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198-166
1 Christianson, Grace K (OGC) From:Dewhurst, Andrew D (OGC) Sent:Tuesday, June 10, 2025 8:59 AM To:AOGCC Permitting (CED sponsored) Subject:FW: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Follow Up Flag:Follow up Flag Status:Flagged Operator is requesting to withdraw these sundries. Andy From: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Sent: Thursday, 5 June, 2025 10:11 To: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov>; Byrne, Jan <Jan.Byrne@conocophillips.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: RE: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments Andy, et al, This new interpretaƟon of 20 AAC 25.112(c) and the requirement to P&A each zone within the same pool is a signiĮcant change from what was deemed acceptable by the AOGCC in the past. This has led to hal Ɵng the execuƟon of these 1D P&A operaƟons. ConocoPhillips Alaska requests that our current sundry applicaƟons are withdrawn for the following wells: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) Based on informaƟon presented by the AOGCC at the AADE/SPE luncheon meeƟng on May 22, 2025, ConocoPhillips does not agree that this new requirement will achieve the stated goals or mi Ɵgate the risks menƟoned. We will request a meeƟng on this topic and its implicaƟons aŌer compiling data for discussion. Thank you, Erica Livingston Intervention & Integrity Supervisor, P.E. | ConocoPhillips Alaska +1 907 854 6886 (cell) ekappel@conocophillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 1D-111 (Sundry 325-161) RBDMS JSB 061225 2 From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Wednesday, May 28, 2025 2:58 PM To: Byrne, Jan <Jan.Byrne@conocophillips.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov>; Roby, David S (OGC) <dave.roby@alaska.gov> Subject: [EXTERNAL]KRU West Sak 1D Reservoir Abandonments CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Jan, Regarding: KRU 1D-106 (Sundry 325-159) KRU 1D-111 (Sundry 325-161) KRU 1D-138 (Sundry 325-171) In reviewing the three KRU 1D West Sak abandonments, the proposed work does not meet the requirement of 20 AAC 25.112(c). I do see that there is an exisƟng plug within 50’ of the shallowest perforated interval, but leaving all the perforated zones open to each other does not conĮne all hydrocarbons to their respecƟve indigenous strata and prevent them from migraƟng into other strata. As such, I will not be recommending these sundries for approval. Jack and I are available to discuss this further. Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown 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: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number): 10. Field: KRU West Sak Oil West Sak Oil- P&A 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 7046'N/A Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email:Jan.Byrne@conocophillips.com Contact Phone: 907-265-6471 Authorized Title: Staff Intervention Engineer Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6/1/2025 3.5" Baker GBH 22 Seal Assembly No SSSV 7036' Perforation Depth MD (ft): 6276'- 6670' 6995' 3632'- 3933' 4219'5.5" x 3.5" 16"80' MD 121'121' Length Size Proposed Pools: L-80 TVD Burst 6182' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025650 198-166 P.O. Box 100360, Anchorage, AK 99510 50-029-22911-00-00 ConocoPhillips Alaska, Inc AOGCC USE ONLY Tubing Grade:Tubing MD (ft): 6188' / 3566' No SSSV Perforation Depth TVD (ft): Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY KRU WSAK 1D-111 4227'6230'3598'6230'0 m n P 1 6 5 6 t _ N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 2:30 pm, Mar 24, 2025 Digitally signed by Jan Byrne DN: OU=Wells Group, O=ConocoPhillips, CN=Jan Byrne, E= jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2025.03.24 12:44:22-08'00' Foxit PDF Editor Version: 13.0.0 Jan Byrne 325-161 X 10-407 X AOGCC Witnessed tags of TOC and MIT-T to 1500 psi. AOGCC witness casing cuts before top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut DSR-4/1/25JJL 4/25/25 X 1D-111 P&A Procedure Date: 03/21/25 Network Number: 10460677 Prepared by: Jan Byrne 808-345-6886 1 CContents Objective ....................................................................................................................................................... 2 Current Well Status ....................................................................................................................................... 2 Job Design Data ............................................................................................................................................. 2 Design Envelope ............................................................................................................................................ 2 Volumes ........................................................................................................................................................ 2 P&A ............................................................................................................................................................... 3 Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T ................................................. 3 Slickline – Drift for Eline ............................................................................................................................ 3 Eline – Punch holes in tubing and perform injectivity test ....................................................................... 3 Cementing Unit - Pump Tubing x IA Plug to Surface ................................................................................. 3 Surface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar ........................................ 4 Appendix ....................................................................................................................................................... 6 Tubing Tally ............................................................................................................................................... 6 Liner tally ................................................................................................................................................... 7 Wellbore Schematic .................................................................................................................................. 8 2 OObjective In 2022 a 1D-Pad mechanical well review identified six wells to be Plug and Abandoned (P&A) due to single casing well designs, mechanical integrity damage, and subsidence damage. 1D-111 is a single casing well with multiple shallow 5.5” casing leaks. The objective of this project is to P&A 1D-111. It is recommended that a full P&A be performed by cementing the well to surface and excavating 4 feet below original ground level, removing the wellhead and cellar, and backfilling with gravel/fill to ground level. As subsidence driven deformation continues, the risk of losing well access increases with time. This non-rig P&A ultimately saves money and mitigates future risk to the company. Current Well Status x Known 5.5” leak at 108’ with additional shallow leaks suspected x Surface casing sleeve welded to 14’9” x 2.75” RBP set at 6230’ x Able to drift 2.78” dummy plug to RBP at 6230’ 1/1/25 x MITT to 2000 passed 1/8/25 x T-DDT & IA-DDT passed on 1/28/25 Job Design Data x Last SBHP: 1697 psi at 3672’ TVD on 4/20/11 x Reservoir temperature: 70- 75°F in West Sak D sand x Fracture gradient: 0.67 psi/ft x Fracture pressure: 2433 psi (.67 x 3632’ TVD top slot) Design Envelope x Tubing: 3.5”, 9.3 lb/ft, L-80 x Liner: 3.5”, 9.3 lb/ft, L-80 x Prod Casing: 5.5”, 15.5 lb/ft, L-80 x Wellhead: Vetco Gray horizontal. x MASP: Normal WOG Volumes x 3.5” Tubing from 0’ to 6121’= 53.3 bbls (.0087 x 6121’) x 3.5” x 5.5” Annulus from 0’ to 6121’= 72.8 bbls (0.0119 x 6121’) x 3.5” Casing 35’ above plug = 0.30 bbls (0.0087 x 35’) x Diesel FP, to 2000’ TVD = 2986’ RKB = 26 bbls (.0087 bbl/ft x 2986’) 3 PP&A P&A Plug #1: Reservoir Plug Slickline –Dump bail cement on plug, AOGCC witnessed Tag and MIT-T 1) MIRU Slickline. PJSM. 2) Dump bail 35’ (0.30 bbls) of 15.8 class G cement on top of RBP at 6230’. a. This will put TOC at ~6195’. b. The minimum required cement dump bailed on top of a plug is 25’ (0.22 bbls). 3) WOC a minimum of 48 hours before proceeding to the AOGCC witnessed Tag and MITT. 4) RIH for AOGCC witnessed TOC tag (estimate ~6195’ RKB) and perform MIT-T to 1500 psi. Record Results in WSR. a. Notify the AOGCC Inspector of the timing of the cement plug tag and test (submit AOGCC Test Witness Notification Form 24hrs in advance of witness). 5) Only proceed to next steps if MIT-T passes and TOC is acceptable. P&A: Plug #2 Slickline – Drift for Eline 1) Fullbore drift tubing down to ~6121’ to verify Eline will make it down with punches. 2) RDMO, ready for Eline. Eline – Punch holes in tubing and perform injectivity test 1) RIH with tubing punch to punch holes in 3.5” at ~6121’ (middle of 1st full joint below GLM at 6084’). Punch sufficient holes for 2 BPM circulation rate. Do not punch through 5.5” casing. 2) Verify injectivity through punches. Pump down tubing taking returns off IA to tanks. a. This well had a small amount of fluid returns up the conductor during a failed MITIA in 2016. b. Prep the conductor for fluid returns, contact DHD for assistance/instruction. c. Need to have vac truck onsite during injectivity test ready to vac fluid returns from conductor. d. If 2 BPM circ rate is not achievable punch more holes and repeat injectivity test. e. 2000 psi Max pump pressure. 3) RDMO, ready for Cementing. Cementing Unit - Pump Tubing x IA Plug to Surface Cement Volume Calculations: • 3.5” Tubing from 0’ to 6121’= 53.3 bbls (.0087 x 6121’) • 3.5” x 5.5” Annulus from 0’ to 6121’= 72.8 bbls (0.0119 x 6121’) • Excess: 25% • Total volume: 53.3 + 72.8 = 126.1 x 1.25 = 157.6 bbls 4 1) Contact Halliburton a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Bryce Hinch 307-359-0067). The job is designed for 157.6 bbls of ArcticSet 1 (AS1) cement. 2) Conduct Safety Meeting and Identify Hazards. Inspect wellhead and pad condition to identify any pre-existing conditions. 3) RU HES Cement Equipment and PT surface lines as required. Ensure that hardline is rigged up to pump down the tubing and take returns to a tank from the 3.5” x 5.5” annulus. Also ensure that there is a way to pump down the IA in case the tubing pressures up. Rig up line to flush all surface lines of cement post-job. 4) Open the IA, and pump 20 bbls of diesel down the tubing, taking returns to tank from the IA to confirm circulation. 5) After circulation to IA is confirmed batch up AS1 cement. 6) Line up to pump cement down the tubing, taking returns from the IA. 7) Follow Pump Schedule below: 8) 20 bbls fresh water spacer ahead 9) 106 bbls (2x Tbg) surfactant wash. 10) 106 bbls fresh water spacer. 11) 157.6 bbls of Permafrost Cement (AS1) to surface in tubing and IA (including 25% excess). 12) After approximately 126.1 bbls of cement is pumped away, expect to see IA cement returns. Utilize mud density scale to confirm proper weight Permafrost Cement to surface coming from the IA. Pump contingency cement if needed to obtain good cement to surface. 13) After good IA cement is seen at surface, shut down pumps and close in the IA valve. 14) Close in the master valve, open up the cement clean up line, and circulate to tanks to wash up tree and surface equipment. 15) RDMO SSurface Work – DDT, Excavate Wellhead, Cut, Weld Plate, and Backfill Cellar 1) MIRU required equipment. 2) DHD to perform drawdown test on tubing and IA. 3) Remove well house. 4) Bleed off T/I to ensure all pressure is bled off the system. 5) Remove production tree in preparation for excavation and casing cut. 6) If shallow thaw conditions are found, have shoring box installed during the excavation activity to prevent loose ground from falling into the excavation. 7) Cut off wellhead and all casing strings 4 feet below original ground level. 8) Perform top job if needed to ensure cement is at surface on all strings. AOGCC witness and photo document required. 9) Send the casing head with stub to materials shop. Photo document. 5 10) Weld 1/4" thick cover plate (16" OD) over all casing strings with the following information bead welded into the top. Photo document. AOGCC witness required. ConocoPhillips 1D-111 PTD #: 198-166 API #: 50-029-22911-00-00 11) Remove cellar. Back fill cellar with gravel/fill as needed. Back fill remaining hole to ground level. 12) Obtain site clearance approval from AOGCC. RDMO. 13) Report the final P&A has been completed to the AOGCC. Photo document final location condition after work is completed cementing unit and associated equipment. 6 AAppendix Tubing Tally 7 LLiner tally 8 WWellbore Schematic Current Completion Proposed P&A 1D-111 PTD# 198-166 Proposed P&A Schematic 16” 62.5# H-40 Conductor @ 121' MD 5.5" x 3.5" 15.5# L-80 Production Casing at 7036' MD 3-½” 9.3# L-80 Tubing at 6189' MD RBP at 6230' MD West Sak D sand upper perfs at 6276' West Sak D sand upper perfs at 6276' Seal Assembly at 6188' MD Reservoir Cement Plug Slickline dump bails 35' of cement on top of RBP to place TOC at ~6195' Tubing and IA cement plugs from punches at ~6121' to surface CBL (5.5 x 3.5" x OH) TOC =6190'MD CIBP at 6719' MD Calculated TOC (5.5 x 3.5" x OH) = Surface (Top Job) • Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday,August 26, 2016 2:14 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R.Tyler Subject: KRU 1D-111 (PTD 198-166) Report of failed MITIA Attachments: 1D-111 schematic.pdf; 1D-111 90 day TIO plot jpg Chris, KRU West Sak injector 1D-111 (PTD 198-166)failed a diagnostic MITIA. The well is a single casing well and was shut in and secured with an RBP set in the liner at 6230'. The initial diagnostics suspect multiple leak points. The well will remain shut in and secured while a plan forward is developed. Please let me know if you disagree or have any questions. A wellbore schematic and 90 day TIO plot are attached for reference. Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Pager(907)659-7000 pgr. 909 WELLS TEAM WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1D-111 Run Date: 8/7/2010 August 9, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D-111 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22911-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 v-z ~ Office: 907-273-3527 Fax: 907-273-3535 klinton.wood A~~ ~ ~.201~ Date: C3il . ~r~ch ~~~" `~ a~~ ~ Si ed: ~~ • MEMORANDUM TO: Jim Regg ~,>~~, "?~7C:~~a P.I. Supervisor `~ ~ FROM: Bob Noble Petroleum Inspector C~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-111 KUPARUK RIV U WSAK 1D-111 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `~~ Comm Well Name: KUPARUK RIV U WSAK 1D-111 Insp Num: mitRCN100718135635 Rel Insp Num: API Well Number: 50-029-22911-00-00 Permit Number: 198-166-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~ 1D-il] ~ Well P.T.D~ 1981660 Type Inj. N TypeTest SPT TVD Test psi 3573 ~ IA , 20 1740 - OA 1740 ~ 1640 _ _ 1620 Interval4~TST p/F P Tubing 300 300 Soo 300 Notes: ~,~~~ v~ . 1' ~ 1~ 15ir%D~~ %:j ~ h C1 yy ee ~ ~~~~_ ~.~E i Thursday, July 22, 2010 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 8, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1D-111 Run Date: 7/18/2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -111 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50 -029- 22911 -00 Injection Profile Log 1 Color Log 50- 029 22911 -00 1 j 200 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. U� C 1 "e°6' Anchorage, Alaska 99518 Office: 907 273 -3527 /ttt Fax: 907 273 -3535 rafael.barreto#1 1,1i Go Date: NOV 5 2009 Signed: S :qaskP, (Ji'6 it: ;s r rochamqe • • ~f ~ , ~ t ~ ~ :. .. . ~. ...:., .~o . . ~ ~ ~ ~ ~~ '~~~ f ( ~ ~ROi~cric~ ~36ay~css~c 5~~a~ne~s~ ~~_ T~: A~OGCC ~hristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hote/Open Hote/Mechanical Logs and /or Tubing Inspectaon(Caliper/ MTl~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy ot this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax (907) 245-8952 1) Caliper Report 29-Jun-09 1(}136 1 Report / E~ Caliper Report 30,Jun-09 1 Q111 1 Report / E~ ~z ~ ~~~ - ~~~ 1 ~a~~ ~ i ~ .~ aU -O~~ ! ~ ~ ~-~- ~ ~. ~ 50-029-22955-00 50-029-22911-00 ~~s~:'~''~~"~~ J~.~l~ . ~`; ~~~~ Date : Signed : Print Name: PROACTIVE DIAGPiOSTIC SERVICES, INC., 130 W. INTERNATIONAL d11RPORT RD SUITE C, ANCHORAGE, AFt 99518 PHONE: (907j245-8951 FAx: (9Q7)245-88952 E-MAIL : ; : : _ ° . ' : lMEBSITE : , , : ~ C:'~,pocuments and Settings\Owner~Desktop\Tiansmit_Conoco.docx • Memory Mutti-Finger Galiper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1 D-111 Log Date: June 30, 2009 Field: West Sak Log No. : 7341 State: Alaska Run No.: 1(MIT) API No.: 50-029-22911-00 Pipe1 Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top ~og intvl1.: Surtace Pipe1 Use: Tubing and Production Casing Bot. Log Intvl1.: 6,278 Ft. (MDj tnspection Type : Corrosive 8 Mechanical Damag~ inspection COMMENTS : This caliper data is tied into the DS Nipp/e @ 6,084' (Oriller`s Depth). This log was run to assess the condition of the tubing and production casing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing and production casing logged are in good to poor condition, with a maximum recorded wall penetration of 61% recorded in a line of pits in joint 195 (6,239'). Wall penetrations from 20°~ to 45°~ wall thickness are recorded in 82 of the 205 joints logged. Recorded damage appears as an intermittent line of pits and isolated pitting. No significant areas of cross- sectiona~ wall loss or I.D. restrictions are recorded throughout the tubing and production casing logg~d. The caliper recordings indicate stight buckling from -2,600' to --6,000'. 3.5" TUBING 8~ CASING - MAXIMUM RECORDED WALL PENETRATIONS: Line of pits ( 61%) Jt. 195 @ 6,239 Ft. (MD) Line of pits ( 45%) Jt. 196 @ 6,262 Ft. (MD) Line of pits ( 44%) Jt. 192.1 @ 6,081 Ft. (Mb) Line of pits ( 44°~6) Jt. 194 (c~ 6,154 ~t. (MD) Line of pits ( 44%) Jt. 194.1 ~ 6,184 Ft. {MD) 3.5" TUBING ~ CASING - MAXIMUM RECORDED CROSS-SECT[ONAL METAL LOSS: No significant areas of cross-sectionat wall ioss (> 10%) are recorded throughout the tubing and production casing Ipgged. 3.5" TUBING ~ CASING - MAXIMUM RECORDED Ip RESTRICTIONS: No significant l.D. restrictions are recorded throughout the tubing and production casing logged. Field Engineer: Wm. McCrossan Analyst: C. Wa/drop ~fness: C_ Fifzpatrick PraActive Diagnostic Services, :nc, / P.~. Box 1369, Stafford, TX 77497 Phone: (~81) or (888) 565-9085 Fax: (281} 565-1369 E-mall: PDS~~memorylog.com Prudhoe 6ay Field Office Fhone: (90?) 659-2307 Fax: (4Q7) 659-2~i4 U ~ ~°t `d -lC~Cv ! `~ ~~"~ ~ ~ Correlation of Recorded Damage to Borehole Profile ~ Pipe 1 3.5 in (33.5' - 6276.6') Well: 1 D-1 1 1 Field: West Sak Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: June 30, 2009 ^ Approx. Tool Deviafion ^ Approx. Borehole Profile 1 ;9 2~ ~ i ~35 I l 5(1 ~ i , 1578 ~ 75 2359 ` 1(~U ^- ~ 3150 ~ ~ w .~ ~ E " ~ ~ ~ 125 3929 Q °J o 0 15(~ 4713 175 5502 GLM 1 197 6277 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 197 • u PDS Report Overview ~ ~. Body Region Analysis Well: 1 D-111 Survey Date: )une 30, 2009 Field: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 93 f L-80 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body ~ metal loss body 150 100 50 ~ 0 to 1 to 0 to 20 to 40 to over 1% 10°/ 20% 40% 85% SS% Number of 'oints anal sed total = 205 pene. 0 14 121 63 7 0 loss 101 104 0 0 0 0 Damage Configuration ( body ) 150 100 50 0 _ isolated general line ring hole / poss pitting corrosion corrosio~ corrosion ible hole Number of 'oints dama ed total = 106 106 0 0 0 0 Damage Profile (°k wall) ~ penetra6on body metal loss body a 50 100 n GLM 1 Bottom of Survey = 197 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 Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1D-111 West Sak ConocoPhillips Alaska, Inc USA June 30, 2009 Joint No. Jt. Depth (Ft.) I'~~n. t 1E~.~~~ (In~.) Pen. Body (Ins.) I'en. °6 ~lc~~al I c~s~ °-~~ Min. I.D. (lns.) Comments Damage Profile (°/a wall) 0 50 100 .1 33 (~ 0.01 6 2.90 P P 1 39 ~) 0.03 ~I ? 1 2.93 2 70 l~ 0.03 1"~ I 2.91 3 102 l 1 0.03 1 i l) 2.91 4 133 U 0.03 13 I 2.92 5 165 (~ 0. 3 13 (~ 2.91 6 197 (~ 0.03 1 1 i _92 7 228 t~ 0.04 14 I 2.92 8 260 U 0.03 17 G 2.92 9 292 l~ 0.03 13 1 2.93 10 323 ~~ 0.03 I_3 1 2.93 1 355 t~ 0.03 13 (1 2.92 12 387 ~~ 0.04 1~ ~ 2.92 13 418 ~~ 002 ~~ ~ 1 .91 14 450 t~ 0.04 23 1 I 2.93 15 481 ~~ 0.03 13 1 2.91 16 513 (~ 0.02 9 I 2.92 17 545 ( ~ 0.02 ~) ! 2.92 18 576 ~? 0.03 1;3 I 2.91 19 608 u 0.05 1~) _' 2.93 Line of its. 20 640 u 0.05 1~) I 2.91 ine of its. 21 671 ~~ 0.04 1 ~ ' 2.92 Lin of its. 22 703 ~~ 0.07 ~8 2 92 Line of its. 23 734 U 0.10 39 ~ 2.92 Line of its. 76 U 0. 7 ,'E~ .9 Line of its. 25 795 ~~ 0.04 16 ' 291 26 826 ~~ 0.03 11 I 2.91 27 858 (~ 0.02 ~i I 2.91 28 888 u 0.09 s7 2.90 Line f its. 29 920 ~~ 0.07 ~E, 2.89 Line of its. 30 951 l~ 0.06 ~'-3 I .91 Lin f its. 31 983 u 0.06 ~'~4 I 2.92 Line of its. 32 1014 t~ 0.05 Z1 1 2.92 Line of its. 33 1045 ~1 0.06 ~?~ 1 2.91 Line of its. 34 1076 (1.U6 0.08 31 ~_' 2.93 Line of its. 35 1108 ~~ 0.04 I ~ I 2.92 36 1139 U 0.03 1"~ ~~ 2.91 37 1170 t 1 0.03 I 2 I 2.93 38 1202 ~~ 0.05 I~) 1 2.91 Isolated it6n . 39 1233 ~~ 0.02 ~~ I 2.92 40 1265 u 0.07 Zt3 I 2.91 solated itti 41 1296 t~ 0.05 2U s 2.92 Isolated ittin . 42 1326 t~ 0.02 ~) 1 2.91 43 1358 t1 0.03 1 U n 2.91 44 1389 l) 0.04 14 I 2.90 45 1421 ~~ 0.03 Il I 2.90 46 1452 u 0.06 ~' > I 2.93 Isolated ittin . 47 1484 ~~ 0.05 ._' 1 2.93 Isolated ittin . 48 15 5 t ~ 0. 3 1' I 2.92 49 1546 t) 0.04 1 5 I 2.91 Penetration Body Metal Loss Body Page 1 • 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 1D-111 West Sak ConocoPhillips Alaska, Inc USA June 30, 2009 )oint No. Jt. Depth (Ft.) I'c~i~. t~~„c~i (Int.) Pen. Body (Ins.) Pen. `%, ~1et,~l lc~ss °',~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 50 1578 (~ 0.04 14 u .92 51 1609 U 0.04 18 I 2.92 Isolated i'n . 52 1641 U 0.0 16 I 2.89 53 1672 U 0.04 I' 2.93 54 1702 U 0.04 1 a ~! 2.91 55 1734 ~~ 0.03 1 Z 1 2.90 56 17 5 t~ 04 17 1 2.93 57 1797 ~~ 0.06 25 1 2 91 Line of its. 58 1828 U 0.05 21 Z 2.92 Line of its. 59 1858 u 0.06 2Z ' 2.92 L'ne of its. 60 1890 (~ 0.05 1 E3 I 2.91 Line of its. 61 1921 U 0.05 l(~ 1 2.93 Line of its. 62 1953 ~~ 0.05 ZU 1 2.91 ine of its. 63 1984 (~ 0.0 13 ~i 2.92 64 201 U 0.05 19 Z 2.91 Line of 'ts. 65 2044 ~~ 0.05 Zt) 1 2. 2 ine of iis. 66 2076 ~~ 0.04 1 ~ 1 .90 Line of its. 67 2107 (~ 0.05 1 ti I 2.91 Line of ~ts. 68 213 7 ~~ 0.03 I 3 1 .93 9 2168 ~~ 0.04 17 1 2.91 70 2 O1 ~~ 0.05 20 1 2.9 Li of its. 71 22 2 i~ 0.03 1 ~ 1 2.91 7 2264 U 0.06 24 ' 2.90 Isolated ittin . 73 2296 U 0.05 2t) ' 2.91 Isolated itti . 74 23 7 u 0. 4 14 1 9 75 2359 U 0.04 16 1 2.91 76 2391 i> 0.04 14 ~ 2.91 77 2422 t1 0.03 13 1 2.91 78 2454 U 0.06 24 1 .91 I olate itti 79 2486 ~~ 0.06 2~1 ' 2.91 Isolated ittin . 80 2518 U 0.05 I~) I 2.89 Isolated ~ttin . 81 2549 ~~ 0.04 1 i I 2.90 Shallow 'ttin . 82 2581 U 0. 5 Z~l _' 2.91 Isolated ittin . S~i h BucMin . 83 2613 U 0.05 18 1 2.94 Line of its. 84 2644 (1 0 06 24 _' 2.91 ine of its. 85 2676 U 0.06 Z~ 1 2.91 Lir-e of its. 86 2707 ~~ 0.04 15 I .90 87 2739 u 0.04 16 2 2.91 Sli ht Bucklin . 88 2770 ~~ 0.04 17 .91 89 2802 ~~ 0.05 ZU I 2.90 Line of its. 9 2834 t~ 0.06 22 I 2.91 ine f its. 91 2865 u 0.06 ~4 1 2.92 Line of its. 92 2897 O 0.04 1 7 .91 Line of its. Sli ht Bucklin . 93 2929 t~ 0.06 l~~ .92 Line of its. 94 961 ~1 0.05 1~) 1 2.9 Line of its. 95 2992 ~1 0.06 14 1 2.91 Line of its. 96 302 n 0.06 24 1 2.90 Line of ~ts. 97 3055 ~~ 0.05 I 9 I 2.92 Line of its. 98 3087 ~~ 0. 4 17 1 2.90 Line of >its. 99 3119 ~~ 0.06 _' S 2.93 Line of ~its. Sli ht Bucklin ~. Penetra6on Body Metal Loss Body Page 2 • 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 Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • i LATI O N S H EET 1D-11t West Sak ConocoPhiliips Alaska, inc. USA June 30, 2009 Joint No. Jt Depth (Ft.) I'~~n. i J~nE~t (In~.} Pen. Body (Ins.) I'c~n. % Mclal I oss °`~ Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 1 0 3150 (~ 0.07 29 1 2. 3 Line of ~ts. 101 3182 (~ 0.05 21 1 2.90 Line of its. 102 3213 ~~ 0. 4 14 1 2.92 I 103 3245 l) 0.06 ? i _' 2.9 Line of ' ~ 104 3276 U 0.08 ~ii _' 2.91 Line of its. 105 308 ~~ 0.06 ~'4 2.92 Line of 'ts. 106 3339 U 0.05 .' I I 2.91 Line of its. 107 3371 O 0.05 'U I 2.90 Lin of its. Sli ht Bucklin . 108 3402 U 0.05 ?O I 2.91 Line of its. 109 3432 (~ 0.04 1~~ I 2.91 Line of its. 110 3464 l? 0.06 _'..' ~' 2.97 Line of its. 111 3495 U 0.06 'S I 2.91 Line of its. 112 3527 ~~ 0.04 I' I 2.91 113 3558 ~~ 0.04 1(~ 1 2.92 114 3590 u 0.08 s~ 2.91 Line of its. 115 3621 ~~ 0.06 '4 I 2.92 Line of its. 116 3652 u 0.06 ~'~ 2.91 Line of its. 117 3683 l~ 0.06 21 ! 2.92 Line of its. Sli ht Bucklin 118 3713 ~1 0.06 2 i ' 2.91 Line of its. 119 3744 U 0.09 i4 1 2.92 Line of i. 120 3775 i i 0.05 2U ~? 2.90 Line of its. 1 1 3805 ~~ 0.08 iO _' 2.92 Line of its. 122 3836 ~~ 0.05 19 I 2.92 Line of its. 123 3866 U 0.05 19 ' 2.93 Line of its. 1 4 3898 i~ 0.0 t1 ~' .92 i o i. 125 3929 u 0.09 35 ~' 2.93 Line of its. Sli ht BucMin . 126 3961 U 0.04 1 i I 2.92 Line of its. 127 3991 ~~ 0.07 26 I 2.92 Line of its. 1 8 4022 c~ 0.05 1 t3 I 2.93 Line of its. 129 4054 ~) 0.04 16 ? 2.93 130 4085 U .04 15 _' 2.93 131 4117 U 0.07 Z(~ 2.93 Line of its. 132 4148 ~1 0 07 't~ 2.91 Line of its. 133 4180 U 0.08 3~) ' 2.92 Line of its. Sli ht Bucklin 134 4210 (1 0.0 l:i I 2.92 135 4240 U 0.04 I-1 I 2.92 136 4271 U 0.06 ZZ I 2.88 Lin of its. 137 4303 U 0.04 I5 I 2.90 138 4335 t) 0.04 15 1 2.88 139 436b c~ 0.03 I~ _' 2.90 140 4398 u 0.04 17 1 2.88 Sli ht B cklin . 141 442 9 t~ 0.04 I 4 _' 2.92 142 4~361 U 0.03 I~? _' 2.93 143 4493 ~~ 0.04 15 ~ 2.91 144 4524 ~) 0.03 11 _' 2.92 145 4556 c? 0.04 14 1 2.91 146 4588 l~ 0.03 1 Z 2 2.92 147 4620 (> O.p3 11 1 2.91 148 4650 i~ 0.0 1-3 1 .93 Sli ht c in . 149 4682 ~) 0.04 I> 1 2.92 ~ Penetration Body Metal Loss Body Page 3 . 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 Cornpany: Nominal I.D.: 2.992 in Country: Survey Date: • ~LATION SHEET 1D-111 West Sak ConocoPhillips Alaska, Inc. USA June 30, 2009 Joint No. )t. Depth (Ft.) I'~~n. IIF~sE•i Iln. ) Pen. Body (Ins.) f'c~n. °/, 1Ac~t,il Ic~ss °„ Min. I.D. Qns.) Comments Damage Profile (%wall) 0 SO 100 150 4713 ~~ 0.03 13 ~~ 2.91 151 4745 t~ 0.03 I 3 ~ 2.93 152 4777 ~~ 0.0 1l) 6 2.93 153 4808 ~ i 0.03 I 3 1 2 93 154 4840 ~~ 0.0 11 (> 2.92 155 4872 ~~ 0.05 ZU ~~ 2.92 Isoated ittin . 156 4903 ~~ 0.04 17 t; .92 Sli ht Bu klin . 157 4935 ~~ 0.0 1 1 ,' 2.91 158 4967 ~~ 0.03 1- I 2.91 159 4998 u 0.03 13 1 2.91 160 5030 O 0.05 19 1(1 2.89 Isolated ittin . 161 5062 U 0.04 15 5 2.9 162 5093 U 0.03 11 ~~ 2.91 163 5125 ~~ 0.04 15 I 2.93 164 5156 ~~ 0.04 15 I 2.92 Sli ht Bucklin . 165 5188 t) 0.04 I; ' 2.92 166 5219 (~ 0.03 13 ~.~ 2.91 167 5251 t) 0.04 1 d ' 2.92 168 5282 U 0.02 '~ I 2.93 169 5314 t 1 0.04 15 1 2.93 170 5345 t~ 0.04 1 C~ - 2.92 171 5376 tt 0.04 I(~ 2.91 172 5407 t~ 0.02 ~) E> 2.92 Sli ht Bucklin . 173 5439 t~ 0.05 1 t3 _' 2.92 174 5471 l1 0.02 ~) 2.93 V5 5502 ~~ 0.02 ~~ ts 2.92 176 55 3 ~~ 0.04 l~ _' 2.91 177 5564 U 0.05 ? 1 _' 292 Isolated ittin . 178 5596 U 0.04 1; 1 2.93 179 5628 t) 0.04 I ~ ! 2.91 Sli ht Bucklin . 180 5659 ~~ 0.06 ~' i 2.93 Isolated ittin . 181 5691 ~~ 0.06 ~'4 2.92 Isolated ittin . 182 5722 !! 0.05 1 tS 2.92 Isolated itlin . 183 5754 t? 0.08 ~ s _' 2.92 Isolated ittin . 184 5786 ~~ 0.07 1~) ~' 2.93 Isolated ittin . 185 5817 U 0.06 Z~4 2.91 Isolated ittin . 186 5&49 t~ 0.04 1? ~, 292 187 5880 c~ 0.05 Z 1 ..' 2.92 Line of its. Sli ht Bucklin . 188 5912 U 0.07 26 ~' 2.92 Line of its. 189 5943 t~ 0.05 1~) _~ 2.91 Linc of its. 190 5975 (~ 0.07 2(~ < 2.90 Line of its. Sli ht Bucklin . 191 6006 il 0.08 31 ' 2.89 Line of its. 192 6038 U 0.08 >U _' 2.91 I.ine of its. 192.1 6070 U.(~; 0.11 44 -t 2.96 PUP Line of its. 192.2 6085 U 0 l) U N A GLM 1 Latch 3:00 1923 6091 ~) 0.08 t2 ,? 2.94 PUP Line of its. 193 6105 U 0.10 4l) i 2.90 Line of its. 193.1 6137 (~ 0.03 I1 1 2.89 PUP 193.2 6143 0 l) U 2.81 Camco S-Ni le 193.3 6145 0.01 ? ' 2.93 PUP Penetration Body Metal Loss Body Page 4 . PDS REPORT )OINT 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 1D-111 West Sak ConocoPhillips Alaska, Inc. USA June 30, 2009 Joint No. Jt. Depth (Ft.) I'~~n. I~~~sc~i (Ins.~ Pen. Body (Ins.) Nc~n. °4, ~Ic~t,~l I c~ss °ro Min. I.D. (Ins.) Comments Damage Profile (%wall) 0 50 100 194 6150 ~~ 0.11 4-1 -~ 2.88 Line of its. 194.1 618 U 0.11 44 ~ 2.93 PUP Line of its. 194.2 6188 ~~ 0 (1 u N A Baker GBH-22 Seal Assemb) 194.3 6 O1 ~~ 0 ~.~ U N A Baker Seal Bore Extension 194.4 6203 ~~ 0.11 ~l~' ~' 2.90 PUP Line of its. 194.5 6208 ~~ .10 41 b 2.91 PUP Line of its. 195 6218 i~ 0.16 (~ 1 1 U 2.92 To of 3.5" Production Casin . Line of its. 196 6247 u 0.12 4 i 4 2.91 Line of its. 197 6277 u 0.09 s i ~ 2.93 Line f its. Penetration Body Metal Loss Body Page 5 ~1~ ~ `+~ PDS Report Cross Sections Well: 1 D-111 Survey Date: June 30, 2009 Fieid: West Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin : 3.5 ins 93 f L-80 EUE 8RD Anal st: C. Waldro Cross Section for Joint 195 at depth 6239.33 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 91 % Tool deviaHon = 40 ° Finger 17 Penetration = 0.156 ins Line of pits 0.16 ins = 61~o Wall Penetration HIGH SIDE = UP ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ C~ • Cross Sections page 1 ~ ~ ~ ~ ~ ~^^ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ s ~ ~ _ _ ~~ PDS Report Cross Sections Well: 1D-111 Survey Date: June 30, 2009 Field: b'Vest Sak Tool Type: UW MFC 24 No. 218370 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~'~'o. of Fingers; 24 Tubin : 3.5 ins 9.3 f L-80 EUE 8RD Anal st: C. Waldro Cross Section for Joint 196 at depth 6262.4 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 96 °/a Tool deviation = 41 ° Finger 17 Penetrafion = 0.1 15 ins Line of pits 0.12 ins = 45% Wall Penetration HIGH SIDE = UP i i Cross Sections page 2 _., ~~ KUP ~ 1 D-111 ~OflOCO~'ll~~lpS ( Wall At tributes /M le d Np TD ai: ,... ., ve 500292291100 YY aexane ESTSAK w INJ r. q PWI e, pnc 8~.37 2.028.90 on 7,046_0 __. Cormiat ~SV: NONE 0 e 7/V2008 atlon Last WO: te ~id 47 10 g el~se Dote 9/2l1998 .~w. ~ +a sv am . . on ~ e I aM Tag: SLM 6,618.0 72/5l2008 Rev Reason: TAG FILL 12/8/2008 Casfn Strin o esapM~on Nre Iml ~ MI T f~l ~ IN W ~ Pbs~q atl e at T mra f CONDU OR 16 15.062 0.0 721.0 121.0 62.58 H-40 WEIDED CONWCTOR SURFACE 5 12 4.500 0.0 8,188.0 3,572. 15.50 L-BO BTC-AAOD . i2t PRODUC TION 31f2 2.992 6,18H.0 7,036.0 4.22 .6 .30 L~0 EUE-8rd Tub Strin s 7UEhq D esal on fl~) n (M) To a e~ (~KB) (II ~ IC6) Mrt (ASdq d'aU e ptlnp r Thre ~~~i~. TUBING 31l2 2.992 0.0 6,188.0 3,572.9 9.30 L-80 EUE&d s.o~, Otlwr I n Mole A ll Jwv el : Tu Rue 8 Rat rlevabl FBh ~b~. T QII( ~ mq (~a) roP na (') Descrlptlon CamKt t Rut Drie m~ ,084.0 3,497.8 M.73 Gh S LIfT MCO/ BG 2-9/1/DMV /BT !/ Cwrunenk TA 1 2~1Y@008 2.900 6,143.0 3, 39.9 42.62 NI PL C 5 N IPPLE W/ NO 8fdil1996 2.812 n~w~E, s ias 6.188.0 3,572.9 42.23 S BAICF.R GBH-2 2 LOCATO SEAL ASSEMBLY 8f31/1998 4.000 6,917.0 4,Y31.6 37.80 PL UG CIBP 8/31/7998 ~+ Perfora tions SURFACE. TOP(I~/q ~11~TVD~ ~~ 6.188 T 8011 ~ ~ 2011e 026! ~M••• CCI IIIIIlI[ ~ e~~ 6, 78.0 6,316. 3. 38J 3.668.8 W S D, 1D-111 4/3 1999 4.0 IPF1iF 2.5" HC 31J UJ H onent +/- 90deg NDC D, i80deg. 6,35G.0 6,376.0 3,698.8 3,713.9 YV S B, D-171 1l2917999 4.0 I 2.5' HC 31 J UJ H orient +!- 90dep MIC DP, 180deg, 6,380.0 6.400.0 3, 16.9 3, 34.7 8. 1D-1 1 1899 4.0 IPERF .5" HC 37J UJ H o,ient +/- 90de9 MX DP, 180deg, iv~aF, 6,276G,316 6,414.0 6,144.0 3,745.1 ~,767.5 M, D-111 1/29~1 4.0 IPERP 2. HC 31J UJ H p~ 011211~ ~~- ~"`Fa NU( DP, 18(kleg, 6,472.0 6,A82.0 3,788. 3,795.9 4V S , D-111 4/2 1999 4.0 IP RP 2.5" HC 31J L1J H orient y' 90de9 IA( DP. 180de~, 6,500.0 6, 0.0 3,809.5 3,832.1 YV S A3, 70.1 N 4Rd/ 999 4. I RF 2.S HC 31J UJ H ariant +!- S10Ae8 MX DP, 1 Otlag, iaeaF. 6.358L,376 6,562.0 6,802.0 3, .4 3,888.9 W S A2, 1D-111 428/1999 4.0 IPERF 2.5" HC 31J UJ H OflCfll ~~' ~(~8Q MX DP, 180deg, 6,650.0 6.670.0 3.923.7 3,9392 W S A2, 1D-111 4/27/1999 4.0 IPERF 2.5 HC 31J UJ H aien~'~' 90de9 MX DP, 180deg. NOhf: Q~ w ano r~llon iaEaF. 8rJ(V2006 NO TE: Surfece Casing Pat di Weld ro 14' 9' MD s,aeo-6poa iaEaF 6316b,446 IPERF, 6 4]2L 482 IPERF, 6,5068,530 IPERF, 6,561fi,602 IPERF, s,65o~6,6]0 PLUG. 6.917 PROWCTION, ].038 TD. 7.a46 02/16/07 Schlumbergep NO. 4142 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ¡;¡, 'ì(1 l.. 0 i. .1]7 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ^ ""NED fEB 2 1 2007 5(;/··...1' /91) -I fo(;; Field: Kuparuk UTe.. Well BL CD Color Job# Log Description Date 1D-111, 11638816 INJECTION PROFILE 01/24/07 1 1 H-19 . 11663824 INJECTION PROFILE 01/25/07 1 2T -30 . 11663825 PRODUCTION PROFILE 01/26/07 1 2K-02 11663829 PRODUCTION PROFILE 01/30/07 1 3J-02 11632653 INJECTION PROFILE 01/30/07 1 3J-08 11632657 INJECTION PROFILE 02/03/07 1 2M-05 11632658 SBHP SURVEY 02/04/07 1 1A-19· 11632660 PRODUCTION PROFILE 02/05/07 1 3J-04 . 11628963 INJECTION PROFILE 02/08/07 1 1 C-09 . 11638818 INJECTION PROFILE 02/09/07 1 2M-26 11638819 INJECTION PROFILE 02/10/07 1 1D-03 11628967 PRODUCTION PROFILE 02/11/07 1 1C-20 N/A RSTIWFL 02/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 1/) . . . 'y/ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29,2006 :Mr. Tom Maunder Alaska Oil & Gas Commission 333 West fh Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 6 2007 f'l .,. \ lo(P \C\~ Dear:Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were first filled with cement to a level 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 from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement 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.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~-/cD~ Jerry Dethlefs ConocoPhillips Problem vVells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21'4" 2.9 14'6" 12/16/2006 na na 1 H-1 0 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1H-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 1 0-1 09 197-235 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 10-133 197-206 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 1 0-138 200-048 11'7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 1 0-139 200-049 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 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commiss TO: J . R .-----;, 10 e, {ic,. 1m egg ¡. // A¿;; I!> ! { ~,(¿, r--~'(ï ! ' P.l. Supervisor ' DATE: Monday, October 02, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ID-Il I KUPARUK RIV U WSAK JD-ll I Src: Inspector ~/\\qlp \~ FROM: John Crisp Petroleum Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,JBY--' Comm Permit Number: 198-166-0 Inspector Name: John Crisp Inspection Date: 9/25/2006 Well Name: KUPARUKRIV U WSAK lD-III Insp Num: mitJCr060928103357 ReI Insp Num API Well Number 50-029-22911-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡'lD-III :Type Inj. I W I TVD I 3573 : IA I 210 i 1800'~--- 1720 I 1720! : ~~81660 !TypeTest: SPT : Test p~~ 1500 "TOA : -=- .~=-I~- ,,_____~~_-;--_ Interval OTHER P/F P Tubing I 490 J 500 i 500 I 500 í -==~ . _,,,___ ',_.___L___...L.....--__.__m__ Notes This we!! was one of a batch of mono bore west sak injectors that were repaired by excavating around the casing & patch welded on single string casing. Patch insta!!ed @ 14' 9" MD, . !./ -.---. J,;;',,"-' !\*\\~;,iì::~ \.;/Í¡¡jnu\:;~¡""- , Monday. October 02, 2006 Page I of I MITIA KRU lD- I I I 09-25-06 - post surface ¥g patch.xIs . Gentlemen, \C\~' \ ~{, Attached is the passing post surface casing patch MITIA witnessed by John Crisp. Sincerely, Perry Klein Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1244 «MIT KRU 1D-111 09-25-06.xls?? KRU ID-ll1 Content-Description: MIT KRU ID-lll 09-25-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 ~CANNEU SEP 2 B 20Df I of I 9/28/20067:49 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak / KRU /1D-111 09/25/06 Greenwood / Noble John Crisp ~~ \\Þ \~ Packer Depth Pretest Initial 15 Min. 30 Min. Welll1D-111 I Type Inj. I w TVD I 3,573' Tubing 490 500 500 500 Interval 0 PTD. 1981660 I Type test I P Test psil 1500 Casing 210 1800 1720 1710 P/Fj P Notes: Post casing patch repair, sundry approval #305-072. OA Weill Type Inj. TVD I Tubing Interval P.T.D.I I Type test I Test psil Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval P.T.D.I I Type testl Test psil Casing P/FI Notes: OA Weill Type Inj.1 TVD I Tubing Interval P.T.D.I I Type testl Test psil Casing P/FI Notes: OA Weill I Type Inj.1 TVD I Tubing Interval P.TD. Type testl Test psi! Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 10-111 09-25-06.xls . . PHilLIPS Alaska, Inc. A Subsidiary of PHilLIPS PETROl.EUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 30, 2006 SCANNED SE? 1 3 200B Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for Phillips Alaska, Inc.. wells CD - PTD 201-205, Sundrv # 306-271), 1 D-ll OA (PTD 200-039 Sundry # 306-249), an 1 D-ll1 (PTD 198- 166 Sundry # 305-072). ~ The 10-404 Sundry on CD2-47 is for the installation of a K-Valve in the SSSV profile. The Sundry 10- 404's for both lD-llOA and ID-lll are post surface casing patch documentation. . Please call Marie McConnell/Perry Klein at 907-659-7224, or Jerry Dethlefs / MJ Loveland @ at 659- 7043 if you have any questions. Sincerely, ..' . //7 ~. ¿/ '/ ~./------- ~"" ,.,~ '" --- ~./ -- J/ / f'/0~¡~ /;'/ f/.j/ :l-P V t,..... I í MJ ~veland I çlnocoPhillips Well Integrity Project Supervisor .' Attachments CJf- {{o(o SEP 0 6 2006 . STATE OF ALASKA . Alaska Oil & Gas Cons. Commission ALASKA Oil AND GAS CONSERVATION COMMISSION Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 ...,6.- Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension~""'" Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 (y 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 198-166 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360 50-029-22911-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 112' 10-111 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit AI) (.. 1.~ ¡,ç{) tþ q.,.oi. Kuparuk River Field 1 West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7046' feet true vertical 4234' feet Plugs (measured) Effective Depth measured 7046 feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' PRODUCTION 6076' 5-1/2" 6188' 3573' PRODUCTION 848' 3-1/2" 7036' 4226' Perforation depth: Measured depth: 6276-6316',6356-6400',6414-6444', 6475-6530', 6562-6670' true vertical depth: 3639-3669',3699-3732', 3743-3766', 3787-3832', 3724-3939' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6188' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water·Bbl Casing Pressure Tubina Pressure Prior to well operation NA NA NA Subsequent to operation NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ0 . WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-072 Coota" MJ loVelandlj Dethlefs Printed Nam~Jv:¡,_d Title Well Integrity Project Supervisor Signature , Æ ~ '''A. Phone 907 -659-7043 Date , , ¡.. I ORIGINAL RBDMS BFl SEP 1 ] 2006 ~ le,¡. ~ 'ì' 7- ,,'- Form 10-40 Revised 04/2004 Submit Ori . I Ø:{9!i7/6 . 1 D-111 DESCRIPTION OF WORK COMPLETED SUMMARY . Date Event Summary 7/28/2006 Conductor Removal Prep, Initial T/I= SilO Cut a 18"x 24" window in the conductor @ 5' down from the top of the mandrel han er. Final T/I= SilO 7/29/2006 Remove 9' 6" of condutor. Find leak @ 7' 6". Remove l' 10" more of conductor to try and find good SC (11' 6" conductor removed). Install 2" hose in conductor for vac trucks (fluid seeping up in conductor). Welders buff on bottom of SC with no luck finding good pipe to weld too for patch. Good pipe above collar on top (will UT when we find good pipe on bottom). AOGCC inspector John Crisp witnessed damage. 7/30/20061 Welders cut 24" more off condutor (13' 6" conductor removed). 8/8/2006 Conductor Removal, Initial TII= SilO, Welders cut and removed another 30" of conductor for a total of 17' 7" from the bottom of the Mandrell han er. 8/19/2006 Install SC Patch, Initial TII=SIIO . Driled 59/64" hole in IA @ leak site. Threaded a 3/8" hose into void ,vacced out until! FL 4' below the bottom wedding band weld site. Purged the IA with N2, while Cooper heat brought mandrel hanger up to temp. Continued the purge as welders installed wedding bands and seal welded mandrel hanger to mandrel hanger pup. UT top seal weld and bottom wedding weld with good results. Install 177" SC patch made from 6" .280 wall thickness 5L-X65 pipe. (Final weld 8-20-06) 8/20/2006 SC Repair, MITIA (Post SC patch)-Passed, TII= 2010 . Final weld SC patch. UT magnaflux welds. Replaced IA VR plug. Post Patch MITIA, pumped 2 bbl diesel total down IA. Pressured up to 1,800 psi, monitor for 15 min, no visible leaks. Pressured up to 3,000 psi, started MITIA, 15 min pressure 2,970 psi, 30 min pressure 2,960 psi, No visible leaks. Bled down IA to 0 psi, secured well. Wrap new SC patch with Denso wrap tape from 10" below bottom weld of patch up to mandrel hanger. Final TII= 4010 . Reported MITIA to AOGCC, did not reset clock, need witnessed MITIA after BOI and warmed up. 8/21/2006 Patched Conductor: Super suck down 6" around conductor for welders, install 17' 6" of 16" conductor with 4" ni pie, well is repaired and read for cement top off. ConocoPhillips Alaska Inc; ID-ll1 Surface Casmg Repair '" . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhiJlips Alaska Inc. West Sak 1 KRU 110-111 08/20/06 Rogersllves/Noble- ASRC Packer Depth Pretest Initial 15 Min. 30 Min. Well/1O-111 Type Inj. I N TVD 3,573' Tubin!; 20 20 40 40 Interval 0 P.T.D. 1981660 I Type test I P Test psi 1500 Casing 0 3000 2970 2960 P/F P Notes: Post casing patch repair, sundry approval #305-072. OA WRP in casing at 6232' Weill Type Inj. I TVD I Tubin!; Interval P.T.D.I Type test I Test psi Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubin!; Intervall P.T.D.I Type tes~ Test psi Casing P/F Notes: OA Weill I Type Inj. TVD I Tubin!; Intervall P.T.D. I Type tes~ Test psi Casing P/F Notes: OA Weill I Type Inj.! TVD I TubínQ Intervaq P.T.D. I Type tes~ Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) SCANNEr} SEP 1 3 2006 MIT KRU 10-111 08-20-06.xls KRU lD-lll Passing MIT data Tom, Jim, & Bob, ì q 7f-lfòC¡; Attached is an MIT for injection well 10-111 (PTO 1981660) post single casing excavation welded sleeve patch repair. The repair was completed on 8/20. A 10-404 will be submitted reporting the completed repair operations under sundry approval 305-072. This is the second . repair at 10 pad. We are currently in the process of repairing producer 10-110 at this time. 10-110 is the first proactive casing inspection and is also the first west sak producer excavated. While 10-110 didn't have a casing leak yet, corrosion damage was discovered in the top few feet of conductor cement and a sleeve patch will be installed over that damage. The well will be schedule for a witnessed MITIA after BOI and thermally equalized, tentatively planned for late August 2006 or early September. Once a witnessed MITIA passes, the well will be removed from the failed MITIA report. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 «MIT KRU 10-111 08-20-06.xls» SCANNED SEP 0 5 2006 /! Content-Description: MIT KRU ID-lll 08-20-06.xls KRU ID-lll 08-20-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 . 1 of 1 8/22/20068:01 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us 9J \~-z10lp ?æ¿q OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConoeoPhillips Alaska Inc. West Sak 1 KRU 11 D-111 08/20106 Rogersllves/Noble- ASRC Packer Depth Pretest Initial 15 Min. 30 Min. Welll1D-111 I Type Inj. , N TVD I 3,573' Tubing 20 20 40 40 Interval I 0 PTD.11981660 , Type test I P Test psil 1500 Casing 0 3000 2970 2960 P/FI P Notes: Post casing patch repair, sundry approval #305-072. OA WRP in casing at 6232' Weill I Type Inj. I I TVD I Tubing Interval I PTD.I , Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Interval I PTD.I I Type testl I Test psi I Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval I P.T.D.I I Type test/ I Test psil Casing P/FI Notes: OA Weill , Type Inj.1 I TVD I Tubing Interval I PTD.I , Type testl I Test psi' Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT KRU 1 D-111 08-20-06.xls e e WELL LOG TRANSMITTAL PROAcrivE DiAGNOSTÎC SERvicES, INC. To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage. Alaska 99501-3539 RE: Cased HolejOpen Hole/Mechanical Logs andjorTubing Inspection(Caliperj MTT] The technical data listed below is being submitted herewith, Please acknowledge receipt by returning a signed copy of this transmittal letter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 - 8952 1] 2] 3] 4] 5] 6] 7] [9g -ll.1Cç 8] Signed : Print Name: 1C - 119 MTT Report 16-May-06 1C - 121 MTT Report 16-May-06 1C - 131 MTT Report 14-Jun-06 10 - 127 MTT Report 14-Jun-06 ~. 10 - 121 MTT Report 14-Jun-06 JC~MNf.C j .., ¡¡';¡OOt'''; 'J' .,.". 10 - 109 MTT Report 1 5-Jun-06 10 - 120 MTT Report 15-Jun-06 10 - 111 MTT Report 1 5-Jun-06 UÒUJ Date: 11 J u l¡ ~ ~ ~ µ C:)\.u ~V'À~ 0 k l fA-~ ¿. PRoAcTivE DiAGNOSTic SERVicES, INC., 1 ~O W. INTERNATioNAl AiRpoRT Rd SUiTE C, ANdiORAGE, AK 99'; 18 PIIONE: (907)24';-89'; 1 FAX: (907)24';-89';2 E-MAil: Dds'\'\ldiORf\f¡E@r'ìH1oRvlot¡.COM WEbsiTE: MEMORyloG.COM c: \My Documents\ W ork\ DistributionLablesN ew\ Transmit_Original. doc I I I I I I I I I I I I I I I I I I I e e Memory Magnetic Thickness Tool ~~ Log Results Summary \C\Cf," \ Company: Log Date: Log No.: Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: ConocoPhillips Alaska, Inc. June 15,2006 8036 1 3.5" 9.3 Ib EUE Tubing 5.5" 15.51b BTC Production Casing 16" 62.6 lb. Welded Conductor Pipe Well: 1D-111 Field: Kuparuk State: Alaska API No.: 50-029-22911-00 Top Log Intvl.: Surface Bot. Log Intvl.: 196 Ft. (MD) Top Log Intvl.: Surface Bot. Loglntvl.: 196 Ft. (MD) Top Log Intvl.: Surface Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This AtTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing, and 16" conductor pipe within the logged interval. 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, casing and conductor pipe. 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 0' - 196' _ A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report. The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show five intervals of metal loss. A maximum of (-8%) circumferencial metal loss is recorded in the interval between 3' and 12.5'. A maximum of (-5%) circumferencial metal loss is recorded ih the interval between 12.5' and 17'. A maximum of (-5%) circumterencial isolated metal loss feature is recorded at 29'. A maximum of (-3%) circumferencial isolated metal loss feature is recorded at 53.8'. A maximum of (-3%) circumferencial metal loss is recorded in the interval between 54' and 58'. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include 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 & N. Kesseru Analyst: M. T ahtouh & J. Burton Witness: T. Sendon Pro.ß.ctive Diagnostic Services, Inc. P,O. Box 1369, Staffol'd, T;< 77497 Phone: or 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: 659-2307 Fa><: 659-2314 I I I I I I I I I I I I I I I I I I I Magnetic Thickness To g OHz Pass) P'IIOAcriVE DiAq.....mc SE""ic"", !""". Database File: d:\warrior\data\1d-111\1 d-111,db Dataset Pathname KPRKl1 D-111/run1 /log1 Ohz.1 Presentation Format mtt10hz Dataset Creation: Fri Jun 16 15:45:042006 by Calc Sondex Warrior VTO Charted by Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/mìn) -2001 -6.2 MTTP12 (rad) 3.8 i Il -Lv .~ e--- "- ~- -"" b~r- ..- Tree Tubing Hang -3.5" Collar Pup Jt. I I I I f-- } 8% Metal Loss- \ f--- c- :..... f--- ~..- t-- ¡---. f---. - ¡---- - 5% Metal Loss_ " .".~ 3.5" - -'-i- ~ Jt 1 '---..' I 20 - I I - ¡.. -" I - -- I m-" Isolated Metal Loss ~- f- 3 5~ Collar,- þ I '" '- r 40 i ) f?¥ .'-- <... ""'.5.5" Casing Collar -, I -.,-- - fi% Isolated Metal - - ~ 3%' Metal L~ss Jt 2 - "I---t~1---- -~ 1---- f . 60 - I-- 3.5" Colla'-I.~ . 1----, r - - , !--, "- 1--- "- ... - --. 3.5" Jt 3 ¡;.. f- 1----' r- Bottom of ,16" Conductor ". I I I 80 'if .r 1 j--- I II ~ i. fl , , ... .. , "" , , ., I I I I I I I I I I I I I I I I I I I 1 I I I I I ~ _I I.' 5.5" Casln~ C I---- t ~5"~lIam I---- :5iiiiiii - 100 - "- f-- --. --~- u_ - ..- .,.- - --t- ---~ ----- "- -.. "- 3.5" - I Jt. -4 - - ,....- ---. ---- I .. - - -- --- ~- -- -¡-- 120 .. ~'~- - f- ~^-- i - .5" Casing Collar - f--3.5" Colla I t-- >- , I 140 ...- #= ¡ ~ ¡---- -- ¡---. ".- !S -- .-.- f---- "- ^--_.,~ 3.5" Jt 5 - .... .... .... ... ........... ~ ;. ..... ... -3.5" COlla~ 160 II -'1- --- II -1----- ~ t f--- f-S.5" Casing Collar :;¡,. I f - ';;: ."--- - -- , 1 -- ~ I 3.5" 0-- ---,-- I I Jt 6 I '-- ¡-- 180 - ¡- - ~ ~ f--- -.-- I ;. ) -- -- --- '- ~ .~ þ35" COlla~ } I , , ¿ ~ - -- - >--- ¡....- Delta Metal Thickness (%) 501 j2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -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 cIrk Detail of Metal Loss tures 3' - 29' PRDAcJiVE DiAG~ SElintÎéE!íiv INC~ Database File: d:\warrior\data\1d-111\1d-111.db Dataset Pathname KPRKf1 D-111/run1/log1 Ohz. 1 Presentation Format mtt10hz Dataset Creation: Fri Jun 16 15:45:042006 by Calc Sondex Warrior V7.0 Charted by Depth in Feet scaled 1 :75 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -2001 -6.2 MTTP12 (rad) 3.8 I Tree I Tubing tfang 1 i -3.5" Collar Pup Jt .,j ¡¡ ~ I I i 8% Metal Loss-- i ;-- ~ ~ I I l '1= , I I 1 I I ;> I it ~ I 1 - 5% Metal Loss t:' I 3.5" ~. ~o ! r-- i Jr Jt 1 ~ 20 ~ 1,-- r - ~ .~ 7 ~~ J::t J I ~ f---- - = ~ I 1- -- --' -- f--- ¡ I I H 5% ¡SOI;;~Metal Loss ~... 4 . 3.5,1'\'OIl~ 1 ~ ib_ ) I t 0 I ' - ~ ~ :- -.:;L_ -50 Delta Metal Thickness (%) 50 126 MTTP01 (rad) 12.6 0 Line Speed (ft/min) ~ -62 MTTP12 (fad) 38 I I I I I I I I I I I I I I I I I I I cIas. Detail Metal Loss F 53.8' - 58' p~ DiAc¡_rlc SF"";",.,., I""'. Database File: Dataset Pathname Presentation Format Dataset Creation: Charted by d:\warrior\data\1d-111\1 d-111db KPRK/1 0-111 Irun1 IIog1 Ohz.1 mtt10hz Fri Jun 16 15:45:042006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1 :50 -50 Delta Metal Thickness (%) o Line Speed (ft/min) 501 -20°1 12.6 3.8 2.6 -6.2 MTTP01 (rad) MTTP12 (rad) e-- =*1- 5.5" Casing Collar [7 ~¡? .) Ll ~' >~1rnJO rrfffir ^^-- ) .. I .~ .. ~ I . i~ 1 < if < ~.- 1 "'" ~ - I~ !;' ; i ; I' ~ ,.. i I ~ I, _0' I I I I I I ::\ ~" ~ ~ 3% Isolated Metal Loss I I I ~ 3% Meta! Loss I i Jt 2 * ::; I " i I 60 . ., '" , ~ 1 I :::: ? ~- ~ I ). .~ ¡I i I \-11 35" <;Ollar-I. ~'_ I I - ~ '> ~ " I I I " I I~ I---- r "; ~ ~ I I ~ - ":;> ~ ~ > > I I : 1= > , .¿ ~o .> .~._.:;:"'..I~ ,2.6 -6.2 -= I 1 < I ~ , - ~..~- ,,"> ~ tt, MTTP01 (rad) MTTP12 (rad) I I r --- L_ n___ __J._.._____ '___..,..L__... ___n__'_m -50 Delta Metal Thickness (%) o Line Speed (ft/min) 3.5" > ~ , 50 12.6 3.8 -200 I KRU 1D-111 I - API: 500292291100 "~"-888VType; NONE-~- I I ~__Well.~. INJ Orig 9/2/1998 ~ C~~Wiðl....~---~~1 ~~~s: deg @ Angle @ TD: 38 deg @ 7046 I Pull Plug, Set WRP 10/17/2005 I Production (0-6188. 00:5.500. Wt15.50) Thread I I NIP _..~-- (6143-6144. 00:3.500) Interval 6276 6316- - 6356 .. 6376 I SEAL -.- (6188-6189. 00:5.000) 1_ 6380.. 6400 1 6414.. 6444 6472 .. 6482 I I Production (6188-7036. 00:3.500. Wt9.30) ·___m____~~ 6500 - 6530 I 6562 - 6602 6650 . 6670 I WRP------ (6232-6233, 00:3.000) I Perf (6278-6316) I Perf (6358-6376) I Perf (6380-6400) Perf (6414-6444) I Perf (6472-6482) PelT (6500-6530) I Perf (6562-6602) Perf (6650-6670) I I PLUG ~...-~-- (69'17-6918. 00:2.900) I I ll.wa: Lonoco.t'nllllps r:.xcaV¡:UIUIl OC I\..t;paH rlUJt;l,;lJ --- .~ Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 ':('0: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding <john_spaulding@admin.state.ak.us>, John Crisp <john_crisp@admin.state.ak.us>, Jeff Jones "<jeffjones@admin.state.ak.us>, Chuck Scheve <chuck_scheve@admin.state.ak.us>, Jim Regg <Jim _ regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us NSK-Wefr-rñt-egrity proj <N1878@conocophillips.com>, aogcc prudhoe bay@admin.state.ak.us \\)-\\\ \<\~-\<O~ 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 SCANNED JUN 2 vl 2006 1 C and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: application/msword lof2 6/26/20067:51 AM ConocoPhillips Alaska, Inc. 1 C and 1 D Surface Casing Corrosion Repair Candidates ) PRIORITY NAME TYPE I PTD# LEAK DEPTH (ft) -; 1 1 C-121 INJ 201-080 4 "---- . -.. 2 1 C-131 INJ 201-185 7 3 1 0-109 INJ 197 -235 5* " _._-,,- \ C\<15- \ ~~ '-( 4 ~ INJ 198-166 5* 5 INJ 197-221 7 6 Gas Lift 197-181 None 7 Gas Lift 198-109 None 8 INJ 198-121 5 9 1D-136 INJ 200-046 None 10 1 0-137 INJ 200-047 None 11 10-138 INJ 200-048 8 12 1 0~139 INJ 200-049 None 13 1 C-119 INJ 201-139 16 14 tC.,135 Jet Pump 201-220 None 1·'·- .. ._.._. ..C. .".__,_.......,:..,c...:....... ............,... ..j 15 1·D..1.35 ESP 197-184 None 16 1D-141 Gas Lift 200-112 None Notes: COMMENTS I STATUS Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig ) Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 1 0-141 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 '- ~ 4fi:~' ._~..t1. .,~' ''''''''fb'' .~ .' ._.. c_ - _ __-~_ --,' ~_ _.~-!'_ ,_~ -'~ ,_"'- _ :f¿~,',i JC:':- ,c_~", """",#.0..-:>.; 0~1JJ~r;.::J \;\ u 1 ~ ,A 1, ì I ~ ~~ i ¡ Ll ~, r p @ u uU ~ fm ¡ ç- [¡\ n fA \ (ñ) n¡7 ""9 ~ . ~ ", ¡¡ i,·"'~ ''1' ~jJ f' !lJ\ ¡¡ IL\\ "\f~\ ,Wi @ J LrJ Lb Lr~ù W U\). LrJ I / FRANK H. MURKOWSKI, GOVERNOR ! I ¡ CONSER~Á~~~~S= í 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 MJ Loveland Brad Gathman Problem Well Supervisors ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kuparuk 1D-111 Sundry Number: 305-072 Dear Mr. Loveland and Gathman: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (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 C unless rehearing has been requested. DATED this ~y of March, 2005 Enc!. SCANNED APR 1 4 20DS '- STATE OF ALASKA "-" REC k ALASKAOILANDGAS CONSERVATION COMMISSION '- EIVED ?li£ APPLICATION FOR SUNDRY APPROVAL MAR 222005 DJìis/'c 20 MC 25.280 J Operation Shutdown D Perforate DAlaska Uil &ß.¡s CO(OO. CommiØu. D Plug Perforations D Stimulate D Time Ei-m Other D Perforate New Pool D Re-enter Suspended Well 0 Þ' 1. Type of Request: Abandon 0 o o Suspend D o D Alter casing Repair well Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Pull Tubing P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7046' 4234' 7046 Casing Length Size CONDUCTOR 121' 16" PRODUCTION 6076' 5-1/2" PRODUCTION 848' 3-1/2" Perforation Depth MD (ft): Perforation Depth TVD (ft): April 2005 Date: 5. Penn it to Drill N?er: e 198-166 'o.! 6. API Number: 50-029-22911-00 \./f' 9. Well Name and Number: 1 D-111 4. Current Well Class: Development Stratigraphic o o Exploratory 0 Service 0 10. FieldlPool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6917 6917 MD TVD Burst 121' 121 6188' 7036' 3573 4226 6276-6316',6356-6400',6414-6444',6475-6530',6562-6670' 3639-3669',3699-3732',3743-3766',3787-3832'.3724-3939' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true Printed Na~77.~J 0\1. and/~ra Signatuy / /~ tJ7 ( Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Tubing Size: 3-1/2" no SSSV 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 GasD WAG 0 GINJ D Plug Integrity D BOP Test D Mechanical Integrity Test )ßl Other: ~~ ~~<-\c~ ~~'" \~\C ~~'t\.. ì ~~~ ?'ro~"\;~<C ~~ ~~~\CH",,_~ \<W.~~"V¿~~~~\ø.-ç-\o ~~ ~\.,~ . f. RBUMS t1tl MAR 2 9 2005 Subsequent Form .UO~ Approveu. '(jk '\ Form 1 O~403 Revised 12/200~ knowledge. Contact: Title: Phone 659-7224 Location Clearance D ¡; QOMMI~$IP~ ¡ \\ LJ U\\\u,\~1 INSTRUCTIONS ON REVERSE BY ORDER OF THE COMMISSION Collapse Tubing Grade: L-80 Tubing MD (ft): 6188' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 MJ LovelandlB Gathman Problem Well Supervisor Date J 8'tvJ /1 ~ Û .S- Sundry Number: 35~ [J 7;)-- Date: {d' /or Submit in Duplicate "-- ~ y ConocoPhiDips Alaska, Inc. Kuparuk WeDlD-lll (PTD 198-166) SUNDRY NOTICE 10-403 APPROVAL REQUEST 03/18/05 The purpose of this Sundry Notice request is for approval to repair a surface casing leak. The repair will include excavation (as needed) around the wellhead, removal of conductor casing, and mechanical patch of the surface casing. The well has been shut-in and secured since June 20, 2003. We1l1D-111 is a mono~e West Sak injector, completed in September 1998. It had been on line with water injection servlce from, May 6, 1999, until, June 20, 2003, when fluid was observed around the wellhead during a State Witnessed 4 year MITIA. At that time, the well was immediately shut-in, the tubing was plugged, and the AOGCC was notified. Diagnostics on the well have determined a leak rate through the surface casing into the conductor at 0.7 gpm @ 900 psi. The liquid leak rate tests results indicate that ~eak is very near the surface, however, the exact depth is not known. A hard tag, assumed to the cement top is at 3 feet in the conductor. Localized corrosion is suspected to be the cause of the failed casing. CP AI proposes the following plan for repair and long-term operation of the well: REPAIR AND OPERATIONS PLAN 1. Verify the well has two barriers between the formation and surface prior to repair operations; 2. Excavate around the wellhead as needed to provide access to the top portion of the casing; 3. Cut and remove the conductor as needed to gain access to the surface casing; 4. Repair / patch the damaged casing as per CP AI Mechanical Engineers direction and the replace the conductor casing; 5. Perform an MIT to verify the repair integrity; 6. Pull the tubing plugs from the well; 7. Perform an AOGCC witnessed MIT-IA and MIT-T to verify mechanical integrity of the well is competent; 8. Return well to injection service; 9. Perform an MIT-IA every 4-years subject to standard test criteria (0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 10. Shut-in the well and notify the AOGCC should MITis or injection rates and pressures indicate further communication problems. NSK Problem Well Supervisor +\"'\S~~\\ \s c"m."~\!t~'J \J.Jj SlId"'-/.. ~II~\ ~~~Cj . <:....û, OS \ ('..s; T i'- \x. \11''(,..\ \ '-i " \\ I. ~ '\',,''0 \"'-.t) Sj \; CJ. ~ ~ "Y I b,j"\-. \ \- '\ '/ 1"'\.0 \-- COt---S~IL\Q:Sj 0- \J'--\cn"'ô '~\k: S'V'\.CJè o h.. Ú.10~'0 \'0 S <L'{ \S \ <,. <ì \-h.Cé <;<Lö. \ \oo~ "\ So ú.. \?o.t br ~Cy.~hjQlCL~~ 'Æ~~5.;JS-: 01-29-05 .... ..... ~ : - :CQnQCoPhilliþS AI~IG\,I.n~, :, . .' 1D-111 ,'.' , . . . API: 500292291100 Tubing SSSV Type: NONE (Q.6188. 00:3.500, 10:2.992) Production (Q.6188. 00:5.500. Wt15.50) NIP (6143-6144. 00:3.500) PLUG (6143-6144, 00:2.812) SEAL (6188-6189, 00:5.000) Production (6188-7036. 00:3.500. Wt:9.30) Perf (6276-6316) Perf (6356-6376) Perf (638Q.6400) Perf (641«)444) Perf (6472-6482) Perf (650Q.6530) Perf (6562-6602) Perf (665Q.6670) PLUG (6917-6918, 00:2.900) ~;:~~~&ttO ,i> Annular Fluid: 3% KCI Reference Log: Last Tag: 6860 Last Tag Date: 121712000 Ca'sirnJ' String ":'All~ Description Conductor Production Production Tl!bing String .; Tubing . Size I Top 3.500 0 PerforationsSurnmary..··. . Interval TVD 6276 - 6316 3639 - 3669 6356 - 6376 3699 - 3714 6380 - 6400 3717 - 3732 6414 - 6444 3743 - 3766 6472 - 6482 3787 - 3795 6500 - 6530 3809 - 3832 6562 - 6602 3856 - 3887 6650 - 6670 3924 - 3939 '--- KRU 1 D-111 Well Type: INJ Orig 9/2/1998 Completion: Last w/o: Ref Log Date: TD: 7046 ftKB Max Hole Angle: 67 deg @ 2029 Angle @ TS: deg @ Angle @ TD: 38 deg @ 7046 Rev Reason: Set Plug last Update: 2/27/2004 - -- -- Top Bottom TVD Wt Grade Thread 0 121 121 62.58 H-40 WELDED 0 6188 3573 15.50 L-80 BTC-MOD 6188 7036 4226 9.30 L-80 EUE-8rd Grade I Thread L-80 EUE-8rd -- , , Size 16.000 5.500 3.500 Bottom 6188 Zone Status Ft SPF Date Type Comment WS D Zone D 40 4 4/30/1999 IPERF 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg WS B Zone B 20 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, 18Odeg, orient +/- 90deg 2.5" HC 31J UJ HMX DP, +/- WSB Zone B 20 WSA4 Zone A4 30 WSA3 Zone A3 10 WSA3 Zone A3 30 WS A2. Zone A2. 40 WSA2. Zone A2. 20 4 4/29/1999 IPERF 4 4/29/1999 IPERF 4 4/29/1999 IPERF 4 4/28/1999 IPERF 4 4/28/1999 IPERF 4 4/28/1999 IPERF 4 4/27/1999 IPERF St MD TVD Man Man Type VMfr V Type VOD latch Port TRO Date VIv Mfr Run Cmnt 6084 3498 CAMCO KBG-2-9 CAMCO DMY 1.0 INT 0.000 0 Description ID CAMCO DS NIPPLE W/ NOGO 2.812 6143 PLUG 2.812" CS-A2 PLUG SET 6/20/2003 0.000 6188 SEAL BAKER GBH-22 LOCATOR SEAL ASSEMBLY 4.000 6917 PLUG Set CIBP 4/27/99 0.000 hKU vv t::st ~i:11\. llIJtJ\"LUI 1 U-l 1 1 ;:)LQLU;:) .~ \ S. ~- \ <.a C,.o Subject: KRU West Sak injector 1D-111 status From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> Date: Thu, 17 Jul 2003 10: 1 0:31 -0800 To: tom_maunder@admin.state.ak.us CC: "n1617" <n1617@conocophillips.com> Tom: The following is status report for the failed MIT on West Sak water injection well 1D-111 (PTD 1981660) . 06/20/03: MITIA failed during 4-year State witnessed MIT. Reported to AOGCC via email and through Field Inspector. Well secured with a tubing plug. 06/24/03: The DHD crew charged the IA with nitrogen to blow the fluid level down to the leak point. A fluid level was shot at 36', which correlates within a couple feet of the bottom of the first joint of casing. This well is completed with 5-1/2", 15# L-80 ABM-BTC production casing inside a 13-3/8" conductor. There is 3-1/2" tubing and a packer (locater seal) at 6188' md. We have not performed a leak rate yet, but based on the fluid rate loss during the MIT the leak rate should be no more than 1/2 gpm or so. There are only a couple of alternatives to fix this type of leak¡ either perform a rig workover or attempt to seal the leak with a product like SealTite. SealTite has shown good preliminary plugging ability on 2E-14 and 3F-06 surface casing. CPA will formulate repair alternatives and submit a proposed plan to the AOGCC via Sundry Notice 10-403 sometime in the next few weeks. Please let me know if you have more questions. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska KR U West. ~.a).(uiIlJ~~t()..}~~!!!~~~t1J.~.~~ 1 of 1 3/25/2005 8:05 AM r i:111t::U IVll11/"\. 1 U- 1 II\. TT 170 1 VVV J -- '~~I Subject: Failed MITIA 1D-111 (#1981660) From: Tom Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 14 Ju12003 07:57:26 -0800 To: NSK Problem Well Supv <n1617@conocophillips.com> cc: john_spaulding@admin.state.ak.us, jim_regg@admin.state.ak.us, AOGCC North Slope Office <aogcc -prudhoe _ bay@admin.state.ak.us> Jerry, MJ or NIna, I was getting back to 10-111 and the failed MIT. What has the diagnostics shown on the failure?? This note was from June 23. What are the plans to remedy?? Tom Maunder NSK Problem Well Supv wrote: Attached are the 4 year cycle MITIA Results for 10 and 3R11-0 (PTO#1920160). Well 10-111 (PTO#1981660) Failed the MITIA due to a discovered leak in the IA by Conductor. The injector was SI and freeze protected. Once diagnostics have been initiated on 10-111, we will inform you of our ongoing progress. Please call with any questions. (See attached file: MIT KRU 3R-110 06-20-03.xls) (See attached file: MIT KRU 10 06-20-03.xls) Thanks, Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 ------------------------------------------------------------------------ Name: MIT KRU 3R-110 06-20-03.xls MIT KRU 3R-110 06-20-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 Name: MIT KRU 10 06-20-03.xls MIT KRU 10 06-20-03.xls Type: EXCEL File Capplication/msexcel) Encoding: base64 1 of I 3/25/2005 8:08 AM MEMORANDUM TO: Randy Ruedrich Chair THRU: Jim Regg FROM' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. · ) 06, 09, 106, 109, 111 John H. Spaulding / Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL P.T.D.I 1790960 Notes: P.T.D. I 1980650 Notes: P.T.D, I 1972400 Notes: P.T,D. I 1972350 Notes: P.T,D. I 1981660 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnj.I S I T.V.D. I 6265 I Tubing I 1795 I 1790 I 1790 I 1790 I lntervall 4 TypetestI P ITestpsil 1566 I Casingl 1360I 2500 I 2500I 2490I P/F I --P Type lnj.I S I T.V.D. I 6150 I Tubing I 1792 I 1790 I 1790 I~ J lntervalI 4 TypetestI P ITestpsil 1538 I Casingl 390 I 2535 I 2520 I 25101 P/F I P I Type,nj.I S IT'v'D' I 3630 I Tubing 1131o 1131o 1131o I 1310 I,,,terva. I 4 I Type testI P I Testpsil 908 I Casingl 460 I 2620 I 2620 I 2610I P/FI P I Typelnj. I S I T.V.D. I 3550 I Tubing 11320 I 1320 I 1320 I 1320 I lntervall 4 I Type testI P I Testpsil 888 I Casingl POS. I 25501 25501 25501 P/F I P I Type lnj.I S I T.V.D. I 3573 I Tubingl ~0I~oI~o I I lntervall 4 I I ITypetestl P ITestpsil 893 ICasingl POS. I 2500I 400 , I P/FI _FI I ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER I NJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) .1DoT'had a positive pressure (basically 0 psi) when checked prior to rig up of the pump. The IA was pressured up to 2500 psi as noted and immediately started to bleed down. After 15 min. pressure was at 400 psi. Ultimately the IA went clear to 0 psi on the guage. As I was checking the IA the last time I noticed that diesel was coming up through the the hanger flutes. Approxiamtely 5 gals. over flowed into the cellar area. This was cleaned up. I contacted Tom Maunder and he suggested that the well be shut-in until CPAI offered a repair program to the AOGCC. Jeny Dethlefs Dethlefs CPAI rep. concurred with the shut-in advice. M.I.T.'s performed' _5 Number of Failures: 1_ Attachments: Total Time during tests: 3 hours cc' MIT report form 5/12/00 L.G. mit kru ld 6-20-03 jsl.xls 7/17/2.003 Well Compliance Report File on Left side of folder 198-166-0 KUPARUK RIV U WSAK ID-III 50- 029-22911-00 Roll #1: Start: Stop Roll #2: Start Stop MD 07046 TVD 04234 Completion Date: 9/2/98 Completed Status: 1W1NJ PHILLIPS ALASKA INC Current: Name Interval D 8765 1,2 SPERRY MPT/GR/EWR4 L CBL FINAL 6000-6900 CH 5 L DGR/EWR4-MD FINAL 121-7045 OH L DGR/EWR4-TVD FINAL 121-4233 OH L INJP-PSP FINAL 6100-6750 CH 5 L SCMT-PSP FINAL BL(C) 6000-6900 4/15/99 CH 5 R SRVY RPT SPERRY 0-7046. OH - --- -- ---- Are Dry Ditch Samples Required? yes~) Daily Well Ops Was the well cored? yes no Analysis Description Received? yes~ Comments: Sent Received T/C/D OH 10/21/98 10/28/98 5/6/99 5/19/99 10/21/98 10/22/98 10/21/98 10/22/98 1/27/00 2/4/00 6/8/99 6/16/99 10/13/98 10/14/98 And Received? yes no Sample Set # Wednesday, November 08, 2000 Page 1 of 1 6~8~99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'i'N: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b,~ ~ 99239 CBT W/PSP/SCMT 990221 1 1C-18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 u~ ~ ~- 99248 SCMT 990216 1 , 1D-125 99249 CBT W/PSP/SCMT 990220 1 1 D-114 I,.~ ~ ~- 99246 CBT W/PSP/SCMT 990421 1 1 D- 128 99247 SCMT 990215 i ..... ,, 1 D- 122 ~,~ ~ ~__.. 99244 CBT W/PSP/SCMT 990226 1 1 D- 111 ~,~ ~ .. 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 ~,~ ~ ¢_ 99242 SCMT 990122 1 ,, SIGNED: ~ DATE: \ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 5/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12557 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD-R Print 1D-10 ~ c:~ ~" 98193 REPROCESSED DSI 980410 1 1 ! 1D-111 CBL 990415 1 1 1D-114 CBL 990421 1 1 1D-132 WFL W/RST 990416 1 1 2B-02 PROD. PROFILE 990423 1 1 3N-18 PROD. PROFILE 990425 1 1 3G-25X 99200 USIT 980107 1 3H-11 99201 USIT 990428 1 , SIGNED.~~ DATE: j~/~)/ '1 ¢'~ 'i~J~,) Alaska 0il & Gas C~lis. Please sign and relurn one copy of Ibis transmi~al to Sherrie al the above address. Thank you. ARCO Alaska, Inc. ~ ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 6, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 : : ::~. ;..z. ~ Subject: iD- 111 (Permit No. 98-166) Well Completion Report . Dear Mr. Co~ssioner: Enclosed is the well completion repo~ for the completion on ~UID-111. An~n0rage If there are any questions, please call 265-6120. Sincerely, T. W. Mc Kay Drilling Team Leader AAI Drilling ORIGINAL TWM/skad - STATE OF ALASKA ' ~ , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED [~ ABANDONED~ SERVICE ~-] Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-166 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22911 "~~-~ 9 Unit or Lease Name 4 Location of well at surface ~. 29' FSL, 596' FEL, Sec. 14, T11N, R10E, UM ..... · ' : :.' - "' ~111~1~ Kuparuk River Unit At Top Producing Inte~al~~~~~~ ~: 10 Well Number 1539'FNL, 1950'~L, Sec. 14, T11N, R10E, UM :~__;~::~/.~;.. . 1D-111 1137' FNL, 1665' ~L, Sec. 14, T11N, R10E, UM .... " KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. ~ 15 Water Depth, if offshore 16 No. of Completions 28-Aug-98 30-Aug-98 02-Sep-98~ NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickn~s of permafrost 7046' MD & 4234' TVD 6917' MD & 4132' TVD YES ~ NO ~ NA feet MD 2165 APPROX 22 Type Electric or Other Logs Run GR/Res, SCMT w/CCUGR~emp/Pres 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE Wf GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 65.5¢ H-40 SURF. 121' 24" 9 cu yds High Early 5.5" x 15.5~ L-80 SURF. 6187' 8.5" 890 sx AS III L & 498 sx Class G 3.5" 9.3~ L-80 6187' 7036' 8.5" (included above) 24 Pedorations open to Production (MD+TVD of Top and BoUom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6276'-6316' MD 3639'-3669' TVD 4 spf 3.5" 6189' N/A 6650'-6670' MD 3924'-3939' TVD 4 spf 6562'-6602' MD 3856'-3887' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 6500'-6530' MD 3809'-3832' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6472'-6482' MD 3787'-3795' TVD 4 spf N/A N/A 6414'-6444' MD 3743'-3767' TVD 4 spf 6380'-6400' MD 3717'-3732' TVD 4 spf 6356'-6376' MD 3699'-3714' TVD 4 spf 27 PRODUCTION TEST Date First Production Method of OperatiOnlnjector(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BDt CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casin9 Pressure CALCULATED OIL-BBL GAS-MCF WATER-BDt OIL GRAVIS-APl (corr) Press. 24-HOUR RATE: Brief description of lithology, porosity, fractures, apparent dips and 'p~es~nc~Of ~il', ~as ~r Water. Submit core chips. : '. ,' ::-. np! !NAL N/A Form 10-407 Submit in duplicate Rev. 7-]-80 CONTINUED ON I~EVERSE SIDE 9. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. West Sak Sand 6268' 3633' Base West Sak 6836' 4068' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signe Title __ DATE Prepared by Name/Number Sharon Allsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 only 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 1/26/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-iii WELL ID: AK9565 TYPE: AFC: AK9565 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:08/28/98 START COMP: RIG:RIG ~ 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22911-00 08/28/98 (D1) TD: 2179' (2179) SUPV:DON E. BREEDEN MW: 9.5 VISC: 253 ?V/YP: 38/46 POH @ 2746' APIWL: 6.4 Move rig from 1D-114 to iD-iii and accept rig @ 0400 hrs. 8/28/98. NU diverter and test system. Spud at 121' and drill to 2179' 08/29/98 (D2) TD: 5368' (3189) SUPV:DON E. BREEDEN MW: 9.5 VISC: 275 PV/YP: 43/66 DRILLING AT 6175' Drill from 2179' to 3032' APIWL: 5.2 08/30/98 (D3) TD: 7045' (1677) SUPV:DON E. BREEDEN MW: 9.6 VISC: 195 PV/YP: 42/66 REAMING WITH HOLE OPENER Drill from 5368' to 7045' APIWL: 3.8 08/31/98 (D4) TD: 7045' ( 0) SUPV:DON E. BREEDEN MW: 9.6 VISC: 78 PV/YP: 23/29 CEMENTING CASING APIWL: 4.3 Ream from 2400' to 3168', 3734' to 4300', 4587' to 4680', 5157' to 5251', 5535' to 5725', & 5819' to 5913'. Run 5.5" X 3.5" casing. 09/01/98 (D5) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD: 7045' ( 0) STING INTO SBE,LAND TUBING, PRESSURE TEST 3.5", FREEZE PROTEC SUPV:CUNNINGHAM/LUTRICK Pump cement. Lost returns. Top job. Test BOPE 300/3000 psi. Run 3.5" tubing. 09/02/98 (D6) MW: 0.0 VISC: 0 PV/YP: 0/ 0 A?IWL: 0.0 TD: 7045' ( 0) DISPLACE TO 3% KCL SEAWATER SUPV:CUNNINGHAM/LUTRICK Freeze protect well. ND BOPE, NU tbg head and test tree to 300/5000 psi. Release rig @ 1200 hrs. 9/2/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~ K1(1D-111(W4-6)) WELL JOB SCOPE JOB NUMBER " 1 D-111 DRILLING SUPPORT-CAPITAL 0321992052.11 DATE DAILY WORK UNIT NUMBER 04/27/99 SET CIBP, PERF RUN #1 8345 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 3 NO YES SWS-STEPH ENSON ODELL FIELD AFC# CC# Signed ESTI MATE AK9565 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY ISET BAKER CIBP AT BOTTOM OF WELL (WET SHOE), COMPLETED PERF RUN #1,6650'- 6670', 2-1/2" HOLLOW CARRIER, 4 SPF, DEEP PENETRATING, 180 DEG PHASE, +/- 90 DEG. [PER] TIME LOG ENTRY 10:00 SWS ON LOCATION, SAFETY MEETING, RU TO RUN ClBP. PICK UP CCI/BAKER 05 RUNNING TOOl/BAKER 2.75" CIBP. 11:20 PT LUBRICATOR TO 3000 PSI 11:30 RIH W/CIBP. VERY SLOW GOING, MINIMAL BYPASS AROUND TOOL. 13:40 ON BOTTOM, TIE-IN. SET CIBP IN MIDDLE OF BOTTOM JOINT OF TUBING. TAG BOTTOM @ 6938', SET CIBP AT 6917'. GOOD SURFACE INDICATION OF SET. PULL UP 100', RUN DOWN TOTAG CIBP. TAG @ 6917'. 14:15 PERFORM CASING PRESSURE TEST: PRESSURE TUBING UP TO 1750 PSI. 14:20 TUBING PRESSURE = 1750 PSI 14:30 TUBING PRESSURE = 1640 PSI 14:40 TUBING PRESSURE = 1600 PSI 14:50 TUBING PRESSURE = 1600 PSI, TEST COMPLETE, PASSED TEST. 14:55 POOH W/SETTING TOOL. 15:30 OOH W/SETTING TOOL, SWAP TO CCI/10' GUN/ROLLERS, RIH. 16:00 SETTING DOWN @ 1975', ABLE TO WORKAS DEEP AS 2060', CAN NOT GO DEEPER. TOOLS SIMPLY STOPPING DUE TO HIGH ANGLE. 16:45 POOH TO CHANGE OUT TOOLS. 17:10 OOH WITH 10' GUN, WILL RUN 20' GUN FOR MORE WEIGHT. 17:30 RIH W/CCL/20 GUN/ROLLERS. WORK THROUGH AREAS WHERE LAST RUN STOPPED AT -1970 AND -2100. WORK TO BOTTOM. 18:30 ON BOTTOM, TIE-IN. PARK GUNS AT 6650'-6670', 2-1/2" HOOLOW CARRIERS, 4 SPF, DEEP PENETRATING, 180 DEG PHASE, +/- 90 DEG. BLEED WHP FROM 1000 PSI TO 300 PSI. TIME 18:35 19:20 19:45 LOG ENTRY SHOOT GUN # 1,6650' - 6670'. GOOD SURFACE INDICATION. WHP DROPPED TO 50 PSI. POOH. OOH, ASF. SBFN. WILL CONTINUE IN A.M. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' KI(1D-111(W4-6)) WELL JOB SCOPE JOB NUMBER " 1D-111 DRILLING SUPPORT-CAPITAL 0321992052.11 DATE DAILY WORK UNIT NUMBER 04/28/99 PERF 8345 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 N O YES SWS-V ETRO MI LE KO LSTAD FIELD AFC# CC# Signed ESTI MATE AK9565 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 250 PSI 150 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERF 6562'-6602' & 6500'-6530' & 6472'-6482' W/2.5" HC 31J UJ HMX DP/4 SPF/180 DEG PHASING WITH ORIENTING MNET[Perf] TIME LOG ENTRY 07:30 MIRU SWS 08:40 PT LINES TO 3000 PSI 08:50 RIH W/2.5" X 20' HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET - NO PROBLEM GETTING DOWN 09:45 TIE IN 09:55 WHP=500 PSI- PERF 6582'-6602' W/2.5" HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET-WHP DROPPED TO 350 PSI - TENSION DROP- POOH 10:35 BLEED DOWN LUBRICATOR - OOH - ALL SHOTS FIRED 11:10 RIH W/2.5" X 20' HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET 11:45 GUN SET DOWN AT 3400, 3940, 3950, AND 3940 DUE TO DEVIATION - PULL UP 20' ABOVE SET DOWN POINT- GO BACK DOWN AND GUNS WENT THROUGH 12:10 TIE IN 12:20 WHP=200 PSI - PERF 6562'-6582' W/2.5" HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET- TENSION DROP - POOH 13:00 OOH - ALL SHOTS FIRED 13:30 RIH W/2.5" X 30' HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET - NO PROBLEM GETTING DOWN 14:25 TIE IN 14:35 WHP=250 PSI - PERF 6500'-6530' W/2.5" HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET - TENSION DROP- NO CHANGE IN WHP- POOH 15:15 BLEED DOWN LUBRICATOR - OOH - ALL SHOTS FIRED 16:00 RIH W/2.5" X 10' HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET AND 6' X 2 1/8" WEIGHT BAR - NO PROBLEM GETTING DOWN TIME LOG ENTRY 17:00 TIE IN 17:10 WHP=250 PSI- PERF 6472'-6482' W/2.5" HC DP/4 SPF/180 DEG PHASING WITH ORIENTING MAGNET- TENSION DROP - POOH 18:00 BLEED DOWN LUBRICATOR - OOH - ALL SHOTS FIRED o LD GUN 18:45 RDMO SWS ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~ K1(1D-111(W4-6)) WELL JOB SCOPE JOB NUMBER " 1D-111 DRILLING SUPPORT-CAPITAL 0321992052.11 DATE DAILY WORK UNIT NUMBER 04/29/99 PERF 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 NO YES SWS-ELMORE KOLSTAD FIELD AFC# CC# Signed ESTIMATE AK9565 18WSTF7SC InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 300 PSI 150 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY I PERF 6414'-6444' & 6380'-6400' & 6356'-6376' W/2 1/2" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG [Perf] TIME LOG ENTRY 10:00 MIRU SWS 11:30 PT TO 3000 PSI 12:00 RIH W/2 1/2" X 30' HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG - NO PROBLEM GETTING DOWN - MAITAIN 300 PSI WHP 13:45 TIE IN 14:04 PERF 6414'-6444' W/2 1/2" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG - TENSION DROP - LOG UP - POOH 15:00 OOH - ALL SHOTS FIRED - 15:30 PU 20' GUN W/WEIGHT BAR/ROLLERS TOP AND BOTTOM/CCL - RIH 16:10 TIE IN 16:20 PERF 6380'-6400' W/2 1/2" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG - TENSION DROP - WHP=300 PSI- LOG UP - POOH 16:50 OOH - ALL SHOTS FIRED 17:00 PU 20' GUN CCL/WEIGHT BAR/ROLLERS TOP AND BOTTOM - RIH - NO PROBLEMS GETTING DOWN 17:45 TIE IN 17:50 PERF 6356'-6376' W/2 1/2" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG - TENSION DROP - LOG UP - POOH 18:30 OOH - ALL SHOTS FIRED - LD GUN AND LUBRICATOR 18:50 RD SWS - LEAVE EQUIPMENT SPOTTED ON LOCATION TO CONTINUE JOB IN THE MORNING ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~' K1(1D-111(W4-6)) WELL JOB SCOPE JOB NUMBER ' " 1 D-111 DRILLING SUPPORT-CAPITAL 0321992052.11 DATE DAILY WORK UNIT NUMBER 04/30/99 PERF 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 YESJ YES SWS-ELMORE KOLSTAD FIELD AFC# CC# Signed ESTI MATE AK9565 18WSTF7SC InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn I Final Outer Ann 300 PSI 150 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY IPERFORATE FROM 6276'-6316' WITH 2.5" HC 31J UJ HMX DP/4SPF/180 DEG ORIENTED +/- 90 DEG - STATIC BHP & BHT AT MID-PERF (6475' MD) = 1619 PSIG, 76 BEG F [Perf] TIME LOG ENTRY 08:15 MIRU SWS 08:45 PT LUBRICATOR TO 3000 PSI 09:00 RIH W/2.5" X 20' HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG WITH WEIGHT BAR/CCI/ROLLERS TOP AND BOTTOM - NO PROBLEMS GETTING DOWN 09:45 TIE IN TO JEWELRY 10:00 PERF FROM 6296'-6316' WITH 2.5" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG -TENSION DROP - LOG UP - POOH 10:30 OOH - ALL SHOTS FIRED 10:45 PU 2.5" X 20' HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG WITH WEIGHT BAR/CCL/ROLLERS TOP AND BOTTOM - NO PROBLEMS GETTING DOWN 11:30 TIE IN TO JEWELRY 11:40 PERF FROM 6276'-6296' WITH 2.5" HC 31J UJ HMX DP/4 SPF/180 DEG ORIENTED +/- 90 DEG -TENSION DROP - LOG UP - POOH 12:10 OOH - ALL SHOTS FIRED 12:30 RIH WITH STATIC PRESSURE GAUGE 13:00 STATIC PRESSURE AND TEMPERATURE READING AT MID-PERF (6475' MD) FOR 20 MINUTES 13:40 OOH WITH PRESSURE/TEMPERATURE GAUGE 14:30 RIG DOWN EQUIPMENT FROM 1D-111 AND SPOT EQUIPMENT AT 1D-114 FOR NEXT DAYS WORK- SWS RE- HEADED Kuparuk Unit Kuparuk ID 1D-111 S UR VEY REPORT October, 1998 Your Reft API-500292291100 Last Survey Date 30-August-98 Job# AKMMS0351 KBE- 111.60' DRILLING SERVICEr; A DI~ON OF DRJ~,~I. INOUfft'~lr.~ INC. ORIGINAL .RECEIVED OCT 1 4 i998 Atas~a Oii & Gas Cons. Commission Anchorage Survey Reft svy82 Sperry-Sun Drilling Services Survey Report for 1D-111 Your Ref: API-500292291100 Kuparuk Unit Measured Depth (ft) Incl, Sub-Sea Depth (ft) 0.00 0.000 0.000 -111.60 121.00 0.000 0.000 9.40 195.91 0.550 271.560 84.31 283.74 0.400 248.670 172.14 372.19 0.760 264.330 260.58 462.23 3.570 271.680 350.55 556.39 8.030 279.140 444.20 647.43 11.820 301.110 533.90 739.23 14.770 314.550 623.25 829.54 18.180 316.400 709.84 920.75 24.450 319.190 794.77 1013.41 32.760 322.170 876.05 1104.46 36.710 324.040 950.86 1195.34 37.340 324.320 1023.42 1285.65 42.410 322.430 1092.71 1376.30 47.170 322.230 1157.02 1467.05 52.420 321.300 1215.58 1558.01 54.380 321.090 1269.81 1647.64 60.430 321.570 1318.07 1839.64 61.830 321.770 1410.77 2028.92 67.370 323.220 1491.93 2218.09 66.340 322.580 1566.29 2499.70 65.440 327.350 1681.38 2686.02 64.180 324.230 1760.69 2974.74 64.790 325.730 1885.07 3354.37 64.400 327.890 2047.95 3733.16 64.660 327.250 2210.84 3924.28 64.820 325.830 2292.40 4207.13 65.100 323.270 2412.14 4491.56 64.200 320.310 2533.93 Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) fit) (ft) 0.00 0.00 N 0.00 E 121.00 0.00 N 0.00 E 195.91 0.01N 0.36W 283.74 0.09 S 1.07W 372.18 0.26 S 1.94W 462.15 0.24 S 5.33W 555.80 0.89 N 14.76W 645.50 6.73 N 29.03W 734.85 19.80 N 45.43W 821.44 38.08 N 63.36W 906.37 62.70 N 85.53W 987.65 97.08 N 113.49W 1062.46 138.58 N 144.59W 1135.02 182.95 N 176.61W 1204.31 229.37 N 211.18W 1268.62 279.90 N 250.20W 1327.18 334.31N 293.10W 1381.41 391.21N 338.86W 1429.67 450.15 N 386.01W 1522.37 582.04 N 490.29W 1603.53 717.66 N 594.30W 1677.89 856.39 N 699.22W 1792.98 1066.75 N 846.76W 1872.29 1206.17 N 941.51W 1996.67 1419.55 N 1091.02W 2159.55 1706.50 N 1278.74W 2322.44 1995.14 N 1462.13W 2404.00 2139.33 N 1557.42W 2523.74 2348.07 N 1706.05W 2645.53 2550.02 N 1864.99W 5959693.95 N 560490.60 E 5959693.95 N 560490.60 E 5959693.96 N 560490.24 E 5959693.85 N 560489.53 E 5959693.67 N 560488.66 E 5959693.67 N 560485.27 E 5959694.73 N 560475.83 E 5959700.44 N 560461.51E 5959713.38 N 560445.01 E 5959731.52 N 560426.94 E 5959755.96 N 560404.57 E 5959790.11N 560376.34 E 5959831.36 N 560344.90 E 5959875.47 N 560312.52 E 5959921.61 N 560277.58 E 5959971.83 N 560238.15 E 5960025.89 N 560194.82 E 5960082.42 N 560148.60 E 5960140.98 N 560100.98 E 5960272.03 N 559995.64 E 5960406.80 N 559890.54 E 5960544.69 N 559784.51E 5960753.85 N 559635.28 E 5960892.50 N 559539.41 E 5961104.68 N 559388.18 E 5961390.10 N 559198.17 E 5961677.26 N 559012.46 E 5961820.68 N 558916.00 E 5962028.21N 558765.71E 5962228.87 N 558605.14 E Dogleg Rate (°/lOOft) 0.000 0.734 0.272 0.441 3.130 4.794 5.815 4.634 3.820 6.962 9.097 4.493 0.718 5.772 5.253 5.838 2.163 6.765 0.735 3.007 0.627 1.579 1.659 0.514 0.524 0.167 0.677 0.826 0.992 Vertical Section fit) 0.00 0.00 0.22 0.56 0.94 2.98 9.49 22.66 42.91 68.27 101.24 145.50 197.37 252.09 309.96 373.79 443.04 516.00 591.42 759.46 930.34 1104.27 1361.14 1529.58 1790.05 2132.39 2473.52 2646.13 2902.33 3159.21 Kuparuk 1D Comment Continued... 13 October, 1998 - 7:46 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for ID-111 Your Ref: API-500292291100 Kuparuk Unit Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 4777.28 65.390 324.470 2655.65 2767.25 2754.78 N 2022.67 W 5061.10 64.870 323.450 2775.02 2886.62 2962.99 N 2174.17 W 5156.62 61,880 321.840 2817.82 2929.42 3030.86 N 2225.96 W 5250.70 59.480 321.880 2863.89 2975.49 3095.38 N 2276.61 W 5344.02 57.990 324.340 2912.33 3023.93 3159.16 N 2324.50 W 5438.88 55.330 323.360 2964.46 3076.06 3223.15 N 2371.24 W 5533.74 52.360 322.870 3020.42 3132.02 3284.40 N 2417.20 W 5627,50 50.010 322.220 3079.18 3190.78 3342.40 N 2461.62 W 5723.35 49.740 322.050 3140.95 3252.55 3400.26 N 2506.60 W 5817.11 49.200 321.800 3201.88 3313.48 3456.36 N 2550.55 W 5911.38 46.720 323.470 3265.01 3376.61 3511.98 N 2593.05 W 6005.05 44.990 324.130 3330.24 3441.84 3566.21 N 2632.75 W 6101.35 44.670 325.960 3398.54 3510.14 3621.85 N 2671.64 W 6202.67 42.100 323.320 3472.18 3583.78 3678.62 N 2711.88 W 6386.40 40,510 325.390 3610.20 3721.80 3777.14 N 2782.57 W 6670.62 39.410 324.860 3828.05 3939.65 3926.89 N 2886.94 W 6987.87 37.800 323.880 4075.96 4187.56 4087.79 N 3002.22 W 7046.00 37.800 323.880 4121.90 4233.50 4116.57 N 3023.22 W 5962432.35 N 558445.82 E 5962639.34 N 558292.65 E 5962706.80 N 558240.32 E 5962770.90 N 558189.14 E 5962834.29 N 558140.74 E 5962897.90 N 558093.49 E 5962958.79 N 558047.04 E 5963016.42 N 558002.16 E 5963073.92 N 557956.71 E 5963129.66 N 557912.31 E 5963184.94 N 557869.36 E 5963238.86 N 557829.23 E 5963294.18 N 557789.89 E 5963350.62 N 557749.19 E 5963448.56 N 557677.71E 5963597.48 N 557572.15 E 5963757.44 N 557455.57 E 5963786.05 N 557434.34 E All data is in feet unless otherwise stated. Directions and coordinates are rela[ive to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 323.560° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7046.00ft., The Bottom Hole Displacement is 5107.45ft., in the Direction of 323.706° (True). Dogleg Rate (°/100rt) 1.382 0.374 3.474 2.551 2.761 2.934 3.159 2.564 0.313 0.611 2.941 1.915 1.380 3.104 1.141 0.405 0.543 0.000 Vertical Section (ft) 3417.59 3675.08 3760.44 3842.43 3922.18 4001.42 4078.00 4151.04 4224.31 4295.54 4385.54 4432.75 4500.61 4570.18 4691.42 4873.89 5071.80 5107.43 Kuparuk 1D Comment Projected Survey Continued... 13 October, 1998 - 7:46 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for ID-111 Your Ref: API-500292291100 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 7046.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4233.50 4116.57 N 3023.22 W Comment Tie-on Survey Projected Survey 13 October, 1998 - 7:46 - 4 - DrillQuest D FI I I--I-- I IM 13 WELL LOG TRANSM1TY~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 October 21, 1998 RE: MWD Formation Evaluation Logs 1D-111, AK-MM-80351 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 1 LDWG formatted Disc with verification listing. API#: 50-029-22911-00 OCT 998 ~i & G~ -Cons. Commissm An~omge 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A 1'3r~,_~.q~.r Indlmfri~n In~ ('.c~mn~nv 0 F! I I--/I IM 13 SEFI~/I C:E S 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 October 21, 1998 1D-111, AK-MM-80351 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention ot~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 ID-Ill: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22911-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22911-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia ,. O~T ~,-:-'''' i, 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 =_. n I::! I I--I_ I I~1 G 13-Oct-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-111 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 7,046.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RE b VED OCT 1 4 i998 0i~ & Gas ~ns. Oommi~o~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS August 26, l~NSERVATION COMMISSION Thomas W. McKay Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 ae~ Kuparuk River Unit 1 D-111 ARCO Alaska. Inc. Permit No. 98-166 Sur. Loc. 29'FSL, 596'FEL, Sec. 14, T1 iN, R10E, UM Btmhole Loc. 1122'FNL, 1643'FWL, Sec. 14, T11N, R10E, UM Dear Mr. McKav: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is the approved application for permit to drill thc above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-111. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a permitted existing well on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a period longer than one year. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling beloxv the surface casing shoe, must be given so that a representative of the Commission max' witness the tests. Notice may be given by Id inspector on the North Slope pager at 659-3607. David W. Johnston Chairman BY ORDER OF THE COMMISSION dltTEnclosure cc; Department of Fish & Game, Habitat Section w/o encl. Department of Enviromncntal Conservation w/o encl. STATE OF ALASKA ALASh,~-~ OIL AND GAS CONSERVATION COMMI~81ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Reddll lb Type of Well Exploratory Stratigraphic Test Development Oil Re-Entry Deepen Service X Development Gas SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 4]', ?ad 7]' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 29' FSI., 596' FEI., Sec. 14, 'TI IN, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1421' FNL, 1856' FWL, Sec. 14, TllN, R10E, [JIM 1D-111 #U-630610 At total depth 9. Approximate spud date Amount 1122' FNL, 1643' FWL, Sec. 14, T11N, R10E, UM 8/28/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and property line 1D-109 7093' MD 1122' @ TD feet 30' @ 100' feet 2560 4242' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 64.5° Maximum surface 1432 psig At total depth (TVD) 1 88 ] psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplin9 Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' _+200 CF 8.5" 5.5" x 15.5# L-80 BTC M 6194' 41' 41' 6235' 3586' 652 Sx Arcticset IIIL & 8.5" 3.5" 9.3# L-80 8rd MOD 858' 6235' 3586' 7093' 4242' 525 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ! ECEiV Surface Intermediate0RJGJN L Production Liner ! \U6 15 1998 Perforation depth: measured true vertical A]as~ 0il & Gas Cons. Commission 20. Attachments Filing fee X Property plat BOP Sketch X Diverter Sketch A~horage Ddlling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21' Ihe~ re by certify that the f°reg°ing is true and c°rrec~ t° the'best °f mY kn°wledge zt~"*'""'l "'")//) // J 7/'/ //'''''' '~p '~'''''-'' .... ~,~ ~,. ~/. &T_~/" ~"-~' ,,~ -.~,-. /f / C/L/. O" S , ,o vS n s ~ Commission UseOnly Permit Umber AP~ number /I Approva~ date ,,~ ~/ ~',~ I See cover ~e~erfor ,,S,'~-/6 ~ I 50- 0.2.~'- _~_ ~4 ~'"('_ _"" I CP -- C:~ ~ --/'' I other requirements Conditions-of ~pproval Samples required Yes ;~K No Mud Icg required Yes ~ No Hydrogen sulfide measures Yes ~ No Directional survey required ~' Yes No Required working pressure for BOPE 2M (3M~ 5M 10M 15M Other: Original Signea By [:)avid W. Johnston byordero, ~__~ Approved by Commissioner the commission Date e,,~.,..;, Form 10-401 Rev. 7-24-89 I ARCO Alaska, Inc. ~ Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 10, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-111 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designated as a monobore injection well using a 5 1/2" x 3 Y2" tapered casing string, with 3- 1/2" tubing used as a tieback string. 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 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 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). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-111, such as shallow gas. There have been ten (10) Kuparuk wells and twenty (20) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) 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 monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) 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. Please note that the anticipated spud date for this well is August 28, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Scott Goldberg ,~ Operations Drilling Engineer CC: West Sak 1 D-111 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill, Case and Completion Plan for West Sak 1 D-111 (B2) Monobore Injector General Procedure: Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. o Weld Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. . . . Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 5 ~" casing _+1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is close to the surface, a top job may be performed in lieu of utilizing the port collar. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Before stinging into seal bore, freeze protect well with enough diesel to cover Permafrost. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig. 10. 11. If necessary, 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. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 12. Rig up E-line unit and RIH with through-tubing perforating guns. 13. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 1D-111 (B2) Page 1 HH, 08/06/98, v.1 14. Install back pressure valve, shut in and secure well. 1D-111 (B2) Page 2 HH, 08/06/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-111 (B2) Drilling Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12% Drillinq Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. 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' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-111 (B2) 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 safely be drilled using a diverter system only for well control purposes. 1D-111 (B2) Page 1 HH,08/10/98,v.1 Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,661TVD. 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 = (4089 fi) (0.46- 0.11) psi/fi = 1432 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 casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 5-1/2" 15.5# LB0 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. Drillinq Area Risks: Drilling risks in the West Sak 1D-111 (B2) 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, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-111 (B2) is WS 1 D-109. As designed, the minimum distance between the two wells would be 30' at 100' MD. 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-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-111 (B2) 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-111 (B2) Page 2 HH,08/10/98,v.1 C~,o,e~ ~ r,,=~ For: BROCK'WAY Dale plotted : II-Jun-G8 Plot Reflrence i8 ~ 10-111/B2 V~. ~5. Coor~notes ore ~n feet ~fer~nce slot ~11 I. Vert~al Oept~a ore ref~ence ~8 (Park~ ~245). 323.56 AZIMUTH ***Plane of Proposal*** ARCO Alas Inc. F~el e Location :Norfh Slope, Alaska <- West (feet) 5150 2800 2450 2100 1750 1400 1050 700 .350 0 550 I I I t I I I I I I I I I I I I I I I I I i TO LOCATION: t 4200 TO - Casing Pt 1122' FNL, 1643' FWL Bose West Sok Sands SEC. 14, T11N, RIOE TARGET - West Sak A5 West Sok Sends / EOD Top Ugnu Sands Begin Angle Drop k 3850 3500 5150 TARGET LOCATION: 2800 1421' FNL, 1856' FWL / SEC. 14, T11N, RIOE TARGET TVD=5804 2450 350 TM0=6521 DEP=4761 NORTH 58,30 WEST 2828 0 oRKB ELEVATION: 112' 2100 350 I 1750 KOP TVI]=500 TMD=500 DEP=O 700 ~15.69 / ~21.11 DLS: 6.00 deg per 100 ft F ~,26.77 ~.,_ !o50 '~2~ ~5.5`3 9 F1050 6 Base Permafrost ~_ ",~56.08 ~ 1 z, O0 "-,~.C TVD= 1 424 TMD= 1 642 DEP=550 ~ 700 1750 -[ 350 rn j MAXIMUM A - 64.5 BEG ~ 0 2100 ~ Begin Turn to Target ~ F 0 ® i > 2450 ~ [---- '~'~-~ S TI M AT E-~'-~ 350 ~ ~ I SURFACE LOCATION: ~ 29' FSL, 596' FEL I SEC. 14, T11N, RIOE }_ 2800 9 69 I V 315o '~90.69 OLS: 2.00 deg per !00 ft .69 5500 2.6.~9 TARGET - A3 TVD=3g04 TMD=6521 DEP=4761",x 3850 TARGET ANGLE TD- CSG PT TVD=4~4g TMD=?093 DEP=51MB~XX~7 4200 40 DEG 4550 I I I f I I r I I I [ i [ I I I I I I I I I I I I I I I l 350 0 550 700 i 050 1400 1750 21 O0 2450 2800 3150 3500 5850 4200 4550 4900 5250 Vertical Section (feet) -> Azimuth 323.56 with reference 0.00 N, 0.00 E from slot #111 Z ARCO Alaska, Inc. Pad 1D 111 slot #111 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : WS 1D-III/B2 Vets. #5 Our ref : prop2215 License : Date printed : 11-Jun-98 Date created : 17-Apr-97 Last revised : 11-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 18 1.601,w149 30 36.284 Slot Grid coordinates are N 5959693.682, E 560490.724 Slot local coordinates are 29.00 N 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 1 Your ref = WS 1D-iii/B2 Vers. #5 Last revised = 11-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 270.00 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 270.00 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 270.00 500.00 0.00 N 0.00 E 0.00 0.00 600.00 6.00 270.00 599.82 0.00 S 5.23 W 6.00 3.11 650.00 9.00 270.00 649.38 0.00 S 11.76 W 6.00 6.98 700.00 10.87 283.69 698.64 1.12 N 20.25 W 6.00 12.93 800.00 15.69 299.56 795.97 10.03 N 41.19 W 6.00 32.53 900.00 21.11 307.79 890.84 27.75 N 67.21 W 6.00 62.24 1000.00 26.77 312.72 982.20 54.08 N 98.02 W 6.00 101.73 1100.00 32.55 316.02 1069.07 88.75 N 133.28 W 6.00 150.56 1200.00 38.39 318.41 1150.48 131.37 N 172.60 W 6.00 208.21 1300.00 44.26 320.25 1225.55 181.47 N 215.57 W 6.00 274.03 1400.00 50.16 321.74 1293.45 238.50 N 261.69 W 6.00 347.31 1500.00 56.08 323.00 1353.44 301.84 N 310.48 W 6.00 427.25 1600.00 62.00 324.09 1404.86 370.79 N 361.39 W 6.00 512.96 1642.01 64.50 324.51 1423.77 401.25 N 383.28 W 6.00 550.47 2000.00 64.50 324.51 1577.90 664.33 N 570.87 W 0.00 873.53 2183.71 64.50 324.51 1657.00 799.33 N 667.13 W 0.00 1039.31 2500.00 64.50 324.51 1793.18 1031.77 N 832.87 W 0.00 1324.75 3000.00 64.50 324.51 2008.46 1399.21 N 1094.87 W 0.00 1775.97 3500.00 64.50 324.51 2223.74 1766.65 N 1356.86 W 0.00 2227.19 4000.00 64.50 324.51 2439.02 2134.09 N 1618.86 W 0.00 2678.41 4500.00 64.50 324.51 2654.30 2501.53 N 1880.86 W 0.00 3129.62 S000.00 64.50 324.51 2869.58 2868.97 N 2142.86 W 0.00 3580.84 5109.67 64.50 324.51 2916.80 2949.56 N 2200.33 W 0.00 3679.81 5200.00 62.69 324.51 2956.97 3015.43 N 2247.30 W 2.00 3760.70 5300.00 60.69 324.51 3004.39 3087.11 N 2298.41 W 2.00 3848.73 5396.42 58.76 324.51 3053.00 3154.91 N 2346.75 W 2.00 3931.98 5400.00 58.69 324.51 3054.86 3157.40 N 2348.52 W 2.00 3935.04 5500.00 56.69 324.51 3108.31 3226.21 N 2397.59 W 2.00 4019.54 5600.00 54.69 324.51 3164.67 3293.46 N 2445.54 W 2.00 4102.13 5700.00 52.69 324.51 3223.88 3359.07 N 2492.32 W 2.00 4182.70 5800.00 50.69 324.51 3285.87 3422.96 N 2537.87 W 2.00 4261.15 5900.00 48.69 324.51 3350.56 3485.04 N 2582.14 W 2.00 4337.39 6000.00 46.69 324.51 3417.87 3545.25 N 2625.07 W 2.00 4411.33 6100.00 44.69 324.51 3487.72 3603.51 N 2666.61 W 2.00 4482.87 6200.00 42.69 324.51 3560.02 3659.75 N 2706.71 W 2.00 4551.93 6300.00 40.69 324.51 3634.70 3713.91 N 2745.33 W 2.00 4618.43 6334.51 40.00 324.51 3661.00 3732.10 N 2758.30 W 2.00 4640.77 6500.00 40.00 324.51 3787.77 3818.71 N 2820.05 W 0.00 4747.13 6521.17 40.00 324.51 3803.99 3829.79 N 2827.95 W 0.00 4760.74 6521.19 40.00 324.51 3804.00 3829.80 N 2827.96 W 0.01 4760.75 KOP Begin Turn to Target EOC Base Permafrost Begin Angle Drop Top Ugnu Sands Anchorage Top West Sak Sands / EOD TARGET - West Sak A3 WS 1D-B2 Rvsd 22-Jan-98 6893.23 40.00 324.51 4089.00 4024.52 N 2966.79 W 0.00 4999.86 Base West Sak Sands 7000.00 40.00 324.51 4170.79 4080.40 N 3006.64 W 0.00 5068.48 7093.23 40.00 324.51 4242.21 4129.19 N 3041.43 W 0.00 5128.40 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref ~ WS 1D-III/B2 Vers. #5 Last revised = 11-Jun-98 Comments in we11path MD TVD Rectangular Coords. Comment 500.00 650 00 1642 01 2183 71 5109 67 5396 42 6334 51 6521 17 6521 19 6893 23 7093 23 5OO 649 1423 1657 2916 3053 3661 3803 3804 4089 4242 00 0.00 N 0.00 E KOP 38 0.00 S 11.76 W Begin Turn to Target 77 401.25 N 383.28 W E0C 00 799.33 N 667.13 W Base Pe=mafrost 80 29%9.56 N 2200.33 W Begin Angle Drop 00 3154.91 N 23%6.75 W Top ~gnu Sands 00 3732.10 N 2758.30 W Top West Sak Sands / EOD 99 3829.79 N 2827.95 W TARGET - West Sak A3 00 3829.80 N 2827.96 W WS 1D-B2 Rvsd 22-Jan-98 00 402%.52 N 2966.79 W Base West Sak Sands 21 4129.19 N 30%1.43 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3829.80N 2827.96W 9-0ct-96 A~RCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 0.00 0.00 29.00 N 596.00 100.00 0.00 270.00 100.00 29.00 N 596.00 200.00 0.00 270.00 200.00 29.00 N 596.00 300.00 0.00 270.00 300.00 29.00 N 596.00 400.00 0.00 270.00 400.00 29.00 N 596.00 500.00 0.00 270.00 500.00 29.00 N 596.00 600.00 6.00 270.00 599.82 29.00 N 601.23 650.00 9.00 270.00 649.38 29.00 N 607.76 700.00 10.87 283.69 698.64 30.12 N 616.25 800.00 15.69 299.56 795.97 39.03 N 637.19 900.00 21.11 307.79 890.84 56.75 N 663.21 1000.00 26.77 312.72 982.20 83.08 N 694.02 1100.00 32.55 316.02 1069.07 117.75 N 729.28 1200.00 38.39 318.41 1150.48 160.37 N 768.60 1300.00 44.26 320.25 1225.55 210.47 N 811.57 1400.00 50.16 321.74 1293.45 267.50 N 857.69 1500.00 56.08 323.00 1353.44 330.84 N 906.48 1600.00 62.00 324.09 1404.86 399.79 N 957.39 1642.01 64.50 324.51 1423.77 430.25 N 979.28 2000.00 64.50 324.51 1577.90 693.33 N 1166.87 2183.71 64.50 324.51 1657.00 828.33 N 1263.13 2500.00 64.50 324.51 1793.18 1060.77 N 1428.87 3000.00 64.50 324.51 2008.46 1428.21 N 1690.87 3500.00 64.50 324.51 2223.74 1795.65 N 1952.86 4000.00 64.50 324.51 2439.02 2163.09 N 2214.86 4500.00 64.50 324.51 2654.30 2530.53 N 2476.86 5000.00 64.50 324.51 2869.58 2897.97 N 2738.86 5109.67 64.50 324.51 2916.80 2978.56 N 2796.33 5200.00 62.69 324.51 2956.97 3044.43 N 2843.30 5300.00 60.69 324.51 3004.39 3116.11 N 2894.41 5396.42 58.76 324.51 3053.00 3183.91 N 2942.75 5400.00 58.69 324.51 3054.86 3186.40 N 2944.52 5500.00 56.69 324.51 3108.31 3255.21 N 2993.59 5600.00 54.69 324.51 3164.67 3322.46 N 3041.54 5700.00 52.69 324.51 3223.88 3388.07 N 3088.32 5800.00 50.69 324.51 3285.87 3451.96 N 3133.87 5900.00 48.69 324.51 3350.56 3514.04 N 3178.14 6000.00 46.69 324.51 3417.87 3574.25 N 3221.07 6100.00 44.69 324.51 3487.72 3632.51 N 3262.61 6200.00 42.69 324.51 3560.02 3688.75 N 3302.71 PROPOSAL LISTING Page 1 Your ref : WS 1D-iii/B2 Vets. #5 Last revised : 11-Jun-98 Dogleg Vert Deg/100ft Sect W 0.00 0.00 W 0.00 0.00 W 0.00 0.00 W 0.00 0.00 W 0.00 0.00 W 0.00 W 6.0O W 6.00 W 6.OO W 6.00 0.00 KOP 3.11 6.98 Begin Turn to Target 12.93 32.53 W 6.00 62.24 W 6.00 101.73 W 6.00 150.56 W 6.00 208.21 W 6.00 274.03 W 6.00 347.31 W 6.00 427.25 W 6.00 512.96 W 6.00 550.47 EOC W 0.00 873.53 W 0.00 W 0.00 W 0.00 W 0.00 W 0.00 0.00 0.00 0.00 2.00 2.00 W 2.00 W 2.00 W 2.00 W 2.OO W 2.OO 1039.31 Base Permafrost 1324.75 1775.97 2227.19 2678.41 3129.62 3580.84 3679.81 Begin Angle Drop 3760.70 3848.73 3931.98 Top Ugnu Sands 3935.04 4019.54 4102.13 4182.70 W 2.00 4261.15 W 2.00 4337.39 W 2.00 4411.33 W 2.00 4482.87 W 2.00 4551.93 6300.00 40.69 324.51 3634.70 3742.91 N 3341.33 W 2.00 6334.51 40.00 324.51 3661.00 3761.10 N 3354.30 W 2.00 6500.00 40.00 324.51 3787.77 3847.71 N 3416.05 W 0.00 6521.17 40.00 324.51 3803.99 3858.79 N 3423.95 W 0.00 6521.19 40.00 324.51 3804.00 3858.80 N 3423.96 W 0.01 4618.43 4640.77 TOp West Sak Sands / EOD 4747.13 4760.74 TARGET - West Sak A3 4760.75 WS 1D-B2 Rvsd 22-Jan-98 6893.23 40.00 324.51 4089.00 4053.52 N 3562.79 W 0.00 4999.86 Base West Sak Sands 7000.00 40.00 324.51 4170.79 4109.40 N 3602.64 W 0.00 5068.48 7093.23 40.00 324.51 4242.21 4158.19 N 3637.43 W 0.00 5128.40 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-iII/B2 Vers. #5 Last revised = 11-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 29.00 N 596.00 W KOP 650.00 649.38 29.00 N 607.76 W Begin Turn to Target 1642.01 1423.77 430.25 N 979.28 W EOC 2183.71 1657.00 828.33 N 1263.13 W Base Permafrost 5109.67 2916.80 29?8.56 N 2796.33 W Begin Angle Drop 5396.42 3053.00 3183.91 N 2942.75 W Top Ugnu Sands 6334.51 ]661.00 3761.10 N 3354.30 W Top West Sak Sands / EOD 6521.17 3803.99 3858.79 N 3423.95 W TARGET - West Sak A3 6521.19 3804.00 3858.80 N 3423.96 W WS 1D-B2 Rvsd 22-Jan-98 6893.23 4089.00 4053.52 N 3562.79 W Base West Sak Sands 709].23 4242.21 4158.19 N 3637.43 W TD - Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 29.00N 596.00W 7093.23 4242.21 4158.19N 3637.43W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3858.80N 3423.96W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C O O R D PROPOSAL LISTING Page 1 Your ref : WS 1D-iIi/B2 Vets. #5 Last revised : 11-Jun-98 NGULAR INATES vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 270.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 0.00 270.00 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 0.00 270.00 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 600.00 6.00 270.00 599.82 0.00 S 5.23 W 3.11 1.61 1.57 0.90 270.00 650.00 9.00 270.00 649.38 0.00 S 11.76 W 6.98 1.82 1.71 0.98 270.00 700.00 10.87 283.69 698.64 1.12 N 20.25 W 12.93 2.09 1.85 1.05 274.80 800.00 15.69 299.56 795.97 10.03 N 41.19 W 32.53 2.93 2.16 1.22 287.68 900.00 21.11 307.79 890.84 27.75 N 67.21 W 62.24 4.25 2.51 1.40 296.37 1000.00 26.77 312.72 982.20 54.08 N 98.02 W 101.73 6.09 2.91 1.61 302.43 1100.00 32.55 316.02 1069.07 88.75 N 133.28 W 150.56 8.50 3.36 1.89 306.82 1200.00 38.39 318.41 1150.48 131.37 N 172.60 W 208.21 11.47 3.84 2.26 310.13 1300.00 44.26 320.25 1225.55 181.47 N 215.57 W 274.03 15.00 4.36 2.72 312.69 1400.00 50.16 321.74 1293.45 238.50 N 261.69 W 347.31 19.05 4.87 3.30 314.74 1500.00 56.08 323.00 1353.44 301.84 N 310.48 W 427.25 23.59 5.37 4.00 316.41 1600.00 62.00 324.09 1404.86 370.79 N 361.39 W 512.96 28.54 5.84 4.80 317.80 1642.01 64.50 324.51 1423.77 401.25 N 383.28 W 550.47 30.69 6.02 5.15 318.29 2000.00 64.50 324.51 1577.90 664.33 N 570.87 W 873.53 49.12 7.61 8.26 320.68 2183.71 64.50 324.51 1657.00 799.33 N 667.13 W 1039.31 58.63 8.42 9.88 321.17 2500.00 64.50 324.51 1793.18 1031.77 N 832.87 W 1324.75 75.01 9.81 12.66 322.02 3000.00 64.50 324.51 2008.46 1399.21 N 1094.87 W 1775.97 100.96 12.02 17.08 322.67 3500.00 64.50 324.51 2223.74 1766.65 N 1356.86 W 2227.19 126.92 14.23 21.50 323.05 4000.00 64.50 324.51 2439.02 2134.09 N 1618.86 W 2678.41 152.89 16.45 25.93 323.30 4500.00 64.50 324.51 2654.30 2501.53 N 1880.86 W 3129.62 178.87 18.66 30.36 323.47 5000.00 64.50 324.51 2869.58 2868.97 N 2142.86 W 3580.84 204.86 20.87 34.79 323.61 5109.67 64.50 324.51 2916.80 2949.56 N 2200.33 W 3679.81 210.55 21.36 35.77 323.63 5200.00 62.69 324.51 2956.97 3015.43 N 2247.30 W 3760.70 215.13 21.77 36.54 323.65 5300.00 60.69 324.51 3004.39 3087.11 N 2298.41 W 3848.73 220.05 22.25 37.38 323.67 5396.42 58.76 324.51 3053.00 3154.91 N 2346.75 W 3931.98 224.63 22.73 38.15 323.69 5400.00 58.69 324.51 3054.86 3157.40 N 2348.52 W 3935.04 224.80 22.75 38.18 323.69 5500.00 56.69 324.51 3108.31 3226.21 N 2397.59 W 4019.54 229.39 23.26 38.94 323.70 5600.00 54.69 324.51 3164.67 3293.46 N 2445.54 W 4102.13 233.81 23.78 39.68 323.72 5700.00 52.69 324.51 3223.88 3359.07 N 2492.32 W 4182.70 238.06 24.32 40.38 323.73 5800.00 50.69 32%.51 3285.87 3422.96 N 2537.87 W 4261.15 242.12 24.86 41.05 323.75 5900.00 48.69 324.51 3350.56 3485.04 N 2582.14 W 4337.39 246.00 25.42 41.68 323.76 6000.00 46.69 324.51 3417.87 3545.25 N 2625.07 W 4411.33 249.68 25.97 42.27 323.77 6100.00 44.69 324.51 3487.72 3603.51 N 2666.61 W 4482.87 253.18 26.53 42.83 323.78 6200.00 42.69 324.51 3560.02 3659.75 N 2706.71 W 4551.93 256.49 27.09 43.36 323.79 6300.00 40.69 324.51 3634.70 3713.91 N 2745.33 W 4618.43 259.60 27.65 43.85 323.80 6334.51 40.00 324.51 3661.00 3732.10 N 2758.30 W 4640.77 260.65 27.84 44.01 323.80 6500.00 40.00 324.51 3787.77 3818.71 N 2820.05 W 4747.13 265.70 28.77 44.80 323.81 6521.17 40.00 324.51 3803.99 3829.79 N 2827.95 W 4760.74 266.34 28.89 44.90 323.81 6521.19 40.00 324.51 3804.00 3829.80 N 2827.96 W 4760.75 266.34 28.89 44.90 323.81 6893.23 40.00 324.51 4089.00 4024.52 N 2966.79 W 4999.86 277.69 30.97 46.68 323.84 7000.00 40.00 324.51 4170.79 4080.40 N 3006.64 W 5068.48 280.95 31.57 47.19 323.85 7093.23 40.00 324.51 4242.21 4129.19 N 3041.43 W 5128.40 283.79 32.09 47.63 323.85 All data is in feet unless otherwise stated. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-Iii/B2 Vets. #5 Last revised : 11-Jun-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Su~rey Tool Error Model Major Minor Vert. 0 7093 ARCO (H.A. Mag) User specified 283.79 32.09 47.63 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0.00 N 0.00 E KOP 650.00 649.38 0.00 S 11.76 W Begin Turn to Target 1642.01 1423.77 401.25 N 383.28 W EOC 2183.71 1657.00 799.33 N 667.13 W Base Permafrost 5109.67 2916.80 2949.56 N 2200.33 W Begin Angle Drop 5396.42 3053.00 3154.91 N 2346.75 W Top U~nu Sands 6334.51 3661.00 3732.10 N 2758.30 W Top West Sak Sands / EOD 6521.17 3803.99 3829.79 N 282?.95 W TARGET - West Sak A3 6521.19 3804.00 3829.80 N 2827.96 W WS 1D-B2 Rvsd 22-Jan-98 6893.23 4089.00 4024.52 N 2966.79 W Base West Sak Sands 7093.23 4242.21 4129.19 N 3041.43 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this we11path Target n~.me Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Ja~ 557632.000,5963500.000,0.0000 3804.00 3829.80N 2827.96W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LISTING Page 1 Your ref : WS 1D-iIi/B2 Vets. #5 Last revised ~ 11-Jun-98 Dogleg Vert G R I D C O O R D S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 100.00 0.00 270.00 100.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 200.00 0.00 270.00 200.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 300.00 0.00 270.00 300.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 400.00 0.00 270.00 400.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 500.00 0.00 270.00 500.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 600.00 6.00 270.00 599.82 0.00S 5.23W 6.00 3.11 560485.49 5959693.64 650.00 9.00 270.00 649.38 0.00S 11.76W 6.00 6.98 560478.97 5959693.59 700.00 10.87 283.69 698.64 1.12N 20.25W 6.00 12.93 560470.47 5959694.63 800.00 15.69 299.56 795.97 10.03N 41.19W 6.00 32.53 560449.46 5959703.37 900.00 21.11 307.79 890.84 27.75N 67.21W 6.00 62.24 560423.30 5959720.88 1000.00 26.77 312.72 982.20 54.08N 98.02W 6.00 101.73 560392.28 5959746.96 1100.00 32.55 316.02 1069.07 88.75N 133.28W 6.00 150.56 560356.74 5959781.34 1200.00 38.39 318.41 1150.48 131.37N 172.60W 6.00 208.21 560317.08 5959823.63 1300.00 44.26 320.25 1225.55 181.47N 215.57W 6.00 274.03 560273.71 5959873.37 1400.00 50.16 321.74 1293.45 238.50N 261.69W 6.00 347.31 560227.13 5959930.02 1500.00 56.08 323.00 1353.44 301.84N 310.48W 6.00 427.25 560177.83 5959992.96 1600.00 62.00 324.09 1404.86 370.79N 361.39W 6.00 512.96 560126.36 5960061.49 1642.01 64.50 324.51 1423.77 401.25N 383.28W 6.00 550.47 560104.23 5960091.77 2000.00 64.50 324.51 1577.90 664.33N 570.87W 0.00 873.53 559914.53 5960353.29 2183.71 64.50 324.51 1657.00 799.33N 667.13W 0.00 1039.31 559817.18 5960487.49 2500.00 64.50 324.51 1793.18 1031.77N 832.87W 0.00 1324.75 559649.58 5960718.55 3000.00 64.50 324.51 2008.46 1399.21N 1094.87W 0.00 1775.97 559384.63 5961083.81 3500.00 64.50 324.51 2223.74 1766.65N 1356.86W 0.00 2227.19 559119.67 5961449.07 4000.00 64.50 324.51 2439.02 2134.09N 1618.86W 0.00 2678.41 558854.72 5961814.34 4500.00 64.50 324.51 2654.30 2501.53N 1880.86W 0.00 3129.62 558589.77 5962179.60 5000.00 64.50 324.51 2869.58 2868.97N 2142.86W 0.00 3580.84 558324.82 5962544.86 5109.67 64.50 324.51 2916.80 2949.56N 2200.33W 0.00 3679.81 558266.71 5962624.97 5200.00 62.69 324.51 2956.97 3015.43N 2247.30W 2.00 3760.70 558219.21 5962690.46 5300.00 60.69 324.51 3004.39 3087.11N 2298.41W 2.00 3848.73 558167.52 5962761.71 5396.42 58.76 324.51 3053.00 3154.91N 2346.75W 2.00 3931.98 558118.63 5962829.11 5400.00 58.69 324.51 3054.86 3157.40N 2348.52W 2.00 3935.04 558116.84 5962831.58 5500.00 56.69 324.51 3108.31 3226.21N 2397.59W 2.00 4019.54 558067.22 5962899.99 5600.00 54.69 324.51 3164.67 3293.46N 2445.54W 2.00 4102.13 558018.73 5962966.84 5700.00 52.69 324.51 3223.88 3359.07N 2492.32W 2.00 4182.70 557971.42 5963032.06 5800.00 50.69 324.51 3285.87 3422.96N 2537.87W 2.00 4261.15 557925.35 5963095.57 5900.00 48.69 324.51 3350.56 3485.04N 2582.14W 2.00 4337.39 557880.58 5963157.29 6000.00 46.69 324.51 3417.87 3545.25N 2625.07W 2.00 4411.33 557837.17 5963217.14 6100.00 44.69 324.51 3487.72 3603.51N 2666.61W 2.00 4482.87 557795.16 5963275.06 6200.00 42.69 324.51 3560.02 3659.75N 2706.71W 2.00 4551.93 557754.61 5963330.96 6300.00 40.69 324.51 3634.70 3713.91N 2745.33W 2.00 4618.43 557715.56 5963384.79 6334.51 40.00 324.51 3661.00 3732.10N 2758.30W 2.00 4640.77 557702.45 5963402.88 6500.00 40.00 324.51 3787.77 3818.71N 2820.05W 0.00 4747.13 557640.00 5963488.98 6521.17 40.00 324.51 3803.99 3829.79N 2827.95W 0.00 4760.74 557632.00 5963499.99 6521.19 40.00 324.51 3804.00 3829.80N 2827.96W 0.01 4760.75 557632.00 5963500.00 6893.23 40.00 324.51 4089.00 4024.52N 2966.79W 0.00 4999.86 557491.60 5963693.56 7000.00 40.00 324.51 4170.79 4080.40N 3006.64W 0.00 5068.48 557451.31 5963749.11 7093.23 40.00 324.51 4242.21 4129.19N 3041.43W 0.00 5128.40 557416.13 5963797.62 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes iNTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-Iii/B2 Vets. #5 Last revised : 11oJun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 650.00 1642.01 2183.71 5109 67 5396 42 6334 51 6521 17 6521 19 6893 23 7093 23 500.0O 0.00N 0 649.38 0.00S 11 1423.77 401.25N 383 1657.00 799.33N 667 2916.80 2949.56N 2200 3053.00 3154.91N 2346 3661.00 3732.10N 2758 3803.99 3829.79N 2827 3804.00 3829.80N 2827 4089.00 4024.52N 2966 4242.21 4129.19N 3041 .00E KOP .76W Begin Turn to Target .28W EOC 13W Base Permafrost 33W Begin Angle Drop 75W Top Ugnu Sands 30W Top West Sak Sands / EOD 95W TARGET - West Sak A3 96W WS 1D-B2 Rvsd 22-Jan-98 79W Base West Sak Sands 43W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this wellpath Target n~.me Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,596]500.000,0.0000 3804.00 3829.80N 2827.96W 9-Oct-96 o~o,,~ =, r..=. For: BROCKIfAY Plot R4fErenc~ i~ ~ 10--111/82 V~. 05. ARCO Alaska, Inc. STrucTure : Pod 10 Well : 111 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 24.0 220 200 180 160 140 120 1 O0 80 60 4.0 20 Ai~(~'~Or~'g'¢;20 4.0 60 ~20 I ~ ~ ' f f I t I f I I i 1 I I I ! I I i I ! t I I I f , : : / '" X '} 1000 ~ ~ ~ 1899 99 '.- ' k " ~ : ~ 1 700 ,' j ',,. ~ ~ 400 ',, : ~ ~ 2 ~ aa i ; ", " ~ ~ ~ '] 900 "",,, / ",, ,,oo ',: / , '"'"'"' k '~ ""' ~: ~ , ~oo / & i ". ~ 5~ 900 ', ~ " 220 q ~ "x% ~ 300 , ~ ~ ~ 2000 "8nO ," ; 220 ' ' ' ~ ~ ~00 ~oo 1 ~,, "-,, ',, ~ '~ ~ k, 7%( ,.," ~ ~ooo' ......... "'"'"',.l' "' ~oo ..., ,'~oo~,, '.. "',. '",, ~ ', '~ ~, ,,' / ~ r ~80 200 '~, ~ 800 ~ 600 ./' ~ ,,' ,," b · ",,, '",, 'k k k, ~ ",, soo..-'" ~9oo~ 7" ,"' 1 ',.,"..,,~oo ',, ~ ,,,,.~. ~ ,,,, ~..,.- .~,,oo.,.,oo~ ,~ol ,,, ,, ,~ % x ou= ,, ,,, ~oo=,,'~ ,,' /~:,~o ~ ",. ",. 9o~', %", ', '"-.._ soo,..' ~.." //%: i ", ", 'x % ~oo ", ~, ~ . y ~¢a/~./ I ' · ' -' ' I ~/ · 4 ~ ", 'x x ~ , , = .. 600. ,7~e/ / :.c ', % 'x X ~ ~ ~00¢' / I ~ ~cc~ '~ -- I ,, ,,, ',, ,, ,, . ...- ., , '.. .. ~ : ~o ,-soo / I ~ ~' "'"" "'" '"' 11 '", ", ~ C : '~ i "-.. "-.. ", ", ", k ".. ', 60070¢ / '~0~ h-so , ; ".. '-. ".. -'.. 'x % ', ', 50o / / ~ ' i "'. '".. '".. "', ",kg°°", ',,¢ /~ lOOi ' eo ~~ '"'~, '% "'o ~o x~ % ",, ~o. ~ '"'-..... ""--... ""-,.._ '"'-,..._ , ~o 1 ~ ~ooo ~~~, ~. ',,, ~o, · ~ , 600 ..... ..?oo ~o !~ '"-.... '"-.., '",,,700 '"--... '"~ ~ ~ %~oo "-... "'-.. "... "-,? i I~ -.... '.... .... ....... 7oo ~oo [ ~ ~ 7oo _ __ ~ '% .... -. -.. ~ zo 1300 ~ 240 220 200 180 160 140 120 ~ O0 80 60 40 20 0 20 40 60 <- West (feeT) i o,0,,~ ~ ~,~ For: BROCKWAY PlOt ~eference ~e ~ 10-111/~2 V~. ~. Cad,,nates a~ ;n ~e~ ~fe~ence slot fl I I. Alaska, Inc. Structure : Pod 1'3 Field : Kuporuk River Unit Well : 11 1 Alaska Location : North Slope, <- West (feet} 800 760 720 680 640 600 560 520 480 440 400 560 320 280 24(] 200 ''~' ~e,' ' ' ' ' 'aL' ' ~. '~ '¢~x~ ' ' 880 4 X¢¢, NY4. .... %F-¢ '¢¢ 2300 ~ %. L~.¢ ,L ~C 840 -t '.. ", ~ ', ,..'X~ "' ~- 840 8o~ 4 ", ',, \' " ", \ 1- 800 / ,~oo',,, ,,,, ,, ~ ',, ,;oo ",, \ / 1 ',, ', ~ ,, ',,. I ", ". ~ " 1500 ~ % 760 "t "' \' ' 1 500 ~' '" '; ~, b 760 ~ ',,,,, ',,,,, ,,,, ~ ',,, / ',,., -,,, ',,,, \:,oo ',,, '"', ~Ol ,,,,, ',,,, ,,,,,~ ,,,, ',,, I ',, ',,46oo ,,,,\,,,~ ',,, .o~ '...,. ".... '.,,,, \ ',,,, ',,,, ~o-~ '",, "',, '\',,,, \ '"',, ~ }- ~o 1300 ".,~ "\.. '"~,\!400 '. ',, ",, "~ 1200 , ~o J ~ '"",, '"'\, \'" ~ '"' '""... ""... "",~. 1500 '""\'" '".., J- Z -..., \ ,,. o ~ --'-,.... '-...... ',,,.,.',,,\, ~,,~oo ",,,, · "\ \'. 1.300 k ' ~o 4 '-.. -.. "',,. ",,, '--- ~ ',. I " " x " ',," ~ ' " ~ '-.. '-.. 1~00 "'".' ", 440 "-.. "... "'... '\,,. ~ ,7r,O ",, ~ 440 ~oo --....,~oo---.... '-,,.,",,., , \ %~oo ".. '".. ' , '% 1400 i 2CO '~,, cO0 360 '-.. '-. ". '.. , ~ h ~60 F O0 '.... '-...!200 '"'"" "'. ,~,~n~ 32C '.. -.. -..., .~__ ~ % 280 ~ "'-.. 17a(J"... ".:".. '"% i IOC~ ~ "'- '". ". '%. 1300 2~0 ~ "-,.."-.,. "-,.',., i- ~o ~ 1400 '-. -. '. -. I 2r.0 ~oc ~ '--...,~o~...,oo;<'-.. ~ '-.. "-. '.. 1200 L, I 120 i ~ , ~ ~ ~ ~ ~ ~ ~ , ~ , ~ ~ ~ '~ 120 800 760 720 680 640 600 560 520 480 440 400 ~60 320 280 240 200 ! 60 <- West (feet) Alaska fne! For: BROCKWAY : ii-J~.-98 10-111/82 V~l. ~5. ~aoc d -.- ! 700 J Z i%, '-,. 21o0 ~50C .. ~.............. ; ~CC 2 '~ "-. i 2600 "... ~300 q 1200 i 110C i 1 1000 i 900 l 800 I Structure : Pad 10 Well: 111 j Field : Kuparuk River Unit Location : North Slope, Alaska, <- West (feet) 2100 2000 1900 1800 1700 1600 1500 14-00 I..300 1200 1100 1000 900 800 700 600 2600 ] 2700 '~ 2200 ..: ,,,, ', ',~ 3000 ', 2500 ",, " ",, "" · '~. 2400 ,, ~ 2900 2408 4 ,. %. 2600 '; 2800 ',, I ",,,,,,, ",,,,,,, ' ".,, 2100 2500 "% 2.300 '", ",. 2700 "'. ,, , I .. ',~ 2500 ', .. ,. 2600 ', 2200 -i "'.. , ! ,,, ~ 2000 -~ "',. 2200 ",, '"',, ' 2;00 ~ '"' " \ ".. 2400 '.. 2500 ",, 2000.4 '" ""' ' '~ 1900 2000 t ',. 2100 ", '"~ 2400 ", 1 go0 '"., "% 2300 ' '"'. \ ~ 900 200 ", '"" \ ~-1 aa ", '", 2006",, ',, 2.300 ". 4000 '". " ~ 5800 ",, F ',. '.% 2200 '"x 5700 ',, .. · ",~ 2200 X 5600 ',,, ~ ! 700 '"' "" · ~"X3500 ' F .~ 1900. "' '.,,.,,. ",.... '.,. ~ 3400 ', 60C ',~ 2100 "' ',.. '~ 2100 "" ,, '", ~ 3200 ~- · sec 18od'~ "". ',.. ", '",. ~ 3100 , - · ',.. 2000 '-.. 2000 '"..,. '"',~..2000 ' ;, 'X~O00 [ * 4CC "'""-,.]'"'"'",.. 9oo 2oc 2506".. '""- 170~%. '"., '""~ g00 '-~ 1 go0 ".. '.. "- '. % 2~00 """"'"'"'"'""" '""'"' "%""100 '"'""" ' ~00 270~X~ 200 24-0~)'"'. "'". '" " "-.. ".. 1800 160Oh,. ",, ".. '~'-' ", ',, ~ : CC '... 1800 J · --....3200 25 ... "-... .., 1700 I '"'-.. 5000 '" '" 1700 i 1000 -'"-.~ 29 O0 ".. '% "", "-..%2800 -... -... 500% '., aa '"" '"" ' ' '" b 220~''~'~ 7 ',, ' ", F "-..~00 ". '..i 600gOO .., .. 8O0 i ~ 2_~00 21C~b'%-. "'"-. 700i i 700 21 O0 2000 1 gO0 1800 1700 1600 1500 1400 1500 1200 11 O0 i 000 900 800 700 6C0 <- West (feet) ~,~ 24.00 i2600 ! ',, [ 2sca 4700 ~23001 4-600'! '~ [2~002300 4 oo ! .L 2200 ~ I ~ L ~.4oo ~, 2~Ge I Z 0 ! c..o,. ~ ~,~:~ For: BROCKWAY Oa~e i=latte~: I t-4un-§8 ='or Reference ;s ~ ~0-11 I/~2 Verl. Cc~,~otes a~e ,n feet ~fe~ence srot ~tll. :~r~e ve~,co~ 9eoms a~e ref~ence ~8 (Park~ [ ' RCO Alaska, Inc. Structure : Pad lO Well : 111 Field : Kuporuk River Unit Lo¢ofion : North Slope, <- West (feet) 3500 5200 3;00 3000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 ;900 ~800 ~ 700 I I I I I I ~ I i I 1 ! ! I I 1 I I I ! I I I I ' ' ' I ] ~ I 4300 ~ 4200 i 4!06 ,,, "~ 4200 1 4000 ' I 5300 ~ , ' '~ 4000 3soo ~ ',. 3900 [ · I ', ',~ 3800 38oo~ 3200 ~ , 't 5700 3700 " '"'~ 3600 3100 ~ "',, '~ 3500 3600 · , ', 3400 I 3500 q '", 3000 ~ "', "~ 3300 3~00 ~ ,, ' · - ",,,, ',~ 3200 ~ 2900 ", ', '~ 3! OO 3200 - 2800 '",, 310C 3CCC J 290O 2800 2700 2600 ! ", '~ 3000 · " ~4300 '", ', '~ 4200 2700 '%,,, '",,,, ~ 4100 · "%2900 ' 4000 "',, '~ 3900 ,, ', · ~ 3800 '", '" ~ 3700 ", '",, '~ i600 2600 ~ · ,, , · ~ 3500 ,,, ,~ 2800 ,. 3400 ,, · · , · ,~ 3200 2500 ~ ' " ',, ', ,,.3100 "', 2700 ', · ~200 4100 4000 3900 3800 3700 ~3600 L 3~oo I 0 - 3400 -+. r ~200 L ¼ - 3000 - 290O F 2800 2700 2600 :~cc ~. ",, ~ :~oo ~ ,, 2400 ~, , 5500 5200 3~00 5000 2900 2800 2700 2600 2500 2400 2500 2200 2100 2000 1900 ~800 ~700 <- Wesf (feel) "ARCO Alaska, Inc. Structure: Pod 1 ID Well : 1 11 Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA ..... Po~nt .....UO Inc O~ ~ ~ E~ V. S~ct D~,cJ/10C ~ ~ 0.~ 0.~ 0.~ 0.~ O K~ ~.~ o.~ 270,~5~,~ o~ o.~ o.~ o.~ Begin Turn [o Target 550.~ g.~ 270.~~4g.~ 0 ~ --11.7~8.~ B.~ ~ ~ ~'~ur~ 16~2.0164.~ ~24.51 t~25.~~1.25--5~.28550.¢7 6.~ ~ ~ H~d 510~.5764.~ 324.51 2gt6~ 2949.55 -~.33 3579.81 0.~ ~ al ~ap~um 6354.51~.~ 524.51 Tcmlt ~ tO-B2 R,~ 2 6521.19~.~ 524.51 580~.~5B~.~-2827. gS 4780.75 0.01 ~ of H~d ~895.25~.~ 524.51 4089.~402~.52 --29~.79 ~agg.~ 0.~ T.O. & E~d ~ Ho~ 7095.25~.~ 524.51 4242.21 4129.19 --~41.~5128.~ 0.~ 330 520 1700 310 .... 540 50 TRUE NORTH 0 10 C.~ot,~ ~ ~.~ For: BROCKWAY O~te plotted : Il--Jun--g8 Plot Refer=ncc is WS 10-111/B2 V~. ~5. Ca~dinat~ ore in ¢e~ reliance slot ~1 1 t. j T~e Ved~ca[ O~pths o~ r~nce R~B (Parker ~245). , 2O 9oo goo 50 ""41 O0 3oo 60 290 280 270 260 ;01501 05O0 3500 180 2 t i 70 8o co 100 250 1!0 240 120 230 130 22e" ~7oo ~" '210 200 190 180 Normci Plane Travelling Cylinder - Feet 11oo soo 50 ]~0 ]70 All depths shown are Measured depths on Reference A~CO Alaska, Inc. Pad 1D 111 slo= #111 Kuparuk River Unit North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T by Baker Hughes INTEQ Your ref : WS 1D-III/B2 VerB. #5 Our ref : prop2215 License : Date printed : ll-Jun-gs Date created = 17-Apr-9? Last revised : 11-Jun-98 Field is centred on n?0 16 18.576,w150 5 56.536 Structure is centred on n?0 18 1.316,w1A9 30 18.908 Slot location is n?0 18 1.601,w1A9 30 36.284 Slot Grid coorctinates are N 5959693.682, E 560490.72% Slot local coorchtnates are 29.00 N 596.00 W Projection type~ alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clear~nces less ~han 500 feet DECREASING CLEARANCES of less t~m, 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-5142'>,,115,Pad LD WS 1D-113/C1 VerB. #4,,ll3,Pad 1D WS 1D-125/H2 VerB. #5,,125,Pad 1D WS 1D-123/~1 VerB. #4,,123,Pad 1D WS 1D-13%/L5 VerB. #3,,134,Pad 1D WS 1D-132/K% VerB. #3,,132,Pad 1D wS 1D-131/L3 VerB. #3,,131,Pad 1D WS 1D-128/K2 VerB. #3,,128,Pad 1D PMSS <0 - ?340'>,,10,Pad 1D PMSS <0-5462'>,,129,Pad 1D PMSS <0-4414'>,,121,Pad 1D PMSS c0-4530'm,,120,Pad 1D PMSS ¢0-4515'),,119,Pad 1D PMSS <0-4590'm,,118,Pad 1D PMSS ¢0-5205'>,,117,Ped 1D PMSS <0-4850'),,109,Pad 1D PMSS <0-5126'm,,106,Pad LD PMSS c381-6092'),,105,Pad 1D PMSS <1957-5265'>,,133,Pad 1D PNSS <O-5015'>,,135,Pad 1D PMSS <0-%778'>,,130,Pad 1D PNSS <0-50%7'>,,124,Pad 1D WS 1D-112/A1 VerB. #4,,112,Pad 1D WS 1D-110/C3 VerB. #4,,110,Pad 1D WS 1D-108/A3 VerB. #%,,108,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-Jun-g8 65.6 701.4 ?01.A 2-Jun-98 44.7 633.3 633.3 5-Jun-98 315.0 650.0 650.0 9-Jun-98 240.0 200.0 200.0 2?-May-98 540.0 300.0 300.0 27-~ay-98 465.0 200.0 200.0 2?-May-98 450.0 200.0 200.0 1-Jun-98 360.0 580.0 580.0 28-Apr-98 585.0 100.0 100.0 2-Ju~-98 419.3 300.0 300.0 2-Jun-98 206.0 650.0 650.0 2-Jun-98 193.1 633.3 633.3 2-Jun-98 175.6 650.0 650.0 2-Jun-98 135.0 100.0 600.0 2-Ju~-98 105.0 600.2 600.2 2-Jum-98 30.0 100.0 100.0 2-Jun-98 75.0 100.0 100.0 2-Ju~-98 104.5 300.0 300.0 2-Jun-98 477.3 300.0 300.0 2-Jun-98 554.4 633.3 633.3 2-Juno98 434.9 400.0 400.0 2-Ju.n-98 292.9 650.0 650.0 2-Jun-98 43.1 500.0 500.0 2-Jun-98 15.0 200.0 2600.0 2-Jun-98 45.0 200.0 200.0 WS 1D-101/C5 VerB. #3,;w~l,P&d 1D WS 1D-104/A? VerB. #3,,104,P&d 1D WS 1D-103/B6 VerB. #3,,103,P&d 1D WS 1D-102/A5 VerB. #3,,102,P&d LD ws 1D-107/B4 VerB. #1,,10?,Pad 1D WS 1D-151/Gll VerB. 91,,151,P&d 1D WS 1D-138/K6 VerB. #1,,138,P&d 1D WS 1D-161/L? VerB. #1,,161,Pad 1D WS 1D-160/K8 VerB. #1,,160,P&d 1D WS 1Do159/L9 VerB. #1,,159,P&d 1D WS 1Do15?/K10 VerB. 91,,157,P&d LD W$ 1D-156/J9 VerB. #1,,156,Pad 1D W$ 1D-155/H8 VerB. #1,,155,P&d LD W$ 1D-154/J11 VerB. 91,,154,P&d 1D w$ 1D-153/H10 verB. #1,,153,P&d 1D W$ 1D-150/F10 VeTs. #1,,150,P&d 1D WS 1D-152/G9 VerB. #1,,152,P&d 1D WS 1D-149/F8 VerB. #1,,149,P&d LD WS 1D-148/E11 VerB. #1,,148,Pad 1D WS 1D-147/E9 VerB. #1,,147,P&d 1D WS 1D-146/D10 VerB. #1,,146,Pad LD W$ 1D-145/Cll VerB. #1,,1%5,Pad LD W$ 1D-14%/D8 VerB. 91,,144,P&d LD W$ 1D-143/C9 VerB. 91,,143,P&d 1D W$ 1D-139/B8 VerB. #1,,139,P&d ~ W$ 1D-140/A9 VerB. 91,,140,P&d LD W$ 1D-142/S10 VerB. 91,,142,P&d 1D WS ID-141/&11 VerB. #1,,141,Pad 1D WS 1D-158/h11 VerB. #1,,158,Pad 1D WS 1D-136/J7 VerB. 91,,136,P&d 1D TOTCO Burvey,,WB-8,P&d LD LD-B Version #3,,LD-B,Pad 1D 1D-F Version #2,,LD-F,P&d LD 1D-D Version #2,,1D-D,P&d LD P~ c0-8365 ),,1,P&d LD P~S ¢0-9?83 ),,2,Pad LD P(~S ¢0-80?0 ),,3,P&d LD P~NS ¢0-7502 ),,4,Pad 1D P~MS ¢0-8930 >,,5',P&d LD MSS ¢3311-8200'>,,7,Pad LD PMSS <556-7024'>,,9,Pad LD W$ 1D-126/J1 VerB. #5,,126,Pad LD WS LD-122/F2 VerB. #4,,122,P&d 1D WS 1D-127/L1 VerB. #3,,127,Pad LD WS 1D-114/D2 VerB. #5,,11%,Pad LD WS 1D-116/E1 VerB. 94,,116,Pad LD 163.1 118.1 133.1 1%8.1 58.2 522.2 602.0 665.4 651.0 636.5 607.7 S93.4 579.1 564.8 550.6 508.1 536.% 494.0 480.0 466.1 451.8 436.1 424.7 407.9 333.0 358.1 389.5 374.5 622,1 572.0 632.0 407.0 495.5 377.0 177.0 88.0 31.6 152.1 271.5 392.2 512.0 159.8 330.0 222.7 345.0 75.0 96.3 200.0 200.0 200.0 300.0 300.0 300.0 300.0 300.0 200.0 300.0 300.0 400.0 300.0 300.0 300.0 400.0 500.0 300.0 500.0 520.0 540.0 SO0.O 600.2 633.3 650.0 600.0 580.0 200.0 580.0 616.7 600.0 650.0 600.0 1080.0 400.0 580.0 100.0 633.3 100.0 400.0 666.7 300.0 666.7 200.0 540.0 720.0 200.0 200.0 200.0 200.0 300.0 300.0 300.0 6340.0 300.0 200.0 300.0 300.0 400.0 300.0 300.0 300.0 400.0 500.0 300.0 500.0 520.0 540.0 500.0 600.2 633.3 650.0 600.0 580.0 200.0 4141.6 616.? 600.0 650.0 600.0 1080.0 400.0 580.0 100.0 633.3 633.3 400.0 666.7 300.0 666.7 200.0 540.0 720.0 z0" DIVERTER SCHErv,,4TIC Kuparuk River Unit West Sak 'Operations 5 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 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 welibore fluids or gas is detected. Open valve to achieve diversion ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16' Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16' 2000 psi Ball Valve 4. 20' - 2000 psi Drilling Spool With One 16" Outlet 5. One 16' HCR Knife Valve With 16' Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line Will Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20' - 2000 psi Annular Preventer TAB, 06/12/98, v.2 · · .3-5/8" 5000 psi BOF .ack Kuparuk River Unit West Sak Operations -Injector Wells I 7 4 3 2 ! Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed wi~ 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. I~11 BOP stack and manifold with water. 2. Check that all hold-down screws are fully retracted. Predetermine deptYl that test plug will seat and seat in wellhead. Run in lock-down screws in head. 3. Close annu .lar 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 end manual kill and choke line vanes. 6. Close to13 pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi es in step 4. ConUnue testing all vanes, lines, and chokes with a 250 psi low 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 anti 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 vanes are set in the ddlling position. 11. Test standpipe vanes to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Reco~ 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. 16' Starting Head 2. 7-1/16' 5000 psi Tubing Head 3. 7-1/16' x 13-5/8' 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8' 5000 psi x 13-5/8' 5000 psi Spacer Spool 5. 13-5/8' 5000 psi Pipe Rams 6. 13-5/8' 5000 psi Drilling Spool w~l'l Choke and Kill Lines 7. 13-5/8' 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on i~ottom 8. 13-5/8' 5000 psi Annular Preventer ** VBRS will accomodate 3-1/2" to 6' or 4-1/2" to 7' pipe OD's as appropriate TAB, 06/15/98, v.2 0£SCRIP'rlON 1-0 O ! 2 · 111 1114 · 11,I 122 12~ 125 124 125126 127 128 14.' 15 2.1 24 THIS SURVEY 22 VICINITY MAP SCALE: I'- lldlLg N LEGEND 0 EXT$~TNG CONDUCTORS · 'AS-BUlL 7" CONDUCTOR LOCA 170N ARCO Alaska, Inc. CAOD FILE NO. DRAWING NO:. LK610401§ SEE SHEET ~ 2 FOR NOTES ANO LOCATION INFORMATION .~ LOUNSBURY & ~OCIATES. INC. ~- 10 U~ ~ DRI~ ~ 1-0 ~ST SAK PH~E lB - ~ CONDUCTORS AS-BUILT LOCA~ONS CEA-D 1D X-610~15 ~EEm:~? ~ ~R ,[SBF K98017,4¢$ IPTI(~I I. COORDINAI~$ SHOI~4V ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES 57-1OWN ARE TRUE. ~.. 8A515 OF'L~TION$ AiV'D'ELEVAFIONS ARE D.S. I-0 " ' MONUMENTS PER LHD AND ASSOCIAIES. ~. CONDUCTORS ARE LOCATED FRII-IIN PROTRACTEO SECTION 2..[ 1'OWIVSHIP II NORI"H, RANGE I0 EAST. U.M. 4. OAI"E$ OF' SURVEY." 6/9/98, FIELD BK. L98-45, PGE. 21-25; ANO 6/12/98, RELD BK. L98-45, PGE. 47-4& 5. ORILL SITE' I-0 C.~ID NORTH IS ROTA TED 00" Ol° 0.5' ViE'Et FROM A.E.P. ZONE 4 GRIO NORTH. 6. EE~ DRAWING N5~-3.$~.1 FOt? AS-BUILT LOCA170NS OF COIVOUCTORS I-8' ~-0IOX-6104010 FOR CONOUCTORS I05, I06, I0.9.1 I5, I 17-121,124.129, I.,TO, I J3 & I-)5; ANO CEA-OIOX-6104013 FOR CONOUCTORS 9 ~ I(1 LS. IB THIS SURVEY VICINITY MAP 'SCALE: I' = t M~LE 11 .%959. J6.%92 ~959,.~34. ~4 .%959.229.23 x 560. 490.59 560. 49(168 560. 49(167 550, 49(1 58 550. 49(1 74 5EO, 490. 64 550. 490. 8.) Sec. 23, Lot. 70' 17' 5&509 70' 17' 70' 17' 5&210' 70* !7' 5&065 70' 17" 57.17~' 70* 17' 5ZO..~ 70* 17' 5~.291' 149' -)0' I49' .TO' I49' -)0' J~372' I49' -)0' 149' .TO' 3~.J95' 149' -)0' .l~ 40~' SURVEYOR'S CERTIFICA TIE I HEREBY CERTIFY TH, ar I ~4M PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURV~YIN6 IN THE STATE OF' ,~L~SK4 ANO r~r THIS PLAT REPRESENTS A SURLY DONE 8Y ~ OR UNDER MY DIRECT S~ERVISiON ~ T~r ALL DI~NSIONS 4ND OTHER DETaiLS ~RE CORRECT ~$ OF JU~ 13. 1998. ARCO Alaska, Inc. LK6104015 6/15/98 LOUNSBURY ASSOCIATES. INC. AREA' lO U00U~' XX DRILL SITE 1-0 WEST SAK PHASE lB - WELL CONDUCTORS AS-BUILT LOCATIONS CEA-O1DX-610401 5 m' = UNIf- Ol we t Sak 1D-111 (B2) Injector Completion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' TAM International 5-1/2" Port Collar Stnd. Grade BTC Threads set +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 6235' MD / 3586' 'I-VD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 6235' MD / 3586' -I-VD) to (+/- 7093' MD / 4242' TVD) G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1' Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2' Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. I jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Eiaker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands HH, 8/10/98, v.1 1D-114 Cement Volumes Surface Hole Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time PPg ff3/sx gal/sx hours Class Additive 1 Additive 2 Additive 3 Additive 4 Density Yield Water Requirement Thickening Time PPg ft3/sx gal/sx hours % % % % % % bbls sacks 111 525 bbls sacks ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor August 10, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-111 West Sak Phase lB Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designated as a monobore injection well using a 5 Y2" x 3 Y2" tapered casing string, with 3- 1/2" tubing used as a tieback string. 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 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 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). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-111, such as shallow gas. There have been ten (10) Kuparuk wells and twenty (20) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfielclCompany 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) 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 monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) 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. Please note that the anticipated spud date for this well is August 28, 1998. If you have any questions or require further information, please contact Scott Goldberg at (907) 263-4622 or Tom McKay at (907) 265-6890. Operations Drilling Engineer CC: West Sak 1 D-111 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Cliff Crabtree NSK6 Drill, Case and Completion Plan for West Sak 1D-111 (B2) Monobore Iniector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displace cement with non freezing completion brine, bump the plug and pressure test casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results of pressure test NOTE: TAM Port Collar will be placed in the 5 Y2" casing +_1000' TVD below the surface. Port collar will only be opened and used if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is close to the surface, a top job may be performed in lieu of utilizing the port collar. 6. Nipple down diverter, nipple up tubing head and BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Before stinging into seal bore, freeze protect well with enough diesel to cover Permafrost. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 8. Nipple down BOP's. Install production tree and pressure test same. 9. Secure well, release rig. 10. If necessary, 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. 11. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 12. Rig up E-line unit and RIH with through-tubing perforating guns. 13. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 1D-111 (B2) Page 1 HH, 08/06/98, v.1 14. Install back pressure valve, shut in and secure well. 1D-111 (B2) Page 2 HH, 08/06/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-111 (B2) Drilling Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. 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' TVD. This will be used as a contingency if cement is not brought to surface as planned. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-111 (B2) 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 safely be drilled using a diverter system only for well control purposes. 1D-111 (B2) Page I HH,08/10/98,v. 1 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 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7' ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,661TVD. 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 = (4089 ft) (0.46- 0.11) psi/ft = 1432 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 casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi. The 5-1/2" 15.5# LB0 BTC casing to be used has a burst rating of 7,000 psi; 7'0 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drilling Area Risks: Drilling risks in the West Sak 1D-111 (B2) 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, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. Well Proximity Risks: The nearest existing well to West Sak 1D-111 (B2) is WS 1 D-109. As designed, the minimum distance between the two wells would be 30' at 100' MD. Annular Pumpin.q 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 1D-111 (B2) 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-111 (B2) Page 2 HH,08/10/98,v.1 35O 350 C~otea W ~h For: BROCKWAY Oote p~otted : II-Jun-Off Plot Reference is W~ 10-111/82 Vets. ~5. Coord;notes ore in feet reference slot ~11 I. Vert~ol Depths are ref~ence ~B (Parker 1050 1400 1750 2100 2450 4200 Ii 2800 I 3150 3~3.56 AZIMUTH 4761' (TO TARGET) ***Plane of Proposal*** 3850 4200 ELEVATION: 112' FARCO A1 aska, Inc, Structure : Pad 1 D Well : 111 IField : Kuporuk River Unff Locofion : North Slope, AlaskoI RKB <- West (feet) 3150 2800 2450 2100 1750 1400 1050 700 350 0 550 I I I I I I I I I I I I I I I I II I I I TD LOCATION: TD - Casing Pt 1122' FNL, 164-,_3' FWL Base West Sok Sonds SEC. 14, T11N, RIOE TARGET - West Sak A3 West Sok Sonds / EOD Top Ugnu Sands Begin Angle Drop TARGET LOCATION: 1421' FNL, 1856' FWL SEC, 1¢, T11N, RIOE TARGET YVD=3804 TMD=6521 0EP=4761 NORTH 3830 WEST 2828 3850 -3500 5150 2800 2450 2i O0 1750 ½KOP TVD=500 TMD=500 DEP=0 ~6'0C7 BEGIN 700 ~10.8 TURN TO TARGET WD=649 TMD=650 DEP=7 1400 32 5'69 1.11 DLS: 6.00 deg per 100 ft 6.77 85.539 !050 %'2566.08 Bose Permafrost ~..~.~= 1 424 TMD= 1 642 DEP=550 k . PERMAFROST TVD=1657 TMD=2184 DEP=1039 X, EOC MAXIMUM ANGLE ~ kk 64.5 DEG ~ ~ Begin Turn to Torget ~ ~ [ SURFACE LOCATION: ~ 129' FSL, 596' FeE 9 69 69 BLS: 2.00 dee per 100 ft .69 5500 2.69 P 4 40.69 TARGET - A3 TVD=3804 TMD=6521 DEP=4761X~ x T '% I) - CSG PT TVI)=4242 TMD=7093 DEP=5128~ 700 350 0 350 TARGET ANGLE 40 DEG 4550 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t I I 350 0 550 700 1050 1400 1750 21 O0 2450 2800 3150 3500 3850 4200 4550 4900 5250 VerticalSection (feet)-> Azimuth 323.56 with reference 0.00 N, 0.00 E from slot #111 Z 0 ARCO Alaska, Inc. Pad 1D 111 slot #111 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : WS 1D-iii/B2 Vets. #5 Our ref : prop2215 License : Date printed : 11-Jun-98 Date created : 17-Apr-97 Last revised : 11-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n?0 18 1.601,w149 30 36.284 Slot Grid coordinates are N 5959693.682, E 560490.724 Slot local coordinates are 29.00 N 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 270.00 100.00 0.00 N 0.00 E 200.00 0.00 270.00 200.00 0.00 N 0.00 E 300.00 0.00 270.00 300.00 0.00 N 0.00 E 400.00 0.00 270.00 400.00 0.00 N 0.00 E 500.00 0.00 270.00 500.00 0.00 N 0.00 E 600.00 6.00 270.00 599.82 0.00 S 5.23 W 650.00 9.00 270.00 649.38 0.00 S 11.76 W 700.00 10.87 283.69 698.64 1.12 N 20.25 W 800.00 15.69 299.56 795.97 10.03 N 41.19 W 900.00 21.11 307.79 890.84 27.75 N 67.21 W 1000.00 26.77 312.72 982.20 54.08 N 98.02 W 1100.00 32.55 316.02 1069.07 88.75 N 133.28 W 1200.00 38.39 318.41 1150.48 131.37 N 172.60 W 1300.00 44.26 320.25 1225.55 181.47 N 215.57 W 1400.00 50.16 321.74 1293.45 238.50 N 261.69 W 1500.00 56.08 323.00 1353.44 301.84 N 310.48 W 1600.00 62.00 324.09 1404.86 370.79 N 361.39 W 1642.01 64.50 324.51 1423.77 401.25 N 383.28 W 2000.00 64.50 324.51 1577.90 664.33 N 570.87 W 2183.71 64.50 324.51 1657.00 799.33 N 667.13 W 2500.00 64.50 324.51 1793.18 1031.77 N 832.87 W 3000.00 64.50 324.51 2008.46 1399.21 N 1094.87 W 3500.00 64.50 324.51 2223.74 1766.65 N 1356.86 W 4000.00 64.50 324.51 2439.02 2134.09 N 1618.86 W 4500.00 64.50 324.51 2654.30 2501.53 N 1880.86 W 5000.00 64.50 324.51 2869.58 2868.97 N 2142.86 W 5109.67 64.50 324.51 2916.80 2949.56 N 2200.33 W 5200.00 62.69 324.51 2956.97 3015.43 N 2247.30 W 5300.00 60.69 324.51 3004.39 3087.11 N 2298.41 W 5396.42 58.76 324.51 3053.00 3154.91 N 2346.75 W 5400.00 58.69 324.51 3054.86 3157.40 N 2348.52 W 5500.00 56.69 324.51 3108.31 3226.21 N 2397.59 W 5600.00 54.69 324.51 3164.67 3293.46 N 2445.54 W 5700.00 52.69 324.51 3223.88 3359.07 N 2492.32 W 5800.00 50.69 324.51 3285.87 3422.96 N 2537.87 W 5900.00 48.69 324.51 3350.56 3485.04 N 2582.14 W 6000.00 46.69 324.51 3417.87 3545.25 N 2625.07 W 6100.00 44.69 324.51 3487.72 3603.51 N 2666.61 W 6200.00 42.69 324.51 3560.02 3659.75 N 2706.71 W PROPOSAL LISTING Page 1 Your ref = WS 1D-iii/B2 Vets. #5 Last revised : 11-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 6.00 6.00 6.00 0.00 KOP 3.11 6.98 Begin Turn to Target 12.93 32.53 6.00 62.24 6.00 101.73 6.00 150.56 6.00 208.21 6.00 274.03 6.00 347.31 6.00 427.25 6.00 512.96 6.00 550.47 EOC 0.00 873.53 0.00 1039.31 Base Permafrost 0.00 1324.75 0.00 1775.97 0.00 2227.19 0.00 2678.41 0.00 3129.62 0.00 3580.84 0.00 3679.81 Begin Angle Drop 2.00 3760.70 2.00 3848.73 2.00 3931.98 Top Ugnu Sands 2.00 3935.04 2.00 4019.54 2.00 4102.13 2.00 4182.70 2.00 4261.15 2.00 4337.39 2.00 4411.33 2.00 4482.87 2.00 4551.93 6300.00 40.69 324.51 3634.70 3713.91 N 2745.33 W 2.00 6334.51 40.00 324.51 3661.00 3732.10 N 2758.30 W 2.00 6500.00 40.00 324.51 3787.77 3818.71 N 2820.05 W 0.00 6521.17 40.00 324.51 3803.99 3829.79 N 2827.95 W 0.00 6521.19 40.00 324.51 3804.00 3829.80 N 2827.96 W 0.01 4618.43 4640.77 Top West Sak Sands / EOD 4747.13 4760.74 TARGET - West Sak A3 4760.75 WS 1D-B2 Rvsd 22-Jan-98 6893.23 40.00 324.51 4089.00 4024.52 N 2966.79 W 0.00 4999.86 Base West Sak Sands 7000.00 40.00 324.51 4170.79 4080.40 N 3006.64 W 0.00 5068.48 7093.23 40.00 324.51 4242.21 4129.19 N 3041.43 W 0.00 5128.40 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-iIi/B2 Vers. #5 Last revised : 11-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0.00 N 0.00 E KOP 650.00 649.38 1642.01 1423.77 2183.71 1657.00 5109.67 2916.80 5396.42 3053.00 6334.51 3661.00 6521.17 3803.99 6521.19 3804.00 6893.23 4089.00 7093.23 4242.21 0 00 S 401 25 N 799 33 N 2949 56 N 3154 91 N 3732 10 N 3829 79 N 3829 80 N 4024.52 N 4129.19 N 11.76 W Begin Turn to Target 383.28 W E0C 667.13 W Base Permafrost 2200.33 W Begin Angle Drop 2346.75 W Top Ugnu Sands 2758.30 W Top West Sak Sands / E0D 2827.95 W TARGET - West Sak A3 2827.96 W WS 1D-B2 Rvsd 22-Jan-98 2966.79 W Base West Sak Sands 3041.43 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3829.80N 2827.96W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N ~ U L A R Depth Degrees Degrees Depth C O O R D I N A T E S PROPOSAL LIgTING Page 1 Your ref : WS 1D-IIi/B2 Vets. #5 Last revised : 11-Jun-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 29.00 N 596.00 W 0.00 0.00 100.00 0.00 270.00 100.00 29.00 N 596.00 W 0.00 0.00 200.00 0.00 270.00 200.00 29.00 N 596.00 W 0.00 0.00 300.00 0.00 270.00 300.00 29.00 N 596.00 W 0.00 0.00 400.00 0.00 270.00 400.00 29.00 N 596.00 W 0.00 0.00 500.00 0.00 270.00 500.00 29.00 N 596.00 W 0.00 0.00 600.00 6.00 270.00 599.82 29.00 N 601.23 W 6.00 3.11 650.00 9.00 270.00 649.38 29.00 N 607.76 W 6.00 6.98 700.00 10.87 283.69 698.64 30.12 N 616.25 W 6.00 12.93 800.00 15.69 299.56 795.97 39.03 N 637.19 W 6.00 32.53 900.00 21.11 307.79 890.84 56.75 N 663.21 W 6.00 62.24 1000.00 26.77 312.72 982.20 83.08 N 694.02 W 6.00 101.73 1100.00 32.55 316.02 1069.07 117.75 N 729.28 W 6.00 150.56 1200.00 38.39 318.41 1150.48 160.37 N 768.60 W 6.00 208.21 1300.00 44.26 320.25 1225.55 210.47 N 811.57 W 6.00 274.03 1400.00 50.16 321.74 1293.45 267.50 N 857.69 W 6.00 347.31 1500.00 56.08 323.00 1353.44 330.84 N 906.48 W 6.00 427.25 1600.00 62.00 324.09 1404.86 399.79 N 957.39 W 6.00 512.96 1642.01 64.50 324.51 1423.77 430.25 N 979.28 W 6.00 550.47 2000.00 64.50 324.51 1577.90 693.33 N 1166.87 W 0.00 873.53 2183.71 64.50 324.51 1657.00 828.33 N 1263.13 W 0.00 1039.31 2500.00 64.50 324.51 1793.18 1060.77 N 1428.87 W 0.00 1324.75 3000.00 64.50 324.51 2008.46 1428.21 N 1690.87 W 0.00 1775.97 3500.00 64.50 324.51 2223.74 1795.65 N 1952.86 W 0.00 2227.19 4000.00 64.50 324.51 2439.02 2163.09 N 2214.86 W 0.00 2678.41 4500.00 64.50 324.51 2654.30 2530.53 N 2476.86 W 0.00 3129.62 5000.00 64.50 324.51 2869.58 2897.97 N 2738.86 W 0.00 3580.84 5109.67 64.50 324.51 2916.80 2978.56 N 2796.33 W 0.00 3679.81 5200.00 62.69 324.51 2956.97 3044.43 N 2843.30 W 2.00 3760.70 5300.00 60.69 324.51 3004.39 3116.11 N 2894.41 W 2.00 3848.73 5396.42 58.76 324.51 3053.00 3183.91 N 2942.75 W 2.00 3931.98 5400.00 58.69 324.51 3054.86 3186.40 N 2944.52 W 2.00 3935.04 5500.00 56.69 324.51 3108.31 3255.21 N 2993.59 W 2.00 4019.54 5600.00 54.69 324.51 3164.67 3322.46 N 3041.54 W 2.00 4102.13 5700.00 52.69 324.51 3223.88 3388.07 N 3088.32 W 2.00 4182.70 5800.00 50.69 324.51 3285.87 3451.96 N 3133.87 W 2.00 4261.15 5900.00 48.69 324.51 3350.56 3514.04 N 3178.14 W 2.00 4337.39 6000.00 46.69 324.51 3417.87 3574.25 N 3221.07 W 2.00 4411.33 6100.00 44.69 324.51 3487.72 3632.51 N 3262.61 W 2.00 4482.87 6200.00 42.69 324.51 3560.02 3688.75 N 3302.71 W 2.00 4551.93 6300.00 40.69 324.51 3634.70 3742.91 N 3341.33 W 2.00 4618.43 6334.51 40.00 324.51 3661.00 3761.10 N 3354.30 W 2.00 4640.77 6500.00 40.00 324.51 3787.77 3847.71 N 3416.05 W 0.00 4747.13 6521.17 40.00 324.51 3803.99 3858.79 N 3423.95 W 0.00 4760.74 6521.19 40.00 324.51 3804.00 3858.80 N 3423.96 W 0.01 4760.75 KOP Begin Turn to Target EOC Base Permafrost Begin Angle Drop Top Ugnu Sands Top West Sak S~nds / EOD TARGET - West Sak A3 WS 1D-B2 Rvsd 22-Jan-98 6893.23 40.00 324.51 4089.00 4053.52 N 3562.79 W 0.00 4999.86 Base West Sak Sands 7000.00 40.00 324.51 4170.79 4109.40 N 3602.64 W 0.00 5068.48 7093.23 40.00 324.51 4242.21 4158.19 N 3637.43 W 0.00 5128.40 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 14, T11N, R10E and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-iii/B2 Vets. #5 Last revised : 11-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 29.00 N 650.00 649.38 29.00 N 1642.01 1423.77 430.25 N 2183.71 1657.00 828.33 N 5109.67 2916.80 2978.56 N 5396.42 3053.00 3183.91 N 6334.51 3661.00 3761.10 N 6521.17 3803.99 3858.79 N 6521.19 3804.00 3858.80 N 6893.23 4089.00 4053.52 N 7093.23 4242.21 4158.19 N 596.00 W KOP 607.76 W Begin Turn to Target 979.28 W EOC 1263.13 W Base Permafrost 2796.33 W Begin Angle Drop 2942.75 W Top Ugnu Sands 3354.30 W Top West Sak Sands / EOD 3423.95 W TARGET - West Sak A3 3423.96 W WS 1D-B2 Rvsd 22-Jan-98 3562.79 W Base West Sak Sands 3637.43 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 29.00N 596.00W 7093.23 4242.21 4158.19N 3637.43W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3858.80N 3423.96W 9-Oct-96 ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth PROPOSAL LISTING Page 1 Your ref : WS 1D-iII/B2 Vets. $5 Last revised : 11-Jun-98 R E C T A N G U L A R Vert Ellipse Semi Axes Minor C 00 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 270.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 270.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 270.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 0.00 270.00 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 0.00 270.00 500.00 0.00 N 0.00 E 0.00 1.31 1.31 0.75 N/A 600.00 6.00 270.00 599.82 0.00 S 5.23 W 3.11 1.61 1.57 0.90 270.00 650.00 9.00 270.00 649.38 0.00 S 11.76 W 6.98 1.82 1.71 0.98 270.00 700.00 10.87 283.69 698.64 1.12 N 20.25 W 12.93 2.09 1.85 1.05 274.80 800.00 15.69 299.56 795.97 10.03 N 41.19 W 32.53 2.93 2.16 1.22 287.68 900.00 21.11 307.79 890.84 27.75 N 67.21 W 62.24 4.25 2.51 1.40 296.37 1000.00 26.77 312.72 982.20 54.08 N 98.02 W 101.73 6.09 2.91 1.61 302.43 1100.00 32.55 316.02 1069.07 88.75 N 133.28 W 150.56 8.50 3.36 1.89 306.82 1200.00 38.39 318.41 1150.48 131.37 N 172.60 W 208.21 11.47 3.84 2.26 310.13 1300.00 44.26 320.25 1225.55 181.47 N 215.57 W 274.03 15.00 4.36 2.72 312.69 1400.00 50.16 321.74 1293.45 238.50 N 261.69 W 347.31 19.05 4.87 3.30 314.74 1500.00 56.08 323.00 1353.44 301.84 N 310.48 W 427.25 23.59 5.37 4.00 316.41 1600.00 62.00 324.09 1404.86 370.79 N 361.39 W 512.96 28.54 5.84 4.80 317.80 1642.01 64.50 324.51 1423.77 401.25 N 383.28 W 550.47 30.69 6.02 5.15 318.29 2000.00 64.50 324.51 1577.90 664.33 N 570.87 W 873.53 49.12 7.61 8.26 320.68 2183.71 64.50 324.51 1657.00 799.33 N 667.13 W 1039.31 58.63 8.42 9.88 321.17 2500.00 64.50 324.51 1793.18 1031.77 N 832.87 W 1324.75 75.01 9.81 12.66 322.02 3000.00 64.50 324.51 2008.46 1399.21 N 1094.87 W 1775.97 100.96 12.02 17.08 322.67 3500.00 64.50 324.51 2223.74 1766.65 N 1356.86 W 2227.19 126.92 14.23 21.50 323.05 4000.00 64.50 324.51 2439.02 2134.09 N 1618.86 W 2678.41 152.89 16.45 25.93 323.30 4500.00 64.50 324.51 2654.30 2501.53 N 1880.86 W 3129.62 178.87 18.66 30.36 323.47 5000.00 64.50 324.51 2869.58 2868.97 N 2142.86 W 3580.84 204.86 20.87 34.79 323.61 5109.67 64.50 324.51 2916.80 2949.56 N 2200.33 W 3679.81 210.55 21.36 35.77 323.63 5200.00 62.69 324.51 2956.97 3015.43 N 2247.30 W 3760.70 215.13 21.77 36.54 323.65 5300.00 60.69 324.51 3004.39 3087.11 N 2298.41 W 3848.73 220.05 22.25 37.38 323.67 5396.42 58.76 324.51 3053.00 3154.91 N 2346.75 W 3931.98 224.63 22.73 38.15 323.69 5400.00 58.69 324.51 3054.86 3157.40 N 2348.52 W 3935.04 224.80 22.75 38.18 323.69 5500.00 56.69 324.51 3108.31 3226.21 N 2397.59 W 4019.54 229.39 23.26 38.94 323.70 5600.00 54.69 324.51 3164.67 3293.46 N 2445.54 W 4102.13 233.81 23.78 39.68 323.72 5700.00 52.69 324.51 3223.88 3359.07 N 2492.32 W 4182.70 238.06 24.32 40.38 323.73 5800.00 50.69 324.51 3285.87 3422.96 N 2537.87 W 4261.15 242.12 24.86 41.05 323.75 5900.00 48.69 324.51 3350.56 3485.04 N 2582.14 W 4337.39 246.00 25.42 41.68 323.76 6000.00 46.69 324.51 3417.87 3545.25 N 2625.07 W 4411.33 249.68 25.97 42.27 323.77 6100.00 44.69 324.51 3487.72 3603.51 N 2666.61 W 4482.87 253.18 26.53 42.83 323.78 6200.00 42.69 324.51 3560.02 3659.75 N 2706.71 W 4551.93 256.49 27.09 43.36 323.79 6300.00 40.69 324.51 3634.70 3713.91 N 2745.33 W 4618.43 259.60 27.65 43.85 323.80 6334.51 40.00 324.51 3661.00 3732.10 N 2758.30 W 4640.77 260.65 27.84 44.01 323.80 6500.00 40.00 324.51 3787.77 3818.71 N 2820.05 W 4747.13 265.70 28.77 44.80 323.81 6521.17 40.00 324.51 3803.99 3829.79 N 2827.95 W 4760.74 266.34 28.89 44.90 323.81 6521.19 40.00 324.51 3804.00 3829.80 N 2827.96 W 4760.75 266.34 28.89 44.90 323.81 6893.23 40.00 324.51 4089.00 4024.52 N 2966.79 W 4999.86 277.69 30.97 46.68 323.84 7000.00 40.00 324.51 4170.79 4080.40 N 3006.64 W 5068.48 280.95 31.57 47.19 323.85 7093.23 40.00 324.51 4242.21 4129.19 N 3041.43 W 5128.40 283.79 32.09 47.63 323.85 All data is in feet unless otherwise stated. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Vertical section is from wellhead on azimuth 323.56 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-iIi/B2 Vets. #5 Last revised ~ 11-Jun-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 7093 ARCO (H.A. Mag) User specified 283.79 32.09 47.63 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0.00 N 0.00 E KOP 650.00 649.38 0.00 S 11.76 W Begin Turn to Target 1642.01 1423.77 401.25 N 383.28 W EOC 2183.71 1657.00 799.33 N 667.13 W Base Permafrost 5109.67 2916.80 2949.56 N 2200.33 W Begin Angle Drop 5396.42 3053.00 3154.91 N 2346.75 W Top U~nu Sands 6334.51 3661.00 3732.10 N 2758.30 W Top West Sak Sands / EOD 6521.17 3803.99 3829.79 N 2827.95 W TARGET - West Sak A3 6521.19 3804.00 3829.80 N 2827.96 W WS 1D-B2 Rvsd 22-Jan-98 6893.23 4089.00 4024.52 N 2966.79 W Base West Sak Sands 7093.23 4242.21 4129.19 N 3041.43 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this wellpath ================================= .... Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3829.80N 2827.96W 9-0ct-96 ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : WS 1D-Iii/B2 Vets. #5 Last revised : 11-Jun-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 0.00 0.00 0.00 0.00 0.00N 100.00 0.00 270.00 100.00 0.00N 200.00 0.00 270.00 200.00 0.00N 300.00 0.00 270.00 300.00 0.00N 400.00 0.00 270.00 400.00 0.00N 0.00E 0.00 0.00 560490.72 5959693.68 0.00E 0.00 0.00 560490.72 5959693.68 0.00E 0.00 0.00 560490.72 5959693.68 0.00E 0.00 0.00 560490.72 5959693.68 0.00E 0.00 0.00 560490.72 5959693.68 500.00 0.00 270.00 500.00 0.00N 600.00 6.00 270.00 599.82 0.00S 650.00 9.00 270.00 649.38 0.00S 700.00 10.87 283.69 698.64 1.12N 800.00 15.69 299.56 795.97 10.03N 0.00E 0.00 0.00 560490.72 5959693.68 5.23W 6.00 3.11 560485.49 5959693.64 11.76W 6.00 6.98 560478.97 5959693.59 20.25W 6.00 12.93 560470.47 5959694.63 41.19W 6.00 32.53 560449.46 5959703.37 900.00 21.11 307.79 890.84 1000.00 26.77 312.72 982.20 1100.00 32.55 316.02 1069.07 1200.00 38.39 318.41 1150.48 1300.00 44.26 320.25 1225.55 27.75N 54.08N 88.75N 131.37N 181.47N 67.21W 6.00 62.24 560423.30 5959720.88 98.02W 6.00 101.73 560392.28 5959746.96 133.28W 6.00 150.56 560356.74 5959781.34 172.60W 6.00 208.21 560317.08 5959823.63 215.57W 6.00 274.03 560273.71 5959873.37 1400.00 50.16 321.74 1293.45 1500.00 56.08 323.00 1353.44 1600.00 62.00 324.09 1404.86 1642.01 64.50 324.51 1423.77 2000.00 64.50 324.51 1577.90 238.50N 301.84N 370.79N 401.25N 664.33N 261.69W 6.00 347.31 560227.13 5959930.02 310.48W 6.00 427.25 560177.83 5959992.96 361.39W 6.00 512.96 560126.36 5960061.49 383.28W 6.00 550.47 560104.23 5960091.77 570.87W 0.00 873.53 559914.53 5960353.29 2183.71 64.50 324.51 1657.00 799.33N 667.13W 0.00 1039.31 559817.18 5960487.49 2500.00 64.50 324.51 1793.18 1031.77N 832.87W 0.00 1324.75 559649.58 5960718.55 3000.00 64.50 324.51 2008.46 1399.21N 1094.87W 0.00 1775.97 559384.63 5961083.81 3500.00 64.50 324.51 2223.74 1766.65N 1356.86W 0.00 2227.19 559119.67 5961449.07 4000.00 64.50 324.51 2439.02 2134.09N 1618.86W 0.00 2678.41 558854.72 5961814.34 4500.00 64.50 324.51 2654.30 2501.53N 1880.86W 0.00 3129.62 558589.77 5962179.60 5000.00 64.50 324.51 2869.58 2868.97N 2142.86W 0.00 3580.84 558324.82 5962544.86 5109.67 64.50 324.51 2916.80 2949.56N 2200.33W 0.00 3679.81 558266.71 5962624.97 5200.00 62.69 324.51 2956.97 3015.43N 2247.30W 2.00 3760.70 558219.21 5962690.46 5300.00 60.69 324.51 3004.39 3087.11N 2298.41W 2.00 3848.73 558167.52 5962761.71 5396.42 58.76 324.51 3053.00 3154.91N 2346.75W 2.00 3931.98 558118.63 5962829.11 5400.00 58.69 324.51 3054.86 3157.40N 2348.52W 2.00 3935.04 558116.84 5962831.58 5500.00 56.69 324.51 3108.31 3226.21N 2397.59W 2.00 4019.54 558067.22 5962899.99 5600.00 54.69 324.51 3164.67 3293.46N 2445.54W 2.00 4102.13 558018.73 5962966.84 5700.00 52.69 324.51 3223.88 3359.07N 2492.32W 2.00 4182.70 557971.42 5963032.06 5800.00 50.69 324.51 3285.87 3422.96N 2537.87W 2.00 4261.15 557925.35 5963095.57 5900.00 48.69 324.51 3350.56 3485.04N 2582.14W 2.00 4337.39 557880.58 5963157.29 6000.00 46.69 324.51 3417.87 3545.25N 2625.07W 2.00 4411.33 557837.17 5963217.14 6100.00 44.69 324.51 3487.72 3603.51N 2666.61W 2.00 4482.87 557795.16 5963275.06 6200.00 42.69 324.51 3560.02 3659.75N 2706.71W 2.00 4551.93 557754.61 5963330.96 6300.00 40.69 324.51 3634.70 3713.91N 2745.33W 2.00 4618.43 557715.56 5963384.79 6334.51 40.00 324.51 3661.00 3732.10N 2758.30W 2.00 4640.77 557702.45 5963402.88 6500.00 40.00 324.51 3787.77 3818.71N 2820.05W 0.00 4747.13 557640.00 5963488.98 6521.17 40.00 324.51 3803.99 3829.79N 2827.95W 0.00 4760.74 557632.00 5963499.99 6521.19 40.00 324.51 3804.00 3829.80N 2827.96W 0.01 4760.75 557632.00 5963500.00 6893.23 40.00 324.51 4089.00 4024.52N 2966.79W 0.00 4999.86 557491.60 5963693.56 7000.00 40.00 324.51 4170.79 4080.40N 3006.64W 0.00 5068.48 557451.31 5963749.11 7093.23 40.00 324.51 4242.21 4129.19N 3041.43W 0.00 5128.40 557416.13 5963797.62 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #111 and TVD from RKB (Parker #245) (112.00 Ft above mean sea level). Bottom hole distance is 5128.40 on azimuth 323.63 degrees from wellhead. Total Dogleg for wellpath is 93.02 degrees. Vertical section is from wellhead on azimuth 323.56 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Pad 1D,111 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : WS 1D-iIi/B2 Vets. #5 Last revised : 11-Jun-98 Comments in wellpath MD TVD Rectangular Coords. Comment 500.00 500.00 0.00N 0.00E KOP 650.00 649.38 0.00S 11.76W Begin Turn to Target 1642.01 1423.77 401.25N 383.28W EOC 2183.71 1657.00 799.33N 667.13W Base Permafrost 5109.67 2916.80 2949.56N 2200.33W Begin Angle Drop 5396.42 3053.00 3154.91N 2346.75W Top Ugnu Sands 6334.51 3661.00 3732.10N 2758.30W Top West Sak Sands / EOD 6521.17 3803.99 3829.79N 2827.95W TARGET - West Sak A3 6521.19 3804.00 3829.80N 2827.96W WS 1D-B2 Rvsd 22-Jan-98 6893.23 4089.00 4024.52N 2966.79W Base West Sak Sands 7093.23 4242.21 4129.19N 3041.43W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 7093.23 4242.21 4129.19N 3041.43W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised WS 1D-B2 Rvsd 22-Jan 557632.000,5963500.000,0.0000 3804.00 3829.80N 2827.96W 9-Oct-96 I c~:,~ w r,~:. For: BROCkSf^Y RCO Alaska, Inc. I '---~ru c--~u r~-.' P a cl-~-- ' Well: I [ Field : Kuparuk River Unit Location : North Slope, <- West (feet) 240 220 200 180 160 14.0 120 100 80 60 40 20 0 20 40 60 [ ', \ '~ ~ 0oo ', " \ ..... o ~ 300 -I ", k ', ', ~ ~, ~ .' ? 330 I % ~ ', ~ ~ ~ 17oo ~ i ' q '"~ ~ ~oo '~ ~ ~ ~ 2~ oo i · ", ", ~ 900~ ~ / ! J "~ ~ ",, '",, ~- ~ ~¢ ~ ~ / ' ' ~ 700 ~1300 ~ ] 220 x , ,,' ~"800 ~ ~o~o ...,.,,, '",,,,. X ,,, ,, .,,, ~ ~., J ", ".,~oo '~ X~,, ~ ,,,, ~.... ~,,~ ,..~o~ ",' ~ X '~ ~o~ ~ ",~ ~ooe' ,,'"~ ,,'" ] ', 'x ~ % ', ', ~ ," 600/'.70~/ / ' ',,,~ ~ ~ ~",, '~ ~oo ~ .... .'" '/.-/~ J~.-.., ",,,~,~ ~ x',,,, ,~ ~o?..;ooA~ , .,"'"",-'"",-,,, "" Zoo-- I '-., '-.. "-, ',,~', x ', ~ ~ X_ ~7oo ~ ~ "'-. 1 400 "'3~, ~',. ,uu '~ ~ 80~ ',: , / · .. ',. %, %, % '% '~ - '% '% '. '% ', ~. ,. ,. ,. , ,, ,. ,~ ""--... '"'-.... "'"... '"'-... ~o;"-,,~ ~ :~/ . ,o 4 %,oo~~ '".... --- "x %oo:**] ~oo ~o 1~ '"-...'"-.., % ~oo '"'-... "-~ 4 ~ ~oo '"-. '-,.. ".,. '-...~oo j, ' "-. "-. ". '----. 700 6uO o ~~ ---... ---., '--,,_ - ............ ~ 1~oo ~ ~800 ~ "-~ t200 '"~ 7~ ' ~ i 1700 ~.., -.. ',., , i ~ ~ ~oo ~1~oo~~oo;~;.-...~4~oo r '- '%. "., ~ 300 ~ 20 500 I ~ ~ ¢oo L 40 / 40 / r / i i i I i i i i i i i i i i i i i i i i i i i i i i i ~ [ i 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 <- West (feet) /X For: BROCKTfAY Date plotted : II-Jun-g8 ~ef4rence ;8 ~ 10-111/82 Vets. ~5. Co~c;notes a~ ;n feet ~fe,ence slot ~1 Il. Cept~s ore ref~ence RK8 (Patk~ t2~). ield : Kuporuk River Unit Location : North Slope, <- West (feet) 800 760 720 680 640 600 560 520 480 4-40 400 ~6C) 320 280 24-0 200 160 84O 8OO 76O 720 680 64C 600 560 52O 4-8O 440 400 360 520 280 240 20C 160 120 '"'"' '"'" '"'"' ", "',,,, '"',,, '"',,, 200 '",,, 800 1400',,,,,, ",,,,,, ",\,\ ~ "~,,, 1300 '"",,~5000[ "", "", "',, ", ',,,,, ',,,,, ',,,,, 'X'X~oo ',,,, '",... '".,. ~ 6oo '",,,, ~ ,,,,,,, ,,,,. [~.o '",, '",, ",, 2000 ", ' 1.300 ",% ",,, "'""~ 1 q-Q0 ~ "',, ~ 640 ", ',, ',, ~ ', i~r~ i ",, ", "", ~ ~9oo \ "~ L '",-, '",,,,."',,,, '",,,, \ ",,, r '" '\ '\- "\ ~ 18nO L '"'-.,, '"',,. "",, '"',,. "',,1.300 '"-, "'-. "',, '", "',. "'"'".,., '"'"'%L500 12 ~'",::;'",,,,. '""',,,,. '"-, ""-, '"", ""' : , ""', 400 ~ '""", '"'"'- '""-'\" ~ "", 12n0 x. 1600 / -.. ',. ',,.",, '~ 400 ',,. '~"-"-' ",, ~ '"'. "" '% ,. ' ',. L 360 -,.. ,........ ',.,:::,,,,,, ~ '"""".,...'"'"'"..,.. 1,0 ~":~,'.',',,,, '"'"'". ~ '"'-. '"'-,., 11 O0 '",'". "-,..x.1 400 "'. ". ", ",, 200 '".. 1 600'-. 100~'" . 760 720 680 640 600 560 520 480 440 400 560 320 280 240 200 160 <- West (feet) /k I Z 0 For: BROCKWAY Oete I~otted : Il-Jun-g8 ore ;n feet reference s[o[ ~111. Cep~s ore ref~ence ~8 (Park~ ~2~5). 26O0 2500 2408 2300 2200 2100 200O I,At C0 Alask Structure : Pad 1D .=Il · ~ ield : Kuparuk River Unit Loca[Jon : Norfh Slope, Alaskat <- West (feet) 2100 2000 1 g00 1800 1700 1600 1500 I 400 1300 1200 1100 1000 g00 800 700 600 I I f I I r I I I I I I ",, '~ 3000 \, · ' "" '~ 2900 ',. 2400 ',, , \ ",, "~ 2600 ',. 2800 \. ,, ,,, 'k, 2too ',~ 2300 '., 2700 ", ",, "~ 2500 ', 'k 2600 \ · . ~ 2000 "',. 2200'"' ', 1900 ~ 800 1700 v C' 1600 © 1500 1400 -~ 300 ] 1 1200 110C , 2400 ~ 2600 4800~ \ 2400 2300 4500 i 220O I L 4400 ~ I ,, / 1-2'cc '"',, ',., 2400 ',. 2500 ", ~ ', ¢ ', "', '~ 1900 2000 ,, 1000 go0 · ., 2100 ', , , ",,, ",,. "~,2400 '", '", 2300 ' "' ~ ', ', ", 11091 ". '., ',, ,, t~420o ,, ~9oo ",, ",, ",,, ~¢!oo "" 200~", '~ 2300 ",.4000 I ,, ',, ',, ~k3goo ~ 1~oo ~ ~oo ~ '",, "',, "',, ',3800 ,,.. '~,,2200 ',,,, N5700 '\, '",, '", '",2200 ~x3600 \', ~,700 ",,, ~ ',,, ,,;~oo ~ ~', "', '". ~3400 \\ "~'¢'2"'"..,.., '",,,., '"~,,~100 '"'~,2100 X~3300 ~\,'7uO ~600 % '-,. 21oo "- ", '",,. ~3200 ", ~oc :ooo '-.'-. 250d%, ".. 1^~^ "., '\ % .... '.. ',~ ~uu " '\ ~ "-.... ".... ".% X% ~. ,~ 2700~ :200 240¢' '" .]':,, 'x. '" '" 1800 1600'A, 'h'. 'k "". '~'. ",. "x x,. 'k~ F ~00 / 8O0 700 ", 'k 1800 '.. F [~1'"'-,._3200 230d"'- '"' ", ', ',, 1700 / 3000~g00 ""' '"% 1700 '~,~"",,,, '"',,., F 1000 O0 ",. ",. '"'-...~700 '".. "-.. ',,,, ,,,,, ,,,,16oof '"..~600 220~-.'"-. ~kg°° ""-.. ""., 1600 ", ',o 1700 -%0 .... I I I I I I I I I I I I I I t I I I I [ I : i I I / 700 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 <- Wesf (feel) Z 0 i c~o:~ ~ ~,~ For: BROCKWAY I Oate ¢latted : II-Jun-g8 ~'Cl ~efllrence ;~$ ~ 10-111/82 Vets. ~5. T~e Ve~,cal Oeotna ore ref~ence ~K8 (Porker 3900 q 380c 4 3700 j 3600 - 3500] 340C 1 320¢ 3100 q A:,RCO Alaska, Inc. JStructure : Pad 10 Well: 111 JField : Kuparuk River Unit Location : North Slope, West (feet) 3300 5200 3100 5000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 j , , , , ~ , , , , , , , , , , , , , , , , , I , , , , , , , , =300 (i 4300 I 4200 ~ z2CO 4106 "~ ¢200 4i00 %, '% ', '~ 4100 4COO ',, 40OO 5500 ~',, '~ 4000 ',. 3900 3900 '"' 'k 3800 3200 ~,,,, ',,,, I 3800 " "3700 '""', "'"' [ 3700 ,, · ~ 3600 3i00 ~"',, '~ 3500 3600 '"" ',. 3400 ~ A "'"' "",,,,, F 3~0o I 5000 ~, "',. "~ 3300 1 Z ', F 3400 '",,, "~ 3200 2900 I~na I CD k 3100 [ 5200 2800 ",, ",,,, , : L ~ O0 'k 3000 ~ · 3COO '-,, ,,,,,,,, '~, 4200 5000 2700 %, '~,¢100 ',,,,,,. '~ 4000 "~ 2900 , 2900 ,,,\,,,". "'",,,,,,,,,,,, '~ '~,38003900,~ · 3700 2900 2800 2600 ~ ~,3600 ', '~ 3500 2800 '",.,, '",~ 2800 '~ 3400 ', ,~ 5300 2700 2700 '", , '"', ',. 5200 2500 ~ "',,,,, '" ',, ',,.31001 2600 "', ',. 2700 , 2600 2400 x, 3300 5200 5100 3000 2900 2800 2700 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 <- Wesf (feel) C 0 A1 aaka, Inc. Structure: Pad 1D Well : 1 11 Field : Kuparuk River Unit Location : North Slope, Alaska WELL PROFILE DATA ..... P~'nt .....UD I,c 0Er tva North Eo~tV. Sect ~¢ ~ 0.~0.~ O.~ 0.~ 0.~ 0.~ O.~ 0.~ KOP 500.~ 0.~ 270.~5~.~ 0.~ 0.~ 0.~ aeg~n Turn to T~rget ~50.~ g.~ 270.~~49.~ 0.~ --1L75 6.95 ~ of ~'ld~um 16+2.0154.~ ~24.51 1~2~.~ ~1.25-3~.28 550.~7 ~ of HoEd 5~09.~7~4.50324.51 291e.~29~9.5~ -~.5~ ~679.81 0.~ ~ cf D~ep/Tum 6334.51~.~ 324.51 5661.~5732.10 -27~.~0~6~.77 T~r~et ~ ID-82 Rvsd 2 6521.1g~.~ ~24.51 580~.~3829.80 -2827.98 ~7E0.75 0.01 ~ of H~d 6895.23~.~ 324.51 4089.~402~.52 --~66.7g ~g99.86 0.~ '.O. & End ~ HG~ 7093.25~.~ 324.51 4242.21 4129.19 -~41.~ ~128.~ 0.~ 530 540 550 520 1700 310 ..-: ~.-' 3300 .-' 3700 ""4100 s 3oo TRUE NORTH ~oo ...... ]oo Creot, d by fi.ch For: BROCKWAY Dote plotted : 11-Jun-ga Plot Reference is W$ 1D-III/B2 Ve. rs. Go~dinot~ ore in fe~ reference 8lot ~111. r~e Ve~iccI Oep~s o~ r~nce RgB (Parker goo 50 6O 290 7O 280 8O 05OO 270 9O 260 100 250 110 240 120 230 150 · 22.. 0" ~7oo ~" 210 200 11o0 soo 50 Normal Plane Travelling Cylinder - Feet 160 190 180 170 All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 111 slot #111 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : WS 1D-IIi/B2 VerB. #5 Our ref : prop2215 License : Date printed : 11-Jun-98 Date created : 1?-Apr-9? Last revised : 11-Jun-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is n?0 18 1.601,w149 30 36.284 Slot Grid coordinates are N 5959693.682, E 560490.724 Slot local coord/nates are 29.00 N 596.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less ~=an 1000 feet are ind/cated by an asterisk, e.g. 487.4* Object wellpath PMSS <0-5142'>,,liS,Pad 1D WS 1D-113/C1 VerB. #4,,ll3,Pad 1D WS 1D-125/H2 Vets. #5,,125,Pad 1D WS 1D-123/G1 VerB. #4,,123,Pad 1D WS 1D-134/L5 VerB. #3,,134,Pad 1D WS 1D-132/K4 VerB. #3,,132,Pad 1D WS 1D-131/L3 VerB. #3,,131,Pad 1D WS 1D-128/K2 VerB. #3,,128,Pad 1D PMSS <0 - 7340t>,,10,Pad 1D PMSS <0-5462 PMSS <0-4414 PMSS <0-4530 PMSS <0-4515 PMSS <0-4590 PMSS <0-5205 PMSS <0-4850 PMSS <0-5126 >,,129,Pad 1D >,,121,Pad 1D >,,120,Pad 1D >,,11~,Pad 1D >,,liS,Pad 1D >,,11?,Pad 1D >,,109,Pad 1D >,,106,Pad 1D PMSS <381-6092'>,,105,Pad 113 PMSS <1957-5265'>,,133,Pad 1D PMSS <O-5015~>,,135,Pad 1D PMSS <0-4778~>,,130,Pad 1D PMSS <0-5047~>,,124,Pad 1D WS 1D-112/A1 VerB. #4,,112,Pad 1D WS 1D-110/C3 VerB. #4,,110,Pad 1D WS 1D-108/A3 VerB. #4,,108,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 2-Jun-98 65.6 701.4 701.4 2-Jun-98 44.? 633.3 633 5-Jun-98 315.0 650.0 650 9-Jun-98 240.0 200.0 200 2?-May-98 540.0 300.0 300 27-May-98 465.0 200.0 200 27-May-98 450.0 200.0 200 1-Jun-98 360.0 580.0 580 28-Apr-98 585.0 100.0 100 2-Jun-98 419.3 300.0 300 2-Jun-98 206.0 650.0 650 2-Jun-98 193.1 633.3 633 2-Jun-98 175.6 650.0 650 2-Jun-98 135.0 100.0 600. 2-Jun-98 105.0 600.2 600. 2-Jun-98 30.0 100.0 100. 2-Jun-98 75.0 100.0 100. 2-Jun-98 104.5 300.0 300. 2-Jun-98 477.3 300.0 300. 2-Jun-98 554.4 633.3 633. 2-Jun-98 434.9 400.0 400. 2-Jun-98 292.9 650.0 650. 2-Jun-98 43.1 500.0 500. 2-Jun-98 15.0 200.0 2600. 2-Jun-98 45.0 200.0 200. WS 1D-101/C5 Ve=S. #3,,l~',P&d 1D WS 1D-104/47 VetS. #3,,104,P&d 1D WS 1D-103/B6 VetS. #3,,103,Pad 1D WS 1D-102/45 VetS. #3,,102,P&d 1D WS 1D-10~/B% Vets. #1,,107,P&d 1D WS 1Do151/G11 Vets. #1,,151,Pe~ 1D WS 1D-138/K6 Vets. #1,,138,P&~ LD WS 1D-161/L? Vets. #1,,161,P&~ 1D WS 1D-160/K8 vere. #1,,160,P&d 1D WS 1D-159/L9 Vets. #1,,159,Pad 1D WS 1D-157/K10 Vets. #1,,157,Pad LD WS 1D-156/J9 Vets. #1,,156,P&d 1D WS 1D-155/H8 Vets. #1,,155,P&d 1D wS 1D-iSA/J11 Vets. #1,,154,Pa~ 1D WS 1D-153/H10 Vets. #1,,153,Pad 1D WS 1D-150/F10 Vets. 91,,150,P&d 1D ws 1D-152/G9 Vets. #1,,152,Pad 1D WS 1D-149/F8 Vets. #1,,149,Pad 1D WS 1D-lAS/Ell Vets. 91,,148,Pad 1D WS 1D-147/E9 Vets. #1,,147,Pad 1D WS 1D-146/D10 Vets. 91,,146,P&~ LD WS 1D-145/Cll Vets. 91,,145,P&d LD WS 1D-144/D8 Vets. 91,,144,Pa~ LD WS 1D-143/C9 VeTs. 91,,143,Pa~ LD WS 1D-139/B8 Vets. #1,,139,P&~ 1D WS 1D-140/49 Vets. 91,,140,Pa~ LD WS 1D-142/B10 Vats. 91,,142,Pad 1D WS 1D-141/411 Vets. #1,,141,Pad 1D WS 1D-158/L11 Vets. #1,,158,Pad LD WS 1D-136/J7 Vets. 91,,136,P&d LD TOTCO Survey,,WS-8,Pad 1D 1D-B Version #3,,LD-B,P&~ LD 1D-F Version #2,,1D-F,Pa~ 1D 1D-D Version #2,,LD-D,P&~ 1D P~M~ ¢0-8365'>,,1,Pad LD P~MS <0-9783'>,,2,P&~ 1/) PGMS <0-80?0'>,,3,Pad 1D PGMS <0-7502'>,,4,Pld 1D PGMS <0-8930'>,,5,Pad LD P~MS <0-8610'>,,6,Pad LD ' MSS <3311-8200'>,,7,P&d LD PMSS <556-7024'>,,9,Pad 1D WS 1D-126/J1 Vets. 95,,126,P&d 1D WS 1D-122/F2 Vets. 94,,122,P&~ LD WS 1D-127/L1 Vets. 93,,127,Pa~ 1D WS 1D-iii/D2 Vets. 95,,114,P&~ 1D WS 1D-116/E1 Vets. #4,,116,P&~ 1D 27 -May- 98 27 -May- 98 27-May-98 27-May-98 27 -May- 98 15-Apr-97 27-May-98 27 -May- 98 27-May- 98 27 -May- 98 15-Apr-97 15-Apr- 97 15-Apr- 97 15oApr- 97 15-Apr- 97 15-Apr-97 15-Apr- 97 15oApr- 97 15-Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr- 97 15-Apr- 97 27 -May- 98 27-M&y-98 27-May-98 27-May-98 27 -May- 98 21-May-98 24 -Nov- 97 24 -Nov- 97 24-Nov-97 10 -Dec- 97 4-Aug- 92 4 -Aug- 92 4 -Aug- 92 13 -Nov- 97 13 -Nov- 97 6-Nov- 97 29-A~r- 98 27-May-98 9-Jun- 98 27 -May- 98 11- Jun- 98 2-Jun- 98 163.1 118.1 133.1 148.1 58.2 522.2 602 0 665 4 651 0 636 5 607 7 593 4 579.1 564.8 550.6 508.1 536.4 494.0 480.0 466.1 451.8 436.1 424.7 407.9 333.0 358.1 389.5 374.5 622.1 572.0 632.0 407.0 495.5 377.0 177.0 88.0 31.6 152.1 271.5 392.2 512.0 159.8 330.0 222.7 345.0 75.0 96.3 200.~--* 200.0 200.0 200.0 3OO.0 300.0 300.0 300.0 300.0 200.0 300.0 300.0 400.0 300.0 300.0 300.0 400.0 500.0 300.0 500.0 520.0 540.0 500.0 600.2 633.3 650.0 600.0 580.0 200.0 580.0 616.7 600.0 650.0 600.0 1080.0 400.0 580.0 100.0 100.0 400.0 666.7 300.0 666.7 200.0 540.0 720.0 200 0 200 0 200 0 200 0 300 0 300 0 300.0 6340,0 300.0 200.0 300.0 300.0 400.0 300.0 300.0 300.0 400.0 SO0.O 300.0 500.0 520.0 540.0 500.0 600.2 633.3 650.0 600.0 580.0 200.0 4141.6 616.7 600.0 650.0 600.0 1080.0 400.0 580.0 100.0 633 3 633 3 400 0 666 7 300 0 666 7 200.0 540.0 720.0 z0" DIVERTER SCHEia,4TIC Kuparuk River Unit West Sak'Operations 6 4 3 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 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 ARCO ALASKA, INC. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" Conductor 2. Slip-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi Ball Valve 4. 20" - 2000 psi Drilling Spool With One 16" Outlet 5. One 16" HCR Knife Valve With 16' Diverter Line. The Valve Opens Automatically Upon Closure Of Annular Preventer. Diverter Line Will Be Placed For Optimum Dispersion in Prevailing Wind Conditions 6. 20' - 2000 psi Annular Preventer TAB, 06/12/98, v.2 · · 3-5/8" 5000 psi BOP r .ack Kuparuk River Unit West Sak Operations -Injector Wells 5 4 3 2 1. 16' Starting Head 2. 7-1/16' 5000 psi Tubing Head 3. 7-1/16' x 13-5/8' 5000 psi Double Studded Adapter/Spacer Spool 4. 13-5/8' 5000 psi x 13-5/8' 5000 psi Spacer Spool 5. 13-5/8' 5000 psi Pipe Rams 6. 13-5/8' 5000 psi Drilling Spool with Choke and Kill Lines 7, 13-5/8' 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8' 5000 psi Annular Preventer 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 ail 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 end 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 ddlling 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. Pedorm BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6' or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.2 '127j 128 ~GEND s~ SHE~ , 2 FOR NO~ ~0 L0~ON IN--nON o ~s~ c~oucro~s ~ LOUNSBURY ARCO A'*~u-,o..a, Inc. ~ ~ST SAK PHASE lB - ~ CONDUCTORS AS-BUILT LOCA~ONS LK6104015 6/15[98 CEA-D1DX-610~15 1 ~ 2 NO TES 0£SCRIP TION PEi~-' ,CS8/ K980! 7ACS t. COORDINAIE$ SHOWN ARE A.$.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN CEA LEVEL. ALL DISTANCES SHOWN AR£ TRUE. 2.-i~ASi5 OF' 'LOCATIONS /.iND' ELEVA 1'IONS ARE D.E` I-0 .... MONUMENTS PER LHD AND AS$OClATEE` J. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTION 2J, TOWNSHIP II NORTH, RANGE 10 EAST, U.M. 4. DAleS OF' SURVEY: 6/9/98, FIELD BK. L98-45, PGE` 21-25; AND 6/12/98, FIELD BK. L98-45, PGE, 47-48. 5. DRILL SllE l-O GRID NORTH IS ROTA TED 00' 01' 05' I~$T FROM A.E`P. ZONE 4 GRID NORTH. 6. SE~ DRAWING NSK-$.5;I FOR AS-BUILT LOCATIONS OF' CONDUCTORS I-8' CEA-OIDX-61OADIO FOR CONOUCTORS I05,106, log. I I5, I 17- I21,124.129, I:0, l:J & IJS; AND CEA-DIDX-6104DIJ FOR CONDUCTORS 9 & IO~ S'UR 22 VIC/N/TY MA P 'SC, ALE: I' = I MS.E IND.I Y 125 5,959, J79. J5 126 ! 5,959,J6~92 128 ! 5,959, J.,T4.14 I:I I 5.959.244.05 I32 ! 5,959,229.23 Sec. 23, 7.11 N., R. ID E. X 550, 490. 59 560, 490. 68 560, 49~ $ 7 560, 490. 58 560, 490. 74 5EO, 490. 64 560, 490. 85 Lot. 70' 17' 58.509' 70' 17. 5~:58= 70' 17. 58.210' 70* 17* 58. 065' 70' 17. 57.179' 7O* 17. 5X033' 70" 17' 5~.291' Long. 149' JO' J6. J61' 149' JO' J~.J$2 149' JO' JS. J66' I49' .~0 ' 149' $0' -~6.389 149' JO' JG. J95' 149' .,TO' SURVEYOR'S CER TIFI CA TE I HEREBY CERTIFY rEAr I ~ PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF' ALASKA AND THAt THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THai' ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF' JUNE 13, 1998. ARCO Alaska, Inc. CAO0 FILE NO. DRAWING NO:. LK6104015 LOUNSBURY ASSOCIATES. INC. NF, g~I~ PI..M~I~ SUR'lrlYoRI AREA: 10 MOOULE: XX DRILL SITE 1-0 WEST SAK PHASE lB - WELL CONDUCTORS AS-BUILT LOCATIONS SHEET: REV:- CEA-D1DX-6104D15 2 ~ 2 UNIT- D1 WesfSak 1 D-111 (B2) Injector Completion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' TAM International 5-1/2" Port Collar Stnd. Grade BTC Threads set +/- 1000' TVD Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 6235' MD / 3586' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 6235' MD / 3586' TVD) to (+/- 7093' MD / 4242' -I-VD) G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin dow~ F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.34f EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Iiaker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands HH, 8/10/98, v.1 1D-114 Cement Volumes Surface Hole Casing Depth Casing OD Casing Weight Hole Size Upper Casing Volume/Foot Upper Annulus Volume/Foot Lower Casing Volume/Foot Lower Annulus Volume/Foot Shoe Joint Length 500' TVD Above WS HiStrgth Depth Base Permafrost Top of 3 1/2" Permafrost Excess Below Permafrost Excess :inches feet feet feet Class Additive 1 Additive 2 Additive 3 Additive 4 Additive 5 Additive 6 Density Yield Water Requirement Thickening Time PPg ift3/sx gal/sx hours Thickening Time PPg ft3/sx gal/sx hours bbls sacks 111 bbls 525 sacks · WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION COMPANY, ///'~__.,~ ENGINEERING DATE WELL NAME _.~, /~) '"//,/',? INIT CLASS //" C~,,,'; 4.-i.~ 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 ........... PROGRAM: exp [] dev [] redrll [] serv/~wellbore seg II ann. disposal para req II 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 we,bore 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 3000 psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOL AREA ~' .~¢___.) UNIT# ////,/~' ~:~ ON/OFF SHORE N N N N N N N N N N N N N lN N N N N N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures.. Y N // 31. Data presented on potential overpressure zones ....... Y/.N 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports ....... ./ Y N [exploratory only] ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (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 COMMISSION' DWJ RNC , co GEOLOGY: R P C/~.~' M:chek~list rev 05~29~98 dlf:C:\msoffico\wordian\diana\checMisl E N G I N E_E,__R. Uq G :,- UlC/Annular Annular disposal has not been rcqucstcd as part of thc Permit to Drill application for Kuparuk River Unit Well No. 1 D-~. Plcasc notc that an,,' disposal of fluids generated from this drilling operation which arc pumped down thc surfacc/production casing annulus of a pcrrnittcd existing ,,veil on Drill Site ID must comply xvith thc rcqu~rcmcnts and limitations of 20 AAC 25.080. .-\pproval of this pcrmit to drill docs not authorizc disposal of drilling x~astc in a x'olumc grcater than 35.000 barrels through thc annular space of a single xvcll or for a period longer than one year. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of.this nature is accumulated at the-end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drillir Services LIS Scan Uti=~ty Thu Oct 15 13:04:35 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA (WEST SA/<) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80351 R. MCNEILL D. BREEDEN 1ST STRING iD-Iii 500292291100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 15-0CT-98 MWD RUN 2 AK-MM- 80351 R. MCNEILL D. BREEDEN 14 llN 10E 29 596 .00 111.60 70.60 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 8.500 7045.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION WITH MIKE WERNER OF ARCO ALASKA, INC. ON 10/13/98. 3. MWD RUNS 1 AND 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. WELL ID-Ill REACHED A TOTAL DEPTH OF 7045'MD, 4233'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 78 0 7004.5 RPM 78 0 7004.5 RPS 78 0 7004.5 RPX 78 0 7004.5 GR 85 0 7012.0 FET 117 5 7004.5 ROP 119 0 7045.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 2746.0 2 2746.0 7045.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...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 28 8 Name Min Max DEPT 78 7045 ROP 16.0572 1727.99 GR 8.0538 153.117 RPX 0.4551 2000 RPS 0.0674 2000 RPM 0.2083 2000 RPD 0.304 2000 FET 0.0504 7.2497 Mean Nsam 3561.5 13935 324.339 13853 71.1121 13855 74.2992 13854 106.388 13854 106.986 13854 185.939 13854 0.305658 13775 First Reading 78 119 85 78 78 78 78 117.5 Last Reading 7045 7045 7012 7004.5 7004.5 7004.5 7004.5 7004.5 First Reading For Entire File .......... 78 Last Reading For Entire File ........... 7045 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File HeRder .... Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI3MBER: 2 P_AW 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 RPD 78.0 RPM 78.0 RPS 78.0 RPX 78.0 GR 85.0 FET 117.5 ROP 119.0 ,$ 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: STOP DEPTH 2705.5 2705.5 2705.5 2705.5 2713.0 2705.5 2746.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MI/D 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): 29-AUG-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 2746.0 121.0 2746.0 .0 67.4 TOOL NUMBER P1038CRG6 P1038CRG6 8.500 8.5 LSND 9.50 253.0 9.7 350 6.4 7.000 MUD AT MAX CIRCULATING ~RMPEP~ATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 5.674 7.500 6.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 28.4 First Name Min Max Mean Nsam Reading DEPT 78 2746 1412 5337 78 GR 13.2621 141.519 67.5075 5257 85 RPX 0.6813 2000 135.229 5256 78 RPS 0.7785 2000 217.219 5256 78 RPM 0.699 2000 225.656 5256 78 RPD 0.7472 2000 419.62 5256 78 ROP 39.6328 1727.99 338.584 5255 119 FET 0.0504 0.7113 0.254018 5177 117.5 Last Reading 2746 2713 2705.5 2705.5 2705.5 2705.5 2746 2705.5 First Reading For Entire File .......... 78 Last Reading For Entire File ........... 2746 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSI' ~.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NIIMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2706 0 7004.5 RPD 2706 0 7004.5 RPM 2706 0 7004.5 RPS 2706 0 7004.5 RPX 2706 0 7004.5 GR 2713 5 7012.0 ROP 2746.5 7045.0 $ LOG HEADER DATA DATE LOGGED: 30-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46/EWP4 1.38 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 7045.0 TOP LOG INTERVAL (FT) : 2746.0 BOTTOM LOG INTERVAL (FT) : 7045.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 37.8 MAXI~ ANGLE: 65.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P1038CRG6 EWR4 ELECTRON[AG. RESIS. 4 P1038CRG6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 275.0 MUD PH: F~JD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.4 350 5.2 3.500 2.383 5.000 4.500 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD 2 FT/H 4 1 68 OR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 41.1 Name Min Max Mean DEPT 2706 7045 4875.5 ROP 16.0572 887.071 315.632 GR 8.0538 153.117 73.3159 RPX 0.4551 2000 37.0529 RPS 0.0674 2000 38.6358 RPM 0.2083 2000 34.4421 RPD 0.304 2000 43.0891 FET 0.0822 7.25 0.336752 Nsam 8679 8598 8598 8598 8598 8598 8598 8598 First Reading 2706 2746.5 2713.5 2706 2706 2706 2706 2706 Last Reading 7045 7045 7012 7004.5 7004.5 7004.5 7004.5 7004.5 First Reading For Entire File .......... 2706 Last Reading For Entire File ........... 7045 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.~_ Date of Generation ....... 98/10/15 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/15 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File
