 4908' 30' 30' 4938' 3634' 435 sx Class G & 390 sx Class G 7.875" 3.5" 9.3# L-80 EUE 8rd M 705' 4938' 3634' 5643' 4248' (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 ORIGINAL Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production . . Perforation depth: measured : ii "; true vertical ., il, i: ?~¢ ;.:::; '; ' ~.:¢!:.; :.. -'~ 20. Attachments Filing fee ['~ Property Plat E] BOP Sketch r~ Diverter Sketch E] Drilling program Drilling fluid program [~ Time vs depth plot r-]Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements r"] 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Carl Mark Chambers 265-131~. Signed ~ , Title: Drilling Engineering Superviso, Date ~l~.~l Chip A,vord~ ~ ~ Pr~.n~r~d bv ,C;h~r~n AIl.~un-Drak~ / Commission Use Onl) Permit Number APl number I Approval da~.///~/~ ISee cover letter ~Z 043, -- "~' 50- 0 2- ~P-.- ~,Z.. ~ ~',,~" 0 I for other requirements Conditions of approval Samples required E]Yes [~ No Mud log required E] Yes ,~ No Hydrogen sulfidemeasures D Yes J~ No Directional surveyrequired ~ Yes D No Required working pressure for BOPE D2M; D 3~.~ D 5M; D lOM;D r~ c,,(~)L~ ~ I%1('~ ,~,l~f,,~ Other: ORIGINAL SIGNEDBY by order of Approved by Robel't N. Christenson Commissioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate 1D-136 West Sak Monobore Injector 5-1/2" x 3-1/2" Tapered String Planned Completion 13-3/8" 68# L-80 BTC Conductor @ 80' 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 Iiaker 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 @ 5643' MD / 4248' TVD MAC 03/15/0O Drill, Case and Completion Plan for West Sak 1D-136 Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 13-3/8". Weld landing ring on conductor. 2. MIRU Nordic Rig 3. Install diverter & function test same. 3. 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. 4. Circulate and condition hole to run casing. POOH. 5. 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. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. 7. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 8. PU and RIH with 3-1/2" tubing to just above seal bore extension and displace well to brine. 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. 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. 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 3/28/00 Drilling Fluid Program, Pressure Calculations & Drilling Area Risks West Sak 1 D-136 Drilling Fluid Tvpe 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 1D-136 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 from surface 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 3,710'. 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 = (4048 ft)(0.46 - 0.11 psi/ft) -- 1416 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 1 D-136 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-136. Well Proximity Risks: The nearest existing well to 1 D-136 is 1D-08. The wells are 15.6' from each other at a depth of 600' MD. The nearest planned well to 1 D-136 is 1 D-137. As currently planned the wells will be 13.997' from each other at a depth of 600' 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-136 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. 1D-136 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 @ 4923'(approximately 100' above the D Sands), TD @ 5643' MD. Top of Tail cement @ 4350' (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 1694' MD, Volume Calcs: Pump 20 bbls Arco Preflush, 50 bbls MUDPUSH XL @ 10.0 ppg. Cement from MD to 4350' with Class G + adds @15.8 ppg and from 4350' 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: 1173.6 ft3+ 667.0 ft3 = 1840.6 ft3/4.44 ft3/sk = (300% excess): (1694') x 0.1732 ft3/ft x 4 = (45% excess): (4350'-1694') x 0.1732 ft3/ft x 1.45 = 1173.6 ft3 667.0 ft3 1840.6 ft3 415 sks - Round up to 435 sks Have an additional 260 sks of lead on location for Top Out]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): (4923'-4350') x 0.1732 ft3/ft x 1.45 = 3.5" x OH (45% Excess): (5643'-4923') x 0.2714 ft3/ft x 1.45 = 80' shoe joint: 80' x 0.04822 ft3/ft = Total: 143.9 ft3 283.3 ft3 3.9 ft3 143.9 ft3 + 283.3 ft3 + 3.9 = 431.1 ft3/1.17 ft3/sk = 431.1 ft3 369 sks - Round up to 390 sks BHST = 70F, BHCT = 65F CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl Arco Preflush, 50 bbls 10.0 ppg MUDPUSH XL, 415 sks (328 bbls) ASLite Lead, drop plug, 369 sks (77 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 3.5 and 5.5 BPM for mud removal in Effective Laminar Flow. Drop the rate below 3 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 3bpm. 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-136 WPs 0 -- 600 - 4~.,2tart Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD 1200 - 1800 - .-- > 2400 - 3000 - 3600 - O O II .-- ~ 4200 - -- I DrillQuest' ~o./2ir Rate Increase @ 2.500°/1 00ft: 800.00ft MD, 799.27ft TVD vertical Dogleg SectionRate 0.00 0.00 0.000 20.92 1.500 97.15 2.500 253.06 3.500 328.06 0.0O0 752.29 4,000 2589.71o,o0o 3001.264.0O0 3094.914.000 3161.744.000 Proposal Data for 1D-136 WP1 Vertical Origin: 1 D-138 Horizontal Odgln: 1D-136 Measurement Units: ft Nodh Reference:Tree North Dogleg severity: Degrees per 10Oft Vertical Section Azimuth: 123.489° Vertical Section Description: 1D-136 Vertical Section Origin: 0.00 N,0.00 E Measured Incl. Azlm. VerticalNorthlngs Easflngs Depth Depth 0.00 0.0O0 0,461 0.00 0.00 N 0.00 400.00 0.000 0.461 400.00 0.O0 N 0.O0 800.00 6.000 123.471799.27 11.54S 17.45 12O0.O016.000t23.4711191.42 53.58 S 81.04 E 1600.0030.000123.4711558.71 139.56 S 211.09 1750.003O.OOO123.4711688.61 180,93 S 273.65 2381.5055.260123.4712149.48 414.89 S 627.54 4617.5055.26O123.4713423.67 1428.25 S 2160.26 5223.9931.000123.4713863.00 1655.22 S 2503.56 5431.5322.699123.4444048.00 1706.85 S 2581.69 5642.5914.256123.4024248.00 1743.67 S 2637.46 I C tWeJJProperties ..... Well: 10-136 WPs Horizontal Coordinates: Ref. Global Coordinates: 595.~ 949.0 Ref. Well: 855. ~3 S, l Rel. Geographical Coordinates: 70° ! 7' 55.; RKB Elevation: 95.C~ ~lt ab( 95.O ~lt ab( North Reference: True North Units: Foot 5959049.01 N, 58049320 E 855.23 S, 2.18 70" 17' 55.2801" N, 149" 30' 30.3527" W 95.0Oit above Mean Sea Level 95.001t above Well Section Azimuth: 123.469° (True North) Scale: linch = 60Oft lOOO.OO 1100.oo t~'°Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1191.42ft TVD 2oo.o0 1400.00 EnO Dir: 1600.0Oft MD, 1558.71ft TVDt500'00 600.00 tart Dir @ 4.000°/100ft: 1750.00ft MD, 1688.61ft TVD 18oo.oo ' 1900.00 200o.00 210o.oo 00,>o9/End Dir: 2381.50ft MD, 2149.48ft TVD 2400~00 2500.00 27oo.00 280o.oo 2000.00 200.00 300.00 00.00 700.oo 800.00 100.oo 420o.0o 300.00 400.00 5oo 00 tart Dir @ 4.000°/1 00ft: 4617.50ft MD, 3423.67ft TVD 700.00 9oo.oo ................................................................................................................... .%c;;o:;o ............ /7-.~7/o. oo m) 0 ~ ~ B ~776 O0 1 VI) ............... .. . .................... A 3 - 3863. O0 7'VI) 53o0.oo 400.00 ........................................................................................................................................ .~o.;...~/ _ ~o~,~.oo m~ Total Depth: 5642.591t MD, 4248.00tt TVD 5 1/2" X 3 1/2" Liner - 5642.59 MD, 4248.00 TVD 0 600 1200 1800 2400 3000 North Slope Alaska Alaska State Plane 4 Kuparuk 1 D 1 D-136 WPs ID' tHQuest Current Well Properties Well: 1 D-136 WPs Horizontal Coordinates: Ref. Global Coordinates: 5959049.01 N, 560493.20 E Ref. Well: 855.23 S, 2.18 E Ref. Geographical Coordinates: 70° 17' 55.2601' N, 149° 30' 36.3627" W RKB Elevation: 95.00ft95'00ft aboveab°ve WelIMean Sea Level North Reference: True North LUn ts: Feet 0 -- -400 - ~ -800 - .-- o Z -1200 - o -1600 - .-- ',r-- __ O Scale: linch = 400ft Eastings 0 400 800 1200 I I I I Start Dir @ 1.500°/100ft: 400.00ft MD 400.00ft TVD D r Rate Increase @ 2.500°/100ft: 800.00ft MD, 799.27ft TVD Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1191.42ft TVD 1600 2O0O I 2400 I End Dir: 1600.00ft MD, 1558.71ft TVD Start Dir @ 4.000°/100ft: 1750.00ft MD, 1688.61ft TVD End Dir: 2381.50ft MD, 2149.48ft TVD Start Dir @ 4.000°/100ft: 4617.50ft MD, 3423.67ft TVD I I 0 400 Scale: linch = 400ft INJ 136 TARGET 3863.00 TVD 1655.22 S, 2503.56 E Total Depth: 5642.59ff MD, 4248.00ft TVD 5 1/2' X 3 1/2' Liner - 5642.59 MD, 4248.00 TVD I I I I I 800 1200 1600 2000 2400 -0 - -400 -- -800 Eastings Reference is True North - -1200 -- -1600 o .-- Sperry-Sun Drilling Services Proposal Data- 1D-136 WPs- 1D-136 WP1 180. 071 180. 071 15 March, 2000 - 12:04 - I - DrillQuest Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Measured Depth Incl. Azim. (ft) o.oo o.ooo o.ooo 200.00 0.000 0.000 400.00 0.000 0.000 450.00 0.750 123.471 500.00 1.500 123.471 550.00 2.250 123.471 600.00 3.000 123.471 650.00 3.750 123.471 700.00 4.500 123.471 750.00 5.250 123.471 800.00 6.000 123.471 Sub-Sea Depth (ft) -95.00 105.00 305.00 355.00 404.99 454.96 5o4.91 554.82 604.69 654.51 704.27 Vertical Depth fit) 0.00 200.00 400.00 45O.OO 499.99 549.96 599.91 649.82 699.69 749.51 799.27 850.00 7.250 123.471 753.93 848.93 900.00 8.500 123.471 803.46 898.46 950.00 9.750 123.471 852.83 947.83 1000.00 11.000 123.471 902.01 997.01 1050.00 12.250 123.471 950.98 1045.98 1100.00 13.500 123.471 999.73 1094.73 1150.00 14.750 123.471 1048.21 1143.21 1200.00 16.000 123.471 1096.42 1191.42 1250.00 17.750 123.471 1144.27 1239.27 1300.00 19.500 123.471 1191.65 1286.65 1350.00 21.250 123.471 1238.52 1333.52 1400.00 23.000 123.471 1284.83 1379.83 1450.00 24.750 123.471 1330.55 1425.55 1500.00 26.500 123.471 1375.63 1470.63 Local Coordinates Global Coordinates Northings Eastings Northings (ft) (fi) (fi) 0.00 N 0.00E 5959049.01N 0.00 N 0,00 E 5959049.01N 0.00 N 0o00 E 5959049.01N 0.18 S 0.27 E 5959048.83 N 0.72 S 1.09 E 5959048.30 N 1.62 S 2.46 E 5959047.40 N 2.89 S 4.37 E 5959046.16 N 4.51 S 6.82 E 5959044.55 N 6.49 S 9.82 E 5959042.59 N 8.84 S 13.37 E 5959040.28 N 11.54 S 17.45 E 5959037.61N 14.72 S 22.27 E 5959034.47 N 18.50 S 27.98 E 5959030.74 N 22.87 S 34.60 E 5959026.42 N 27.84 S 42.11E 5959021.51N 33.40 S 50.51E 5959016.02 N 39.54 S 59.80 E 5959009.95 N 46.27 S 69.98 E 5959003.31 N 53.58 S 81.04 E 5958996.08 N 61.58 S 93.15 E 5958988.18 N 70.39 S 106.47 E 5958979.48 N 79.99 S 120.99 E 5958969.99 N 90.38 S 136.70 E 5958959.74 N 101.54 S 153.58E 5958948.71 N 113.46 S 171.61 E 5958936.93 N Eastings (ft) 560493.20 E 560493.20 E 560493.20 E 560493.48 E 560494.30 E 56O495.67 E 56O497.59 E 560500.06 E 5605O3.07 E 560506.64 E 560510.75 E 560515.59 E 560521.33 E 560527.98 E 560535.53 E 560543.98 E 560553.32 E 560563.55 E 560574.67 E 560586.84 E 56O600.23 E 560614.83 E 560630.62 E 560647.59 E 560665.72 E Dogleg Rate (°/100ft) o.ooo o.ooo 1.5oo 1.5oo 1.5oo 1.5oo 1.5oo 1.5oo 1.5oo 1.5oo 2.500 2.500 2.500 2.500 2.500 2.500 2.500 2.500 3.500 3.500 3.500 3.500 3.500 3.500 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 0.00 0.00 0.00 0.33 1,31 2.94 5.23 8.18 11.77 16.02 2O.92 26.69 33.54 41.47 50.48 60.55 71.69 83.90 97.15 111,67 127.63 145.04 163.87 184.11 205.73 Comment Start Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD Dir R~elncrease @ 2.500°/100~:800.00ff MD, 799.27ff TVD Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1191.42ft TVD Continued... 15 March, 2000 - 12:05 - I - Dr#/Quest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (~) ~t) 1550.00 28.250 123.470 1420.03 1600.00 30,000 123.471 1463.71 1750.00 30.000 123,471 1593.61 1800.00 32,000 123,471 1636.47 1850.00 34.000 123,471 1678.40 1900.00 36.000 123,471 1719.36 1950.00 38.000 123.471 1759.29 2000.00 40,000 123.471 1798.14 2050,00 42.000 123,471 1835.87 2100.00 44.000 123.471 1872.44 2150.00 46.000 123,471 1907.79 2200.00 48.000 123.471 1941.89 2250.00 50,000 123,471 1974.69 2300.00 52.000 123.471 2006.16 2350.00 54.000 123.471 2036.25 2381.50 55,260 123.471 2054.48 2400.00 55.260 123.471 2065.02 2600.00 55.260 123.471 2178.99 2800.00 55.260 123,471 2292.96 3000.00 55.260 123,471 2406.94 3200.00 55,260 123.471 2520.91 3400.00 55,260 123,471 2634.88 3600.00 55.260 123.471 2748.85 3800.00 55.260 123,471 2862.82 4000.00 55.260 123.471 2976.79 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 1515,03 126.14 S 190.79 E 5958924.41 N 560685.00 E 1558.71 139,56 S 211.09 E 5958911.15 N 560705.41 E 1688.61 180.93 S 273.65 E 5958870.29 N 560768.30 E 1731.47 195.13 S 295.13 E 5958856,26 N 560789.90 E 1773.40 210.14 S 317.85 E 5958841.43 N 560812.73 E 1814.36 225.96 S 341.77 E 5958825.81 N 560836.78 E 1854.29 242.55 S 366.87 E 5958809.42 N 560862.01 E 1893.14 259.91 S 393.12 E 5958792.27 N 560888.40 E 1930.87 278.00 S 420.48 E 5958774.41 N 560915.90 E 1967.44 296.80 S 448.92 E 5958755.83 N 560944.50 E 2002.79 316.30 S 478.41 E 5958736.57 N 560974.15 E 2036.89 336.47 S 508.92 E 5958716.65 N 561004.81 E 2069.69 357.28 S 540.39 E 5958696.09 N 561036.45 E 2101.16 378.71 S 572.80 E 5958674.93 N 561069.03 E 2131.25 400.73 S 606.11 E 5958653.17 N 561102.52 E 2149.48 414.89 S 627.54 E 5958639.18 N 561124.06 E 2160.02 423.28 S 640.22 E 5958630,90 N 561136.81 E 2273.99 513.92 S 777.31 E 5958541.36 N 561274.63 E 2387.96 604.56 S 914.41 E 5958451.83 N 561412.45 E 2501.94 695.20 S 1051.50 E 5958362.30 N 561550.27 E 2615.91 785.84 S 1188.60 E 5958272.77 N 561688.09 E 2729.88 876.48 S 1325.69 E 5958183.23 N 561825.91 E 2843.85 967.12 S 1462.79 E 5958093.70 N 561963.73 E 2957.82 1057.76 S 1599.88 E 5958004.17 N 562101.55 E 3071.79 1148.40 S 1736.98 E 5957914.63 N 562239.37 E Dogleg Rate (°/100ft) 3,500 3.500 0,000 4.000 4.000 4.000 4.000 4,000 4.000 4,000 4.000 4.000 4.000 4.000 4,000 4.000 0.000 0.000 0.000 0,000 0,000 0.000 0.000 0,000 0,000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 228,72 253.06 328.06 353,81 381.04 409.71 439.80 471.27 504.07 538.17 573.52 610.09 647.82 686.68 726.61 752.29 767.49 931.84 1096.19 1260.54 1424.89 1589.24 1753.59 1917.94 2082.29 Comment End Dir: 1600.00ft MD, 1558.71ft TVD Start Dir @ 4.000°/100ft: 1750.00ft MD, 1688.61ft TVD End Dir: 2381.50ft MD, 2149.48ft TVD Continued... 15 March, 2000 - 12:05 - 2 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (fi) (ft) 4200.00 55.260 123.471 3090.76 3185.76 4400.00 55.260 123.471 3204.73 3299.73 4600.00 55.260 123.471 3318.70 3413.70 4617,50 55.260 123.471 3328.67 3423.67 4650.00 53.960 123.471 3347.50 3442.50 4700.00 51.960 123.471 3377.61 3472.61 4750.00 49.960 123.471 3409.11 3504.11 4800.00 47.960 123.471 3441.93 3536.93 4850.00 45.960 123.471 3476.06 3571.06 4900.00 43.960 123.471 3511.44 3606.44 4950.00 41.960 123.471 3548.03 3643.03 5000.00 39.960 123.471 3585.78 3680.78 5037.71 38.452 123.471 3615.00 3710.00 5050.00 37.960 123.471 3624.66 3719.66 5100.00 35.960 123.471 3664.61 3759.61 5120.15 35,154 123.471 3681.00 3776.00 5150.00 33.960 123.471 3705.59 3800.59 5200.00 31.960 123.471 3747.54 3842.54 5223.99 31.000 123.471 3768.00 3863.00 5250.00 29.960 123.468 3790.41 3885.41 5300.00 27.960 123.462 3834,16 3929.16 5350.00 25.960 123.456 3878.72 3973.72 5400.00 23.960 123.449 3924.05 4019.05 5431.53 22.699 123.444 3953.00 4048.00 5450.00 21.960 123.441 3970.09 4065.09 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1239.04 S 1874.07 E 5957825.10 N 562377.19 E 1329.68 S 2011.17 E 5957735.57 N 562515.01E 1420.32 S 2148.26 E 5957646.03 N 562652.83 E 1428.25 S 2160.26 E 5957638.20 N 562664.89 E 1442.86 S 2182.36 E 5957623.76 N 562687.11 E 1464.87 S 2215.65 E 5957602.02 N 562720.57 E 1486.29 S 2248.05 E 5957580.87 N 562753,14 E 1507.08 S 2279.50 E 5957560.32 N 562784.76 E 1527.24 S 2309.98 E 5957540.42 N 562815.40 E 1546.72 S 2339.45 E 5957521.17 N 562845.03 E 1565.51S 2367.88 E 5957502.61N 1583.59 S 2395.22 E 5957484.75 N 1596.73 S 2415.10 E 5957471.77 N 1600.93 S 2421.44 E 5957467.63 N 1617,50 S 2446,52 E 5957451,25 N 562873.60 E 562901.09 E 562921.07 E 562927.45 E 562952.66 E 1623.96 S 2456,29 E 5957444.87 N 562962.48 E 1633.30 S 2470.41 E 5957435.64 N 562976,68 E 1648.31 S 2493.10 E 5957420,83 N 562999.49 E 1655.22 S 2503.56 E 5957414.00 N 563010.00 E 1662.49 S 2514.56E 5957406.81 N 563021.06 E 1675.84 S 2534.76 E 5957393.63 N 563041.36 E 1688.34 S 2553.67 E 5957381.28 N 563060.37 E 1699.97 S 2571.27 E 5957369.79 N 563078.07 E 1706.85 S 2581.69 E 5957363.00 N 563088.54 E 1710.72 S 2587.54E 5957359.18 N 563094.43 E Dogleg Rate (°/100ft) 0.000 0.000 0.0oo 0.ooo 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.OOO 4.000 4,000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 2246,63 2410.98 2575.33 2589.71 2616.21 2656,12 2694.95 2732.66 2769.2O 2804.53 2838.60 2871.38 2895.21 2902.81 2932.88 2944.59 2961.52 2988.73 3001.26 3014.45 3038.65 3061.32 3082.42 3094.91 3101.92 Comment Start Dir @ 4.000°/100ft: 4617.50ft MD, 3423.67ft TVD A3 INJ 136 TARGET A1 Continued... 15 March, 2000 - 12:05 - 3 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) (ft) 5500.00 19.960 123.434 4016.78 5550.00 17.960 123.425 4064.06 5600.00 15.960 123.414 4111.88 5642.59 14.256 123.402 4153.00 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 4111.78 1720.57 S 2602.47 E 5957349.44 N 563109.43 E 4159.06 1729.52 S 2616.02 E 5957340.60 N 563123.06 E 4206.88 1737.55 S 2628.20 E 5957332.67 N 563135,30 E 4248.00 1743.67 S 2637.46 E 5957326.63 N 563144.61 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to 1 D-136. Northings and Eastings are relative to 1 D-136. Magnetic Declination at Surface is 26.703° (24-Feb-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1D-136 and calculated along an Azimuth of 123.469° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5642.59ft., The Bottom Hole Displacement is 3161.74ft., in the Direction of 123.469° (True). Dogleg Rate (°/100ft) 4.000 4.000 4.000 4.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 3119.81 3136.05 3150.64 3161.74 Comment Total Depth: 5642.59ft MD, 4248.00ft TVD 5 1/2" X 3 1/2" Liner Continued... 15 March, 2000 - 12:05 - 4 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) 400.00 800.00 1200.00 1600.00 1750.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 400.00 0.00 N 0.00 E 799.27 11.54 S 17.45 E 1191.42 53.58 S 81.04 E 1558.71 139.56 S 211.09 E 1688.61 180.93 S 273.65 E 2381.50 2149.48 414.89 S 627.54 E 4617.50 3423.68 1428.25 S 2160.26 E 5642.59 4248.00 1743.67 S 2637.46 E Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northings (ft) (ft) (ft) (ft) 5037.71 3710.00 3615.00 1596.73 S 5120.15 3776.00 3681.00 1623.96 S 5223.99 3863.00 3768.00 1655.22 S 5431.53 4048.00 3953.00 1706.85 S Comment Start Dir @ 1.500°/100ft: 400.00ft MD, 400.00ft TVD Dir Rate Increase @ 2.500°/100fl: 800.00ft MD, 799.27ft TVD Dir Rate Increase @ 3.500°/100ft: 1200.00ft MD, 1191.42ft TVD End Dir: 1600.00ft MD, 1558.71ft TVD Start Dir @ 4.000°/100ft: 1750.00ft MD, 1688.61ft TVD End Dir' 2381.50ft MD, 2149.48ft TVD Start Dir @ 4.000°/100ft' 4617.50ft MD, 3423.67ft TVD Total Depth · 5642.59ft MD, 4248.00ft TVD Eastings Formation Name (ft) 2415.10 E D 2456.29 E B 2503.56 E A3 2581.69 E A1 Continued... 15 March, 2000 - 12:05 - 5 - DrillQuest 1.05.05 Sperry-Sun Drilling Services Proposal Report for 1D-136 WPs - 1D-136 WP1 Revised: 7 March, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) 5642.59 4248.00 Targets associated with this wellpath Target Name INJ 136 TARGET Casing Detail 5 1/2" X 3 1/2" Liner Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3863.00 1655.22 S 2503.56 E 3768.00 5957414.00 N 563010.00 E 70°17'38.9755"N 149° 29'23.3903"W Target Target Shape Type Point 15 March, 2000 - 12:05 - 6 - DrillQuest 1.05.05 Sperry-Sun Alaska Anticollision Report GLOBAL SCAN APPLIED: All wellpaths within 100'+ 100/1000 of reference Reference: Definitive Plan Interpolation Method: MD Interval: 100.000 ft Error Model: ISCWSA Ellipse Depth Range: 0.000 to 5642.828 ft Scan Method: High Side + Azimuth Maximum Radius: 664.283 ft Error Surface: Ellipse Survey Program for Definitive Wellpath Date: 02/28/2000 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 0.000 5353.720 Planned: 1D-136 WP1-2 Vl MWD MWD - Standard Summary =~.~~ ~f~ :~]]~1~ i~~~ == :. : :=~fe~ = 0ffs~ C~r~Ctr No,Go Allowable ~ii~ Area Deviation warning : ft ft Kuparuk 1D Pad 1D-06 1D-06 V2 486.715 500.000 256.026 9.460 246.566 Pass: Major Risk Kuparuk 1D Pad 1D-07 1D-07 V2 879.369 800.000 132.368 17.205 115.164 Pass: Major Risk Kuparuk 1D Pad 1D-08 1D-08 V12 586.631 600.000 15.575 9.281 6.294 Pass: Major Risk Kuparuk 1D Pad 1D-10 1D-10 V2 581.597 600.000 52.606 9.942 42.664 Pass: Major Risk Kuparuk 1D Pad 1 D-102 WPs 1D-102 WPs V0 Plan: 1D Out of range Kuparuk 1D Pad 1D-11 1D-11 V4 688.009 700.000 23.184 11.654 11.530 Pass: Major Risk Kuparuk 1D Pad 1D-131 1D-131 V2 734.569 800.000 148.066 17.929 130.137 Pass: Major Risk Kuparuk 1D Pad 1D-132 1D-132 V2 746.406 800.000 108.438 17.216 91.222 Pass: Major Risk Kuparuk 1D Pad 1D-133 1D-133 V2 955.009 1000.000 170.882 16.649 154.233 Pass: Major Risk Kuparuk 1D Pad 1D-133 1D-133PB1 V2 955.009 1000.000 170.882 16.649 154.233 Pass: Major Risk Kuparuk 1D Pad 1D-134 1D-134 V2 860.998 900.000 92.161 16.560 75.601 Pass: Major Risk Kuparuk 1D Pad 1D-135 1D-135 V2 482.415 500.000 90.649 6.923 83.726 Pass: Major Risk Kuparuk 1D Pad 1D-137 WPs 1D-137 WPs V0 Plan: 1D 600.288 600.000 13.997 2.296 11.702 Pass: Minor Risk Kuparuk 1D Pad 1 D-138 WPs 1D-138 WPs V0 Plan: 1D 300.000 300.000 30.004 0.952 29.052 Pass: Minor Risk Kuparuk 1D Pad 1D-139 WPs 1D-139 V3 Plan: 1D-139 500.609 500.000 45.170 1.869 43.301 Pass: Minor Risk Site: Kuparuk 1D Pad Well: 1D-06 Rule Assigned: Major Risk Wellpath: 1D-06 V2 Inter-SiteError: 0.000 AlloWable Deviation ft Warning 90.000 90.000 100.000 100.000 0.000 0.000 -0.41 -0.41 255.477 0.000 255.552 189.998 189.998 200.000 199.998 0.051 0.000 -0.53 -0.53 255.803 1.577 254.226 289.995 289.995 300.000 299.995 0.157 0.224 359.33 359.33 255.930 4.068 251.862 389.994 389.994 400.000 399.994 0.270 0.661 359.24 359.24 255.772 7.216 248.556 486.715 486.708 500.000 499.994 0.314 0.880 359.04 235.57 256.026 9.460 246.566 Pass Pass Pass Pass Pass 582.981 582.911 600.000 599.993 0.283 0.944 358.46 234.99 257.783 11.003 246.788 679.022 678.774 700.000 699.993 0.264 0.911 357.42 233.95 261.230 12.287 248.976 774.683 774.083 800.000 799.992 0.329 0.724 355.92 232.45 266.553 13.362 253.310 867.868 866.651 900.000 899.991 0.478 0.648 353.96 230.49 273.928 14.986 259.191 959.504 957.192 1000.000 999.987 0.692 0.816 351.58 228.11 283.184 17.527 266.107 Pass Pass Pass Pass Pass 1050.289 1046.265 1100.000 1099.929 0.962 0.953 348.94 225.47 293.254 20.136 273.864 1140.319 1133.845 1200.000 1199.695 1.284 1.210 346.20 222.73 303.513 23.259 281.414 1228.751 1218.988 1300.000 1298.987 1.654 1.600 343.55 220.08 312.801 26.916 287.601 1314.289 1300.095 1400.000 1397.417 2.070 1.968 340.75 217.28 320.870 30.629 292.697 1400.000 1379.833 1500.000 1494.692 2.554 2.340 337.62 214.15 328.176 34.481 297.048 Pass Pass Pass Pass Pass 1482.351 1454.797 1600.000 1590.237 3.098 2.750 334.16 210.69 334.160 38.676 300.105 1564.952 1528.171 1700.000 1683.500 3.705 3.200 330.44 206.97 338.756 43.217 301.776 1655.937 1607.152 1800.000 1774.118 4.423 3.678 326.75 203.28 341.750 48.309 301.616 1750.000 1688.612 1900.000 1861.883 5.185 4.170 323.24 199.77 340.189 53.626 296.870 1832.335 1758.695 2000.000 1947.144 5.902 4.628 319.26 195.79 337.838 58.561 292.146 Pass Pass Pass Pass Pass 1910.424 1822.766 2100.000 2029.799 6.631 5.069 314.52 191.04 338.157 63.452 290.484 1987.242 1883.331 2200.000 2109.523 7.418 5.554 309.20 185.72 341.662 68.418 291.872 2062.938 1940.450 2300.000 2185.835 8.256 6.081 303.59 180.11 348.298 73.907 295.769 2137.574 1994.123 2400.000 2259.414 9.129 6.613 297.93 174.46 359.590 79.545 303.447 Pass Pass Pass Pass 16" DIVFmTER SCHEMATIC- Nr'-',dic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 10" 150 ANSI Blanked k r~ Open .~ F ...... · To Accumulator I · Closed ~" ~''~__ I ~ .... From Accumulator f Closed 3" Ball Valve Blanked 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 2. 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 3/7/00 .... 1" 5000 psi BOP Stac' ' Kuparuk River Unit West Sak Operations -Injector Wells J 4 3 2 I 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/OO Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement above Port Collar (1000' TVD)/ Perform Top ,Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One Stage Cement Job to Surface / / Cement below Port Collar (1000' TVD) If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Nipple Up and Test BOP's Cement to Surface 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 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 cementing. If conditions indicate a good job, 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 Y2" 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 Y2" TAM Combo Tool, with 2 7/8" EUE Box by Pin and 5 Y2" 15.5 ppf Packer Cups · 5 Y~" 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 ~" 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 Inte~rit~ 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: Surface Location: Target Location: Bottom Hole Location: West Sak 1D-136 618' FNL, 598' FEL, Sec 23, T11 N, R1 2273' FNL, 1904' FWL, Sec. 24, T11 N, R10E 2362' FNL, 2038' FWL, Sec. 24, T11 N, R10E Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1 D 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) 7) 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. The drilling fluid program, in addition to t'he 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 May 10, 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: KRU 1D-136 Well File Chip Alvord Tom McKay ATO- 1 O3O ATO-1060 0100925 Date03-21-00 ** ** Amount * *.******* 100.00. Void after 90 days ...... vet ~2.5,000.00 qoooo,,. //) -'/,~ & WELL PERMIT CHECKLIST FIELD & POOL NAME/'~~ WELL .~- ADMINISTRATION COMPANY ,_~_ ENGINEERING GEOLOGY INIT CLASS PROGRAM: exp dev redrll serv ~ wellbore seg ann. disposal para req 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 ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to 9OOO psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... 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 UNIT# ON/OFF SHORE G~L AREA CU Y N ®U Y 30. 31. D~IEI 33. ~/~//~:~ 34. ANNULAR DISPOSAL35. With proper cementing records, this plan APPR DATE Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Y N~Y N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. //'Y N' v . , Contact name/phone for weekly progress reports [exploratory j~Cly] Y N .. :-: Y N GEOL~_GY: ENGINEERING: UIC/Annular COMMISSION: u 7_:O¥1~fd~ ' ' Commentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry 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. ~ ~~ -GY-~ Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 31,2005 6515 1 3.5" 9.3 lb. L-80 EUE 8RD Tubing & Liner Well: 1 D-136 Field: Kuparuk State: Alaska API No.: 50-029-22955-00 Top Log I ntvl1 .: Su rface Bot. Log IntvI1.: 4,985 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the OS Nipple @ 4,900' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing and liner logged appears to range from good to poor condition. Wall penetrations from 20% to 65% are recorded throughout the interval logged. The damage appears in the form of scattered, shallow pitting with deeper lines of pits and lines of corrosion - eventually broadening into areas of corrosion further down hole. No significant areas of cross-sectional wall loss are recorded throughout the tubing and liner logged. Deposits restrict the J.D. to 2.13" in joint 157 (4,977'). MAXIMUM RECORDED WAll PENETRATIONS: Line Corrosion Line Corrosion Corrosion Line Corrosion Line Corrosion ( 65%) ( 63%) ( 61 %) ( 59%) ( 55%) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: Jt. Jt. Jt. Jt. Jt. 123 @ 69 @ 148 @ 58 @ 54 @ 3,853 Ft. (MD) 2,154 Ft. (MD) 4,645 Ft. (MD) 1,811 Ft. (MD) 1,684 Ft. (MD) No significant areas of cross-sectional wall loss (> 11 %) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Deposits Deposits Minimum J.D. = 2.13" Minimum J.D. = 2.74" Minimum J.D. = 2.75" Minimum J.D. = 2.75" Minimum J.D. = 2.75" SCANNED J4UG ~j 1 2.005 Jt. Jt. Jt. Jt. Jt. 157 @ 105 @ 138 @ 135 @ 117 @ 4,977 Ft. (MD) 3,304 Ft. (MD) 4,334 Ft. (MD) 4,239 Ft. (MD) 3,650 Ft. (MD) I Field Engineer: N. Kesseru Analyst: M. Lawrence Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Staffor'd, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 (ids. Well: Field: Company: Country: 10-136 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Weight 9.3 ppf Grade & Thread l-80 EUE 8RD Nom.OD 3.5 ins Penetration and Metal Loss (% wall) _ penetration body 200 .. metal loss body 150 ILLJ 100 50 0 """""'" o to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 162) pene. 0 1 29 46 86 loss 8 152 2 0 0 o o Damage Configuration ( body) 100 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 158) 25 43 90 0 0 \ PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins July 31,2005 MFC 24 No. 99628 1.69 24 M. Lawrence Upper len. 1.2 ins lower len. 1.2 ins Nom. Upset 3.5 ins Damage Profile (% wall) _ penetration body o 0e... ~ === ===-- c:::: Ëæ:::::.- t=;;' nm metal loss body 50 100 { 5°1 a.---.. l00~ , . GlM 1 Bottom of Survey = 157 Analysis Overview page 2 cl13s~ Well: Field: Company: Country: Minimum Diameter Profile 10-136 Kuparuk ConocoPhillips Alaska USA July 31,2005 MFC 24 No. 99628 1.69 inches 2.992 inches Survey Date: Tool: Tool Size: Tubing 1.0.: Minimum Measured Diameters (In.) 1.69 1.79 1.89 1.99 2.09 2.19 2.29 2.39 2.49 2.59 2.69 2.79 2.89 2.99 0.1 .. æ -: -:=: 12 ~ 16 Ii 20 I 24 28 J! 32 il 36 _i 40 I 44 48 52 liil 56 I 60 64 68 72 j 76 5 80 ::I Z 84 "'~ .... :.~: c ]. 88 92 I.... 96 100 --=! 104 .\ 108 -= 112 116 120 ~~ 124 ,," . 128 '". ,- ,\i ª 132 ........1 136 140 :', ")I ......-.. 144 =Fi=i 148 152 I 154 .....J, 156 '=e 157 -... { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 1 0-136 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 31,2005 Joint Jt. Depth P (' 11. Pen. Pen. Melal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Com men ts (% wall) (Ins.) (Ins.) (y;) (Ins.) 0 50 100 .1 23 0 0.04 17 3 2.93 PUP Shallow corrosion. 1 27 0 0.03 13 1 2.93 Shallow pitting. 2 57 0 0.03 13 4 2.92 Shallow pitting. 3 89 0 0.04 14 :.¡ 2.92 Shallow corrosion. 4 120 0 0.04 16 2 2.91 Shallow corrosion. 5 151 0 0.04 15 2 2.91 Shallow corrosion. Lt. Deposits. 6 183 0 0.04 14 4 2.91 Shallow corrosion. 7 214 0 0.03 13 2 2.92 Shallow pitting. 8 246 0 0.04 14 1 2.93 Shallow corrosion. 9 277 0 0.04 14 2 2.93 Shallow corrosion. 10 308 0 0.04 14 2 2.94 Shallow pitting. 11 340 0 0.03 11 2 2.94 12 371 0 0.04 17 1 2.93 Shallow corrosion. 13 401 0 0.04 15 2 2.91 Shallow corrosion. Lt. Deposits. 14 433 0 0.05 21 2 2.93 Isolated pitting. 15 464 0 0.04 16 2 2.93 Shallow corrosion. 16 496 0 0.03 13 2 2.92 Shallow corrosion. 17 527 0 0.03 13 2 2.93 Shallow pitting. 18 559 0 0.03 11 2 2.94 19 590 0 0.04 14 2 2.94 Shallow corrosion. 20 622 0 0.03 13 J 2.93 Shallow pittin~. 21 653 0 0.03 13 1 2.92 Shallow corrosion. 22 684 0 0.04 14 2 2.91 Shallow pitting. 23 716 0 0.04 15 2 2.92 Shallow corrosion. 24 746 0 0.04 16 1 2.92 Shallow pitting, 25 778 0 0.03 10 1 2.91 26 809 0 0.03 12 2 2.92 27 841 0 0.04 17 2 2.93 Line of Shallow Pits. 28 872 0 0.06 22 1 2.90 Line of Pits. 29 902 0 0.04 16 2 2.92 Line of Shallow Pits. 30 934 0 0.07 28 2 2.92 Line of Pits. 31 964 0 0.04 15 1 2.92 Line of Shallow Pits. 32 995 () 0.04 14 2 2.92 Line of Shallow Pits. 33 1026 0 0.07 26 2 2.93 Line of Pits. 34 1057 0 0.06 22 2 2.93 Line of Pits. 35 1088 0 0.14 54 4 2.93 Line of Pits. 36 1120 0 0.08 31 2 2.93 Line of Pits. 37 1151 () 0.10 39 3 2.94 Line of Pits. 38 1183 0 0.13 50 6 2.93 Line. of Pits. Lt. Deposits. 39 1214 0 0.10 38 J 2.92 Line of Pits. Lt. Deposits. 40 1246 0 0.11 43 4 2.93 Line of Pits. 41 1277 0 0.12 47 3 2.94 Line of Pits. 42 1308 0 0.10 40 J 2.92 Line of Pits. 43 1338 0 0.11 45 3 2.91 Line Corrosion. 44 1370 0 0.11 43 5 2.93 Line Corrosion. 45 1401 0 0.11 42 6 2.92 Line Corrosion. Lt. Deposits. 46 1432 0 0.11 43 4 2.91 Line Corrosion. Lt. Deposits. 47 1463 0 0.11 45 4 2.91 Line Corrosion. Lt. Deposits. 48 1494 0 0.13 SO 6 2.92 Line Corrosion. Lt. Deposits. 49 1523 0 0.12 48 6 2.90 Line Corrosion. Lt. Deposits. I Penetration Body Wi! Metal Loss Body Page 1 { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-136 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 31/2005 Joint Jt. Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body 0/0 Loss I.D. Comments (Ins.) (Ins.) (Yo (Ins.) 50 1554 0 0.13 51 5 2.89 Line Corrosion. Lt. Deposits. 51 1586 0 0.13 51 6 2.90 Line Corrosion. Lt. Deposits. 52 1617 0 0.12 46 7 2.92 Line Corrosion. Lt. Deposits. 53 1647 0 0.13 52 .5 2.92 Line Corrosion. Lt. Deposits. 54 1678 0 0.14 55 .5 2.94 Line Corrosion. Lt. Deposits. 55 1710 () 0.14 55 4 2.92 Line Corrosion. 56 1741 0 0.12 48 6 2.92 Line Corrosion. 57 1772 0 0.12 47 6 2.93 Line Corrosion. 58 1803 0 0.15 59 7 2.93 Line Corrosion. 59 1835 () 0.13 50 b 2.92 Line Corrosion. 60 1866 0 0.13 51 6 2.90 Line Corrosion. Lt. Deposits. 61 1898 0 0.13 52 .5 2.90 Line Corrosion. Lt. Deposits. 62 1928 0 0.13 52 .5 2.87 Line Corrosion. Lt. Deposits. 63 1958 0 0.13 50 .5 2.89 Line Corrosion. Lt. Deposits. 64 1990 () 0.14 54 5 2.89 Line Corrosion. 65 2021 0 0.12 47 .5 2.89 Line Corrosion. 66 2052 0 0.13 50 .5 2.91 Line Corrosion. Lt. Deposits. 67 2083 0 0.11 44 .5 2.86 Line Corrosion. Lt. Deposits. 68 2114 0 0.12 47 6 2.86 Line Corrosion. 69 2146 0 0.16 63 6 2.90 Line Corrosion. Lt. Deposits. 70 2177 0 0.13 53 6 2.88 Line Corrosion. Lt. Deposits. 71 2209 0 0.12 47 6 2.86 Line Corrosion. 72 2240 0 0.12 47 6 2.84 Line Corrosion. Lt. Deposits. 73 2271 0 0.12 46 6 2.86 Line Corrosion. Lt. Deposits. 74 2303 0 0.11 43 6 2.86 Line Corrosion. Lt. Deposits. 75 2334 0 0.12 46 6 2.87 Line Corrosion. 76 2366 0 0.09 36 4 2.88 Line Corrosion. Lt. Deposits. 77 2397 0 0.11 45 .5 2.78 Line Corrosion. Lt. Deposits. 78 2429 () 0.09 37 6 2.78 Line Corrosion. Lt. Deposits. 79 2460 0 0.10 38 6 2.76 Line Corrosion. Lt. Deposits. 80 2491 0 0.10 38 .5 2.80 Line Corrosion. Lt. Deposits. 81 2523 0 0.11 42 6 2.77 Line Corrosion. Lt. Deposits. 82 2554 0 0.09 37 7 2.76 Line Corrosion. Lt. Deposits. 83 2586 0 0.07 28 7 2.79 Line Corrosion. Lt. Deposits. 84 2617 () 0.11 43 6 2.80 Line Corrosion. Lt. Deposits. 85 2648 0 0.09 34 4 2.84 Line Corrosion. 86 2679 0 0.11 43 6 2.80 Line Corrosion. Lt. Deposits. 87 2710 0 0.10 39 6 2.82 Line Corrosion. Lt. Deposits. 88 2742 0 0.10 39 8 2.83 Line Corrosion. 89 2772 0 0.10 40 4 2.85 Line Corrosion. 90 2803 0 0.09 35 6 2.81 Line Corrosion. Lt. Deposits. 91 2834 0 0.10 39 6 2.80 Line Corrosion. 92 2865 0 0.10 39 .5 2.85 Line Corrosion. 93 2897 0 0.09 34 .5 2.83 Line Corrosion. Lt. Deposits. 94 2928 0 0.11 45 6 2.81 Line Corrosion. 95 2960 0 0.11 44 7 . 2.83 Line Corrosion. 96 2991 0 0.10 39 4 2.78 Line Corrosion. 97 3022 0 0.11 45 6 2.80 Line Corrosion. Lt. Deposits. 98 3054 0 0.10 40 7 2.81 Line Corrosion. 99 3085 0 0.10 41 7 2.81 Line Corrosion. Page 2 Damage Profile (% wall) o 50 100 ..~ ... ... ... ... .. · ... .. .. Ü .. .. ... ... .. · ... .. · .. · ... II. .. ~.. .. þ. .. . Penetration Body ~~::j Metal Loss Body :/. PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 EUE 8RD 0.254 in 0.254 in 2.992 in Joint Jt. Depth >cn. Pen. Pen. Metal Min. No. (Ft.) Upsc->t Body °/0 Loss 1.0. (Ins.) (I ns.) 'Yo (Ins.) 100 3117 0 0.09 33 6 2.81 101 3148 () 0.08 32 ß 2.80 102 3180 () 0.08 32 6 2.80 103 3211 () 0.13 50 6 2.80 104 3242 0 0.07 29 C) 2.79 105 3274 0.06 0.09 35 6 2.73 106 3304 0 0.10 39 4 2.75 107 3335 () 0.12 46 .5 2.81 108 3367 () 0.10 39 6 2.80 109 3398 0 0.10 38 6 2.81 110 3429 0 0.11 42 6 2.85 111 3460 0 0.11 44 5 2.86 112 3492 0 0.10 39 .5 2.83 113 3523 0 0.12 46 6 2.81 114 3555 0 0.11 43 6 2.77 115 3586 0 0.09 35 6 2.75 116 3618 0 0.10 41 6 2.75 117 3649 0 0.09 36 .5 2.75 118 3679 0 0.12 47 6 2.84 119 3711 0 0.08 33 8 2.81 120 3742 0 0.08 32 8 2.79 121 3774 0 0.09 35 6 2.81 122 3805 0 0.10 39 .5 2.80 123 3836 0 0.17 65 ß 2.80 124 3868 0 0.10 41 5 2.78 125 3899 0 0.12 46 6 2.80 126 3931 0 0.09 37 7 2.79 127 3962 0 0.13 52 7 2.78 128 3994 0 0.10 41 7 2.79 129 4025 0 0.12 46 6 2.79 130 4055 0 0.10 39 7 2.81 131 4085 0 0.10 39 7 2.80 132 4117 0 0.13 53 9 2.80 133 4148 () 0.11 44 7 2.82 134 4179 0.12 0.11 45 9 2.75 135 4211 0.10 0.12 46 7 2.75 136 4240 () 0.11 44 7 2.80 137 4271 0 0.11 44 9 2.78 138 4303 0 0.13 50 9 2.75 139 4334 0 0.13 53 9 2.77 140 4366 0 0.11 43 7 2.81 141 4397 () 0.12 46 9 2.78 142 4428 0 0.11 42 <) 2.78 143 4459 0 0.13 52 10 2.78 144 4490 0 0.12 48 9 2.82 145 4522 0 0.12 46 7 2.83 146 4553 () 0.12 49 ß 2.83 147 4585 0 0.11 45 10 2.80 148 4615 0 0.16 61 11 2.79 149 4646 0 0.11 45 9 2.81 Well: Field: Company: Country: Survey Date: 1 D-136 Kuparu k ConocoPhillips Alaska, Inc. USA July 31, 2005 Comments Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Line Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. D~posits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Line corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Corrosion. Lt. Deposits. Page 3 Damage Profile (% wall) o 50 100 ... .. .. .. ... ... ... ... .... .11. ... -III- -Ill- - .. - .. - ... -III- -Ill- ... - -III ... .. ., , I - -III ... 1/ I Penetration Body U:a Metal Loss Body I { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 10-136 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal 1.0.: 2.992 in Country: USA Survey Date: July 31,2005 Joint Jt. Depth f)en. Pen. Pen. M('lal Min. Damage Profile No. (Ft.) Upsel Body 0/0 Loss 1.0. Comments (% wall) (Ins. ) (Ins.) % (Ins.) 0 50 100 150 4678 0 0.12 46 7 2.80 Corrosion. Lt. Deposits. 151 4709 0 0.13 52 B 2.83 Corrosion. Lt. Deposits. 152 4740 0 0.13 50 11 2.79 Corrosion. Lt. Deposits. 153 4772 0.09 0.11 43 9 2.78 Corrosion. Lt. Deposits. 154 4802 0 0.12 47 7 2.83 Corrosion. Lt. Deposits. 154.1 4833 0 0.10 40 ') 2.82 PUP Corrosion. Lt. Deposits. 154.2 4848 0 0 0 0 N/A GLM 1 (Latch @ 11 :00) 154.3 4854 0 0.11 43 7 2.83 PUP Line corrosion. Lt. Deposits. 155 4869 0 0.11 45 10 2.81 Line corrosion. Lt. Deposits. 155.1 4900 0 0 0 0 2.81 OS Nipple 156 4901 0 0.10 40 ~) 2.84 Corrosion. Lt. Deposits. 156.1 4933 0 0.12 46 5 2.84 PUP Corrosion. Lt. Deposits. 156.2 4939 0 0 0 0 N/A Seal Assembly 156.3 4952 O.Of) 0.11 44 7 2.89 PUP Corrosion. 157 4962 0 0.10 38 6 2.13 Corrosion. Deposits. I Penetration Body .il~:i! Metal Loss Body Page 4 ····~---->lS ~ B' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-13 6 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst July 31,2005 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 123 at depth 3853.16 ft Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 92 % Tool deviation = 51 0 Finger 21 Penetration = 0.166 ins Line Corrosion 0.17 ins = 65% Wall Penetration HIGH SIDE = UP Cross Sections page 1 Ic- -->.. ..& ~ ø· PDs Report Cross Sections Well: Fìe~d: Company: Country: Tubing: 1 0-13 6 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 69 at depth 21 54.31 ft Tool speed = 51 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 95 % Tool deviation = 50 0 Finger 16 Penetration = 0.16 ins Line Corrosion 0.16 ins = 63% Wall Penetration HIGH SIDE = UP Cross Sections page 2 .1_->.··& ~ ø· PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-13 6 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 ppf L-80 EUE 8RD Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 31, 2005 MFC 24 No. 99628 1.69 24 M. Lawrence Cross Section for Joint 157 at depth 4977.11 ft Tool speed = 54 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 98 % Tool deviation = 43 0 Finger 11 Projection = -0.612 ins Deposits Minimum 1.0. = 2.13 ins HIGH SIDE = UP Cross Sections page 3 ~PHILLlPS Ala~.,a, Inc. A SUbSidiaryl of PHILLIPS PET1 ROLEUM ~~~~NY API: 500292295500 SSSV Type: NONE Annular Fluid: Reference Log: Last Tag: 5493 LastTag Date: 11/15/00 Casing String - ALL Description CONDUCTOR. PRODUCTION LINER Tubing String - ALL Size I Top 3.500 0 Perforations Summary Interval TVD 5012 - 5059 3699 - 3736 TUBING (0-4941, 00:3.500, 10:2.992) PROOUCTlON (0-4952, 00:5.500, Wt:15.50) Gas U1t lanctellDummy Valve 1 (4847-4848, 00:4.725) 5094 - 5140 3764 - 3802 5150 - 5173 3810 - 3830 5201 - 5208 3853 - 3859 5218 - 5266 3867 - 3908 5287 - 5363 3926 - 3989 I ~ _ ~U 1 D-136 Well Type: INJ Orig Completion: 5/7/00 Last W/O: Ref Log Date: TO: 5680 ftKB Max Hole Angle: 62 deg @ 3085 Angle @ TS: deg @ Angle @ TO: 33 deg @ 5680 Rev Reason: Add PERFS by ImO Last Update: 4/10101 Size Top Bottom TVD Wt Grade Thread 16.000 0 110 110 62.58 H-40 WELDED 5.500 0 4952 3653 15.50 L-80 BTCM 3.500 4952 5676 4252 9.30 L-80 EUE 8RD Bottom TVD Wt Grade Th read 4941 3645 9.30 L-80 EUE 8RD Zone Status I Ft SPF Date Type Comment WSD 47 4 8/1/00 IPERF 2.5" HSD Ultra-jet DP, 60 de!; phasing WSB 46 4 8/1/00 IPERF 2.5" HSD Ultra-jet DP, 60 de!; phasing WSA4 23 4 8/1/00 ¡PERF 2.5" HSD Ultra-jet DP, 60 de!; phasing WSA3 7 4 7/31/00 IPERF 2.5" HSD DP Chgs, 60 deg ph WSA3 48 4 7/31/00 IPERF 2.5" HSD DP Chgs, 60 deg ph WSA2 76 4 7/31/00 IPERF 2.5" HSD DP Chgs, 60 deg ph Gas Lift MandrelsNalves NIP St MD TVD Man Man VMfr V Type VOD Latch Port TRO Date Vlv (4900-4901, Mfr Type Run Cmnt 00:3.500) 1 4847 3577 CAMCO KBG29 CAMCO DMY 1.0 INT 0.000 0 6/13/00 Other ()Iugs, equip., etc.) -JEWELRY Depth TVD Type Description ID 4900 3615 NIP CAMCO OS NIPPLE 2.813 4941 3645 SEAL BAKER GBH-22 SEAL ASSY 3.500 SEAL (4941-4942, 00:5.500) 8 Perf (5012-5059) Perf (5094-5140) Perf (5150-5173) Perf (5201-5208) Perf (5218-5266) Perf (5287-5363) Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Jun 13 16:43:41 2000 Reel Header Service name ............. LISTPE Date ..................... 00/06/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/06/13 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: MWD RUN 1 AK-MM-00032 B. HENNINGSE D. HIEM 1D-136 500292295500 PHILLIPS Alaska, Inc. Sperry Sun 13-JUN-00 MWD RUN 2 AK-MM-00032 R. FRENCH D. WESTER 23 liN 10E 616 602 .00 101.22 70.90 RECEIVED JUN 2 1 000 Alaska Oil & Gas Cons. Commission Anchorage # WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.875 13.375 110.0 7.875 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M. WERNER OF PHILLIPS ALASKA, INC. AND R KALISH OF SPERRY-SUN ON 05/02/00. MWD DATA IS CONSIDERED PDC. 4. RUNS 1 AND 2 REPRESENT WELL 1D-136 WITH AN API%: 50-029-22955-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5680'MD, 4255'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAT COMBINED. SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SPACING). SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. EXTRA MEDIUM DEEP THE FOLLOWING CURVES REPRESENT EWR4 DATA PROCESSED WITH VERTICAL RESISTIVITY INVERSION (VRI) MODELING: VEXP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (EXTRA SHALLOW SPACING). VESP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (SHALLOW SPACING). VEMP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (MEDIUM SPACING). VEDP = ENHANCED PHASE SHIFT-DERIVED RESISTIVTY (DEEP SPACING). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 72.0 RPD 100.0 RPM 100.0 RPS 100.0 RPX 100.0 FET 110.0 ROP 114.0 VEDP 4420.5 VEMP 4420.5 VESP 4420.5 VEXP 4420.5 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: STOP DEPTH 5626.5 5633 5 5633 5 5633 5 5633 5 5633 5 5681 5 5420 0 5420.0 5420.0 5420.0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 72.0 2465.5 2 2422.5 5681.5 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 FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 28 8 32 9 36 10 40 11 44 12 Name Service Unit Min Max DEPT FT 72 5681.5 ROP MWD FT/H 0 6325.22 GR MWD API 15.71 128.75 RPX MWD OHMM 1.32 504.16 RPS MWD OHMM 1.59 2000 RPM MWD OHMM 1.83 2000 RPD MWD OHMM 1.67 2000 FET MWD HOUR 0.1866 10.3567 RPX MWD OHMM 1.434 106.597 RPS MWD OHMM 1.26 203.959 RPM MWD OHMM 1.32 212.891 RPD MWD OHMM 1.51 282.087 Mean Nsam 2876.75 11220 118.645 11136 67.4953 11110 25.3338 11068 49.9291 11068 65.0514 11068 97.1128 11068 0.721809 11048 12.2012 2000 13.4715 2000 13.513 2000 14.7679 2000 First Reading 72 114 72 100 100 100 100 110 4420.5 4420.5 4420.5 4420.5 Last Reading 5681 5 5681 5 5626 5 5633 5 5633 5 5633 5 5633 5 5633 5 5420 5420 5420 5420 First Reading For Entire File .......... 72 Last Reading For Entire File ........... 5681.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/13 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 ....... 00/06/13 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 STOP DEPTH GR 72.0 2422.0 RPD 100.0 RPM 100.0 RPS 100.0 RPX 100.0 FET 110.0 ROP 114.0 $ 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): 2429 0 2429 0 2429 0 2429 0 2429 0 2465 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 02-MAY-00 Insite 0.41 MEMORY 2466.0 .4 54.4 TOOL NUMBER PB01494GRV4 PB01494GRV4 7.875 110.0 Water Based 9.80 200.0 9.0 1000 5.2 2.000 1.738 1.700 2.300 76.0 88.5 76.0 76.0 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 DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 Size Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 72 2465.5 ROP MWD010 FT/H 0 1546.69 GR MWD010 API 15.71 116.96 RPX MWD010 OHMM 1.32 504.16 RPS MWD010 OHMM 1.59 2000 RPM MWD010 OHMM 2.14 2000 RPD MWD010 OHMM 1.67 2000 FET MWD010 HOUR 0.1866 2.0598 Mean 1268.75 107 64.6907 46.4427 103.797 139.71 215.094 0.591155 Nsam 4788 4704 4701 4659 4659 4659 4659 4639 First Reading 72 114 72 100 100 100 100 110 Last Reading 2465.5 2465.5 2422 2429 2429 2429 2429 2429 First Reading For Entire File .......... 72 Last Reading For Entire File ........... 2465.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/13 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 ....... 00/06/13 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 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 2422.5 5626.5 RPD 2429.5 5633.5 RPM 2429.5 5633.5 RPS 2429.5 5633.5 RPX 2429.5 5633.5 FET 2429.5 5633.5 ROP 2466.0 5681.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 04-MAY-00 Insite 0.41 MEMORY 5680.0 32.5 61.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ TOOL NUMBER PB014 94GRV4 PB014 94GRV4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 7.875 110.0 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: Water Based 9.50 240.0 9.7 600 4.8 2.600 1.822 2.000 3.000 68.0 99.9 68.0 68.0 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 ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD020 FT/H 4 1 GR MWD020 API 4 1 RPX MWD020 OHMM 4 1 RPS MWD020 OHMM 4 1 RPM MWD020 OHMM 4 1 RPD MWD020 OHMM 4 1 FET MWD020 HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Service Unit Min Max DEPT FT 2422.5 5681.5 ROP MWD020 FT/H 0 6325.22 GR MWD020 API 16.43 128.75 RPX MWD020 OHMM 1.86 66.46 RPS MWD020 OHMM 1.64 111.16 RPM MWD020 OHMM 1.83 108.64 RPD MWD020 OHMM 2.09 105.09 FET MWD020 HOUR 0.2132 10.3567 Mean Nsam 4052 6519 127.161 6432 69.5525 6409 9.86121 6409 10.7566 6409 10.7849 6409 11.3674 6409 0.816381 6409 First Reading 2422.5 2466 2422.5 2429.5 2429.5 2429.5 2429.5 2429.5 Last Reading 5681 5 5681 5 5626 5 5633 5 5633 5 5633 5 5633 5 5633 5 First Reading For Entire File .......... 2422.5 Last Reading For Entire File ........... 5681.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/06/13 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/06/13 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 00/06/13 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File