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Home My WebLink About184-117 ge Project Well History File Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file, RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: m Grayscale items: [] Other. No/Type m Other items scannable by large scanner [] Poor Quality Originals: ..~ OVERSIZED (Non-Scannable) [] Other: , NOTES: '[] : Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl. DATE; IS/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /SI Scanning Preparation __~ x 30 = BY: BEVERLY BRE. VINCENT SHERYL~ LOWELL Production Scanning Stage ~ PAGE COUNT FROM SCANNED FILE: BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO BREN VINCENT SHERYL MARIA LOWELL DATE: · Isl IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIOUAL PAGE BASIS RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /SI General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScan ned.wpd • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well F Rug Perforations r Perforate r Other Conductor Extension Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory r _ 184-117 ' 3.Address: 6.API Number: r P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-21149-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0025667 • 2G-11 • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool ■ 11.Present Well Condition Summary: Total Depth measured 8670 feet Plugs(measured) None true vertical 6370 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 8028 true vertical 0 feet (true vertical) 5917 Casing Length Size MD TVD Burst Collapse CONDUCTOR 63 16 104 104 1640 630 SURFACE 3281 10.75 x 9.625 3318 2706 3520 2020 PRODUCTION 8597 7 8634 6345 7240 5410 SCAB LINER 522 4.5 8546 6283 7780 6350 MINED NO , L012, Perforation depth: Measured depth: 8229' 8420' True Vertical Depth: 6059'-6194' [[�� 0C 0 8 2L, ... Tubing(size,grade,MD, and TVD) 3.5,J-55, 8140 MD,5996 TVD AOGCC Packers&SSSV(type,MD,and TVD) PACLER-BAKER SEAL ASSY, GBH-22 W/MULE SHOE @ 8028 MD and 5917 TVD SSSV-CAMCO"DS"NIPPLE @ 539 MD and 539 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development P.° • Service r Stratigraphic r' 16.Well Status after work: Oil Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ r WAG r GINJ r SUSP R. ' SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-443 Contact MJ Loveland/Martin Walters Email n1878 @conocophillips.com Printed Name Martin Walters Title WI Project Supervisor Signature Phone:659-7043 Date: 9/25/2013 ...40,729 ,-.4,91,, , RBEIMS OCT i i 4 / 3 Form 10-404 Revised 10/2012 1('f ` 5 // Submit Original Only • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 September 25, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-404 Sundry for ConocoPhillips Alaska, Inc. well 2G-11, PTD 184-117, Sundry# 313-443 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, /74, s Martin Walters ConocoPhillips Well Integrity Projects Supervisor Tjs THE STATE Alaska i and Gas __= ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 t4E1) ` N •"A l Y V Martin Walters 5 WI Project Supervisor ConocoPhillips Alaska, Inc. g U 7 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G-11 Sundry Number: 313-443 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a:4 Cathy P. oerster Chair DATED this 5 day of September, 2013. Encl. 4— A - STATE OF ALASKA x / 't `" ` AI A OIL AND GAS CONSERVATION COMA ION / , 3 APPLICATION FOR SUNDRY APPROVALS��/l, � 4 20 AAC 25.280 "= ` _.i 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved HrOgrarn Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:Conductor Extensid • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ry Exploratory r 184-117 r 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21149-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 2G-11 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025667 , Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8670 • 6370 Casing Length Size MD TVD Burst Collapse CONDUCTOR 63 16 104' 104' 1640 630 SURFACE 3281 9.875 3318' 2706' 3520 2020 SCAB LINER 522 4.5 8546' 6283' 7780 6350 PRODUCTION 8593' 7 8634' 6345' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8229-8420 6059-6194 3.5 J-55 8140 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER=BAKER SEAL ASSY MD=8028 TVD=5917 SSSV=CAMCO DS NIPPLE MD=539 TVD=539 12.Attachments: Description Summary of R-oposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r -Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/1/2013 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878anconocophillips.com Printed Name Martin�Walt rs Title: WI Project Supervisor Signature ��/��l r• / .v,: , Phone:659-7043 Date:08/12/13 C Commission Use Only Sundry Number: 3„Ntt3 Conditions of approval: Notify Commission so that a representative may witness ✓�� / Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r s r�� RB S OCT 1 0 7 Other: Spacing Exception Required? Yes ❑ No E Subsequent Form Required: /4=9— 4 c 4 rt,'' `�/9 APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: 9`S—/3 � ;,l / Approved app) ti i d 2 o the from the date of approval. wi , Form 10-403(Revised 10/2012) ` C Submit Form and Attachments in Duplicate t Vr' 2 II3 '0 • • • ConocoPhillips AUG 14 201'.' Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 August 12, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10-403 Application for Sundry Approv1s for ConocoPhillips Alaska, Inc. well 2G-11, PTD 184-117 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, 74;-. 7Z4/),) Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • • • ✓ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 2G-11 (PTD 184-117) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 12, 2013 This application for Sundry approval for Kuparuk well 2G-11 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. 2G-11 recently underwent a workover that replaced the entire wellhead assembly. Subsequent to the workover the conductor is 64"below the desired height. With approval, the conductor extension will require the following general steps: 1. Examine surface casing for any corrosion damage. 2. Extend the conductor to starter head and fill the void with cement and top off with sealant. 3. File 10-404 with the AOGCC post repair. • • r P //7,OF T��s THE STATE Alaska Oil and Gas Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ro- OF �. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 Fax: 907.276.7542 SCANNED JUL 2 9 2313 Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. �'�-�''-' "7 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G-11 Sundry Number: 313-385 Dear Mr. Huck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • P-711 Cathy P. oerster Chair / DATED this( 'f day of July, 2013. Encl. • STATE OF ALASKA / A� A OIL AND GAS CONSERVATION COM SION (kA APPLICATION FOR SUNDRY APPROVALS 4 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill l; s Perforate New Pool (r." Repair w ell €■ 6hange Approved Program (i Suspend E Rug Perforations ta.r3 Perforate r Pull Tubing Time Extension E Operational Shutdown E Re-enter Susp.Well f Stimulate r Alter casing Imo' Other:REVISED SUNDRY = 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc.0 Development Iw • Exploratory E 184-117- 3.Address: 6.API Number: Stratigraphic E Service F- P.P. O. Box 100360,Anchorage,Alaska 99510 50-029-21149-004 7. If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes F No I✓ 2G-11 r 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25667* Kuparuk River Field/Kuparuk River Oil Pool* 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 86704, 6367 8129' none Casing Length Size MD ND Burst Collapse CONDUCTOR 68 16 104' 104' SURFACE 3282 9.625 3318' 2711' RECEIVED PRODUCTION 8600 7 8634' 6342' JUL 18 2013 AOGCC Perforation Depth MD(ft): , Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8229-8238,8243-8245,8350-8370,8390-842C 6056-6062,6066-6067,6142-6156,6170-6191• 3.5 J-55 8141 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER FHL PACKER MD=8112 TVD=5973 SSSV-BAKER FVL SSSV MD=2176 TVD=2000. 12.Attachments: Description Summary of Proposal . (■ 13. Well Class after proposed work: Detailed Operations Program ( BOP Sketch E Exploratory r Stratigraphic I— Development F. Service E 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/17/2013 Oil °° Gas E WDSPL is Suspended ) • 16.Verbal Approval: Date: WINJ )w GINJ Is WAG I~ Abandoned r Commission Representative: GSTOR I SPLUG 1— 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Drew Huck @ 265-6828 Email: Andrew.Huck(cilcop.com Printed Name Drew Huck Title: Drilling Engineer Signature 0- 9f Phone:265-6828 Date 7/12/2,0 13 Commission Use Only Sundry Number: 31 3.-✓335 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test I/Mechanical Integrity Test E Location Clearance I- - 3coo /se, QcP /Sr ( 1,- - ) Other: ike.g.42..........A.S pac in Exce tion Re uired? Yes ❑ No Subsequent Form Required: Q —y�? RBDMS JUL 2 3 20 �\ CpMIM S APPROVED BY �t Approved by: P t,f!', ,„. 'cation is vaftCi tOrI1SLI N.- _ _ - T- ,, _t:l _�,r Date: 7—/' 13 p Form 10-403(Revi d 10/2012) ORIGINAL Submit Form and Attachments in Duplicate \'9 • • RECEIVED • Iv • • JUL 182013 ConocoPhillips OGGC Alaska P.O.BOX 100360 ANCHORAGE,ALASKA 99510-0360 17 July 2013 Commissioner Dan Seamount State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for a Revised Application for Sundry Approval to workover the Kuparuk Well 2G-11 (PTD#184-117, Sundry#313-275). Well 2G-11 was drilled and completed in 1984/1985 as an A-sand only producer. On 5/18/11 the well experienced a release of hydrocarbons to surface via a split sealed conductor and accompanying pressure relief valve, which was believed to be the result of a surface casing leak. A tubing plug was installed, the well was excavated in June/July of 2012, and the conductor was removed, but the surface casing was found to be in good condition. Subsequent work suggested that the leak point was actually located in the wellhead via the OA X OOA packoffs. An attempt was made to repair the OA X OOA packoffs, which appeared to initially be successful. However, when an MITOA was subsequently performed on 7/7/12, once a pressure of 900 psi was reached, the wellhead moved up 3". Further investigation suggests that the 10-3/4"X9-5/8" surface casing was hung with an emergency slip arrangement after the mandrel hanger parted just below the wellhead during drilling of the production hole; however, the report notes that no slips were installed. This may have been what allowed the wellhead to move up. The OA X OOA packoffs have not been successfully tested since the last MITOA attempt. To restore integrity to this well, a rig workover was planned to replace the entire wellhead, with the top—2,000' of 7" casing also being replaced. The initial plan was to place a cement plug before the workover and to only pull the upper completion above the packer at 8,112', replacing it after the other work was complete, which would have set the well up for a CTD cement pilot hole exit. ConocoPhillips requested a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A& C-sand perfs in this manner, which was approved. The cementing was completed on 7/10/2013. Doyon 141 moved over the well on 7/14/2013. The rig proceeded to pull the completion; however the seals did not come out of the packer and the packer and tailpipe were pulled with the completion. To fix this issue, after the wellhead and 7" have been replaced, the plan is to weight up to 11.4 ppg mud (KWM), mill the cement, and run and cement in place a 4- 1/2"scab liner before running the upper completion. CDR2 will then be able to exit through the 4- 1/2" and 7"to drill laterals. This will likely need to happen in the next 2 weeks. If you have any questions or require any further information, please contact me at 265-6828. Regards, 1/4,/( Drew Huck Drilling &Wells Engineer CPAI Drilling and Wells • • 2G-11 Kuparuk Producer Capital Rig Workover& Subsequent CTD Sidetrack PTD #: 184-117 Sundry#: 313-275 Current Status The rig is currently on well 2G-11 and the 3-W completion has been pulled. Scope of Work for RWO !� ♦ Pull 3-W J-55 tbg from well, including packer. COMPLETE ♦ Run 7"csg scraper, run CBL, set RBP, cut-pull 7"csg above TOC ♦ Remove McEvoy Gen I wellhead, replace with FMC Gen V system, starting with 10-3/4"slip-lock ♦ Replace 7"casing above TOC ♦ Mill cement and run and cement in 4-1/2"scab liner ♦ MU and TIH w/new 3-W L-80 gas lift completion to surface General Well info MASP: 2,892 psi using current SBHP and 0.1 psi/ft gradient Reservoir pressure/TVD: 3,504 psi/6,123' TVD (TOP A-sand) SBHP survey 6/27/13 Wellhead type/pressure rating: McEvoy Gen I Tubing Head Adapter: 3-1/8" 5K x 7-1/16" 3K Tubing Spool: 7-1/16" 3K x 11" 3K Interm. Csg. Spool: 11" 3K x 16-3/4"2K BOP configuration: Annular/Pipe/ Blind/Flowcross/Pipe TIFL/ MIT-IA/MIT-OA: MIT-IA Passed 04 May 2013 MIT-T Passed 10 June 2011 Cement+Tubing tested to 2,000 psi 10 July 2013 Cement negative tested 16 July 2013 w/8.6 ppg brine MIT-OA Passed 03 April 2009—unable to test since then because of OAXOOA leak at wellhead. Well Type: Producer Actual Rig Start Date: 14 July 2013 Production Engineer: Mike Balog/Deanna Van Dam RWO Engineer: Drew Huck Work: 265—6828 Cell: 303—328—5835 E-Mail: Andrew.Huck @conocophillips.com • • Proposed Revised Procedure Summary: Pre-RWO Work 1. RU E-Line: Obtain updated SBHP, Perforate tubing tail 8,126'-8,127'. COMPLETE 2. RU Coil: Mill D-Nipple, Cement Perforations in accordance with CTD practices for cement pilot exit. a. Cement with 24 bbl of 17 ppg cement, target TOC is perfs in tubing tail. COMPLETE 3. RU Slickline: Tag top of cement and pressure test at least 72 hours after cement pumped. COMPLETE 4. Set BPV w/i 24 hrs of rig arrival. COMPLETE RWO:M/RU, BOP Test 5. MIRU Doyon 141. COMPLETE 6. Pull BPV, obtain SITP& SICP, and verify well is dead. COMPLETE 7. Set BPV&blanking plug, ND tree, NU BOPE & PT BOPE to 250/3,000 psi and annular to 250/3,000 psi. COMPLETE Note: Tubing head is Gen I McEvoy 3K, so while MASP is 2,922 psi, BOPE high test pressure will be 3,000 psi because of 3K top flange on tubing head. RWO:Pull 3-1/2"completion, Pull&Replace 7", Install& cement 4-1/2"scab liner, Replace 3-1/2" 8. Pull BPV, screw in landing joint, BOLDS's, unland tubing hanger COMPLETE. 9. POOH laying down tubing spooling up control line. COMPLETE-packer came as well. Point Forward Procedure -----4- 10. RIH w/7"casing scraper on drillpipe to top of PBR or tubing stub, circulate well clean. POOH standing back drillpipe. 11. RU E-line: RIH w/CAST-M. Log from PBR/tubing stub back to surface to determine condition of casing and top of cement. Fire a string shot across the 2nd collar above the top of cement. 12. RIH &set an RBP (or IBP) below the top of cement. PT to 3000 psi and drawdown test to 0 psi. Sw:PI Dump 50'of sand on top of plug. POOH standing back drillpipe. 13. ND BOP stack, ND tubing head and RU Hydratight. Slowly release lock down screws and allow casing to grow. 14. Cut off 7"casing growth. 15. NU 5M BOP stack to the 3M casing head. 16. Cut the 7"casing above the top of cement. 17. C/out lower BOPE pipe rams to 7"solid body. PT BOPE to 250/3,000 psi and annular to 250/3,000 psi. Note: Top Casing head flange is Gen I McEvoy 3K, so while MASP is 2,922 psi, BOPE high test pressure will be 3,000 psi because of 3K top flange on casing head. 18. Spear the 7"casing. Circulate out the Arctic Pack from the OA. 19. POOH laying down 7"casing. 20. RIH with 9-5/8" storm packer and set at-100' ✓---7. eT I5-6D e s L 21. ND BOP Stack, back off on lockdown screws and remove casing head and starting head. a. If bottom part of wellhead does not come off, cut exposed 10-3/4" pup joint off with exterior WACHS cutter or cut coupling. 22. Install FMC 1Q4" slip-lo*sy ttemm on exposed 10-3/4" stub. 23. NU new FMC Gen V Tubing Head & BOP Stack, PT BOP's to 250/4,000 psi and annular to 250/3,500 psi. 1 ? ? casi•c, 24. Pull storm packer at-100'. NE40 25. RIH w/a 9-5/8"casing scraper to the top of the 7" stub, circulate well clean. POOH standing back drillpipe. 26. RIH w/the backoff tool to the top of the 7" casing stub, engage stub and backoff. POOH standing back drillpipe. 27. RIH w/7"casing spear, retrieve 7"casing stub. POOH standing back drillpipe. 28. RU GBR casing crew& RIH w/new 7"TC-Il casing. 29. Circulate gelled diesel into the 7"x 9-5/8" annulus to surface and screw into top of 7"casing, PT casing to 3000 psi. • • 30. ND BOPE and tubing head, pull 7"casing in tension and land in the slips. Cut excess 7" casing w/ Wachs cutter. 31. Test packoffs, NU tubing head and BOPE. C/out lower pipe rams to VBR's. Function test rams on test joint. �T 32. RIH w/RBP retrieving head to top of plug, circulate to clean up sand and any remaining arctic pack, engage RBP and pull to release. 33. Weight up to 11.4 ppg fluid (-125 psi overbalance), RIH and mill cement to PBTD of 8,549' or as deep as practical. POOH. 34. RIH with 4-Y"scab liner. RU SLB cementers, establish circulation rate, pump 10 bbl spacer followed by—24 bbls Class G cement, drop wiper plug and chase w/ KWF until plug bumps. Pressure up to to set liner hanger at—8,050' RKB. Slack off to check hanger is set. 35. PU to expose rotating dog sub and slack off to set liner top packer. Pick up and circulate cement out of the hole until clean fluid returns. POOH and WOC. 36. RIH w/new 3-1/2"gas lift completion to just above the SBE, t CI brine, engage the SBE until fully located, space out, mark the pipe and pull out of the SBE. RWO:Finish Completion, RDMO 37. Space out w/pups, MU hanger. Land the hanger, RILDS. 38. PT the tubing/liner to 3,000 psi, bleed tubi PT the IA to 2,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 39. Pull the landing joint, install BPV. 40. ND BOPE. 41. NU and test tree. Pull BPV. 42. Swap well over to diesel through the SOV. 43. Set BPV. 44. RDMO. Post-RWO Work 45. Reset well house(s) and flowlines of adjacent wells. 46. Pull BPV. 47. RU Slickline: Set catcher in DS nipple. Pull SOV from GLM, run DV. 48. Turn well over to Operations for pre-CTD wellwork. S ! 2G-11 ConocoPhillips Proposed Completion Huck 07/17/13 Exict : 16"62.5#sting Cemented H 40, originallyCondu sealed or Al 1 2.875"DS-Nippl @-500' Arctic Pack Cement Shoe. Estimated TOC-2,121' MD. Passed MITOA to 1,800 psi 4-3-09 3 W MMG,1-W Tubing: @-3,072' mi 3-'/2"9 3#L-80 EUE-8rd AB-Mod Surface Casing: 9-5/8"35.9#J-55 BTC 3,318' MD/2,711'TVD 3%"MMG,1-'/:" 1 Joint 10-3/4"45.5#K-55 BTC on top @-4,864' - 2 10-3/4" Pup Joints May need 10-3/4" K-55 BTC joints and collars 3 W MMG,1-W @-6,060' Cement 3 W MMG,1-W . Arctic Pack @-6,956' 3 W MMG,1-W TOC 15.8 ppg Estimated @+/-7,750'MD from CBL @-7,553' run 9/17/1984. Some cement above. 3WMMG,1-W �I @-8,000' 2.813"DS-Nipple SEM @-8,030' Baker ZXP Liner Top Packer @-8,040'MD 4-%"11.6#R3 Liner from ZXP to-8549'MD C-4 Perforations 8,229'-8,238' Kuparuk `C' Sands @ 8,226' MD/6,054' TVD C 1B Perforations 8,243'-8,245' Formation Pressure — IA-5 Perforations 8,350%8,370' ; Kuparuk `A' Sands @ Estimated 11.1 ppge — :I A-4 Perforations 8,390'-8,420' : _8,325' MD 1 6,125' TVD Production Casing: 7"26#J-55 BTC 7"26#L-80 TCII from -2,100'to surface 8,634' MD/6,342'TVD @ 45° It KUP • 2G-11 IC0n0CoPhilhi _ Well Attributes Max Angle&MD TD Alaska Inc Welibore APUUWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ftKB) csxncnphsups 500292114900 KUPARUK RIVER UNIT PROD 52.47 3,300.00 8,670.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... Well Conte'-2Ga1,7/3/201311 19-55 AM SSSV:TRDP 35 1/17/2010 Last WO: 40.98 9/17/1984 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 8,436.0 4/25/2013 Rev Reason:PULLED PLUG haggea 7/3/2013 Casing Strings HANGER 32 ±' (�' Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)..String Wt...String... String Top Thrd , .,. CONDUCTOR 16 15.062 36.0 104.0 104.0 62.50 H-40 rYP Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd ` SURFACE 95/8 8.921 35.9 3,317.6 2,710.5 36.00 J-55 BTC "..\!. 10.75"x9.875" Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth ITVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 34.0 8,634.3 6,341.7 26.00 J-55 BTC Tubing Strings Tubing Description 'St ng 0... 'String ID...Top(ftKB) Set Depth(f...Set Depth(TVD).. String Wt...String...String Top Thrd ' TUBING I 31/2 2.992 32.0 8,141.1 5,993.6 9.30 J-55 EUE-8rd Corn r letion Details Top Depth (TVD) Top no Rant.. Top(ftKB) (ftKB) (•) Item Description Comment ID(in) 32.0 32.0 -0.04 HANGER MCEVOY TUBING HANGER 3.500 2,176.3 2,0002 47.34 SAFETY VLV BAKER FVL SSSV 2.810 CONDUCTOR, • 8,098.0 5,963.0 45.03 PBR BAKER PBR 2.810 36-104 8,111.7 5,972.7 44.99 PACKER BAKER FHL PACKER 2.937 a. 8,128.8 5,984.8 44.93 NIPPLE CAMCO D NIPPLE 2.750 8,140.3 5,993.0 44.90 SOS BAKER SHEAR OUT SUB.ELMD TTL @ 8132'during SWS PPROF on 3.000 SAFETY VLV, `£ 09/08/2004 2,176 I Perforations&Slots Shot Top(TVD) Btm(TVD) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (eh-- Type Comment GAS LIFT, (-_ - : 8,229.0 8,238.0 6,055.8 6,062.2 C-4,UNIT B, 6/26/1994 6.0 APERF 90 deg.Phasing;2 1/8"EnerJet 2.226 2G-11 INIIi 8,243.0 8,245.0 6,065.8 6,067.2 UNIT B,2G-11 6/26/1994 6.0 APERF 90 deg.Phasing;21/8"EnerJet 1`?' 8,350.0 8,370.0 6,141.6 6,155.7 A-5,2G-11 10/30/1984 4.0 IPERF 90 deg.Phasing;4"Schlum Casing 8,390.0 8,420.0 6,169.9 6,191.0 A-4,2G-11 10/30/1984 4.0 IPERF 90 deg.Phasing;4"Schlum Casing Notes:General&Safety End Date Annotation SURFACE • • 1021/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 107536-3,3 8 6/14/2011 NOTE:PSI CONTROL LINE TO 6000 PSI GAS LIFT, C 4,373 GAS LIFT. 1,Mili 6,040 GAS LIFT, 7,298 GAS LIFT, r' 8,057 PBR,8,098 PACKER,8,112 NIPPLE,8,129 - SOS,B,1/0 �ry APERF, 8,229-8,238 APERF, 8,243-8,245 _, Mandrel Details Top Depth Top Port 5... (TVD) Inc! OD Valve Latch Size TRO Run IPERF, N...Top(ftKB) (ftKB) (1 Make Model (in) Sery Type Type (In) (psi) Run Date Corn... 8.350-8.370 1 2,225.7 2,034.2 50.96 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 2 4,373.3 3,407.8 48.15 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 IPERF, - _ • 3 6,040.1 4,564.0 48.37MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 8.390-8,420 _ , 4 7,297.5 5,411.1 47.29 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 5 8,056.9 5,934.1 45.15 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/102011 PRODUCTION, 348,634 • TD,8,670 • • • Page 1 of 1 Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected 1 From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS I 1. (IPBRD)Type Work Code in RBDMS When a Form 10-403 is submitted requesting approval to plug a well for redrill,the initial reviewer(Art or Steve D.)will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked,we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Form 10-403 if"Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating"Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the"Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. „, n„ 1._..__ T___ �._\MI7 TXTT1✓ATT DT TT!`_P«D1 T'DT n/4+/' (11') McEvoy Gen 1 Wellhead • • ��'t�� McEvoy Gen 1 Tubing Head "-� Adapter PN M536797 1111 ` In 11"3K x 3-1/8 5K M 4 ill �. .0_. Height 8" �4� � 1111 � ��nl McEvoy Gen 1 Tubing Spool (Upper SSH) PN M536932 - a`k %. i \ _... 11" x11"3K _ , � � `\`� ; g14S0 with (2)3- /8 3K S " X. II ,I� 1t Bottom of Spool to Center NM 11;NI.f�f l A of 3-1118 3K Outlet for ;l, S Tubing x 7"Annulus(IA) : . 2 ; (� _ is 15.16" :--1. 11%1�%•._i �� /1;S ter_._ 1 1 1 1 N r McEvoy Gen 1 Int Casing 1 - ��a V. I Spool (lower SSH) �- `�•= PN M536590 V 16-3/42Kx 11"3K ... ,,iv. : with (2)3-1/8 3K SSO •lii'ii t BE oA Total Height 25.4" �rt Bottom of Spool to Center �- S of 3-1/8 3K Outlet for e, - `+ ■ IT rillik.- 10-3/4 x 7"Annulus(OA) Q �a �\�` �,„`■ ; 12.72„ ..t"TA �� McEvoy Gen 1 Casin Head — �'"' pii 1i _� - 16"SOW x 16-314 2K H t `•u g '��%��i fN. with (2)4" LPSO �.�.� �,ii4 ill d ��_ r' Total Height 21.2" �� Bottom of Head to Center (! p`M ;4JI .1 of 4" LP Outlet for Le-11111 16-3/4 x 10-3/4"Annulus 1 '� OOA is 8.3" .... 0, 1;,/1 ,.i..,: 1 1 i , , 1 , , , , , , , , , _ 1 1 , ---4 . i . I ASSEMBLY DRAWING OF ARCO WELLI-EAD 16"x IO-34"x 7" CASING x 3-I/2" TUBING • • Schwartz, Guy L (DOA) From: Huck, Drew <Andrew.Huck @conocophillips.com> Sent: Wednesday,July 17, 2013 10:19 AM To: Schwartz, Guy L(DOA) Cc: Ferguson,Victoria L(DOA); Doyon 141 Company Man;Senden, R.Tyler;Toomey,Ian A Subject: RE: 2G-11 (Sundry#313-275) Guy, As discussed in our conversation, here's what happened in this case: our crossover from the tubing hanger to our test joint was supposed to be 1'. What arrived at the rig was 2', which blocked our lower pipe rams, leaving us unable to test, which is why we asked for approval to delay testing of the lower rams until the tubing was out of hole (we tested our upper rams successfully). We've now found a shorter crossover to 4" (our workstring size) and will test the lower rams against 4", as we won't be using 3-1/2" again until running the completion, which will almost certainly be after another required BOP test anyway. We ended up getting the packer and tubing tail unintentionally as well—we had intended to only pull the upper completion, leaving the cement plug and tubing tail for a cement pilot exit with the coil tubing rig. The new plan will be to weight up to 11.4 ppg mud after step 33, mill cement, set a 44/2" scab liner and cement it in place,then run the upper completion. I will send a revised sundry reflecting this. Let me know if you have any questions or concerns. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska. Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Nome) 918-662-1804 (Fax) From: Schwartz, Guy L(DOA) [mailto:guy.schwartz @alaska.gov] Sent: Tuesday, July 16, 2013 3:21 PM To: Huck, Drew Cc: Ferguson,Victoria L(DOA); Doyon 141 Company Man Subject: [EXTERNAL]RE: 2G-11 (Sundry #313-275) Drew, Approved for this sundry( MASP<3000 psi ) ... make note in the BOP test report that verbal was given to test lower VBR ram after tubing hanger is pulled. In the future this request should be in the sundry application. Guy Schwartz Senior Petroleum Engineer 1 AOGCC • • 907-444-3433 cell 907-793-1226 office From: Huck, Drew [maiito Andre vv Huck lconocop hiillps.iom] Sent: Tuesday, July 16, 2013 2:05 PM To: Schwartz, Guy L(DOA) Cc: Ferguson, Victoria L(DOA); Doyon 141 Company Man Subject: RE: 2G-11 (Sundry#313-275) Correction: (Annular/2-7/8"X5"/Blind/Mud Cross/2-7/8"X5") Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Huck, Drew Sent:Tuesday,July 16, 2013 1:59 PM To: 'Schwartz, Guy L(DOA)' Cc: Ferguson, Victoria L(DOA); Doyon 141 Company Man Subject: RE: 2G-11 (Sundry #313-275) Guy, We've got 3-1/2"X6" VBR's in the top cavity and the same all the way in the bottom (Annular/3-1/2"X6"/Blind/Mud Cross/3-1/2"X6"), but our crossover joint for this particular wellhead is too long and blocks the bottom VBR's. We would like to test the top VBR's now and test the bottom set when we get out of the hole with the tubing. MPSP is less than 3,000 psi. Is this ok with you? Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATV 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) 2 • • From: Schwartz, Guy L(DOA) [macho:Cu' schwartz.cu iaska.f; ] Sent:Tuesday,July 16, 2013 12:13 PM To: Huck, Drew Cc: Ferguson, Victoria L(DOA) Subject: [EXTERNAL]RE: 2G-11 (Sundry #313-275) Drew, As per our phone conversation your changes to the procedure are approved. (steps 24-28 just after step 20) Please email a wellhead diagram as soon as you can for our records. Regards Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Schwartz, Guy L(DOA) Sent:Tuesday,July 16, 2013 11:38 AM To: 'Huck, Drew' Subject: RE: 2G-11 (Sundry #313-275) Drew, Call me back.. don't understand your reasoning on moving steps 24-28 yet. Other than that Im ok with changes. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Huck, Drew [maiIr_4o:Andreivtiuck iconocophillj s ccri,] Sent: Tuesday,July 16, 2013 11:09 AM To: Schwartz, Guy L(DOA) Subject: FW: 2G-11 (Sundry#313-275) Guy, I hadn't heard from Victoria on this—I wanted to make sure someone was in the loop on your side. One final correction: We will probably use 7" rams in the top set of pipe rams, not the bottom (correction to step 18). Give me a call when you get a chance. Thanks, 3 • • Drew Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Huck, Drew Sent: Friday,July 12, 2013 8:58 AM To: 'victoria.ferguson @alaska.gov' Subject: 2G-11 (Sundry #313-275) Victoria, A couple corrections and updates for this sundry: 1. The title for the 3ro section of the procedure(starting with step 9) reads"Pull 2-7/8"completion, replace with 3-1/2" completion"—I made a mistake here;as the procedure makes clear,this should be something more like"Pull and replace 7"and 3-1/2", remove and replace wellhead." I wanted to make sure there was no confusion about what we're proposing to do here. 2. I specified an 11" BOP stack in step 16—again,my mistake, Doyon 141 has a 13-5/8"stack as usual. 3. An update: Since I have a leak point through the bottom section of my wellhead, I've decided to do all my 7" work beyond pulling the existing 7"to the TOC in the OA after replacing the wellhead. Effectively,this means steps 24-28 will move ahead of step 20. << File: 2G-11 Approved Sundry.pdf>> Please let me know if you have any questions or concerns. Our cement plug has been pumped and we should be moving to this well soon. Thanks, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 4 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) II' 5 .. • • Schwartz, Guy L (DOA) From: Huck, Drew <Andrew.Huck @conocophillips.com> Sent: Thursday,July 18, 2013 4:07 PM To: Schwartz, Guy L(DOA); Ferguson,Victoria L(DOA) Cc: Toomey,Ian A;Allsup-Drake, Sharon K Subject: 2G-11 Revised Sundry Guy/Victoria, We'll probably need approval of this revised sundry by Monday at the latest(sooner is always better); I don't think we'll get to the revised portion of the work until later next week, but it all depends how things go. Ian will be filling in for me over the weekend, but feel free to call my cell if you have questions or concerns. Thanks, Drew Huck Drilling Engineer ConocoPhi lips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday,July 16,2013 12:13 PM To: 'Huck, Drew' pp -7 Cc: Ferguson,Victoria L(DOR) C� I D L' (i 6 Subject: RE:2G-11 (Sundry#313-275) Drew, As per our phone conversation your changes to the procedure are approved. (steps 24-28 just after step 20) Please email a wellhead diagram as soon as you can for our records. Regards Guy Schwartz Senior Petroleum Engineer AOGCC so JUL l3 907-444-3433 cell 907-7934226 office From: Schwartz, Guy L(DOA) Sent: Tuesday, July 16, 2013 11:38 AM To: 'Huck, Drew' Subject: RE: 2G-11 (Sundry #313-275) Drew, Call me back.. don't understand your reasoning on moving steps 24-28 yet. Other than that Im ok with changes. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Huck, Drew [t?tailto:Andrev,„ Iuc <„conocophilii 4,,cof ] Sent: Tuesday, July 16, 2013 11:09 AM To: Schwartz, Guy L(DOA) Subject: FW: 2G-11 (Sundry #313-275) Guy, I hadn't heard from Victoria on this—I wanted to make sure someone was in the loop on your side. One final correction: We will probably use 7” rams in the top set of pipe rams, not the bottom (correction to step 18). 1 Giv• e me a call when you get a chance. Thanks, Drew Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 303-328-5835 (Home) 918-662-1804 (Fax) From: Huck, Drew Sent: Friday,July 12, 2013 8:58 AM To: 'victoria.ferguson @alaska.gov' Subject: 2G-11 (Sundry #313-275) Victoria, A couple corrections and updates for this sundry: 1. The title for the 3rd section of the procedure (starting with step 9) reads"Pull 2-7/8"completion, replace with 3- 1/2"completion"—I made a mistake here; as the procedure makes clear,this should be something more like "Pull and replace 7" and 3-1/2",remove and replace wellhead." I wanted to make sure there was no confusion about what we're proposing to do here. 2. I specified an 11" BOP stack in step 16—again, my mistake, Doyon 141 has a 13-5/8"stack as usual. 3. An update:Since I have a leak point through the bottom section of my wellhead, I've decided to do all my 7" work beyond pulling the existing 7"to the TOC in the OA after replacing the wellhead. Effectively,this means steps 24-28 will move ahead of step 20. << File: 2G-11 Approved Sundry.pdf>> Please let me know if you have any questions or concerns. Our cement plug has been pumped and we should be moving to this well soon. Thanks, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 907-343-9790 (Cell) 2 G -l( • McEvoy Gen 1 Wellhead 4J1/ ,%':, tt� McEvoy Gen 1 Tubing Head �//' Adapter PN M536797 1111 /\ 1/11 11"3Kx3-1/85K _ � 1 ////_• Height 8" 'flU 4\ \0. �p` McEvoy Gen 1 Tubing Spool (Upper SSH)PN M536932 ,•_±�\ � _ _.. 11"x11"3K ;-• = a:'�\ ,' with(2)3-118 3K SSO 1r- IS _ ` N Total Height 27.4" Bottom of Spool to Center •I-.. !! :I 1 • of 3-1/18 3K Outlet for Tubing x 7"Annulus(IA) -_�_ 1 I' sli K is 15.16",i, ./. t___,._____ .,.., ,-k fil:ifilwil' Inli.. = tgr\t or -. ��!�fl��\rr ;hm .H ; �'' �r McEvoy Gen 1 Int Casing I' O �ill1 Spool(lower SSH) - ;II'; s �-,-; • \" PN M536590 �!� , 16-3/4 2K x 11"3K s: ��' with(2)3-118 3K SSO (4).- C--4-Siffil • ...., iL i� iI Total Height 25.4" (---4- Zill.S ! B ottom of Spool to Center � � : - of 3-118 3K Outlet for 10-314 x 7"Annulus(OA) 12.72" IN� \� 1111\2=_i \,` 1111 NNW a ■ '" ' —•% '��"" McEvoy Gen 1 Casin Head - 11�; `s„f¢. 16 SOW x 16-3/4 2K lin %I i I;;b ' ii,11 with(2)4” LPSO N. ) ` Total Height 21.2" �%_ 4:,Z1 �. „ Bottom of Head to Center II !1►` i 14.1 I of 4"LP Outlet for SCANNED � € ib 16-314 x 10-314"Annulus U . iy I■/■' �� I (OOA) is 8.3" Ili, 1 ■: I 1 i • , G I 1 . 03 .r A1t r,; • S/ .. 4. i� ASSEMBLY DRAWING OF ARCO WELLHEAD 16"x IO-3/4"x 7"CASING it 3-I/2" TUBING ti OF Tit, • • � \ I s v THE STATE Alaska. Oil and Gas ®f LA Coriservation Commission k GOVERNOR SEAN PARNELL 333 West Seventh Avenue �� O'"�+nn` • ¢. Anchorage, Alaska 99501 -3572 ALAS r�ry Main: 907.279.1433 1 JUN 1 2013 Fax: 907.276.7542 N SCN A Drew Huck Drilling Engineer S - I j '7 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G -11 Sundry Number: 313 -275 Dear Mr. Huck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4 11— Daniel T. Seamount, Jr. Commissioner A " K L DATED this V day of June, 2013. Encl. STATE OF ALASKA aj 9 At JUN 3 0 3 2 • A•KA OIL AND GAS CONSERVATION CON•SION IJ 6 , fi APPLICATION FOR SUNDRY APPROVALS ;'li:3 ric 20 AAC 25.280 1. Type of Request: Abandon I- Plug for Redrill I . r Perforate New Pool I Repair w ell i;r , Change Approved Program fa Suspend I" Rug Perforations Perforate r Pull Tubing I✓ . Time Extension ('""° Operational Shutdown E Re -enter Susp. Well r Stimulate I` Alter casing F . Other: I 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ] • Exploratory I" 184 - 117 • 3. Address: Stratigraphic J�` Service l 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 21149 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes I" No Pi 20 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25667 • Kuparuk River Field / Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 8670 - 6367 8129' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 16 104' 104' SURFACE 3282 9.625 3318' 2711' PRODUCTION 8600 7 8634' 6342' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8229 -8238, 8243 -8245, 8350 -8370, 8390 - 8420 6056 -6062, 6066 -6067, 6142 -6156, 6170 -6191 3.5 J - 8141 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER FHL PACKER • MD= 8112 TVD= 5973 SSSV - BAKER FVL SSSV • MD= 2176 TVD= 2000 12. Attachments: Description Surrmary of Proposal I4 . 13. Well Class after proposed work: Detailed Operations Program [ BOP Sketch (— Exploratory E Stratigraphic I" Development I✓. Service ) 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/17/2013 $ Oil I — Gas E WDSPL E Suspended l . 16. Verbal Approval: Date: VVINJ r GINJ ... WAG l Abandoned [ - " Commission Representative: GSTOR I SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Drew Huck @ 265 -6828 Email: Andrew.Huckna cop.com Printed Name Drew Huck Title: Drilling Engineer Signature , : Phone: 265 -6828 Date S ` .5 ; ' s a Commission Use Only Sundry Number: 313 5 Conditions of approval: Notify Commission so that a representative may witness 7� Plug Integrity 1•' BOP Test )t Mechanical Integrity Test I- Location Clearance I — Other: Op t57 - 1-0 .7ovDpsi, - lfie-"r1--7wtc pltiy P 1,g ccvv, c-7t a-ppr vcd per gc/1/1 C ZS.IIZL) Spacing Exception Required? Yes ❑ No V[l Subsequent Form Required: r _ .1_0 411 / APPROVED BY / /C)/0 pproved by: pprovcd application is vaRRY � 9rt from th 9val. Date: Form 10 -403 (Revised 10/2012) Submit Form ark ttachments in Duplicate 3. \ � 1-F 6 /W'3 0 N i61 IN' /A RBD JUN 11 201 I , (, • • — ConocoPhillips 0 2E3 Alaska ACUU P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 31 May 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 2G -11 (PTD 184 -117). Well 2G -11 was drilled and completed in 1984/1985 as an A -sand only producer. On 5/18/11 the well experienced a release of hydrocarbons to surface via a split sealed conductor and accompanying pressure relief valve, which was believed to be the result of a surface casing leak. A tubing plug was installed, the well was excavated in June /July of 2012, and the conductor was removed, but the surface casing was found to be in good condition. Subsequent work suggested that the leak point was actually located in the wellhead via the OA X OOA packoffs. An attempt was made to repair the OA X OOA packoffs, which appeared to initially be successful. However, when an MITOA was subsequently performed on 7/7/12, once a pressure of 900 psi was reached, the wellhead moved up 3 ". Further investigation suggests that the 10- 3/4 "X9 -5/8" surface casing was hung with an emergency slip arrangement after the mandrel hanger parted just below the wellhead during drilling of the production hole; however, the report notes that no slips were installed. This may have been what allowed the wellhead to move up. The OA X OOA packoffs have not been successfully tested since the last MITOA attempt. To restore integrity to this well, a rig workover will be performed to replace the entire wellhead, with the top —2,000' of 7" casing also being replaced. Before the workover, cement will be pumped across the A & C -sand perforations of this well to secure it for the wellhead replacement and to provide a means for a CTD cement pilot hole exit out of the 7" casing after the workover is complete. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A & C -sand perfs in this manner. The 3 -1/2" tubing in the tubing tail will be perforated to allow cement to go above the tubing tail and reduce the risk of contaminated cement at the tubing tail. After the rig workover, a pilot hole will be drilled through the cement and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point to begin drilling the CTD laterals. ,/ If you have any questions or require any further information, please contact me at 265 -6828. Regards, ? (12,76/ I+v¢ll r S to t / � - (e not /"a ii8'v /21 o-t ff Drew Huck h fe5ekve5 a Drilling & Wells Engineer 0CC9. e f t /I� ll� CPAI Drilling and Wells per &rn9? ( i /� 1 '173 • • 2G -11 Kuparuk Producer Capital Rig Workover & Subsequent CTD Sidetrack PTD #: 184 -117 Current Status 2G -11 is currently SI and the perforations are isolated with a CA -2 plug in the D- Nipple at 8,129' MD. Scope of Work for RWO ♦ Pull 3 -1/2" J -55 tbg from well ♦ Run 7" csg scraper, run CBL, set RBP, cut -pull 7" csg above TOC ♦ Remove McEvoy Gen 1 wellhead, replace with FMC Gen V system, starting with 10 -3/4" slip -lock ♦ Replace 7" casing above TOC ♦ MU and TIH w/ new 3 - %" L -80 gas lift completion to surface General Well info MASP: 2,922 psi using current SBHP and 0.1 psi /ft gradient Reservoir pressure /TVD: 3,536 psi / 6,142' TVD (TOP A5 -sand) SBHP survey 4/11/13 Wellhead type /pressure rating: McEvoy Gen 1 Tubing Head Adapter: 3 -1/8" 5K x 7- 1/16" 3K Tubing Spool: 7- 1/16" 3K x 11" 3K Interm. Csg. Spool: 11" 3K x 16 -3/4" 2K BOP configuration: Annular / Pipe / Blind / Flowcross / Pipe TIFL / MIT -IA / MIT -OA: MIT -IA Passed 04 May 2013 MIT -T Passed 10 June 2011 MIT -OA Passed 03 April 2009 — unable to test since then because of OAXOOA leak at wellhead. Well Type: Producer Estimated Start Date: 17 June 2013 Production Engineer: Mike Balog / Deanna Van Dam RWO Engineer: Drew Huck Work: 265 — 6828 Cell: 303 — 328 — 5835 E -Mail: Andrew.Huck @conocophillips.com • • Proposed Procedure Summary: Pre -RWO Work 1. RU E -Line: Obtain updated SBHP, Perforate tubing tail 8,126' - 8,127'. 2. RU Coil: Mill D- Nipple, Cement Perforations in accordance with CTD practices for cement pilot exit. a. Cement with 24 bbl of 17 ppg cement, target TOC is perfs in tubing tail. 3. RU Slickline: Tag top of cement and pressure test at least 72 hours after cement pumped. 4. Load well with fluid before rig moves on 5. Set BPV w/i 24 hrs of rig arrival. RWO: M/RU, BOP Test 6. MIRU Doyon 141. 7. Pull BPV, obtain SITP & SICP, and verify well is dead. 8. Set BPV & blanking plug, ND tree, NU BOPE & PT BOPE to 250/3,000 psi and annular to 250/3,000 psi. Note: Tubing head is Gen I McEvoy 3K, so while MASP is 2,922 psi, BOPE high test pressure will be 3,000 psi because of 3K top flange on tubing head. RWO: Pull 2 -7/8" completion, replace with 3 -1/2" completion 9. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 10. POOH laying down tubing spooling up control line. a. If tubing will not pull free, RU E -line: RIH w/ string shot & RCT to make cut. 11. RIH w/ 7" casing scraper on 3 -1/2" drillpipe to top of PBR or tubing stub, circulate well clean. POOH standing back drillpipe. 12. RU E -line: RIH w/ caliper,and CAST -M. Log from PBR/tubing stub back to surface to determine condition of casing and top of cement. Fire a string shot across the 2nd collar above the top of cement. 13. RIH & set an RBP (or IBP) below the top of cement. PT to 3000 psi and drawdown test to 0 psi. Dump 50' of sand on top of plug. POOH standing back drillpipe. 14. ND BOP stack, ND tubing head and set weight on 7" hanger. Slowly release lock down screws and allow casing to grow. 15. Spear and re -land 7" casing in tension. Cut off 7" casing growth. 16. NU 11" 5M BOP stack to the 3M casing head. 17. Cut the 7" casing above the top of cement. 18. C /out lower BOPE pipe rams to 7" solid body. PT BOPE to 250/3,000 psi and annular to 250/3,000 psi. Note: Top Casing head flange is Gen I McEvoy 3K, so while MASP is 2,922 psi, BOPE high test pressure will be 3,000 psi because of 3K top flange on casing head. 19. Spear the 7" casing. Circulate out the Arctic Pack from the OA w/ heated diesel & seawater. 20. POOH laying down 7" casing. 21. RIH w/ a 9 -5/8" casing scraper to the top of the 7" stub, circulate well clean. POOH standing back drillpipe. 22. RIH w/ the backoff tool to the top of the 7" casing stub, engage stub and backoff. POOH standing back drillpipe. 23. RIH w/ 7" casing spear, retrieve 7" casing stub. POOH standing back drillpipe. 24. RIH with 9 -5/8" storm packer and set at —200' 25. ND BOP Stack, back off on lockdown screws and remove casing head and starting head. a. If bottom part of wellhead does not come off, cut exposed 10 -3/4" pup joint off with exterior WACHS cutter or cut coupling. 26. Install FMC 10 -3/4" slip -lock system on exposed 10 -3/4" stub. a. Consider backing off 10 -3/4" pup and installing more pipe to bring OA outlet above ground level if starting head did not come off without cutting. 27. NU new FMC Gen V Tubing Head & BOP Stack, PT BOP's to 250/4,000 psi and annular to 250/3,500 psi. 28. Pull storm packer at —200'. • • 29. RU GBR casing crew & RIH w/ new 7" TC -II casing. 30. Circulate gelled diesel into the 7" x 9 -5/8" annulus to surface and screw into top of 7" casing, PT casing to 3000 psi. 31. ND BOPE and tubing head, pull 7" casing in tension and land in the slips. Cut excess 7" casing w/ Wachs cutter. 32. Test packoffs, NU tubing head and BOPE. C /out lower pipe rams to VBR's. Function test rams on test joint. 33. RIH w/ RBP retrieving head to top of plug, circulate to clean up sand and any remaining arctic pack, engage RBP and pull to release. POOH standing back drillpipe. 34. RIH w/ new 3 -1/2" gas lift completion to just above the PBR, spot CI brine, engage the PBR until fully located, space out, mark the pipe and pull out of the PBR. a. If tubing did not initially pull free, RIH w/ FHL packer and overshot on bottom of completion and stack packer. Drop the ball & rod, pressure up tubing to 2500 psi to set the FHL packer. While holding 1500 psi on the tubing, PT the IA to 2500 psi. Shear the PBR. Space out 7' from fully located, mark the pipe. POOH two stands. RWO: Finish Completion, RDMO 35. Space out w/ pups, MU hanger. Land the hanger, RILDS. 36. PT the tubing to 3,000 psi, bleed tubing to 1500 psi, PT the IA to 2,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 37. Pull the landing joint, install BPV. 38. ND BOPE. 39. NU and test tree. Pull BPV. 40. Swap well over to diesel through the SOV. 41. Set BPV. 42. RDMO. Post -RWO Work 43. Reset well house(s) and flowlines of adjacent wells. 44. Pull BPV. 45. RU Slickline: Set catcher in D nipple. Pull SOV from GLM, run DV. 46. Turn well over to Operations for pre -CTD wellwork. • • 2G-1 1 ConocoPhillips Proposed Completion Huck 05/31/13 Exi sting 16" 62 .5# Cemented H -40 originally Conductor: sealed SCSSSV, TRMAXX- CMT-SR -Sw/ 2.813" X- profile @ Arctic Pack Cement Shoe. Estimated TOC —2,121' MD. - 1,800' MD Passed MITOA to 1,800 psi 4 -3 -09 Tubing: 3% "MMG, 1 -%° i nj 3 -' /z" 9.3# L -80 EUE -8rd @ TBD Surface Casing: 9 - 35.9# J -55 BTC 3,318' MD / 2,711' TVD 1 Joint 10-%" 45.5# K -55 BTC on top 2 10 -%" Pup Joints 3 W MMG, 1 -W @ TBD Cement 3 %" MMG, 1 - W . Arctic Pack @ TBD 3 % "MMG, 1 - 1/1 TOC 15.8 ppg Estimated @ +/- 7,750' MD from CBL @ TBD run 9/17/1984. Some cement above. 3 W MMG, 1 -W @ TBD 010 Baker FHL Packer @ 8,112' MD 3 %" Camco D Nipple 2.75" @8,129' MD Tubing tail @ 8,140' MD —_ C-4 Perfor 8,229' - 8,238' Kuparuk `C' Sands @ 8,226' MD / 6,054' ND I B Perforations 8,243' - 8,245' I Formation Pressure '— ":'i I A -5 Perforations 8,350'- 8,370' I ; ; Kuparuk `A' Sands @ Estimated 11.1 ppge IA.-4 Perforations 8,390 - 8,420' I 8,325' MD / 6,125' TVD Production Casing: 7" 26# J -55 BTC 7" 26# L -80 TCII from 2,100' to surface 8,634' MD / 6,342' TVD @ 45° KUP 2G -11 Conoco Phillips ' • Well A ttributes Max Angle & Mt? TD Alaska Inc, Welibore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) � �,: l +ull pc 500292114900 KUPARUK RIVER UNIT PROD 52.47 3,300.00 8,670.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Re Release Date " "" SSSV: TRDP 35 1/17/2010 Last WO: 40.98 9/17/1984 Well Contg: - 29-1t , 5/2/2013 183'51 PM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,436.0 4/25/2013 Rev Reason: TAG, RE -SET PLUG haggea 5/2/2013 Casing Strings Ill. PP Casing Description String 0.. String ID .. Top (ftKB) Set Depth (f .. Set Depth (TVD) ... String WE.. String String Top Thrd HANGER, 32 - CONDUCTOR 16 15.062 36.0 104.0 104.0 62.50 H Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd __ - - 1 ' SURFACE 95/8 8.921 35.9 3,317.6 2,710.5 36.00 J -55 BTC itt 10.75 "5c9.875" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 34.0 8,634.3 6,341.7 26.00 L -80 BTC Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 , 2.992 32.0 8,141.1 5,993.6 9.30 J -55 EUE -8rd Completion Details Top Depth (ND) Top Inc! Semi... Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 32.0 32.0 -0.04 HANGER MCEVOY TUBING HANGER 3.500 2,176.3 2,000.2 47.34 SAFETY VLV BAKER FVL SSSV 2.810 CONDUCTOR, 8,098.0 5,963.0 45.03 PBR BAKER PBR 2.810 38 - 104 8,111.7 5,972.7 44.99 PACKER BAKER FHL PACKER 2.937 8,128.8 5,984.8 44.93 NIPPLE CAMCO D NIPPLE 2.750 8,140.3 5,993.0 44.90 SOS BAKER SHEAR OUT SUB. ELMD TTL @ 8132' during SWS PPROF on 3.000 SAFETY VLV, 09/08/2004 2,178 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Intl Top (ftKB) (ftKB) (°) Description Comment Run Date ID (in) GAS LIFT, 8,128.8 5,984.9 44.93 PLUG CA - 2 PLUG 4/25/2013 0.000 2,226 Perforations & Slots Shot Top (ND) Bin (TVD) Dens Top (ftKB) Stan (ftKB) (ftKB) (ftKB) Zone Date (sh.- Type Comment 8,229.0 8,238.0 6,055.8 6,062.2 C-4, UNIT B, 6/26/1994 6.0 APERF 90 deg. Phasing; 2 1/8" EnerJet 2G-11 8,243.0 8,245.0 6,065.8 6,067.2 UNIT B, 2G-11 6/26/1994 6.0 APERF 90 deg. Phasing; 21/8" EnerJet SURFACE " • 8,350.0 8,370.0 6,141.6 6,155.7 A -5, 2G -11 10/30/1984 4.0 IPERF 90 deg. Phasing; 4" Schlum Casing 10.75"x9.875 ", A 36 ,' 8,390.0 8,420.0 6,169.9 6,191.0 A -4, 2G -11 10/30/1984 4.0 IPERF 90 deg. Phasing; 4" Schlum Casing GAS LIFT, Notes: General & Safety 4,373 End Date Annotation 10/21/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 - 6/14/2011 NOTE: PSI CONTROL LINE TO 6000 PSI GAS LIFT, 4 GAS LIFT, 7,298 GAS LIFT, 8,057 U PBR, 8,098 PACKER, 8,112 -,�� NIPPLE, 8,129 I PLUG, 8,129 ' A I SOS, 8,140 APERF, 8,229A,238 APERF, -_ 8,243 -8,245 Mandrel Details Top Depth Top Port (ND) Inc! OD Valve Latch Size TRO Run IPERF, - ' N... Top (ftKB) MKS) ( °) Make Model (in) Sery Type Type On) (poi) Run Date Corn... 0,350 - 0,370 1 2,225.7 2,034.2 50.96 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 2 4,373.3 3,407.8 48.15 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 IPERF, 3 6,040.1 4,564.0 48.37 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 8,390 - 0,420 4 7,297.5 . 5,411.1 47.29 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 5 8,056.9 5,934.1 45.15 MMH FMHO 1 GAS LIFT DMY BK 0.000 0.0 6/10/2011 I , 3 PRODUCTION, 34-8,834 ■ 74,8,870 • • Page 1 of I Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. 1 • 1 Roby, David S (DOA) From: Huck, Drew < Andrew.Huck @conocophillips.com> Sent: Wednesday, June 05, 2013 7:12 AM To: Roby, David S (DOA) Subject: RE: Sundry application for 2G -11 well Dave, They will be targeting a combination of both the existing reserves and new reserves — this is part of the same greater project as wells (from east to west) 2F -11, 2F -19, 2F -18, 2F - -17, [2G -11], 2G -12, and 2G -13 targeting the southern periphery of Kuparuk. The first 3 have been drilled and the fourth is currently being drilled. Let me know if you have any further questions. Regards, Drew Huck Drilling Engineer ConocoPhillips Alaska, Inc. ATO 1566 907-265-6828 303 - 328 -5835 (Cell) 918 - 662 -1804 (Fax) From: Roby, David S (DOA) [mailto:dave.robyCa)alaska.gov] Sent: Tuesday, June 04, 2013 5:12 PM To: Huck, Drew Subject: [EXTERNAL]Sundry application for 2G -11 well Drew, I am reviewing your application to plug the subject well so that a couple thousand feet of the production casing and the wellhead can be replaced. I'm tasked with reviewing applications like this to see if there are any waste considerations and noticed that prior to being shut in the well was still a decent producer. The sundry indicated that after the casing and wellhead are replaced that the well be prepared so that CTD laterals can be drilled, which raises a quick question. Are the proposed laterals going to be targeting the same reserves as the existing wellbore or will they be targeting new reserves, or a combination of the existing and new reserves? Thanks, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793 -1232 i tfr WELL LOG TRANSMITTAL MAY 10 2013 AOGCC; To: Alaska Oil and Gas Conservation Comm. M. Attn.: Makana Bender `mit \\,/ 333 West 7th.Avenue, Suite 100 � Anchorage, Alaska 99501 2-2.54A 77 RE: Multi Finger Caliper(MFC): 2G-11 Run Date: 9/18/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 2G-11 Digital Data(LAS), Digital Log file,Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21149-00 SCANNED MAR 13 2D14 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: C) I\`j Signed: 11.44,4,-(li)l)),azek 1 4 .LJ • STATE OF ALASKA Ma D ;; ALAO OIL AND GAS CONSE RVATION COMISION REPOR O SUNDRY W ELL OPERATIONS OG : I I. Operations Performed: Abandon r " Repair w ell Plug Perforatio �° Stimula Other SC Repair Alter Casing r` Rill Tubing r Perfo New Pbo r" Waiver r Time Extension r Change Approved Program rOperat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: v' 4. Well Class Before Work: ✓ 5. Permit to Drill Number: v _ ConocoPhillips Alaska, Inc. Development F. Exploratory r 184 -117 ✓ 3. Address: 6. API Number: Stratigraphic r Service 50- 029 - 21149 -00 P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation (Lease Number): • 8. Well Name and Number: 1 ADL0025667 2G -11 9. Field /Pool(s): ✓ Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: 1 Total Depth measured 8670 feet Plugs (measured) None true vertical 6367 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8112 true vertical 0 feet (true vertucal) 5973 Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 16 104 104 1640 630 SURFACE 10.75' 3282 13.75 3317 2710 3520 2020 PRODUCTION- 8600 10 8632 6340 7240 5410 SCANNED J 10 2013 Perforation depth: Measured depth: 8229' -8420' True Vertical Depth: 6056' -6191' Tubing (size, grade, MD, and TVD) 3.5, J -55, 8141 MD, 5993 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 8112 MD and 5973 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p7, Service r Stratigraphic r X 15. Well Status after work: Oil e Gas r , WDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r . 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -002 Contact MJ Loveland /Martin Walters Printed Name MJ Loveland � 'e Well Integrity Project Supervisor Signature j Phone: 659 - 7043 Date 5/4/13 ROM MAY — 9 7013. Form 10 -40 Revised 10/2010 /l 2 Submit Original Only • • 2G -11 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary • 06/07/11 Secure well with CA -2 plug in D nipple @ 8129'. 06/10/11 Perform a passing MITT to 2500, Initial T /I /O /OO = 700/750/0/0, pressure up Tubing to 2500 T /I /O /OO = 2500/800/0/0, 15 mins T /I /O /OO = 2450/800/0/0, 30 mins T /I /O = 2430/800/0/0. 06/30/121 Excavate to a final depth of 19'. 07/05/12 Cut and remove 15' of 16" conductor, remove cement to expose surface casing - surface casing in good condition. Rig up N2 on OA (leak hunt) and pressure up to 130 psi when notice leak from inside of starter head - bled OA to 0 psi. 07 /31 /121We1d 16" conductor back in place. 08/04/12 After several attemps to renergize OC pack off and failed MITOA's work was stopped to discuss next steps to take. 'Late April the decision was made to rework the well with a rig. •w • • RECEIVED ConocoPhillips f Alaska OG P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 4, 201 Commissioner Dan Seamount Alas Oi and Gas Conservation Commission 333 West 7 Avenue, Suite 100 An A 99501 Commiss Seamount: Enclose p lease find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. we ll 2G -11, PTD 184 -117, Sundry 312 -002 surface casing repair. Afte fi the surface casing in good condition leak detection diagnostics were perf finding the leak at the outer casing pack off /surface casing interface. Several uns l attempts were made to repair the pack offs. th last several months ConocoPhillips has evaluated several repair methods to fix p ack offs. In late April the decision was made to repair the well with a work over rig. This 10 - 404 closes Sundry 312 -002 with no repair completed. Pl ease call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, ° M oveland ConocoPhillips Well Integrity Projects Supervisor r , • • Ifati[E DIF AusEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Martin Walters , ry � 1 (1 Well Integrity Project Supervisor 'l� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2G -11 Sundry Number: 312 -002 Dear Mr. Walters: WOWED JAN 4 21)16 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '&)" Daniel T. Seamount, Jr. Chair DATED this S day of January, 2012. Encl. • STATE OF ALASKA c 1 T ' ._'_ ' • Y ALASKA OIL AND GAS CONSERVATION COMMISSI '�/ 0 4 Z°12 i APPLICATION FOR SUNDRY APPROVALS SA jA 20 AAC 25.280 »qk,B ' :i a t afl t.LOft3. ot1111113SIOfl 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well FT • Change PC din gram r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:SC Repair P 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ri . Exploratory r 184 -117 3. Address: Stratigraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 21149 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r/ 2G -11 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025667 - Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8670 ' 6367 ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 68 16 104' 104' 1640 630 SURFACE 3282 9 -5/8 3317' 2710' 3520 2020 PRODUCTION 8600 7 8632' 6340' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8229' -8420' 6056' -6191' 3.5 J -55 8141 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER = BAKER FHL PACKER MD = 8112, TVD = 5973 SSSV = BAKER FVL MD = 2018, TVD = 1886 12. Attachments: Description Summary of Proposal p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development W Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2012 Oil r • Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland /Martin Walters Printed Name Martin Walters Title: Well Integrity Project Supervisor Signature r`, ;; L,n;, i I ` ;/. , 6,10 Phone:659 -7043 Date: 12/31/11 Commission Use Only Sundry Number: 3i Z -cot Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r r 14 UL� !^cam a.G Other: * /-----pia G��"4 1 Subsequent Form Required: /O ► zi o y APPROVED BY �� 1 ` Approved by COMMISSIONER THE COMMISSION Date: J AO 83 I iS 't ' �, /1 9 , (2- 4.1 RIGINAL � �4Y Submit in Duplicate' ` * ' • • ConocoPhillips Alaska, Inc. Kuparuk Well 2G -11 (PTD# 184 -117) SUNDRY NOTICE 10 -403 APPROVAL REQUEST 12/31/11 This application for Sundry approval for Kuparuk well 2G -11 is for the shallow inspection and repair of the surface casing. The 2G -11 well that was drilled and completed in 1984/1985 as a development well. / On 5/18/11 the well experienced a release of hydrocarbons to surface via a split sealed conductor and ,/ accompanying pressure relief valve. The well is currently secured with a tubing plug and ConocoPhillips intends to excavate around the well head, remove the conductor, investigate the suspected surface casing leak, and patch the surface casing, if possible. With approval, inspection and possible repair of the surface casing will require the following general steps: 1. Ensure the well is secure with a tubing plug. (Complete) 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Excavate wellhead location to a depth of <26'. 4. Remove the previous sealant treatment from the conductor. ,/ 5. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 6. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Then start removing conductor to find damage to surface casing. Notify AOGCC Inspector for opportune to inspect. 7. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 8. If a patch is required, QA/QC will verify the repair for a final integrity check. 9. Perform MITOA 10. Install anti - corrosion coating as specified by CPAI Corrosion Engineer. 11. Replace the conductor and fill the void with cement and top off with sealant. 12. Backfill as needed with gravel around the wellhead. 13. Remove plugs and return the well to service. 14. File 10 -404 with the AOGCC post repair. / � I /two ptoc Well Integrity Project Supervisor 12/31/2011 f a • • , .. �. KUP • 2G -11 J ConocoPhillips t Well Attributes Max Angle & MD TD al Alask;1.Inu Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) b 5 00292114900 KUPARUK RIVER UNIT PROD 52.47 3,300.00 8,670.0 Lnlncmvl ps , Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••• WellConfiA: - 11,6/14/2011253:16 PM SSSV: TRDP 35 1/17/2010 Last WO: 40.98 9/17/1984 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: SLM 8,461.0 I 6/7/2011 Rev Reason: TAG, GLV C /O, SET PLUG I ninam 6/14/2011 Casing Strings IIIR , Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 36.0 104.0 104.0 62.50 H z`" Casing Description String 0... String ID ... Top (R108) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 32 SURFACE 95/8 8.765 35.0 3,316.6 2,709.9 36.00 J -55 BTC „`. 10.75 "x9.875" ", Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd • PRODUCTION 7 6.276 31.4 8,631.7 6,339.9 26.00 L -80 BTC Tubing Strings Tubing Description String 0... String ID ... p (ftKB) 5et Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2 I To 32 I 8141.1 I 5 I 9 I J -55 EUE -8rd Completion Details Top Depth (TVD) Top Intl Nomi... Top (MB) (ftKB) ( °) Item Description Comment ID (In) 32.0 32.0 - 0.04 HANGER MCEVOY TUBING HANGER 3.500 2,017.7 1,885.6 41.47 SAFETY VLV BAKER FVL SSSV 2.810 CONDUCTOR,_ 8,098.0 5,963.0 45.03 PBR BAKER PBR 2.810 36-104 8,111.7 5,972.7 44.99 PACKER BAKER FHL PACKER 3.000 8,128.8 5,984.8 44.93 NIPPLE CAMCO D NIPPLE 2.750 8,140.3 5,993.0 44.90 SOS BAKER SHEAR OUT SUB. ELMD TTL @ 8132' during SWS PPROF on 3.000 SAFETYVLV, ( �� 1 09/08/2004 2,018 J 4 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID (In) Gas LIFT, 8,129 5,984.9 44.93 PLUG CA - 2 PLUG 6/7/2011 0.000 2,067 Perforations & Slots 0 Shot P Top (TVD) Btm (TVD) Dena Top (MB) BM (ftKB) (RKB) (ftKB) Zone Date (.h..• Type Comment SURFACE 8 ,229 8,238 6,055.8 6,062.2 C-4, UNIT B, 6/26/1994 6.0 APERF 90 deg. Phasing; 2 1/8" EnerJet 2G-11 J I 8,243 8,245 6,065.8 6,067.2 UNIT B, 2G -11 6/26/1994 6.0 APERF 90 deg. Phasing; 2 1/8" EnerJet I 8,350 8,370 6,141.6 6,155.7 A -5, 2G -11 10/30/1984 4.0 IPERF 90 deg. Phasing; 4" Schlum Casing 10.75N9.875 35.3,317 8,390 8,420 6,169.9 6,191.0 A-4, 2G-11 10/30/1984 4.0 IPERF 90 deg. Phasing; 4" Schlum Casing , GAS LIFT, ___ Notes: General & Safety 4,373 End Date Annotation 10/21/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 6/14/2011 NOTE: PSI CONTROL LINE TO 6000 PSI GAS LIFT, 6,040 GAS LIFT, 7,298 GAS LIFT, __ 8,057 PBR, 8,098 PACKER, 8,112 .- NIPPLE : 8,12 9 PLUG, 8,729 S OS,8,140 i APERF. ' 8,229-5238 APERF, - -_ 8,243 -8.245 a Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run IPERF, Stn Top (818) (RKB) (9 Make Model (In) Sery Type Type (in) (pail Run Date Com... 8,350 -8,370 1 2,067.1 1,923.4 43.30 MMH 3 1/2x 1 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 2 4,373.3 3,407.8 48.15 MMH 31/2x 1 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 IPERF. , ' 3 6,040.1 4,564.0 48.37 MMH 31/2 x 1 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 8,390 -5420 4 7,297.5 5,411.1 47.29 MMH 3 1/2 x 1 1 GAS LIFT DMY BK 0.000 0.0 6/8/2011 5 8,056.9 5,934.1 45.15 MMH 3 1/2 x 1 1 GAS LIFT DMY BK 0.000 0.0 6/10/2011 PRODUCTION, T1- 8 • (' 06/08/07 Schlumbel'gel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth CANNED JUN 1 4 2007 ~ 1 20015 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage, AK 99501 ~v I~L.I- JI~ Field: Kuparuk Well Job# Log Description Date BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1 C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 10-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-08A 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1H·07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1B·01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1G·03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1 J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . Schlumbel'ger NO. 3429 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth í"r~[; rit,H-\.F~"~ {~W/~J\J~¥!;L (' FD fì fl- 90 t'¡"'" ~ , V _< V Ú £. U:) 07/08/05 l<6lf- { t 7 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL " 2G-02 / ~ '( -j).1 11047334 BHP SURVEY 06/30105 1 I 2G-13 I~ ~i - i)' 'T 11047336 BHP SURVEY 07/01/05 1 J, 2G-11 If'j -i ('7 11047337 BHP SURVEY 07/01/05 1 y 1Y-14J3~~ (1) 11022907 LEAK DETECTION LOG 06/30105 1 ¡j 3H-19 187.. /J J 11022907 PRODUCTION PROFILE 06/28105 1 ¡j, 1J-Ó3~(A -C).."f 11022893 PRODUCTION PROFILE 06/17/05 1 '1 1 L-09 ,'iD.·1i j C( 11022895 PROD PROFILE W/DEFT 06/19/05 1 .)', 3S-10 ,J.oÂ-l) 1 11001235 PROD PROFILE W/DEFT 06/14/05 1 .i 3F-04 IJ:J' . J.lS 11022891 INJECTION PROFILE 06/15/05 1 1 Y -26A ¡ ~jJ'11 ~ 11022892 PROD PROFILE W/DEFT 06/16/05 1 ;./ 1E-112Jvi.1-({iI 11047339 INJECTION PROFILE U l <- 07/03/05 1 j 1E-102 )..(;'1 ""J...31 11047340 INJECTION PROFILE Vi (... 07/04/05 1 SIGNED: 1/ 1 / (,i t/i~ DATE: I. I Ôlz¿j Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk Color -/' CD "-' ''\ kJ;' ~,I ,..(}'..... ("" " " . " - r :¿t't J" --. Schlumberger NO. 3213 Schlumberger -DCS 2525 Gam bell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 9/2- 7 09/24/04 Company: Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job# Log Description Date BL Color <¡ 'f -OL{ 2- 3C-06 10922465 PRODUCTION PROFILE W/DEFT 09/19/04 1 't5-OS' 2A-18 10802936 PRODUCTION PROFILE W/DEFT 09/12/04 1 ,-t.. 038 2B-12 10802934 INJECTION PROFILE 09/10/04 1 l' If- I ~ 1./ J 2X-11 10802933 PRODUCTION PROFILE 09/09/04 1 }~l- ~S 1B-10 10922467 PRODUCTION PROFILE 09/21/04 1 f) ,. ~5 3G-08 10802935 PRODUCTION PROFILE 09/11/04 1 ra£-OZ ( 2F-08 10922466 PRODUCTION PROFILE 09/20/04 1 t ~'f - (( 7 2G-11 10884019 PRODUCTION PROFILE 09/08104 1 ,~2.-,~~ 1H-19 10802940 INJECTION PROFILE 09/14/04 1 1 2.-0 ~1H-07 10802939 INJECTION PROFILE 09/14/04 1 ~~2 -Dfo 1A-14 10802938 INJECTION PROFILE 09/13/04 1 ( '1"'0702H-03 10802945 INJECTION PROFILE 09/18/04 1 lß~-05' 1Y-02 10802942 INJECTION PROFILE 09/16/04 1 't.1... olf'f 1Q-13 10802941 INJECTION PROFILE 09/15/04 1 '10 7 -H"2. 3H-09 10922468 INJECTION PROFILE 09/22/04 1 I 'iJ6-/tfl 2T-02 10802944 TEMPERATURE SURVEY 09/18/04 1 'fit) - / r,{p1 A-26 10802943 LEAK DETECTION LOG 09/17/04 1 Kuparuk CD .~ ,,-,. SI€;CL I. kj'~ ~ANNED NO\! {j 8 DATE: /f 04 Please sign and retu rLe copy of this transm ittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510- 4. Location of well at surface Stimulate __ Plugging Repair well 5. Type of Well: Development Exploratory Stratigraphic Service 243' FNL, 272' FWL, SEC. 5,-T10N, R9E, UM At top of productive interval 1345' FSL, 1460' FEL, SEC. 5, T10N, R9E, UM At effective depth 1197' FSL, 1293 FEL, SEC. 5, T10N R9E, UM At total depth 1149' FSL, 1214', FEL, SEC. 5, R9E, UM 12. Present well condition summary Total Depth: measured 8670' true vertical 6366' feet Plugs (measured) feet NOI~E Perforate X Other 6. Datum elevation (DF or KB) 14{)' RKI~ 7. Unit or Property name Kuparuk River Unit fest 8. Well number 2G-11 9. Permit number 84-117 10. APl number 50-029-21149 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured 8549' feet Junk (measured) true vertical 6281' feet ~ Casing Length Size Structural Conductor 104' 1 6" Surface 331 6' 9-5/8" Intermediate Production 8632' 7" Liner Perforation depth: measured 8350' -8370', 8390' - 8420' true vertical 6141'-6156', 6170'-6191' Tubing (size, grade, and measured depth) 3 1/2", 9.3#, J-55 TUBING @ 8141' Packers and SSSV (type and measured depth) BAKER FVL SSSV @ 2031', Baker FHL PACKER @ 8119' Cemented Measured depth True vertical depth 202 SX CS II 104' MD 104' TVD 950X PF "E" & 3316' MD 2709' TVD 370 SX PF "C" 450 SX CLASS G 8632' MD 6340' TVD RECEIVED OCT 2 7 1994 Naska.0il & Gas Cons. Commission Anch0ra~e 13. Stimulation or cement squeeze summary Intervals treated (measured) PERFORATE 8229' -8238' MD (6056'-6062' TVD) AND 88243' - 8245' MD (6066'-6067' TVD) W/W/6 SPF 90 DEG PHASING Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operati°n Reoresentative Daily Average Production orln!ection Data OiI-Bbl Gas-Mcr Water-Bbl CasingPressure 565 262 0 920 950~ 432 0 1200 Tubing Pressure 134 164 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true-and correct tO the best of my knowledge. Si~lne~ ~ ~ Title Wells Superintendent Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICAIE. ARCO Alaska, Inc. Subsidiary of Atlantic Richfield. Company WELL DATE 6i~/q4 DAY TI:ME /5'io 1~,3C i'775" DESCRIPTION OF WORK 1~.,4F~T~ "C"',~,ub CONTRACTOR / KEY PERSON PBI'D (RKB) II.~T T_Ap (RKB) - DATE LOG ENTRY KUPARUK RIVER UNIT · WELL SERVICE REPORT ii IA~C/CC# - SCA~ ! ~,~o~,~'~ ~z./,~.~.~ ,,. Im~ cos; u~. IACC~'r~ COST [SSSV ~ / STA~S I vlcI~CK THIS BLOCK IF SUMMAEY IS CO~ ON BACK Iff CO~'L~T~ I I ~coM~L~ STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, In~;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 243' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 1345' FSL, 1460' FEL, Sec. 5, T10N, R9E, UM At effective depth 1202' FSL, 1281' FEL, Sec. 5, T10N, R9E, UM At total depth 1149' FSL, 1214' FEL, Sec. 5, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 8670' 6366' 8549' 6281' feet feet. feet feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 149' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-11 Producer 9. Permit numb. or/~-~provaJ. il0. APl number so-029211 4900 11. Field/Pool Kuparuk River Oil Pool Casing Length Size Structural Conductor 1 04' 1 6" Intermediate 331 6' 9 - 5 / 8" Production Liner Perforation depth: 8632' 7" Cemented 202 Sx C.S. II 950 Sx Permafrost E 370 Sx Permafrost C 450 Sx Class "G" measured 8350'-8370', 8390'-8420' MD true vertical 6142'-6156', 6170'-6191' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 Ib/ft, EUE, 8141' MD Packers and SSSV (type and measured depth) Measured depth True vertical depth 104' 104' 3316' 27O9 8632' 6340' RECEIVED JAN 51 .O~l & Gas Cons. Anch0ra~ Packers: Baker FHL 8119' MD. SSSV: Baker FVL, 2031' MD 13. Stimulation or cement squeeze summary Intervals treated (measured) 8350'-8370', 8390'-8420' MD Treatment description including volumes used and final pressure 1388 bbls Gelled Water, 106,000 #16/20 M Carbo-Lite Proppant, WHTP = 3830 PSI 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 884 3 76 0 1008 732 46 850psi 800psi 16. Status of well classification as: Oil X Gas Suspended Service 150psi 185psi 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. _ .. IS,gned ~ ~ _~ Form 10-404 F~ 66/15/88 Title Sr. Operations Engineer .ARCO Alaska, Inc'~ Subsidiary of Atlantic Richfield Company WELt 2611 PBDT C~TRACTOR '. ~.tt, b~,~ %,,, - ~,,~ ~,, ~' REMARKS WELL SERVICE REPORT I DAYS I DATE I IO FIELD- DISTRICT- STATE I~uP~R.u~ OPERATION AT REPORT TIME ! c.c. Z ,~o~5 ~ ~iL - I( 6o /Yell. gsa'. Co~,'l- ISsooo~ 01:oo OL~:oo 07',00 -- _ 70o 0~ 4 . g Z~, n , ~1~ /b;,/9 IT~o /9;30 Anchora~ [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA "-'"' tO ALASKA OIL AND GAS CONSERVATION COMMI~SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 243' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 1345' FSL, 1460' FEL, Sec. 5, T10N, R9E, UM At effective depth 1202' FSL, 1281' FEL, Sec. 5, T10N, R9E, UM At total depth 1149' FSL, 1214' FEL, Sec. 5, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8 6 7 0' feet 6366' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 14Q' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-11 Producer 9. Permit number/approval number 84-117 10. APl number 50-0292114900 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 5 4 9' feet true vertical 6281 ' feet Junk (measured) Casing Structural Conductor Length Size 104' 16" Cemented 202 Sx C.S. II Measured depth True vertical depth 104' 104' Intermediate 3 31 6' Production 8 6 3 2' Liner Perforation depth' measured true vertical Tubing (size, grade, and measured depth) 9 - 5 / 8" 950 Sx Permafrost E 331 6' 370 Sx Permafrost C 7" 450 Sx Class "G" 8 6 3 2' 8350'-8370', 8390'-8420' MD 6142'-6156', 6170'-6191' TVD 3 1/2", J-55 9.3 Ib/ft, EUE, 8141' MD Packers and SSSV (type and measured depth) 2709' 6340' ; .,-.,..; , ,_ . JUL Packers: Baker FHL 8119' MD. SSSV: Baker FVL, 2031' MD 13. Attachments Description summary of proposal _ Detailed operation program _X_.. BOP sketch _ Hydraulically refracture the A Sand with 110000# of 16/20M carbolite and 1325 bbls of Gelled Water. 14. Estimated date for commencing operation July 12, 1~){~) 16. If proposal was verbally approved Name of approver 15. Status of well classification as: Oil __ Gas __ Suspended Date approved S ervi ce Signed ~')~c~_ that the. foregoincl is true ~a~d correCtFoR COMMISS~t° the rl~st OfUsEmY ONLykn°wledge' Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test __ Subsequent form require 10- Approved by the order of the Commission ORIGINAL SIGNED BY LONNIE C, Commissioner Form 10-403 Rev 5/03/89 Date )AP P r° va I .¢~...~::;r~ Approved Copy Returned SUBMIT IN TRIPLICATE Messrs Lyden and Wade June 29, 1989 Page 3 Kuparuk Well 2G-11 'A' Sand Re-Fracture Procedure - . 1. Obtain a 24 hour well test. ,, . . . . MIRU Slickline unit. RIH with tubing end Iocator and tag fill. Pull GLV's at 2067', 6047', and 8063' and run DVs. RIH with Standing Valve and set in Camco 'D' nipple. Pressure test tubing to 4500 psi to ensure DVs are set. RIH and pull SV. RDMO Slickline. If less than 50 feet of rathole is discovered during the pre-frac wireline operations, a CTU cleanout may be required. Consult with Operations Engineering to determine if the CTU is necessary. MIRU fracture equipment. Install "Tree Saver". Carry out all quality control procedures (Onsite Operations Engineering). The specific procedures will depend on the vendor selected. Check Carbo-Lite for fines due to excessive handling. Obtain a sample of the Carbo-Lite and the gelled water with breaker and from the pad and slurry stages. Record the proppant weight before and after the treatment. Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressureS following the ISIP. Expected wellhead treating pressure: WHTPE = 4000 psig Fracture Gradient = 0.70 psi/ft Tubing Friction -- 300 psi/1000 ft (6000' TVD) (8141' MD) @25 BPM * If treating pressure during the job exceeds 6000 psi, reduce rate to a minimum of 15 BPM. If pressure exceeds 6500 psi, shut down job and confer with Engineering. 8. Rig down frac equipment. Follow attached flowback schedule. After well has completed flowback, obtain 24 hour well test. Contact Operations Engineering for a new gas lift design when necessary. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 243' FNL, 272' FWL, Sec. 5, T10N, R9E, UM At top of productive interval 1345' FSL, 1460' FEL, Sec. 5, T10N, R9E, UM At effective depth 1202' FSL, 1281' FEL, Sec. 5, T10N, R9E, UM At total depth 1149' FSL, 1214' FEL, Sec. 5, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 8 6 7 0' feet 6366' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 140' 7. Unit or Property name Kuparuk River Unit 8. Well number 2G-11 Producer 9. Permit nurn. ber~approval number , 84-117 ./' ~ - ,~0"'7 I10. APl number $0-029211 4900 I11. Field/Pool Kuparuk River Oil Pool Effective depth' measured 8 5 4 9' feet true vertical 6281 ' feet Junk (measured) Casing Structural Conductor Length Size 104' 16" Cemented 202 Sx C.S. II Intermediate 3316' 9-5/8" Production 8 6 3 2' Liner Perforation depth: measured true vertical !! 950 Sx Permafrost E 370 Sx Permafrost C 450 Sx Class '!G" 8350'-8370', 6142'-6156', 8390'-8420' MD 6170'-6191' TVD Tubing (size, grade, and measured depth) 3 1/2", J-55 9.3 lb/,t, EUE, 8141' MD Packers and SSSV (type and measured depth) Packers: Baker FHL 8119' MD. SSSV: Measured depth True vertical depth 104' 104' 331 6' 27'O9' 8632' 634O' -. Baker FVL, 203~';""M~ri~r'°ra~e 13. Stimulation or cement squeeze summary Intervals treated (measured) 8350'-8370', 8390'-8420' Treatment description including volumes used and final pressure Carbo-Lite Proppant, WHTP = 4900 PSI MD 185 bbls Gelled Diesel, 14,300 #20/40 M 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mc, Water-Bbl Casing Pressure feet Prior to well operation Subsequent to operation 425 243 0 949 772 0 0 48O Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 ~lev 06/15/88 163 157 Date //~,¢~, ~:~ ~) ~ / SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL )NTRACTOR ~= ~,=// - REMARKS IPBDT , WELL SERVICE REPORT tFIELD - DISTRICT- STATE OPERATION AT REPORT TIME f--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK REMARKS CONTINUED:. \:jo: ,' · ACCUM. DESCRIPTION DALLY TOTAL CAMCO OTIS S~HLUMBERGER DRESSER-ATLAS DOWELL z/z/ .c ~ ?. ~.~ HALL~D'J'RTO;; W~ T c~ ~ ~- / 5 ~ ARCTIC COIL TUBING FRACMASTER B. J. HUGHES Roustabouts / o ~ ¢ Diesel ,, Methanol SuPervision Pre-Job Safety Meeting AFE ,, , . . TOTAL FIELD ESTIMATE /-/ 7 / / ~,~ ~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 22, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on Kuparuk wells. The wells are listed below. Well Action Anticipated Start Date 2A-2 Conversion March, 1988 3M-6 Conversion April, 1988 3M-7 Conversion April, 1988 3M-12 Conversion April, 1988 3M-21 Conversion April, 1988 2D-9 Fracture March, 1988 2G-11~o,/ Perforate, Fracture March, 1988 If you have any questions, please call me at 265-6840. Sincerely, G. B. Smallwood Senior Operations Engineer GBS:pg'0165 Attachments cc- File KOE1.4-9 ~,l:ldd ~la~:ka Inn_ i,~ ;~ R~,bsidiarv of AtlanticRichlJeldCompany ~-' STATE OF ALASKA ~" ALAL A OIL AND GAS CONSERVATION CO APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend '; Operation Shutdown i ] Re-enter suspended well [-J Alter casing E] Time extension Change approved program 2] Plugging ~ Stirnulate,~ Pull tubing ' ' Amend order r-i Perforate ]~. Other 2. Name of Operator ARCO Alaska, !nc_ 3. Address P.O- Rn× 100360: Anchorage, Alaska 99510 4. Location of well at surface 243' FNL, 272' FWL, Sec. 5, T10N, T9E, UM At top of productive interval 1345' FSL, 1460' At effective cFepth 1202' FSL, 1281' FEL, Sec. 5, TION, R9E, UM FEL, Sec. 5, TION, R9E, UM At total depth 1149' FSL, 1214' FEL, Sec. 5, TION, R9E, UN 5. Datum elevation (DF or KB) 140' RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 26-11 'F~UC~F-~ feet 8. Permit number 84- 117 9. APl Z 4 9OO 50-- 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8670' 6366' 8549' 6281' feet feet feet feet Plugs (measured) Junk (measured) Casing Length Structural Conductor 104 ' Surface 3316' Intermediate 8632' Production Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size 16" 9-5/8" 7" Cemented Measured depth 202 Sx C.S. II 104' 950 Sx Permafrost E 3316' 370 Sx Permafrost C 450 Sx Class "G" 8632' ~ue Vertical depth 104' 2709' 6340' 8350'-8370' 8390'-8420' MD 6142'-6156' 6170'-6191' TVD 3 1/2", J-55, 9.3 lb/ft, EUE, 8141'A~Oora}~ Packers and SSSV (type and measured depth) Dar'! .... R',b,~,-I~LII 911Q' Mil qqqV. R~l~,~v' F'VI , _~0~!' ~r) 12.Attachments ~l~'s"~ri'pti'~'~"s~u'm~'~r'-y'of"i~r~)~os~i-~_~ -~)~t'aile~-o'l~'atio'n'~ program C..; BOP sketch RefractL!re 6 Sand- nPrfn~'atm £ .~anrl R??R'-R24R' MD Fa 4 SPF: fracture C Sand. · 13. Estimated date for commencing operation 03/23/88 14. If proposal was verbally approved Name of approver ~. J,~ 0 j~ 0 ::Z. ~ ~/-.- Date approved 15. I hereby certify that the foregoing is true and correct to the/qest of my knowledge Signed itle . , ~ ,,.4'~ Commission Use Only Conditions of approval Notify commission so representative may witness IApproval No. Date [] Plug integrity ORIGINAL SIGNED BY Approved by LONNIE C, SMITH [] BOP Test © Location clearance qpproved Copy Return~fil~ Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date ,~"-~/ ~ Submit in triplicate /'~ Kuparuk Well 2G-11 Well 2G-11 is currently an 'A' Sand-only producer. The 'A' Sand will be re-fractured to improve a poor flow effeciency. Following the 'A' Sand frac, the 'C' Sand will be perforated and then fracture stimulated. A copy of the proposed procedure is attached. The 'C' sand will be perforated from 8228' to 8248' MD at 4 SPF to open the interval to production. The perforating will be performed with a 2-1/8" through-tubing gun. A 5000 psi BOP and lubricator will be employed during all stages of the perforating work. The tubing will be displaced with diesel prior to performing the perforating. Both fracture stimulations will utilize Carbo-Lite proppant and will use gelled diesel as the carrying fluid. A Sand plug will be set after the 'A' Sand fracture to isolate the 'A' Sand prior to performing the 'C' Sand fracture. A 10,000 psi 'tree saver' will be used during both fracture stimulations. Wellhead pressure/fluid level analysis indicates an average reservoir pressure of 2600 psig in the '^' Sand, and the 'C' Sand pressure is estimated from offset wells at 2700 psig. Messrs. Lyden and Wack' March 14, 1988 Page3 Kuparuk Well 2G-11 'A' Sand Fracture & 'C' Sand Perf/Fracture Procedure Charge Code: 230DS28GL 'A' Sand Fracture Stimillation: 1. Obtain an 'A' Sand 12 hour well test. 2. MIRU Slickline unit. Tag bottom. Pull GLV's and Run DV's. Set blanking plug in Camco 'D' nipple at 8130' MD-RKB. Pressure lest the tubing. 3. Pump Slick Diesel/10% Musol per the attached schedule. Shut down overnight to soak. 4. RU fracture equipment. Install "Tree Saver". . Check diesel for contamination prior to gelling for frac. Obtain a sample of the frac sand and of the gelled diesel with breaker. Record proppant weight on location prior to pumping. After frac, verify and record weight of remaining proppant. . Pump fracture treatment per the attached schedule. Record the 5, 10, and 15 minute pressures following the ISIP. Shut down for a minimum of 30 minutes following the ISIP to allow the pressure to bleed off. Expected wellhead treating pressure: WHTPE = 3400 psig Fracture Gradient = 0.67 psi/ft (6166' TVD) Tubing Friction = 160 psi/1000 ft (8385' MD) * If treating pressure during the job exceeds 6000 psi, shut down job and confer with engineering. e Rig down frac equipment. Begin flowing well to tanks as soon as poss~le at a rate not to exceed 100 BOPD. Record tank straps (rates), choke settings, and WHP's during flowback period. After 24 hours, switch well to test separator. Follow a gradual flowback schedule by dropping WHP by 100 psi/day. Take BS&W samples after every choke change and every 8 hours. Inspect samples for fmc sand. If frac sand is found, increase WHP by 100 psi and contact Operations Engineering (Currier/O'Deil). 9. Continue the flowback schedule until a 150 psi WHP is acheived. Obtain a 12 hour 'A' Sand welltest. Set sand nluo: _ 10. MIRU slickline unit. SI well and tag fill. Confirm location of the tubing tail with an EOT or kickover tool. If an EOT tool is to be used, first RIH with guage ring to make sure tubing is clear of obstructions. 1 1. Calculate the 20/40 M Sand volume needed to fill the 7" to 8305' MD-RKB (22.98 lb/fl in 7" casing). Use the equations on page 5 to calculate the gelled diesel volume needed to transport the sand in a 10 PPG slurry. * Messrs. Lyclen and Wa~ March 14, 1988 Page4 Set Sand Plua [Cont. l: 12. The slurry will be displaced to top 'A' Sand perf. Batch mix the plug volume with gelled diesel at 10 lbs of sand per one gallon of clean diesel. The gelled diesel should have a 2-3 hour Iow temperature breaker. Displace this to a depth of 8350' MD-RKB (top 'A' Sand perf) with slick diesel at 2 BPM, or as slow as surface equipment will allow. Calculate the displacement volume using the equations on page 5. 13. Leave the gelled diesel to break for a minimum of four hours. Confirm location of tubing tail with EOT Iocator or kickover tool and tag fill. If tag shows top of sand plug below 8335' MD-RKB (15' above top A Sand perf), pump in enough 20/40 M sand at 10 PPG to reach a fill level of 8305' MD-RKB. 14. After confirming plug depth is within tolerance, pressure test plug to the maximum wellhead pressure capacity of 3000 psi. Contact Operations Engineering if fluid leakoff is significant. Perforate 'C' Sand: 15. Slowly bleed diesel from tubing until WHP stabilizes (maximum 5 bbls). This will ensure the tubing pressure is in equilibrium with the 'A' Sand and should provide a several hundred psi underbalance for the 'C' Sand perforating. 16. MIRU E-Line Unit. 1 7. RIH w/CCL, perf guns, magnetic decentralizer. 1 8. Tie into depth using the following logs: Schlumberger DIL/SFL 9/1 6/84 Schlumberger CCUCBL 1 0/1 5/84 1 9. Perforate the following interval with a 2-1/8" strip gun. DIL/SFL CCL/CBL Shot Run Depth (MD-RKB) Depth (MD-RKB) Density Rotation I 8228-8248 8228-8248 4 SPF 0deg Pedorating gun specifications: Any of the following service company guns will be acceptable. However, it should be noted that the Schlumberger Enerjet Gun has performed the best in field use and in perforating studies. Schlumberger 2-1/8" Enerjet Dresser 2-1/8" Silverjet Gearhart 2-1/8" E-Jet II 20. RD E-Une Unit. k~essrs. Lyden and Wacl~ Idsrch 14, 1 g88 Paae$ 'C' Sand Fracture Stimulation: 21. Pump MUsol per the attached schedule. Shut down overnight to soak. 22. RU fracture equipment. Install "Tree Saver". 23. Check diesel for contamination prior to gelling for frac. Obtain a sample of the frac sand and of the gelled diesel with breaker. Record proppant weight on location prior to pumping. After frac, verify and record weight of remaining proppant. 24. Pump fracture treatment per the attached schedule. Continuosly record the pressure readings following both ISIP's and the Pre-Pad using a quartz crystal pressure guage at surface. These measurements should provide an accurate 'C' Sand frac gradient and a leakoff coefficient of the gelled diesel. Expected wellhead treating pressure: WHTPE = 3700 psig Fracture Gradient = 0.75 psi/ft (6062' TVD) Tubing Friction = 160 psi/lO00 ft (8238' MD) * If treating pressure during the job exceeds 6000 psi, shut down job and confer with engineering. 25. Rig down frac equipment. Begin flowing well to tanks as soon as poss~le at a rate not to exceed 100 BOPD. Record tank straps (rates), choke settings, and WHP's during flowback period. 26. After 24 hours, switch well to test separator. Follow a gradual flowback schedule by dropping WHP by 100 psi/day. Take BS&W samples after every choke change and every 8 hours. Inspect samples for frac sand. If frac sand is found, increase WHP by 100 psi and contact Operations Engineering (Currier/O'Dell). 27. Continue the flowback schedule until a 150 psi WHP is acheived. Obtain a 12 hour welltest. CTU Cleanout: 28. Rig up CTU for sand plug cleanout. 29. Clean out sand plug using gelled diesel with 24 hour break. This breaker will allow the formation to clean up if gelled diesel is forced into the formation during the CTU cleanout. PBTD -- 7968' MD-RKB. 30. Tag fill after cleanout. 31. Turn the well Io the test separator for a combined A&C Sand test. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~] Perforate [] Other 2. Name of Operator ARCr) Ala_~ka: Inc.. 3, Address P.O. Box 100360~ Anchoraqe, Alaska 99510 4. Location of well at surface 243' FNL, 272' FWL, Sec. 5, T10N, T9E, UM At top of productive interval 1345' FSL, 1460' FEL, Sec. 5, T10N, RgE, UM .t I 2 L, 1281' FEL, Sec. 5, TION, R9E, UM At]~Fle~J~., 1214' FEL, Sec. 5, T10N, R9E, UM 5. Datum elevation (DF or KB) ]40' RKB feet 6. Unit or Property name Kuparuk River Unit 7. Well number 2G-11 ~ 8. Permit number 9. APl n %r~ ~j~r114900 50-- 10. Pool Kuparuk River Oil Poo 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 8670' 6366' feet feet 8549' 6282' feet feet Plugs (measured) Junk (measured) Casing Length Size Structural 104 ' 16" Conductor Surface 3316' 9-5/8" Intermediate 8632 ' 7" Production Liner Perforation depth: measured Cemented Measured depth 202 Sx C.S. II 104' 950 Sx Permafrost E 3316' 370 Sx Permafrost C 450 Sx Class "G" 8632' 8350'-8370' 8390'-8420' MD true vertical Tubing (size, grade and measured depth) True Vertical depth 104' 2709' 6340' Packers and SSSV (type and measured depth) Packer: Baker FHL. 8119' MD. SSSV: Baker FVL, 2031' MD 12.Attachments Description summaw of proposal [] Detailed operations program [] BOP sketch [] Perforate C Sand from 8228' MD to 8248' MD at 8 SPF. 13. Estimated date for commencing operation 01/31/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the~est of my knowledge Signed .//~:~/~ /¢~J~.~ _.~¢./~....~~-- TitleI/.,~ ~.~.<., ~// "ff---*C"'z-,-¢ ~-' ~?J' Date Commission Use Only Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner I Approval No. ~ ,~ -~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate RJ~TURN TO: ARCO Alaska, Inc. Post Offi/--"~ox 100360 Anchoragu. Alaska 99510-0360 Telephone 907 276 1215 DAT~:: 09-05-85 TRANSMITTAL NO:5332A **CONTINUATION 'ARCO ALASKA, INC. KUPARUK OPEP~ATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HERF.%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND P. ETURN ONE SIGNED COPY OF THIS TRANShITTAL. SEQUENCE OF ]..'VENTS FROM ~ELL SEKVICE ~{EPOKTS/PRESSUKE DATA 2G-9 ~'- PBU 08-22-85 2G-9?'- PSU 08-21-85 2G-11j' PBU 08-19-85 2G-16 "~ SBHP 08-19-85 2h-1~- PBU 08-25-85 2h-l-- PBU 0.8-24-85 2U-l'" 'C' SAND PBU 08-23-85 2U-l-~ END 'C' SAND PBU & MISC. 08-24-85 2W-7 ~"''C' SA~qD PBU 08-17-85 2W-7/ 'C' SAND PSU 0~-23-85 2W-7/~/ 'C' S~D PDU 0~-22-85 2X-ll/ PBU 0~-24-85 2X-11 / 'C' SAND PBU 0~-25-85 2X-11/ 'C' SAND PBU 08-26-85 3C-5 -~ BhP & M1SC. 08-29-85 3C-7--~ BHP & MISC. 0~-30-85 3C-8 / ~HP & MISC. 08-31-85 3C-9.-~ BHP & MISC. 08-09-85 3C-10 ~"BHP & MISC. 08-10-85 KUPARUK WELL PRESSURE REPORT ENVELOPE FACES: 3C-12/ STATIC 'A' SAND 07-24-85 CA/~CO 3C-10~ STATIC 'A' SAND 08-10-85 OTIS 3C-9 / STATIC 'A' SAND 08-09-85 OTIS 2Z-16-~ 07-21-85 OTIS 2Z-15" STATIC 'A' SAND 07-17-85 OTIS 2 Z-14.- STATIC 07-20-85 OTIS 2Z-13~ STATIC 'A' SAND 07-17-85 OTIS 2X-4~ PBU 08-12- ~ 5 CA~]CO 2X-4~ PBU 08-13- 85 CAMCO 2U- 1'~ , 08-24-85 UTIS 2A- 13'~' STAT IC 08- 25- 85 CAMCO iR-10 -~ STATIC 'A' SAND U8-15-85 CA~]CO 1R-9 / STATIC 'A' SAND 0~-14-85 CA/~1CO KECEIPT ACKNOWLEDGED: DISTRIBUTION: SPAE* DRILLING W. PASBEE B. CURRIER L. JOHNSTON EXXON CHEVRON* ~IOBIL* PHILLIPS OIL* ~ & M* NSK CLERK J. RATMMELL* ~'- DATE: ~ ,:~- ':.. '",-,... ~..~,,,., ?{-: [, .. ,- '~' ~0."i..- ,. STATE OF ALASKA*'.',',v.,:~. SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARc Alaska, Inc. Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells' 2G-11 2G-15 If you have any questions, please ca-ll me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L79 Enclosures RECEIVED 0 6 1 85 Alaska Oil & Gas Cons. ComrnissJo, AnChorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRJchfieldCompany . ~"'.. STATE OF ALASKA ~ ALASKA .I_, AND GAS CONSERVATION Cr(' .MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc, 84-117 ~. Address 8. APl Number P. 0, Box 100360, Anchorage, AK 99510 50- 029-21149 4. Location of well at surface 9. Unit or Lease Name 24:3' FNL, 272' FWL, Sec.5, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1:345' FSL, 1460' FEL, Sec.5, TION, RgE, UM 2G-11 At Total Depth 11. Field and Pool 1149' FSL, 1214' FEL, Sec.5, T10N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate .KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKBI ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 116. No. of Completions 09/09/84 09/16/84 10/:31/84I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)1 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8670'MD,6:366'TVD 8549'MD,6281 'TVD YES [] NO []I 20:31 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/GR, Gyro (GCT), CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 202 sx Cold Set II 9-5/8" :36.0# J-55 Surf :3:316' 12-1/4" 950 sx Permafrost E & ~70 sx Permafrost C 7" 26.0# L-80 Surf 86:32' 8-1/2" 450 sx Class G . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8:390' - 8420' :3-1/2" 8141 ' 8119' 8:350' - 8370' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Addel~dum, dated 4/2/85, 27. N/A PRODUCTION TEST Date First Production J Method of Operation (Flowing, gas lift, etc.) I 'Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "IF 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED ~,/aska Oil & Form 10-407 GRU6/WC24 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ' ':": 30. ' . ..-.. .: GE0[_oG:iC MAI~IKERs ~' ~.:; ~ .': .... -- .: . .. .' .;FORMATiON, TESTS NAME Include interval tested, pressure data~ all fluids recovered and graviiy, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8228' 6054' N/A Base Upper Sand 8238' 6061' Top Lower Sand 8328' 6125' Base Lower Sand 8509' 6252' .- .: 31. LIST OF ATTACHMENTS Addendum '1 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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~,07 ADDENDUM WELL: 10/16/84 1/27/85 3/o5/85 2G-11 AFE 902217 8549' PBTD Rn gage ring/JB/CBL f/8524'-5840'. Rn GCT gyro f/8500'-surf. Rn pre-frac breakdn tsts in 4 stages w/total of 148 bbls gelled diesel. Frac well in 7 stages w/total of 345 bbls of gelled diesel & 1000# 100 mesh & 16,100# 20/40 mesh. -Drillin~ Superintendent 'e EC£t v£b MA y o ~ ~9f~ /llaska 0il & Gas Cons. Anchorage Commission ~~D~a t e ARCO Alaska, In Post Office-Box 360 ' · Anchorage, Alaska 99510 Telephone 907 277 5637 ,.- ,:.'..::, l"i I" (:J 'T' ]: ,.? 'I` I' I ' ~ Il 'l ~ I- I ~ :" "' O -i .... ,...:'~ ,:::,' -'- ,:::.'-' ..... ..:- I ,.-~ ! F' ).? I:;: I--'.': .~)W i".] 'T Iii: ,? 'T' ....... !') '1 .,J Iii: I... 1... '.'? ?.) .... '7/ -'i 2-'-. 7.; (-) .... !!~ 4 ' C: ' ;.~.' A i'.!)} E,' F-.' l-( }';:, !.:.! i",! :ii.,' ,J I-.! U (:.:. I--I E,? -"/' :"h :[ "'-' "? ¢"~ ]::' .... .,:: o "' :::-...-'- l]; '-'-' I-'t F' f': A H '-' I"'~ ; ...... . :_. £., ,.... ,-, ~ -,. ,.?_, .~ .... l l, "';'"~ :t: ,? ....... ,.-.'..,: .... ~ .... '"'.-: ,:::, .... ,::~...* :r. I::' B'I:;'I.-; ?.- {.:J i'-.! y",f'i!,jli.-.i...I... ,:.,. i-,., .... -'.'3 ~ i ,-':; .... --~ l..: ,:.., .: ~ ........ I... ........ · --,::,l.t :--i: D'"'-"!.!I...'r;'' l::' , , .,~-.l'.,'; -:' ........ :.~, :l...: ........ I::: (..-~ C ;.-: ~i.' ~:-'~ ........ ii-"i" .~. i'--'i., .1.) (:)!.,.j Ii: I... ,...."' ....f: .... (ii: ~ . ,':",.., -i .... ;:;.., :::', .... ~::: ..... ,:-~ T F;.: Ii/. ,'."-? 3? !:-' F::. :':':: I": ....... I':.:. Ii!: ~".'."~ ':;' I..I [.'.'~ r:..' '/" ::-.. f; ,.-, .. ~ ... <., .... ,::,~ .(~:'i .... ~":'.:::----,.::,;"-":'-'_.. ]: ~i.' ]: l::, ';, .i HI I:':l-,l::.,..:. ....... .;o, ...... ,.~ ':~ ¥", .... ,'.::: -"- ,":; ,i 2'. '7 '"' '::' r:, (3 ;-..7 ]" r:' F;,',,':'-"~ :'"' if' r.' i"'{ :::' .............. · ....... ,::'--..;- ............ [) ']" :I: 2 )} .... i --":) '"i' "~ .-. (.) '7---::ii: :?- " ' A ' ,!i.' ;:-"~ i',.! :!) ,-" F' !3 U i:},'-"-'~ i"'i (': :) -.-.]; :() ..... '~ 'i .-- "~l l.."'l .....,..:'"' '-?;" ' ":::'"' "';"" ' !::' li~. F?. F:' }:]: :I::': i'-'.' :.Il';''; I.:." ~'""',' ~......_,, ~.l..._..,r .... il:''TI I::' "i" i'"'..- i'! '[', I-IAI ......... I... :1:)?,11R ']" ['i i'-..! "' /% ~'": · - - '1' 2 ":.'" ..... i 2'- ,.:: ::, l.. i .l;.:, '-:_...":') 4 ,S' ..... F; ['1F' ri T' .:. ,? .......'",.. ~': .... --i: ,.... ''~ ,-- i ;?'--.., ----:!":; -.'.') .... :i!]: -.:~- F' ]:;; [::-~ i'".' ...... [:i::::. ,'" !-:' !'"~ [':: 'i" .f) ....... ['] I.,J [.~'L. I... '_':? r.'. ..... i ,":; ~' ~", ~ ..... i '~ ..... l.--l... {.! :[ ';'~ ]' ?':-- :..,I., .{-;',1--i .......... ..l .-;. .... ,:::,-.l, _,.-l,. ,., ' ..... "'" :~: ,'..')"1" :1. !-! '-~.,--I-I,-:., ---..-~, .-. . I,.- i ......... ~~:~--~ ....... " ;'"'::' F:'() '?'¥' ; .... ' .... .............. -- r., ~--~. (": F': :-::-~ i'"'i I"] '-'.~! 2:-'-- 2 '"' 'i (!:, ..... :} ~}:-----':':i: 4 ,? I :C'~ H ]::' [) T :1: ,!'.;' '-: "? ": ....... ? i:'...' !"] :.:,::.""..-, -" -"}'~ ..... ~ Y .... ::::':~ HI-"' 'f']:,?? _...'- ,._....- ,,, .. ::..'" ..::.'"" .- ,:::."' ~ Q i .-- -i. ':.;- ' .'-"::....: ~-: ..... ~.~'? .,:,r, 1--I :-'"' " t.J' ...... I :1: ,? ... · ~ I '"'. ! -"~ ~, '"" F'B LI/' A ' -,-:-.: "": ~' ;:"'~ .... 2'L-El._-, . ........ ,:.:,-_ .- ,.- -- .... , i. ,:~. ~'-:~ i"--! f':' [) 'F 'r ..'.? ARCO .~!asl(a inC ,s a subsidiary o; ~HantlcR;c.hlleldComp]ny ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Harch 14, 19-85 Mr. C. V. Chatterton Commissioner 'State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-11 Dear Mr. Chatterton' Enclosed is an addendum to the 2G-11 Well History to include with the Well Completion Report dated 12/18/84. If you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU5/L22 Enclosure RECEIVED A~aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticR[chlieldCornpany ARCO Alaska, Inc. Post Office B,.,x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 25, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-11 Dear Mr. Chatterton' Enclosed is an addendum to the 2G-11 Well History to include with the Well Completion Report dated 12/18/84.' If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU4/L190 Enclosure xc' 2G-11 Well File RECEIVED MAR 0 5 19 5 'Alas~ Oi~ & Gas Cons. Commissiorl ..... Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 _chorage, AK 99510 ' //Transmitted herewith are the following items. D/ and return one signed copy of this transmittal. Date: 1/22/85 Transmittal No: PAGE 1 of 2 4988 Please acknowledge receipt OH FINALS Schlumberger 2B-1 CPL Cyberlbok " 2"/5" Neutron/Density "Poro" " 2"/5'" " " "Raw" " 2"~5" DIL-SFL/GR 8/29/84 Run 1 5950 - 6595 8/29/84 Run 1 5950 - 6595 8/29/84 " 5950 - 6595 8/29/84 " 2728 - 6621 2G-11 CPL Cyberlook 2"/5" FDC-CNL/GR "Poro" 2"/5" " ""Raw!' 2"/5" DIL-SFL/OR 9/16/84 Run 1 8000 - 8550 9/16/84 " 8000 - 8594 9/16/84' " 8000 - 8594 9/16/84 "' 3316 - 8632 2D-7 CPL Cyberldok 8/27/84 Run i 6250 - 6756 " 2"/5" Density/Neutron "Raw" 8/28/84 " 6250 - 67'56 " 2"/5" " " "Poro" 8/28/84 " 6250 - 6756 " 2"/5" DIL-SFL/GR 8/28/84 " 3202 - 6786 " RFT "DIL-FDC-CNL-LSS-GR" " RFT Quicklook " 2"/5" LSS DT & Waveforms . Receipt Acknowledged: 8/28/84 " --- 8/28/84 " 6490.5-6619 8/28/84 " 6250- 6778 Date: B. Currier BPA 9 Chevron D&M D!S%RIBUT_I/X~ Drilling ~~~a~/'~' ~.'~.- State of AK Mob~ '~:'"'~"~" ' "~~ ~ - '1 Phill~ps Oil "~':' Un~ NSK Ops. J. ~t~ell":,, Well Files ,.. /cat ARCO Alaska, Inc. Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 RETURN TO: Date: 1/22/85 Transmittal No: PAGE 2 of 2 4988 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 /r~~a. nsmChOrage, AK 99510 · itted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2D-4 CPL Cyberlook 2"/5" Density/Neutron "Raw" 2"/5" " " "Poro" 2"/5" DIL-SFL/GR 8/29/84 Run 1 8000 - 8550 8/29/84 Run 1 8000 - 859~ 8/29/84 Run 1 8000 , 8592 8/29/84 Run 1 3'~44 - 8618 2B-14 CPL Cyberlook 2"/5" Density/Neutron "Poro" 2"/5" " " "Raw" 2"/5" DIL-SFL 8/26/84 Run 1 7050 - 8550 8/26/84 " 7850 - 8558 8/26/84 " 7850 - 8558 8/26/84 " 3398 - 8584 /cat Receipt Acknowledged: Date:~ B. Currier BPAE Chevron DISTRIBUTION Drilling ~~ Pa~sher ~'~Geology /~-~C. G. Philli~lSS~_ii~ Mobil Phillips Oil D & M NSK Ops. J. Rathmell State of AK Sohio Well Files ARCO Alaska, Ir~'-~ Post Office ~,Ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 18, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-11 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2G-11 well history covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Ud. Gruber Associate Engineer JG/tw GRU3/L09 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASI~ ~IL AND GAS CONSERVATION , MMISSION . . . WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. permit Number ARCO Alaska, Inc. 84-117 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21149 4. Location of well at surface 9. Unit or Lease Name 243' FNL, 272' FWL, Sec.5, T10N, R9E, UM~ ~ Kuparuk River Unit At Top Producing Interval I VE[~iFiE[3 I 10. Well Number 1345' FSL, 1460' FEL, Sec.5, T10N, RgE, UM i 2G-11 At Total Depth 1149' FSL, 1214' FEL, Sec.5, T10N~ R9E~ UN B.H.~_ 11.FieldandPool -- Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool 140' RKBI ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 116. No. of Completions 09/09/84 09/16/84 10/31/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 8670'MD,G366'TVD 8549'MD,6281 'TVD YES ~ NO []I 2031 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP/FDC/CNL/GR, Gyro (GCT) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP- BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 104' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 3316' 12-1/4" 950 sx Permafrost E & 270 sx Permafrost C 7" 26.0# L-80 Surf 8632' 8-1/2" 450 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 8390' - 8420' 3-1/2" 8141' 8119' 8350' - 8370' w/4 spf, 90° phasing 26. ACID, FRACTURE, CEMENT SOUEEZE, E'~C. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor~) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE . Anchorage Form 10-407 GRU2/WC26 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE .'.' ~ ". GEoi-0'G]c'MARKERs:: :'!"t '"i .. ;': , :"-FoRMATiON TESTS ' ;:" · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 8228' 6054' N/A Base Upper Sand 8238' 6061' Top Lower Sand 8328' 6125' Base Lower Sand 8509' 6252' 31. LIST OF ATTACHMENTS · We]] History~ Gyroscopic Survey (2 cooies~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 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". AF5 90~1Y7 2G-11 $549' pBTD ~JB/CBL £/$524'-5840'' Bn gage ring/ Rn GCT gyro RECEIVED l','~f:f:~ 0 5 1~85 ¥.~ '~1"\ Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM WELL: 10/16/84 1/27/85 2G-11 AFE 902217 8549' PBTD Rn gage ring/JB/CBL f/8524'-5840'. Rn GCT gyro f/8500'-surf. Rn Pre-frac breakdn tsts in 4 stages w/total of 148 bbls gelled diesel. RECEIVED · /Uaska Oil & C-as 6'o;~s. CommJssior~ Anchorage Drilling ~perintendent Date ~~-Ifl~; · Well 18'~4Zdcled or workov~r opelltlOrl8 I/~ 8tl/~d. ~ ~~ ~vlng. IncluMve only. North Slope Borough Kupa~uk River [ ADL (?25667 Auth. or W.O. no. ITM AF~ 902217 / Drill, Complete & Perforate Doyon #9 AP1 50-029-21149 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 9/o9/84 thru 9/10184 9/11/84 9/12/84 ID,,,, 9/09/84 ]Hour Complete record for each day rep<3rted 1230 Hrs. StYe Alaska eH no. DS 2G-11 ARCO w.,. 56.24% Prior status if a W.O. 16" @ 104' 1472', (1397'), Instl kelly spinner Wt. 9.4, PV 18, YP 20, PH 9, WL 14.2, Sol 7 Accept ri~ @ 0830 hrs, 9/9/84. NU 20" riser & diverter sys. Spud well @ 1230 hfs, 9/9/84. Drl & surv 12¼" hole to 1472'. 500', Assumed vertical 718', 5.1°, S35E, 717.71TVD, 9.56 VS, 7.94S, 5.56E 1169', 20.6°, S39.1E, 1155.42 TVD, 112.19 VS, 84.07S, 74.62E 1360', 25.9°, S44.1E, 1330.85 TVD, 187.42 VS, 140.35S, 124.64E 16" @ 104' 3347', (1875'), TIH w/9-5/8" csg Wt. 9.6, PV 18, YP 16, PH 8, WL 11.6, Sol 8 Drl & surv 12¼" hole to 3347', 13 std short trip, CBU, POOH. RU & RIH w/83 its, 9-5/8" csg. 1593', 28°, S46E, 1538.53 TVD, 293.01VS, 214.95S, 199.37E 2085', 44.3°, S42.5E, 1937.28 TVD, 578.32 VS, 418.82S, 399.04E 2935', 52.1°, S41.0E,' 2483.32 TVD, 1223.66 VS, 910.52S, 825.35E 3264', 52.5°, S42.7E, 2684.51TVD, 1487.63 VS, 1104.43S, 999.03E 9-5/8" @ 3316' 3357', (10'), Conduct leak-off tst Wt. 8.8, PV 3, YP 4, PH 9.5, WL 18.4, Sol 3 Fin rn'g 82 its, 9-5/8", 36#, J-55 + 1 jt 10-3/4", 45.5#, K-55 csg w/FS @ 3316'. M&P 950 sx PF "E", followed by 370 sx PF "C". Displ using rig pmp, bump plug. CIP @ 1400 hrs, 9/11/84. Tst csg to 1500 psi; OK. ND diverter, NU & tst BOPE; OK. PU 8½" BHA, RIH, to 3166', wsh to 3234', tst csg to 1500 psi; OK. DO FC, FS + 10' new formation to 3357'. Conduct leak-off tst to 12.5 ppg EMW. The. above ia correct s,o..,u,. ~/// IDate 9/26/84 Title Drilling Superintendent ARCO 0il and Gas Company Daily Well History--Interim Inatruetiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for-workovers and following setting of oil strin§ until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL #25667 Complete record for each day while drilling or workover in progress 9/13/84 9/14/84 9/15/84 thru 9/17/84 IState Alaska Well no. DS 2G-11 9-5/8" @ 3316' 3896', (539'), Cut 10-3/4" csg & dress Wt. 8.7+, PV 6, YP 6, PH 9.0, WL 14.8, Sol 3 Compl formation tst to 12.5 ppg EMW. Drl 8½" hole to 3896', 16" x 10-3/4" ann leaking, POOH. RU RTTS, RIH, set @ 454'. Pmp mud, comm to 16" x 10-3/4" ann; leak @ 10-3/4" x 9-5/8" XO, POOH w/RTTS. MU RTTS w/retrv BP, RIH, set @ ±2000'. ND stack, PU lnd'g jt, screw into fluted hgr, BO lockdn screws, remove hgr, 10-3/4" parted bet pup jt & hgr. MU 1 jr, 10-3/4" csg, press to 600 psi; no fluid to surf. Suspect leak past BP. RIH, perform top job w/500 sx PF "C" w/retarder. CIP @ 0300 hfs, 9/13/84. Cut 10-3/4" csg & dress. 3826', 47°, S41.1E, 3047.63 TVD, 1916.02 VS, 1423.69S, 1285.49E 9-5/8" @ 3316' 4646', (750'), Drlg Wt. 9.0, PV 6, YP 6, PH 9.5, WL 12.4, Sol 5 NU & tst BOPE to 3000 psi. RIH w/retrv'g tl to RTTS @ 1959', rel RTTS, pull up hole, fsh fell to btm, POOH, Howco tl parted above 8RD connection. RIH w/OS w/6.5" OD grapple, tag fsh @ 3342', POOH, rec'd fsh. RIH w/RTTS, set @ 500', tst csg to 1500 psi; OK, POOH. RIH w/Navi-Drl, drl 8½" hole to 4646'. 9-5/8" @ 3316' 8670', (4024'), POOH, LD DP Wt. 10.2, PV 14, YP 12, PH 9.0, WL 6.4, Sol 10 Drl & surv 8½" hole to 8649', POOH. RU Schl, rn DIL/SFL/GR/SP/FDC/ CNL/GR f/8640'-3316' WLM, RD Schl. RIH w/BHA, drl & surv 8½" hole to 8670', short trip, C&C mud, POOH, LD DP. 4047', 47.1°, 842E, 3198.21TVD, 2077.52 VS, 1544.75S, 1392.78E 5084', 46.3°, 844.2E, 3903.53 TVD, 2837.34 VS, 2099.638, 1912.38E 6091', 48.7°, SSO.1E, 4606/14 TVD, 3558.35 VS, 2614.218, 2417.38E 7257', 47.1°, 849.3E, 5392.16 TVD, 4416.37 rS, 3170.868, 3074.55E 7889', 45.5°, 851.8E, 5828.80 TVD, 4870.97 VS, 3461.198, 3427.37E 8649', 45.78, S55.5E, 6360.31TVD, 5407.70 VS, 3783.178, 3864.89E The above is correctt~j S,onatura dj ' V-L For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDate 9~26/84 ]Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Inatructiona: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in bl~cks provided. The "Final Rel)ert" form may be used for reporting the entire operation if space is available. District Alaska Field Kuparuk River Auth. or W.O. no. AFE 902217 Doyon #9 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. 9/18/84 ICounty or Parish Lease or Unit Title Accounting cost center code State North Slope Borough Alaska ADL #25667 Drill, Complete & Perforate API 50-029-21149 I otal number of wells (active or inactive) on this est center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. I 1230 Hrs. A.R.Co. W.I. 56.24% Date 9/09/84 Complete record for each day reposed 7" @ 8632' 8549' PBTD, RR 10.3 ppg NaC1/NaBr POOH, LD DP. RU & rn 217 jts, 7", 26#, L-80 BTC cst to 8632' w/FC @ 8549', marker jt @ 8273'. Cmt w/450 sx C1 "G" w/l% CFR-2, 5% KC1 & .3% Halad-24. Displ w/327 bbls 10.3 ppg NaC1/NaBr, bump plug. CIP @ 2015 hrs, 9/17/84. ND BOPE, NU adapter flange & master vlv. RR @ 2400 hrs, 9/17/84. Operations suspended - wait on completion rig. IWell no. DS 2G-ll Old TD New TD 8670' (9/16/84) 8549' Released rig Date 2400 Hrs. Classifications-(oil, gas, etc.) 'dil- I PB Depth Kind of rig 9/17/84 Rotary JType completion (single, du~l, etc.) - Single Official rese~oir name(s) Kuparuk Sands Producing method Flowing Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected T. he above is corr~i~ Date ITitle ! For form preparation and distribution, see Procedures Manual, Section 10, Drilling Superintendent SUB.SURFA CE DIRECTIONAL SURVEY r~ UIDANCE F~ONTINUOUS [-~ OOL Company ATLANTIC RICHFIELD COMPANY Well Name Field/Location 2G-11 (249' FNL, 272' FWL, $5, TION, R9E, UM) KUPARI~K. NORTH SLOPE. ALASKA Job Reference No, 69645 Logged By: B EUTL ER/W EST Date NOV-18-84 Computed By: STEVENS GCT DIREC'I'IONAI.~ SURVEY C II ~3T[)NII~,R I,,IST ING A~CU A[,ASKA~ INC. KUPARUK NORTH SbOPf%~ AbAS~A SURVK¥ DATF: 15-0CT-84 [(:t"w G J NEF:R ,.t ~.Ik'l'nflOS flF COMPUTATION TuOb bOCfi'l'I{~N: TA~.~GFi~,TIAL.- avera,jed deviatioD and azimuth I r,~ T I,.. [? [" (') t~ A I' I [3 N: I,l NKAi.< '"~"~' V~'t.~"'F.[PAI. S~(3'['ION: ~-~()RI2',, DI$1r, PROJECTED (i')~',~T~.~ A TARG[T AZIMUTH f_)~ bOU"I'M q4 DI:JG 47 MIN ~.AST ARC() AhASKA, TNC, 2G-11 KIIPARUK NORTH SI,,UPE, AbASKA COMPUTAT.Lf3t~ OATE: 14-NOV-84 PAGE DATg UF SURVEY: 15-0CT-84 KELhY BUSHING EbEVATION: 140.00 FT IN',[I{iRPOI,,ATI:;[) VA[.,U[<S ["'Of< EVEN 100 FEE'[ OF MgA,SUI~EI_) DEPTh TRDE SUI4-SLA CObR~E LASURED VERTICAl,, V£RT~CAL DEVIATION AZIMUTH DEPTH DEPTH DEP'ttt DEG MI.N DEG MIN 0,00 0.0o -1~0.o0 O 0 N 0 0 E 100,00 100,00 -40,00 0 4, N 22 25 W 200,00 20U,O0 bO,O0 (,)14 ~ 34 46 w 300,00 300,00 lo0,00 0 1 S 49 23 E 400,00 400,00 200.00 0 8 N 19 54 W 500,00 boO,O0 't60.~00) 0 20 $ 3b 41 F 600,00 599,9q 459, 9 1 31 S 53 15 E 700 0O 6q9,76 ~5q,76 5 33 S 43 35 E aO0~OO '109.05 659,05 ~ 23 S 41 33 E 90o~00 8o7,4h 757,46 ~1 51 S 44 44 F 1000 00 994,54 854.,54 15 ,j4 1100:00 1090,2q 960,29 lS 3 1200 O0 1184,35 1044.35 21 23 1300:00 1270,47 .11{6,47 24 27 14.00,O0 1.366,56 1P26,56 ~7 3 1500,00 1454.90 1314,90 28 1~ 1600,00 1543,V5 1403,06 28 25 1'700.00 1630,24 1490,~4 30 33 1800 00. 1714,80 15V4,89 33 51 lO00~OO 179~,27 1656.27 ~7 14 S 42 4'7 F $41 52 E S 41 20 E S 40 ,%1 E S 40 24 F S 40 2~ E 2000,00 1673,u7 173:~, ~'1 40 53 2100,00 1947.23 1807,23 44 31 2200,00 2016.21 1R'16.21 2300 O0 ~080.71 1940,'11 2400~00 ~143,02 2o03,02 51 24 2500,00 ~.205,38 206q,t8 51 23 226 'l. 'l 7 VERTICAL POe;LEG RECTANGtJLA~ COORDINATES HORIZ, DEPARTURE :SECTlf)N SEVERITY I~C)RTii/Sf)OTH EA~TtWEST DIST, AZIMUTH FELT DEG/100 FEET FEET FEET DEG 0,00 0,00 0,00 N 0,00 '~,1.4 0,24 0,09 N 0,11 '0.36 0,33 0,37 N 0,14 -0,59 0,25 0,49 N 0,34 -0,63 0,48 0,63 ~t 0,26 -0,5~ 0,05 0,52 N 0,30 O.71 3,25 0,29 S 0,'11 7,01 2,09 4,58 S 5 33 1@.~5 4,33 13,40 S 13:25 36,5~ 5,1~ 20,34 S 25'39 0,00 N 0 0 E 0 14 N 50 30 W 0~39 N 21 16 W 0,60 N 34 51 W 0.08 N 22 47 ~ O.O0 N 30 5'w 0,77 $ 67 37 g 7,03 $ 49 21 £ 18,85 S 44 39 E 36.58 $ 43 56 g 60,42 2,51 B9 23 3,05 123~08 1,91 161,04 2,38 205,19 2,30 25~,03 0,O3 299.26 1 02 348,20 2:75 401,42 3,08 459.50 4,30 42 99 $ 185 21'1 251 289 331 42.45 E 60,42 S 44 38 E 48 S 62,71 E 89,23 $ 44 39 g ~5 S 85,19 E 123,10 $ 43 47 E 2B S 110,57 E 161,91 $ 43 4 E 24 S 139,91 E 205,29 $ 42 57 E (,1 S 172,18 E 252 12 6 43 15 E 20 $ 205,98 E 299~34 6 43 28 E 98 S 240,41 E 348.27 $ 43 39 E 99 $ 277. b6 E 401 4q $ 43 45 E 97 s 459:5. s 45 z 527,52 4,17 590,39 3,34 662,65 3,44 738,8t! 1 02 816,8~ 0:30 894.83 O,bO O,bO 0,40 1,1.6 0,24 377,94 $ 360,96 E 522,62 S 43 41 g 42~,17 S 400 69 E 590,63 5 43 31 g 482,31 S 454:'12 E 662,87 6 43 18 E 539.91S 504.90 E 739.21 6 43 4 E 599.41S 555,67 E 817,35 S 42 49 E 658'91S 606,37 E 896,46 $ 42 37 E 718:36 S 657,10 F 97~,57 2600 OO 2127,77 51 25 2700:00 2330,25 2190.75 51 14 2800~00 2392,74 2~5~,7~ %1 3't 2900,00 2454,30 2314.3o 52 lO 3000,00 ?515.qH 2t75.a~ 52 22 3100,0o 2676,bl 2436.51 52 27 3200,00 2637.~ 2497,46 52 26 .~300 O0 2098,31 2558,31 52 2~ 3400:00 275~,58 2619,%~ 51 56 3500,00 2621,M5 26~1.,45 50 56 3600,00 ~86,;~ 27~5,7S 49 34 3700.0U 2951.b~ 2811.55 4~ 12 3800.00 ]~18.bg 2R'/~.6~ 47 26 3000,00 3ORb.'/g 294~,79 46 39 $ 40 24 E o'12,7b S 40 16 F 1050,59 $ 40 16 F 1128,43 S 40 14 E 1206,98 S 40 24 ~ 12~5,85 S 40 31 E 1364,84 S 40 31 E 1443.90 $ 4U .~o Fi 1523.03 S 40 't3 E 1601,86 S dO 35 E 16'tq,82 S 40 2~ F 1756,59 S 40 42 F 1831.7(; S 40 47 F 1005.6~ S 40 3(3 F: 19'1~,6b 0,43 0,58 0,15 -0,58 1,10 0, '11 1 '11 0:47 0,71 0,54 ~ 42 26 g 77'1 92 S 707,59 E: 1051,59 fi 42 17 E 837:49 S 758.06 F 1129,o2 S 42 9 g 897,b0 $ ~09,01 E 120~,38 ~ 4~ 1 E 957,93 S b60.18 E 128'1,~5 fi 41 55 E 101~,21 S 911,57 E 1360,~4 ~ 41 50 E 1078.46 $ 963,09 F lq45,90 fi 41 45 E 11.~8,/9 S 1014,05 E 15~b,24 ~ 41 42 E 1198,72 S 1066,17 E 1604,26 ~ 41 39 E !25~,04 $ 1117.07 E 1682,41 $ 41 3~ E 1310,65 S 1167.09 E 1759,38 ~ 41 33 E 1373,76 $ 121~,08 E 1834,6g ~ 41 30 E 1429,94 $ ~266.~? E 1908,79 ~ 41 29 E 1,1Fb,5] $ 1312,o8 E 1982,00 5 41 27 L ARCO At, ASI<A, Iii(i, 2C,-1 1 K[IPAEI,JK NORTH 5[,,UPE, ALAOKA CO~'qPUTATI[)~ DA'I:E: 14-NUV-84 PAGE 2 DATE UF SURVEY: 15,'OCT-04 K~I..,L,Y {%bSHI'i,,C; EbEVATIUN: 140,00 FT .[N'.i'FHP()I,ATED VAI,(jE~ FOR I<VEN 1.00 FEE[ OF IV~EA,bt~hEL~ DEPT~ 'I'RL~Fi SUB-SE~ C[]tjRSF~ V~RTICAL DOGLEG RFiCTANGUuA~ COORDINATE~ HORI~, DEPARTURE ~,~SllREi) VF:t~T1CAI, VER'I:ICAL, DEVIATIOh AZIMUTh 8ECTI(1N S~]V~NIT~ NO~TH/5OUTH EAGT/WE~T DIST, A~IMUTH DEPTH DEPTh DF;P'I' H DEG MIN 4000 O0 3155.42 3015.42 46 49 4100 00 322.3,5N 30~3.58 47 16 4200 O0 3291.15 3151.15 47 47 4300 O0 3358 05 32i8.05 48 13 4400 O0 3424~68 32U4.68 48 4500 00 34ql.56 3351,66 47 43 4600 00 3559.16 3419.16 47 25 4700 OO 3627.V1 3487.01 47 6 4800:00 3695.29 3555.29 46 44 4000,00 3763.97 3623,g7 40 30 5000.00 3832.98 3692. q/-, 46 12 5100,00 3902.27 3702,27 40 4 5200.00 3971..79 3811."19 45 q9 5300.00 4041.ol 3o01.61 45 36 5400.00 4111.73 3q'7l ,73 45 21 5500.00 4182.16 4o4~.16 45 3 5600.00 4252.99 4112.99 44 44 5700.00 4324.16 41~4,16 44 30 5800.00. 4395.01 4~55.6] 44 ~0 5900.00 4465.~4 4326.~4 45 2Y O000,Oo 4535.~4 4395.8~ 47 11 6100.00 a002.9~ 4462.95 48 2q ~200 Oo 4668.92 452~.92 48 40 6300~00 4735.35 4595.]5 48 13 0400.00 4801.91 4661.ql 40 16 6500.00 4868.0H 4728.68 48 2 o600.00 4935.~2 4795.R2 4'7 3~ 6700.00 5003.37 4803.~7 47 17 6800.00 5071.25 4931.~5 47 10 bgO0.OO 5139.41 499q.41 4o 56 'lOUO.O0 5207.ol 5007.61 4'1 2 7100.00 5275.03 5135.R3 40 59 7200.00 5343.88 5203.8~ 47 15 7300.00 5411.'12 52~.72 7400.00 5479.31 5339.31 4'1 31 7500.00 5546.9~ 5406.92 47 20 7600.00 5514.~3 5474.93 45 56 7700.00 5583.45 55.t3.45 4h 25 7800 O0 5752.b~ 5612.fi8 45 7900:00 5~22.36 56~?,~b 45 JO DEC; MIN FEET PEG/lO0 FEET FEE'I S 40 35 E 2051.19 $ 40 56 E 2124.1ti S 41 14 E 2197.75 S 41 35 F 2271.95 S 41 46 E 2346.41 S 41 42 E 2420.55 S 41 39 F 2494..22 $ 41 38 E 2557.58 S 41 35 E 2640.53 $ 41 27 E 27!3.09 S 41 lB F 2785.34 $ 41 16 E 2857,31 S 41 6 E 2(129,05 S 41 I E 3000.49 S 40 58 E 3071,62 S 40 54 E 3142.46 S 40 54 E 3212.8~ $ 41 4 E 3282,98 S 41 15 E 3352.80 S 42 5 E 3422.87 S 4~ 54 E 3495.91 S 4~ 23 E 3569 29 S 4~ 3 E 3644:25 S 49 8 Fi 3718.77 S 4~ 56 F 3793.~0 S 48 45 E 3867.47 S 48 41 E 3941.40 5 4~ 51 F 4014.95 S 48 54 E 40~8.20 S 48 42 E 4161.18 S 48 34 E 4234.15 S 4~ 2R E 4307,11 S 48 34 E 4380.25 $ 48 40 E 4453,54 $ 4~ 48 E 4527.06 S ~9 7 F 4600.55 S 49 17 E 467].64 $ 49 32 F ~746,23 S ~9 04 E 481~.13 S 50 16 E q~Sq.55 0,42 0,49 0,84 1051 0,31 1707 0,05 1763 0,'77 1818 0.16 1873 0,28 1928 0,46 198~ 0,46 2037 0.24 0.44 0.29 0,31 0.48 0.36 0.32 0.47 2.47 3,20 2.03 0.18 0,07 0,41 0,19 0.21 0.42 0.18 0.24 0.31 0.32 0.80 0.16 0.07 0,92 FEET DEG 1540 ~1 S 1359.34 E 2054,73 $ 41 25 E 159o 25 S 1407.10 E 2127.90 $ 41 23 E 79 S 1455,57 E 2201,61 $ 41 23 E 54 S 1504.73 E' 2275,94 $ 41 23 E 21 S 1554 34 E 2350,51 $ 41 23 E 61 S 1.003:77 E 2424,76 $ 41 24'E 71 S 16521~5 E 2498.54 $ 41 24 E 59 $ 1'I01,08 E 2572,00 $ 41 25 E 21 S t7%0.21 E 2645.06 S 41 25 E 61 S 1798.41 E 271'1,'14 5 41 25 E 2091,91 S 1845,26 E 2790 12 $ 41 25 E 2146.08 S 1893.54 E 2862 22 $ 41 25 E 2200.16 S 1941.19 E 2934 10 S 41 25 E 2254,14 $ 198a,21 E 3005 08 $ 41 24 E 2307,95 $ 2034,98 E 3076 98 $ 41 24 E 2361 58 S 2081.50 E 3147.97 S 41 23 E 2414:94 $ 2127.70 E 3218.55 8 41 22 E 2467.98 S 2173,77 E 3288.80 fi 41 22 E 2520,65 S 2219 82 E 3358,'i6 6 41 22 E 2573,19 S 2260:35 E 3428,95 S 41 22 E 2025.89 S 2315.95 E 3501.27 S 41 24 E 2676.64 S 2369.98 E 3575.08 S 41 31 E 2720,04 S 242o,60 E 3649.62 $ 41 40 E 2774.97 $ 2483.10 E 3723.74 6 41 49 E 2023.88 $ 2539.48 E 3'797.'/9 S 41 57 E 2872 90 S 2595,51 E 3871.'12 $ 42 5 E 2971:~8 S 2651,21 E 3945 34 S 42 13 E 2970,36 $ 2706,68 E 40~:b0 S 42 20 E 301~,b] S ~762.03 E 4091.57 S 42 27 E 3065.~2 S 2817,08 F 4164,29 6 4~ 34 E 3115.15 S 2871.96 E 4237,02 S 42 40 E 3163.59 S 2920,74 E 4309,77 5 42 46 E 3212,17 $ 7981,o0 E 4382,09 ~ 42 52 E 3260.'11S 3030.74 E 4455.79 $ 42 57 E 3309 32 S 3092 14 E 45~9.12 $ 43 3 E 335'1:09 S 3147:72 £ 4602.47 ~ 43 9 E 3405.57 S 3203'23 E 4575.32 6 43 14 E 3452.97 S 325~.53 E 4'741.74 S 43 20 £ 3499.53 $ 3313.5~ E 4819.q6 ~ 43 20 E 3545,o0 S 3368,o5 E 4890.71 5 43 32 E ARC[') AbASKA. IN(3,, 2G-11 KUPARIIK NORTH ~I, UPE. AL, ASkA DA'IF:: 14-NuV-R4 PAG~ 3 DA'ri OF SURVEY~ 15-UCT-~4 K~[,bY BUSHING EbEVATIUN~ 140,00 FT ENGINEER; bEUTbER/~EST IN'I'Fi~<PO[,AT~D VAIJUFb b'(DR EVEN 100 FEE'I' UF MEASURED I)EPTH TRUE SUR-SEA ~EASIJRFi',) VFRTIPAI, VgR'I,'ICAb DEVIATIHN AZI~UTtl DkPTH DEPTH DEP'I'H VKRTICAI., D(JGbEG RECTANGLJbAR COORDINATE5 HORIZ, DEPARTURE SECTION SEVERITY NORTti/SOUTtt EAST/WEST DfST, AZIMUTH FFET DEG/IO0 FEET FEE'I~ FEET DEG 8000,00 5892,67 5752,6'7 45 15 8100,00 5963.$5 5823.35 45 8300.00 6105.31 5965,~1 44 54 8400.00 6175.'/4 0035.74 45 14 8500 O0 6240.1.4 bl()6.J4 45 19 8600:00 6316,42 01'16,4~ 45 20 8670.00 6365.o~ 0225.62 45 20 $ 50 2g ~ 4900,32 $ 5U 47 E 5030,68 S 51 1~ E 5100.68 $ 51 17 E 5170,68 S 51 31. F 5241.21 S 51 32 F 5311.73 S 51 32 E 53~2,37 S 51 32 F 5431.R2 0,48 0,78 O,bD 0 77 0:44 9.06 O.O0 3590,95 S 3423.43 E 4961,33 $ 43 37 E 3~35,80 S 3478.11 E 5031.53 $ 43 43 g 3080,08 $ 3532,86 E 5101,39 5 43 49 E 3724"0'! S 3587,91 ~: 5171,25 5 43 55 E 376~'37 $ 3643 40 E 5241 65 ~ 44 2 £ 3812,5~ $ 369~:97 E 5312:07 $ 44 8 g 385b,80 S 3754'b9 E 5382'62 $ 44 13 E 3887,77 $ 3793,6~ F 5432,02 5 44 ~7 E COMPUTATION £)AfE: 14-NOV-84 PAGE 4 DAT~ OF SURVEY: 15-OCT-B4 KEI, LY BUSHING EbEVATION: ~gNGINE~R; bEUTbEH/~EST IN']'FiI~POI,ATL'D VALUE5 ~'()I< i:;VC;N 1000 FEET (]F MEASURED DkP'I~ 140,00 FT '£RUE SUB-SEA '.;ASURFI.) VERTICAL VERI'ICAL OEV]AT]~OI"~ AZ.LMu'rh I) I:: P'l_' H DEPTH DEPTH DEG M,IN VD.,RTICA6 Di{C;bEG RI~TC. TANGUGAk COURDINATEb t'iOR17., DgPARTURE SECTION SEVERITY NORTH/,SOUTH EAST/W~$T DIS1, AZIMUTH FEET DEG/IO0 FEE'f FEET FEET DEG MIN O,OO N 0,00 E o OO N 0 0 E 42,99 S 42,45 E 60:42 $ 44 38 E 37~,94 $ 360,96 E 522,o2 $ 43 41E 957,93 S 860 lB E 1287 45 $ 41 55 E 1540.81S 1359~34 E 2054:73 ~ 41 25 E 2091.91 S 1846' 26 E 2790.I2 $ 41 25'E 2675.89 S 2315,95 E 3501.27 $ 41 24 E i~llb,15 S 2871,96 E 4237,02 $ 42 40 E 3~90,95 S 3423.q3 E 4961.~] S 43 37 E .388'1.77 S 3793.08 E 5432.02 $ 44 17 E 0,00 O,O0 -1.~0,00 0 0 [000,00 994,b4 854,54 15 34 ~000.00 1873.~7 1733.87 40 53 {O00,OO 2b15,48 23"15,4b 52 22 lOOO,O0 3155.42 3015,42 4b 49 3000,00 .'3832,9~ 3697,9~ 40 12 )O00.OO 453b.~4 4'i~95.~4 47 11 1000,00 5207.01. 5067.61 47 2 ~000,00 5Bg2.b7 5752.67 45 15 3670.00 636b.b~ o225.62 45 20 N O () E 0.00 S 45 30 E b0.42 S 42 47 E 522.52 S 40 24 E 1285.85 S 40 35 E 2051.19 $ 41 18 E 2'185,34 S 44 54 E 3495,21 S 4~ 34 E 4214,15 s 50 29 E 4qb0.32 S 51 32 E b4Jl.82 O.O0 2.51 4.17 0.43 0,4~ 0,24 3,20 0,48 0,00 ARCO AI.,A,'SKA~ 2G-11 KUPARIIIx NORTH S[,,L)PE, T R U ~EASUI~EI) YERTI DEPTH I.)EP 0.00 40,00 40 140,00 140 240 O0 24O 340!00 340 44O O0 440 540, O0 b40 640°05 640 740,46 74u 841,49 943,~0 94£} 1047,32 104o 1152,55 1140 1260.09 1240 13'10.~'1 1340 1483.00 1440 1596.54 154(,} 1711,36 lb40 1830 4~ 1740 1955~78 1840 2089.07 1940 2236,12 2040 2395,16 2140 2%55.39 2240 2715.5b 2340 2876,6U 2440 3040,23 ?b40 3204.1'1 2640 33~8,12 7740 352~o59 ?~40 3682 6b 2940 . 3831,4b 304U 3o77,4~ 3140 4124,23 3249 427? 03 3340 442~197 344u 4571 6'1 3640 4719:08 3o4U 4BbS.lb 374~ 5010.ih ]840 laC, ALASFA IN'I'ERPOI,A'rEI) VA[,UF~ kflH Fi, CAI,, TH .00 laUO.OO ,Of) tqO0.O0 .O() 2000.00 .O0 2100,00 .UO 2200.00 .u¢} 2300,00 .O(') 24uO.OU .00 25uO.0u .00 26U(). gL: .00 2700.00 .t)() ,O0 290o.00 .00 .Va 310o.00 .OO .00 3300.00 .O0 34U0.00 .0¢) 3%00.Ou ,Un 3600.00 I)A'I'E: 1.4-NL)V-84 PAG~ 5 DATE OF SURVEXI 15-UCT-~4 KELbY BUSHING EbEVATION: 140,00 FT ENGINEER: DEUTbEH/WEST EVEN 1,()0 FEET UF SUB-SEA DEPTH DEV I hTI. f)a AZI MUTt'i SECTION DEG MIN bEG Mia FEET 0 0 N O 0 E 0.0 0 0 12 1'I44 .3,3 W -0.02 0 8 N b 33 F -0.19 0 lO ~ 63 46 ~ ..0.51 0 5 N 4'1 43 E -O,Su 0 6 S 82 38 W -0,71 U 35 S 49 15 E -O.~.b 3 14 S 49 26 F' 2,32 b 28 S 41 b9 [': 11.25 9 55 S 42 43 E 25.49 13 32 S 45 b4 F 46,nb l.b 37 S 44 57 E 73,54 19 58 S 41 20 E 106.2b 23 17 S 40 44 E 145,67 2b 18 S 43 16 E !91.82 28 2~ $ 44 45 E 243.q8 28 23 S 44 39 E 297.62 ~0 54 S 44 37 F 354,03 34 53 S 43 49 E 418.64 39 15 S 43 10 ~ 494.11 4.t 11 $ 41 56 E 583.30 49 23 $ 41 11 E 6BO,7~ 51 25 S 4u 24 Fi tlt3.lO 51 25 S 49 2~ E 937,q5 51 15 S 40 17 E 10o2,b8 52 9 S 40 15 E 11~8.62 52 21 S 40 24 E 1317.64 52 26 S 40 31 E 1447.19 52 R S 4L) 46 E 15'16.7b 50 jo $ 40 33 F 1701.93 48 24 S 40 40 F 1~18.79 47 15 S 40 j9 E 1928.70 4b 44 S 40 32 E 2034.~2 4'1 22 S 41 I E 2141,95 4~ 5 g 41 2q F 2251,~0 48 ? S 41 45 Fi 2363.49 4'1 2~ S 41 41 E 24~3.39 41 3 S 41 38 F ~581.53 4o 34 S 41 31 E 26~7.83 40 11 $ 41 IR F 2792,6b DUGbEG RECTANGUbAt~ COORDINATES SEVERITY N('tH'I'H/5OUTH EAST/WEST DEG/I oo FEET FEET ttOH1Z, DIST. FEET DEPARTURE AZIMUTH DEG MIN O.O0 O,O0 N 0.00 E 0.77 0,01 N 0,01 W 0.UT 0,16 N 0,11 W U,38 U,q7 N O,2b W 0.20 0,51 N 0,~1 W 0,~2 O,b7 N 0,J3 W 0.86 0.29 N 0,08 W 4.67 1,31 S 1,98 E 2.48 7,'10 $ 8.21 E 3,06 18.34 S 17.72 E O.O0 h 0 U 5 U,02 N 45 9 w 0,19 N 33 17 W U,5] N 28 5b w O,bO N 31 23 W u,75 N 26 12' W 0.30 N 14 47 w 2,37 $ 56 30 E 11.26 8 46 51E 25,50 $ 44 0 E q.86 32,99 S 32.14' 2.48 52,23 S 51.77 4.25 7b,10 S 74.16 3,U1 lOb,U2 S 99,97 3 33 140,58 S 130.b6 0:37 177,90 S 167.11 0,98 21b.03 $ 204,b3 3.U9 255,13 S 244,51 3.26 302 41S 289,60 2.93 357:15 S 341,57 4b,06 73,54 10b.26 145,72 191,92 244,08 297,70 354,10 494,1g $ 44 14 E S 44 44 E 5 44 lb E $ 43 19 E S 42 54 E S 43 12 E S 43 28 E fi 43 40 E S 43 45 E 5 43 43 E 3.UO 422 ~8 S 401 95 3.13 502:74 S 472:05 0.33 59b'53 S 553.22 0.02 bgl.81 S b34.45 U.43 7B7,17 S 715,44 u.22 883 55 S 797,11 u.77 982~20 S ~80.85 0.15 l. gBOe98 S 965.24 0.49 1179.06 S 1049.74 1.3d 1274,U7 S 1131.49 E 583,43 E b90,03 F 813 57 938:b8 1065.71 E 1189.97 E 1319,32 E 1449,21 E 1579,10 E 1704,57 $ 43 32 E ~ 43 13 E $ 42 50 E 6 42 31 g fi 42 16 g 6 42 3 g $ 41 53 g 841 45 E $ 41 39 E $ 41 35 E 1.45 1363.95 S 1207.b3 E 1~21,"i4 U.O4 1447.48 S 1279.b0 E 1931.92 0.35 1528.35 S 134U.b7 E 203U,32 0.47 1609.b9 S 1418.70 E 214b.71 O.SO lo92.44 S 1491.35 El 225b,'17 0.87 1775,97 S 1565.74 E 236'1.b2 0.30 1~5b,12 S lb3~.98 E 2477,b7 0.41 1939.03 S 1710.96 E 2585.97 0.37 201~.o6 S 17B1,04 E 2092,44 0.25 2007.42 S 1851.10 E 2797,45 fi 41 31 E 8 41 28 E $ 41 25 E 8 41 23 E $ 41 23 E 8 ~i1 24 g 8 41 24 E 8 41 25 E S 41 25 E ~ 41 25 E 24-11 KUPARIJK COHPUTATION DATE: 14-NOV-B4 PAGE 6 DATE OF SURV~IY: 15-0CT-84 KELLY BUSHING ELF. VA.'I'IUN: 140,00 FT ENGINEER: bEUTbFR/WEST INTERPUI,ATED VAI,UE6 fOR EVEN 100 F'LEI' UF SUB-SEA Db:P~I'H T ~ U E $ U !:;~ - S t: ~ C 0 U t~ b E LA,5!IR,F.,[") VEHTICAI', VER'[':1'CAL DEVIATIOI~ AZXI~UTtt DEP'I'H I)EPTtt F)~PTH DEG MIN i)FG ~,lTl'~ VbRTICAI.., I')O(;LEG R~CCTAN(iULAR COURDINATES M[)RIZ, DEPARTURE SECTION SF:VKRIT¥ NORTH/SOUTH EAST/WEST DiST, AZIMUTH F~iET D~G/IO0 FEET FEET FEET DEG 5154,33 3940.00 3800.0o 45 58 5297,69 404u.00 3gO0,O0 45 37 5440,18 4140,00 4000.00 45 15 5581,70 424,0,00 4100 O0 44 48 4340.0~ 4200~00 44 25 5722 20 5R62~04 4440,00 4~00,00 44 36 P006~2 4540.00 4400,00 47 15 6156,19 464.0,00 450(), 0(., 48 45 6~06,97 4740,00 46()0.0u 48 13 5457,09 4840, O0 4700,00 ~8 5 $ 41 11 E 2~96,32 S 41 2 F: 299g,f14 $ 40 56 ~ 3100,12 $ 40 52 ~ 3200,03 S 41 7 E 3298.50 S 41 33 E 3396 07 S 45 0 E 3499170 S 48 5fl E 3611 43 S 49 7 E .'.~'123:9~ S 4~ ~6 ,F., 3835.63 0,30 0.27 0.24 0,58 0.46 1,99 3,20 0,71 0,13 0,23 2175,48 S 1919,b0 E 2901,30 ~ 41 25 E 2252,90 $ 198"1,13 E 3004,04 $ 4t 24 E 23~9,52 S 2053,71 F 3105,54 8 4! 23 E 2405,20 S 2119 27 E 3205,t7 $ 41 23 E 2479,71 S 2183:99 E 3304,36 S 41 22 ~ 2553 19 $ 2248 46 E 3402,11 S 41 22 E 2529:07 S 2319:11 E 3505,75 S 41 24 E 2704 46 $ 2401 76 E 3615,99 S 41 36 E 2778137 S 248"1!04 ~ 3728,90 $ 41 49 E 2~51 ~7 S 2571 bl E 3840,03 $ 42 2 E 5606,?0 a94U.O0 4ROO.O0 47 .3R 5753,g7 5040.00 4gO0.()O 47 15 6goo,ob 5140.00 5000.()0 4o 56 7047.51 5240.00 5100,00 45 57 7194 ~9 5340.00 5200,00 47 14 7341 fl2 5440.00 5300.00 47 28 7489 77 5540.00 5400,00 47 21 763& 6~ 5~40.00 5500,00 45 49 7781 73 . 5740.U0 56U0,00 4~ 6 7925 14 5540.00 5700.00 45 20 $ 4~ 55 El 4054.49 $ 48 42 F 4101,~1 S ,t8 30 E 420R,85 S 4~ 32 E 43'16,0~ S 48 43 E 4484.28 c 49 6 E 4593 04 $ 49 21 ~t 4700:33 S 49 49 E 4H05,02 $ 50 lq E 4g07,37 0.20 0.37 0,28 0,38 0,58 0,44 0,'i0 2924 ~1S 2654,05 F: 3949 yo ~ 42 13 E 2990~42 S 2730.55 E 4057~99 $ 42 24 E 3067,23 $ 2B~7.55 E 4164,9~ S 4~ 34 E 3138,18 $ 289~,02 E 4271 bl $ 42 43 E 3209 40 $ 297u,46 E 4378 52 6 42 51 f 3281 05 S 3059,~8 ~ 448~ 44 $ 43 0 E 3352 77 S 3142 03 E 4594 93 S 43 8 E 3423 O3 S 32~3:54 E 4701 95 $ 43 16 E 3491,14 S 3303~ 52 E 4805 39 S 43 25 E 3557,03 S 3382,~2 E 4908 49 S 43 33 E 8056 97 5940,00 5800,00 4,~ 54 8207:g4 6o40.0¢) 5gOO.OU 44 45 8349!15 6140.00 boo0,o0 45 ~g ~49~ 25 6240,00 0100.00 45 21 8633,55 6340,00 5200.00 45 20 8670,00 6365,52 0225,62 45 20 $ 50 43 ~ 50u7.45 S 51 1.7 E 5106.23 S 51 22 E 5205,28 $ S1 31 E 5305,54 S 5~ 32 E 5406.07 $ 51 32 F $431.~2 0,~4 0,15 0,~6 3,58 0,00 0,00 3~21,02 S 3460,02 E 5008,35 $ 43 41 E 3683 58 S 3537,22 E 5105,92 ~ 43 50 E 3'145:05 S 3bl. b. ORf 5205,79 ~ 43 58 E 3808,59 S 3594 10 E 5305,~9 5 44 7 E 3871,~5 $ 3773:38 E 5405,29 $ 44 15 E 3887,77 S 3793,58 E 5432.02 $ 44 17 E ARCO ALAL~KA~ TNC, 2C,' 1 1 K. UPARI1K t~(]ATH ,.S[.OPI<, ALA~I<A ~A,SE IIPpk~R SAND ~A6F LLJW~R ~ANU PBTP C(1)MPUTATj. Oi,~ DATE: 14-NOV-B4 I, NTFHPLII,ATkD VAI..,UE$ FOR CHUSf~N HuRiZuN,~ PAGB '1 DATi~ UF SURVg¥1 lb-OCT-U4 KEI,,L¥ BUSHIi,~('; EbEVATION: 140,00 FT ENGINEER: ~EU'I'bEH/w E~ST Pi E A $ u P it,: P P l< P 'l' H SURFACE bUCATLON A'[' f~k.IGI..: 243' ~'Nb, 272/i FW,. $~2C 5 ~lON ~.gE. UM TVD ECTANGULA~ ~0 RDI~A ES 1;' R l.i N Kb SUB-SEA NO[~ TH/SUII'I'H EAST/W~iST 822U.UO t, 054,22 5914,22 3692,42 R2]B.UC, b061 ,31 5921,3~ 3696,82 832b,()0 t.!, 25. lo 5985.10 3736 4b ~b09,00 b252 47 6112 47 3~16:55 ~ 8670, O0 6365.62 622b, b2 3~B7: 77 3548 2b g 3553 78 E 3603 36 E 703 ' 3793 61~ E COMPUT~TIr~h [~'ATE: 14-NOV-R4 PAGE 8 DATb~ OF SURVEY I 15-UCT-~4 KE66Y BU$itI. NG F, LEVATIUN: I~.NG l m[CI.;R: ~EUTbEK/iN£~T 140.00 FT M £ASI..J R ~.:D P EP'i' H Bkl.,(]k, l< I~S SURFACE 6UCATION AT OHIGIN= 243' FN6, 7.72' ~W6, SEC 5 T1UN, Rg~ UM TVD RECTANGU/.A~ ~OURDINATE [. R(,) N K~ SUB-SEA NURTH/SU[ITH EAST/WEST TOP lJPPFk t{AND BASE UPPLR SAN[) 'l"OP LOWER SAND ~A,.S}.: LtJWER fiAf,)U PBTD TOTAb pEPTH 822~.00 6054.22 5914,22 3692,42 8238.00 b061.31 5921.31 3696,82 832~,0o b125.10 5985.10 3736,4b 8509,00 b252.47 6112 47 3816.55 549.00 6780,5B 614():5B 3834,~4 8670,00 0365.62 6225,b~ 3887,77 35,~B 2b ~2 3553 78 E 3603 36 g 3703 99 g' 3726 27 g 3793 68 g FINAl, Wbj[,l, LC)CA'['IL)N AT 'I,'D: 'I:'R U F, SbB-SEA MEASURh.;D VERTICAl', VER'I'ICAL DEPTH DI?PTrt DEPTH ~-{ Ir) {{ 1 7.., () N 1" A [., UEPARTURg D1STAhCk AZIMUTH RbTO.UO 0305.62 h22b.b? 5432,02 S 44 17 ~: SCHLUME EROER ARCO ALASKA, INC. 20-11 KUPARUK NORTH SLOPE, ALASKA OCTOBER 1S, 1984 TVW PLOT FROM OCT DATA JOB REFERENCE 6964S NW WELL 2G-11 SURFACE LOCATION: 243' FNL, 2?2' Pdl., $5, TIO,H, R9E, UM VERTICAL PROJECTION! -2000 - 1000 0 0 1000 2000 2000 4000 SO00 ..i...; ....... :..,!...;...;.4...; ....... ~..-L-;..4...~..L.L.L.4_ .2_~.LI...i..;._L.-;...i...~...L~...~.L;.._~...L.~ ......... ~ ........... ! ...................... ~ .............. ~..' ....................... 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I....L..~-...-' ...L_ ' ' ' ' ' : ' ~ ' : .... , ........ ? ....... i ........ ,'--, .......... ............ ............ t ....... =---d--, ................ t ................... i ....... , .......... t ..................... ............. t .................. ................. ,"t ................. i .......... -3000 -2000 - 1000 0 1000 2000 3000 4000 E~ Suggested form to be inserted in each "Active" well folder to d~.eck for timoly cc'n~liance ~.d_.th our' rc<julations. ? O~rator~ ]~1 N~n~ and Reports and Materials t° be received by: .Required Date Received Remarks · Ccmple~.on Re~ort Yes ' '. -.. _S~les Core mscrip~on Registered S~ey Plat I Inclina~on S~ey ~/~ Drill St~ Test Re~s ARCO Alaska, Inc. Post Office ?-'~ 360 Anchorage, ~,aska 99510 Telephone 907 277 5637 Date: 11/27/84 Transmittal No: 4868 RETURN TO: ARCO ALASKA, INC. = ATTN: Records Clerk ATO-1115B P.O. Box 100360 T~~ran:Chorage, AK 99510 ir,ed herewith-are the following items. Please acknowledge receipt and return one signed copy of this transmittal. CBL' s/Schlumberger/FINALS "Variable Density" "GCT/JB/GA" 9/19/84 " " " 9/31/84 ,, ,1 fl fl ,I 1, ,1 f, ,, ,1 ,f 11 11 ,, ,! ,1 ,, -11 ,I ,I ,I 1, o. 1, 11 .. 1t 11 11 I! I1 11 11 !1 I! II ,I II I1 1, ,I !I II 11 II 11 11 I1 "ocT" lO/O7/84 " "GCT" 10/07/84 " "GCT/JB/GA" 9/31/84 " "GCT/JB/Ring 9/17/84 " "GA/JB/GCT" 9/19/84 " " 9/17/84 " '.'GCT" 7/21/84' " "GCT" 9/21/84 " "GCT/GA/JB" 9/14/84 " !! ~/15/84 " -',ocr/JC" lO/12/84 " " 1o/15/84 " " 10/12/84 " " 1o/13/84 " "ocr/~/oA" lO/22/84 " " 10/22/84 " "~/oA" 8/19/84 " " 8/20/84 Run 3 9/21/84 Run 1 "OCT/~" 10/14/84 Run 1 " 10/14/84 " " 10/05/84 " "OCT" 10/05/84 " "Per, 4"~ 9/10/84 Run 2 5 1/2"/??s/~" 11/05/84 Run 1 Acoustic "VDL/Signature/GR" /cat Receipt Acknowledged: DISTRIBUTION 6597 - 8292 ~2B-3/ 7000 - 8460 ~2B-!6j 4950 - 7004 ~2B-13v~ 5750 - 8408 --2B-14 5700 - 7970 ~2B-15/ 5348 - 6824 ~2B-2 7250 - 9182 ~-2B-4 5055 - 6487 ~-2B-l~ 6200 - 7866 ~2D-5~/ 6800 - 8954 --2D-6 5054 - 6650 ~2DZT/ 5597 - 8084 5650 - 7951 ~2G-9~ 5840 - 8524 ~G-11~ 4940 - 6765 ~2G-10~ 5730 - 7950 --2G-12~ 5790 - 7814- 2G-13~ 5989 - 8624 --2G-14~ 8650 - 9334 ~F-6/ 8650 - 9562 ~lF-6~ 5692 - 6742 ~Y-5/~ 5150 - 7252 4500 - 6550 ~lL-2~ 6800 - 7518 ~L-4 7000 - 8210 7961 - 8941 --2V-8A 6100- 6992 ~1E-24 B. Currier - BPAE Chevron Drilling W. Pasher Geology' /~ G. Phillips Mobil Phillips Oil Sta~e- bf "'AK' ' '. ~ ~ :~ :,-i ~-)I'O ~-i ,3 Sohio Union D&M NSK Ops. J. Rathmeli Well Files' ARCO Alaska, ....~. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 October 23, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Monthly Reports Dear Mr. Chatterton' Enclosed are the Monthly State Reports for the following wells' 2G-9 1L-8 2D-6 2B-16 2G-10 1L-4 2D-5 2B-15 2G-11 1L-3 2D-4 2B-14 2G-12 1L-2 2B-13 2G-13 Si ncerely, ^rea Dr~]lin§ £n§ineer JBK/SH/tw. HILL/01 Enclosures RECEIVED NOV 0 5 llJ , Al~s:~,~ 0~ & {~as Cons. Commlsslort Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C,~MMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-117 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21149 4. Location of Well at surface 243' FNL, 272' FWL, Sec.5, TION, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 140' RKB, Pad 104' 6. Lease Designation and Serial No. ^DL 25667 ALK 2588 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 2G-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of September , 1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1230 hfs, 9/9/84. Drld 12-1/4" hole to 3347'. Ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 3896' . Leak in 16" x 10-3/4" ann detected. Performed top job w/500 sxs PF "C". Drld 8-1/2" hole to 8649'. Ran logs. Drld 8-1/2" hole to 8670'TD as of 9/16/84. 8549'PBTD. Ran, cmtd & tstd 7" csg. Secured well and released rig @ 2400 hfs, 9/17/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests · 9-5/8", 36#, J-55 + Ijt 10-3/4" 45.5#, K-55 BTC csg w/shoe (~ 3316'. Cmtd w/950 sxs PF "E" & 370 sx PF "C". 7", 26#, L-80, BTC csg w/shoe @ 8632'. Cmtd w/450 sxs Class "G". 14. Coring resume and brief description N/A 15. Logs run and depth where run D IL/SFL/GR/SP/FDC/CNL f/8640' - 3316' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A RECEIVED NOV 0 Alaska 0il & Gas Cons. Commission Anchorage 17. I herebyce~/-~hat the foregoing is true and correct to the best of my knowledge. // NOTE--Re~t on/th~ fo~i~ required for each calendar month, regardless of the status of operations, and must be/filed' in duplicate with the Alaska Oil and C-fas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. [~nrm I (3-~C)z1 .,,, , ,,,~, Submit in duplicate ARCO Alaska, Inc. Date: 10/15/84 Transmittal No: 4773 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 r~~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES ~282001 ~ 10/14/84 Run 1 4001 - 9822 ~RFT TAPE #69527 9/11/84 " 2322.5-7683 Schlumberger 1L-4 '"~.'{"- . #69529 9/16/84 " 3293.5-8671.5 " 2G-11 ~-' #69528 9/16/84 " 3394 - 8110 " 2B-15~: #69527 9/11/84 " " 1L-4 ~' DISTRIBUTION B. Adams D & M W.¥. Pasher C.R. Smith G. Phillips -~State of Alaska F.G. Baker Drilling Phillips Oil Sohio P. Baxter Geology BPAE Mobil J.J. Rathmel2 Union Chevron NSK Operations R & D Well Yiles MEMORA qDUM Sta e of Alaska ALASKA OIL ~*~D GAS CONSERVATION COPR~ISSION ~~¢~ DATE: TO: C. V terton Chai~ FILE NO: THRU: Lonnie C Smith -~':~> Commissioner ~ TELEPHONE NO: FROM: SUBJECT: Harold R. Hawkins Petroleum inspector September 14, 1984 D.21.28 Witness BOPE Test on ARCO Alaska, Inc., Well No. 2G-11, KRU, Sec. 5, T10N,RgE,LR,~, Permit No. 84-117. Monday~ September 10, 1984: I left Anchorage at 3:20 pm by Alaska ~irli~es to prUdhoe Ba~', arriving at 4:50 pm and at the KRU Well No. 2G-11. Tuesday, September 1i, 1984: I witness the BOPE test and test on ~he. mu~d systems 'indi¢~tor~ There were no failures. I filled out an AOGCC report which is attached. In summary, i witnessed the BOPE test and checked the mud flow line indicators on ARCO's Well No. 2G-11. The BOPE tests and flow line indicator checks were satisfactorily performed. Attachment 02-00IA(Rev. 10179) ~ O&G: #4 5/84 Inspector STATE OF ALASKA ALASKA 0IL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Well Operator A~ ~-~ .~/~',:/'f'/~. /;)7~- Location: Sec ,~-- T/D~/ R~0 M Re p r es en t a t ive p~x-~7 //5/z~ Permit # ~ --//7 .?~Casing Set @ 37/~ ft. Drilling Contractor ~.~/~FL~ Ri Location, General ~/< Well Sign General Housekeeping ~/~Rig Reserve Pit Mud Systems Visual Audio Trip Tank ~/~ J Pit Gauge ~/: / Flow Monitor ~/r ~' Gas Detectors ~/~ ~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure #Y Representative /~/ ~,//~/~/~0/D ACCUMULATOR SYSTEM Full Charge Pressure psig Pressure After Closure psig/ ~ Pump incr. clos. pres. 200 psig ~ min~J sec. Full Charge Pressure Attained: ~ min~j sec. Controls: Master Remote ~/~ Blinds switch cover Kelly and Floor Safety Valves Upper KellM Lower KellM Ball Type Inside BOP Choke Manifold No. Valves /> No. flanges _~--2 Adjustable Chokes ~//' ~ Hydrauicall7 operated choke Test Time ~7~ Test Pressure Test Pressure .~ Test Pressure ~ Test Pressure _~ Test Pressure /~/Q/w/~L-'' hrs. Repair or Replacement of failed equipment to be made within -------days and Inspector/ Commission office notified. Remarks: ~/p/~)/ /~{3 6)~) ~-~/C~-- Distribution orig. - A0&GCC cc - Operator cc - Supervisor July 19, 19B4 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 .~nchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2G-11 ARCO Alaska, Inc. Permit No. 84-117 Sur. Loc. 243'FNL, 272'FWL, Sec. 5, T10N, R9E, UM. Btmho!e Loc. i153'FSL, l152'FEL, Sec. 5, T!0N, R9E, UM. Dear Mr. Kewim: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spa~ming or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Gs~e. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. k~in Kuparuk River Unit 2G-11 -2- July 19, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, pleas~ also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In-the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C. V. Cha~eerton Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF ~E COMMISSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. , ~ Post Office B(,.. ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 16, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-11 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2G-11, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat A diagram and description of the surface hole diverter system A diagram and description of the BOP equipment Since we estimate spudding this well on August 3, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, O. B. KewigF , Area Drilling Engineer JBK/JG/tw GRU8/L52 Attachments RECEIVED J U L 1 7 ] 84 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany la. Type of work. STATE OF ALASKA '~-" ALASKA OIL AND GAS CONSERVATION COIwMISSlON PERMIT TO DRILL DRILL E~X REDRILL [] 1 b. Type of well 20 AAC 25.O05 SERVICE [] STRATIGRAPHIC [] SINGLE ZONE EiXX '%~ ~.. I 9. Unit or lease name DEEPEN [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] 4. Location of well at surface 243' FNL, 272' FWL, Sec.5, TION, R9E, UM At top of proposed producing interval 1384' FSL, 1383' FEL, Sec. 5, TION, RgE, UN At total depth 1153' FSL, 1152' FEL, Sec.5, TION, R9E, UM 5. Elevation in feet (indicate KB. DF etc.) I ' 6. Lease designation and serial no. RKB 140', PAD 104' J ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Kuparuk River Unit 10. Well number 2G-11 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 2G-l~ell 60' ~ surface feet 16. Proposed depth (MD & TVD) 8673' MD, 6365' TVD 18. Approximate spud date 08103184 19. If deviated (see 20 AAC 25.050) 2770 KICK OFF POINT 500 feet. 3180 Weight 62,5# 36.0# 26.0# 21 SIZE IH°le I Casing 14. Distance to nearest property or lease line miles 243 feet 17. Number of acres in lease feet 2501 20. Anticipated pressures MAXIMUM HOLE ANGLE 47.4° (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program CASING AND LINER Grade Coupling/ / We]~ J-55 J-55 HFIERW BTC] Length SETTING DEPTH MD TOP TVD 80' 36' 36' I 35' I I 3263' 35' i 8640' 33' I I 33' 8673'1 6365' I 22. Describe proposed program: psig@ 80°F Surface psig@ R23CI ft. TD (TVD) MD BOTTOM TVD 1161 116' 3298} 2730' I QUANTITY OF CEMENT (include stage data) ± 200 cf 920 sx Permafrost E & 370 sx Permafrost C 300 sx Class G ARCO Alaska, Inc., proposes to drill a KuParuk River Field development well to approximately 8673' MD (6365' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while.drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2770 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-11 will be 60' away from 2G-10 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge S,GNED ~¢¢J~/A/"~.__~/~ ~ X~ t.~.~ TITLE Area D ri]],ng E ngi neet The space belo~ ~r d~ission~ - ~- f/ ISamples required '[]YES /~NO I Permit number . APPROVED BY Form 10~,01 GRU8/PD20 CONDITIONS OF APPROVAL Approval date Mud log required I Directional Survey required []YES [~LNO I .[~--Y E S E]NO I I IAPl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE 3uly lg, 19tg& by order of the Commission Submit in triplicate Permit to Dril 1 2G-11 workover rig using 3-1/2", 9.2#/ft, J-55, BTC tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Alaska Oil & Oas Cons, Commission A F!rth 9,-3~..~ ,-, 'ANNULAR DIAGRAM #1 13-5/8" 5000 PSI RSRRA BOP STACK PIP~ P,~ 1. 16" - 2000 psi Tanked starting head 2. 11" - 3000 psi casing head 3. 1I" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/B" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 13-5/8" -.5000 psi annular BLIND · RAM~ sDR I LL.l:NG PIPE 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 DOWNSTRFJObM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST i. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VALVES LFPS~ OF CHOI<~S. DON~T TI~ST AGAINST CZOSEJ) CFDI<ZS 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10. MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 B. ~~'PRESSbRE DOWNSTREAM OF CHOKE ISOLATION ~/AL.V~S~ TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR MINUTES BLEED TO ZERO PSI. 11. OPEN BOt'FDM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAJw~s AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KDOMEY PUMP. 15. RECORD TEST INFORMAT!DN ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. J I.IL I .? JSJ4 Alaska Oil & Gas Cons. 7 1. 2. 3. 4. 5. 6. 7. Surface Diverter System 16"-2000 psi Tankco starting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/10" side outlets. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor RECEIVFD ,JIJL 1 ? 19F 4 Alaska Oil & Gas Oons. Oommission Anchorage ARCO Alaska, Inc. Post Office b,~x 100360 ~-.-~___ Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plat - 2G Pad Wells 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer JG/tw GRU8/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ~ G CON O A,$1]:I~i 'r "'~' $! & DS 2G ~2 TI 1II I HEREBY CERTIFY THAT I AM PEOPERLY EEGISTERF~ AND LICENSED TO PKA~ICE ~D ~RV~ING IN THE ~A~ OF- A LA SKA AND ~AT TH 1 S P LAY ~DEK MT DIRECT SUP~VISION A~D ~AT ALL D~AILS ARE A 49th Y-~94419~.0~ X- 5~929.92 236 ~L Y-~94413~.21 X- ~0~929.90 236 ~L Y-~44075.12 236 ~L Y-~94401~.09 X- ~0&929.94 235 ~L LO~A~ IN SE~IO~ 5,T~ ~%,~9E,~,~ Y-~94346~.24 ~T- 70-15-24.3213 X- ~0~969.91 ~N~149-5~-39.024 273 ~L l Z3 ~ 272 ~L 183 ~ X- 508969.92 LON~I49-55-39.02& 272 ~L 243 ~ ~- )0&9~.84LON~ 149=55-~9,0~ 272 ~L 303 ~ ~~ED [~ SE~TIO~ 6,TION,RgE,U.~ Y-~94~345.1~ ~T- X,~0~.~0 ~N~4~-~-4~.~0~ X- 506609.9~ LAT- 7(}- 15-31.5000 LONG- 14g-55-40.1 $2 607 FSI. LAT- 70-15-30.9! 15 LONG- 149-55-40,16~ 547 FSL I. AT- 70-15-30.3204 LONG- 149-55-'I0. I 64 487 FSL I. AT- 70-15-~g.7~99 LONG- I'I9-55-40.1 ~ 4Z7 243 FNL LAT- 70-15-23.735~ LONG- I49-55-49.499 [.AT- ?0-15=24,3252 Kuperuk Project North Slope Driili, D.~ 2. G CONDUCTORS §- 16 AS- BUILT mi... _ ~smte' 6, Z.$4 !,c.~e'None '. WELL PERMITS · :'-. '. '-:.' ?'i '~-~.~ . (1) Fee ":' ~'"') '~'~/'~/ 1. (2) T.o ?-i?-¢? 2. ¢ thru 8) 3. .#~,~ ' 7-/~-~ (3) (',i~ thru (10 and 11) (4) Cas~ ~~ 7-/~~ (12'thru 20) e 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Company. ~'~ · ,. . , Lease & Well No'.. /~' _ .. Is the permit fee attached .............................. Is well located proper distance from property line ....... Is well located proper distance from other wells ........ Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ... Is operator the only affected party ................ · ..... can permit be approved before ten-day wait .............. Does operator have a bond in'force ...................... Is a conservation order needed ...................................... Is administrative approval needed ..................................... REMARKS z4 r/ y '(21 thru~ 24) (6) Add: 21. 22. 23. 24. 25. Is'conductor string provided ......... ' .............................. · Is enough cement used to circulate on conductor and surface ....... ' Will cement tie in surface and. intermediate or production strings · Will cement cover all known productive horizons .............. ; ...... Will surface casing protect fresh water Zones ................ , .... Will all casing give adequate safety in collapse, tension and burstl. Is this well to be kiCked off from an existing wellbore ........... · Is old wellbore, abandonment procedure included On 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required .. ...... _. ...................... ~ Are necessary, diagrams of diverter and ~ ,equipm;nt ;t~ac~e~ .. Does BOPE have sufficient pressure rating,- Test to ~_,~r~ psig .. ,~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. 7~ Additional RemarkS: o ~Z ~0 E.! Geology: Engineering: HWK~ Lcs /~ ~EW ~ WVA~ JKT~HJH ~ JAL ~ ~'j.z rev: 12/08/83 6. CKLT 'INITIAL GEO. UNIT O~/OFF POOL CLASS STATUS AREA NO. SHORE , , 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. D~TE :~.4/!0/ 7 COMYE;,~TS : ** TAPE HEADER SERViCK P,{ A. ~ i:;: DATE :~4/10/ 7 ORIGI;x :0000 TAPE ~:' a ~: E :9529 CONTI~'~L~A'I'I{3k; ff :01. PREVI Oils TAPE ,00I 102~. u N I T : 2<;I l, 1. FN : k UPARUK · :RA,N G: 9 Hq C!3U Iu: k,~, SLOPE', STAT:: ALASKA C T R Y: L, o A I ,, C T Y P E 00 () 0 O0 000 000 oO () UO0 0 0 0 u 0 u C A T El 00 o 0 00 000 000 o 000 o (,) (.) 000 00 u 0 lb 005 007 002 0 {.)4 0 01 012 0 0 6 u 0 3 065 065 065 065 005 065 ALASKA D.[VZSI(.)~:'''~ COi-.~PUTIi.~C, CKI,~q.'ER TAP~j O[~:qS[TY = gO0 ,~.Pl, 69529 DATE LD(';GEO 16 SEP 84 33!6 FT, [, V P 0 1 0. t-~ Il, '2 V F., R ! F I C/~ T I U ;',~ L I S 'I I ~; ,'J; P a G F. 3 9.00 4..q 0 3 o 970 ,a 7 O F 4,47O ra 70 F 3.400 :~ 70 2,090 ~ 140 MklEM SERVIC~ SERVICE [.J,t'.:fT .kPI APl AP1 AP1 FI!,F. SIZE Sm.L, RE.PR ID OROER ~ LOG TYPE; C[~,ASS D E P ~' F T 00 o 00 0 o 0 0 4 SFLU i}].L 0 H.,'4 ~,~ Oo 220 01 o 0 4 i I., D i":. [ L 0 H ,~ ~, 00 120 46 o 0 4 I L H I,';. 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