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182-158
Irna(. ect Well History File Cover 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. ]._ ~ (~- .~ ~ .~Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: D Other BY: ~OBIN VINCENT SHERYL MARIA WINDY Project Proofing BY: BEVERLY ROBIN VINCE~ARIA WINDY Scanning Preparation c~ x 30 = ~ BE~INCENT SHERYL MARIA WINDY Production Scanning Stage 1 BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THiS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS CUE TO QUALITY, GRAySCALE OR COLOR IMAGES ) PAGE COUNT FROM SCANNED FILE: NUMBER IN SCANNING PREPARATION: ~ YES NO MATCHES i~[r~ IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BEVERLY ROBIN DATE'/ 0 S/~ III Illllllllll II II ReScanned findividual page [special a~e~tionJ seasoning completed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (do.e) 12/10/02Rev3NOTScanned.wpd A. , OF 7 • • 4,* I �� , THE STATE M . ask 1k and a " Of L co,kiLertvaUGLI COMMISSI011 s _ ,Q GOVERNOR SEAN PARNELL 333 West Seventh Avenue Y �[ r Anchorage, Alaska 99501 -3572 ALAS ED UN 2 4 'iQ 3 Main: 907.279.1433 SCANNED ,-- Fax: 907.276.7542 James Ohlinger `7 v CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E -28 Sundry Number: 313 -290 Dear Mr. Ohlinger: 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. Commissioner DATED this /U day of June, 2013. Encl. STATE OF ALASKA fa" A KA OIL AND GAS CONSERVATION COMIIISION tt 1 0 -'3 ; a L'; . APPLICATION FOR SUNDRY APPROVALS b K t . -, , y : 20 AAC 25.280 , i. `t. "} . -; 1. Type of Request: Abandon 1" -- Rug for Redrill I• . Perforate New Pool r Repair w ell f Change Approved Program E Suspend E Rug Perforations I✓ . Perforate r Pull Tubing (""" Time Extension E Operational Shutdow n I- Re -enter Susp. Well E Stimulate E Alter casing Other: i" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l� , Exploratory E 182 - 158 3. Address: Stratigraphic [ Service (' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20832 - 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 Yd 1 E - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25651 • 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): 7665 • 6679. 7547' 6562' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79' 16 114' 114' SURFACE 2271 10.75 2305' 2183' PRODUCTION 7599 7 7629' 6644' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): `7088 -7175, 7318 -7328, 7345 -7366 6125 -6208, 6345 -6354, 6371 -6391 3.5 L - 7258 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'FHL PACKER • MD= 7041 TVD= 6080 PACKER - BAKER 'DB' PACKER • MD= 7253 TVD= 6282 NIPPLE - CAMCO 'DS' NIPPLE • MD= 501 TVD= 501 12. Attachments: Description Summary of Proposal , ) 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r.- Development • Service 1 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: / Ajb 7/8/2013 Oil ,i ' Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ I GINJ r WAG r Abandoned E Commission Representative: GSTOR I — SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265 -1102 Email: James.J.Ohlinaer(cop.com Printed Name es Oh 'u er Title: CTD Engineer Signature Lleme a. _` Phone: 265 -1102 Date 6 /O /e "/� Commission Use Only Sundry Number: '5I 3 -9 qt, Conditions of approval: Notify Commission so that a representative may witness Plug Integrity j"" BOP Test 'V" Mechanical Integrity Test E Location Clearance E Other: 5d f f-CS 1" to 4-(MC /2 5 L A /tcr /e plvv ,pla c inchi - a pca- 2.0 A C 25 /JZCI Spacing Exception Required? Yes 0 No Subsequent Form Required: / 0 — 1 / A PPROVED BY t/ Q J y r Approved by: CO MMISSIONER THE COMMISSION Date: (Cj pproved application is valid for 12 mon ths from the date of approval. Form 10 -403 (Revised 10/2012) ORIGINAL Submit Form and Attachme t in Duplicate ‘P \� r��r 6./43/ a3 RBDMS JUN 2 0 20 ���� • • KRU 1E -28 CTD Summary for Perforating & Plugging Sundry (10 -403) Summary of Operations: Well 1E -28 is a Kuparuk A- sand /C -sand production well equipped with 3'/2" tubing and 7" production casing with the C -sand behind a straddled selective. The well was recently worked over by removing the original 2 -7/8" tubing and replacing it with a 3 -1/2" completion. The CTD laterals drilled from the producer- injector well pair 1E- 28A/1F -16A will target the Kuparuk A -sands in fault blocks adjacent and corresponding to the wells current locations. 1E -28 is planned for 4 laterals or 9,365' of total hole in the A -sand reservoir. The existing A -sand perfs have been isolated with a plug in the XN nipple at 7271' RKB covered by a 8' sand plug in the tubing tail. Prior to drilling, the existing C -sand perfs and straddle annulus in 1E -28 will be squeezed with cement to provide a means to kick out of the 3 -1/2" and 7" casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the A & C -sand perfs in this manner. After plugging off the existing C -sand perfs with cement, a mechanical whipstock will be placed in the 3 -1/2" tubing at the planned kickoff point. The 1E -28A and AL1 sidetracks will exit through the 3 -1/2" tubing and 7" casing at 7,215' MD and will target the A4 and A5 sands west of the existing well. The laterals will be completed with 2 -%" slotted liner from TD with the liner top located inside the 31/4." tubing at 7,210' MD. Another mechanical whipstock will be installed so the 1E -28AL2 and AL2 -01 sidetracks can exit through the 3 -1/2" tubing and 7" casing at 7,190' MD and will target the A4 and A5 sands east of the existing well. The laterals will be completed with 2-%" slotted liner from TD with the liner top located inside the 3'/2" tubing at 7,185' MD. CTD Drill and Complete 1E -28 Laterals: July /August 2013 Pre -CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs — T & IC 3. MIT -IA 4. RU slickline. Drift tubing with dummy whipstock 5. RU Eline: GR/CCL for jewelry correlation log 6. RU Eline: Perforate tubing at 7060' -7070' RKB and 7220' -7230' RKB 7. RU coil: Cement Squeeze C -sand perforations, and fill 3 -1/2" x 7" straddle annulus 8. RU slickline. Tag top of cement and pressure test. 9. RU coil: Mill out cement in the 3 -1/2" tubing 10. Prep site for Nabors CDR2 -AC, including setting BPV Page 1 of 2 6/10/2013 • • Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005 (c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c) (4) (a)) A static bottom hole pressure of 1E-28 in September 2012 indicated a reservoir pressure of 2863 psi or 8.7 ppg equivalent mud weight. The maximum down hole pressure in the 1 E -28 pattern is at injector 1E-15 with 3986 psi. It is not expected that reservoir pressure as high as 1E-15 well will be encountered while drilling the 1 E -28 laterals because of offset distance and faulting. Using the 1 E- 15 pressure as the maximum possible in 1E -28, the maximum possible surface pressure, assuming a gas gradient of 0.1 psi /ft, would be 3384 psi. Rig Work v N 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 1E -28A Sidetrack (A4 sand, west) a. Set whipstock at 7215' MD b. Mill 2.80" window at 7,215' MD. c. Drill 2.70" x 3.0" bi- center lateral to TD of 11,100' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7,500' MD 3. 1E -28AL1 Lateral (A5 sand, west) a. Kick off of the aluminum billet at 7,500' MD 1 7-- -9 b. Drill 2.70" x 3.0" bi- center lateral to TD of 11,100' MD c. Run 2%" slotted liner from TD up to 7,210' MD, inside the 3'/2" tubing tail 4. 1E -28AL2 Sidetrack (A4 sand, east) a. Set whipstock at 7190' MD b. Mill 2.80" window at 7,190' MD. c. Drill 2.70" x 3.0" bi- center lateral to TD of 8,450' MD d. Run 2%" slotted liner with an aluminum billet from TD up to 7,500' MD 5. 1E -28AL1 Lateral (A5 sand, east) a. Kick off of the aluminum billet at 7,500' MD b. Drill 2.70" x 3.0" bi- center lateral to TD of 8,450' MD c. Run 2%" slotted liner from TD up to 7,185' MD, inside the 3'/2" tubing tail 6. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pu11 BPV 2. Obtain static BHP. Install GLV's. 3. Return to production Page 2 of 2 6/10/2013 -7 KUP • 1 E -28 Conoco Phi llips ' 1.1 -,,. Well Attributes Max Angle & MD TD Alaska k1C Wellbore API /UWI Field Name Wellbore Status Inc/ ( MD (ftKB) Act Btm (RKB) cnnocactwap5 " 500292083200 KUPARUK RIVER UNIT PROD 44.44 4,100.00 7,665.0 " ' Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date SSSV: NIPPLE 195 9/26/2011 Last WO: 5/30/2013 39.00 10/7/1982 Well Confo4' - :3 54 AM schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: SLM 7,402.0 9/4/2012 Rev Reason: WORKOVER osborl 6/7/2013 Casing Strings HANGER, 30 PP CONDUCTOR Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 34.0 79.0 79.0 65.00 H WELDED Casing Description String 0... String ID ... Top (RKB) Set Depth (t.. Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 33.9 2,304.9 2,182.5 45.50 K - 55 BTC MI ■ Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String INt... String ... String Top Thrd PRODUCTION 7 6.276 30.4 7,629.3 6,644.1 26.00 K BTC ( • 1 Depth 1 1 . 1 :1 EUE CONDUCTOR, • - tails 34-79 Top Depth T ortio) (ftKB) (*) Item Description Comment ID (in) 29.6 29.6 -1.74 HANGER FMC TUBING HANGER w/PUP 2.992 NIPPLE, 501 531.0 501.0 a 16 NIPPLE CAMCO • 7,011.2 6,051.8 18.00 SEAL ASSY BAKER LOCATOR/SEAL 99 VVt... String ... String Top Thrd n • 1 1 String 1 :1 Selective �f Com - '. ■ 1 : .' . `:'. ';;.. a •,• "AM(' \ SURFACE, ,J Top Depth 34 -2,305 (TVD) Top Inc! Noml... Top (RKB) (RKB) (1 Item Description Comment ID (in) 7,017.4 6,057.7 18.01 PBR BAKER 80 PBR 2.980 GAS LIFT, 2,702 7,040.5 6,079.7 17.47 PACKER BAKER 'FHL PACKER 2.900 _ 7,093.2 6,129.9 17.97 NIPPLE CAMCO'D' NIPPLE w/ RHC Plug installed with Ball & Rod 2.812 7,251.0 6,280.5 17.07 SEAL ASSY BAKER 80-32 LOCATOR/SEAL ASSEMBLY 2.400 IIIII Tubing Description String 0... 'String ID ... Top (RKB) Depth (f... Depth (TVD) ... String Wt.. String ... String Top Thrd GAS LIFT, TUBING WO 1995 I 27/8 Str 2.441 I 7,252.7 'Set 7,283.3 'Set D 6,311.4 'String I L - 80 I EUE8rd 4,424 imy Completion Details Top Depth 1111. ( T M Top Inc! Nomi... In Top (RKB( (RKB) P1 Item Description Comment ID (In) 7,252.7 6,282.1 17.05 PACKER BAKER 'DB' PACKER 3.250 GAS LIFT, 5,642 111M 7,256.3 6,285.6 17.01 SBE BAKER SEAL BORE EXTENSION 3250 l ir 7,271.3 6,299.9 16.82 NIPPLE OTIS 'XN' NIPPLE w/2.313" PROFILE 2.250 Mk 7,282.5 6,310.7 16.76 SOS BAKER SHEAROUT SUB (SHEARED) 2.375 GAS LIFT ® - Perforations & Slots 6,376 --- Shot Top (TVD) Btm (TVD) Dens lir. Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (sh °. Type Comment 7,088.0 7,175.0 6,125.0 6,207.9 C-4, C -3, C -1, 10/6/1982 8.0 IPERF UNIT B, 1E -28 GAS LIFT, 6,957 7,318.0 7,328.0 10/6/1982 1 IPERF I 7,345 1 7,366 1 6,370.6 6,390.7 16 8.0 IPERF SEALASSY, / Depth Depth IND) (TVD) 7,01i 1 PBR, 7,017 I Type 1 81 61 1 1 10/25/1995 D TO COMPLETION WITH 10 - AT PERFS ( 2BBLS SHORT OF TOP PERF W/ 16 PACKER, 7,041 BBLS OF 118404# IN THE • 1. 1 104203# • OF 12/18, 7777# O 1 , 7,088.0 7,366.0 6,344.7 6,390.7 FRAC 10/25/1995 FRAC FLUSHED TO COMPLETION WITH 10 PPA BBLS OF DIESEL NIPPLE. I -� - 1 • • • • •'••:' IPERF, - :414• AND 7,088 - 7775 OF 1. 1 104203# OF OF 1 FRAC, 7,088 Notes: General & Safety End Date Annotation 10/18/1995 NOTE: WORKOVER IIIII 9(7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 7, g SEAL A 253 SSY,-\ 7,251 Da SBE, 7,256 I AIM Mandrel Details Top Depth Top Port NIPPLE, 7271 1! S... (TVD) Inc/ OD Valve Latch Size TRO Run N... Top (ftKB) (RIO) (•1 Make Model (in) Sera Type Type On) (psi) Run Date Com... . 1 2,702.3 2,503.5 37.19 Camco KBMG - 1 GAS LIFT SOV BEK 0.000 0.0 5/29/2013 SOS, 7283 2 4,423.7 3,788.5 39.99 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 3 5,642.1 4,800.6 29.92 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 - 7 328 7,378 - 7,328 I 4 6,375.5 5,456.0 22.32 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 FRAC, 7,318 5 6,956.9 6,000.2 18.07 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 IPERF, 7,345 -7,366 1 i PRODUCTION, 30 -7,629 TD, 7,685 1E-28A Proposed CTD Sidetrack 16" 65# H -40 I 3 -1/2" Camco DS nipple @ 501' MD (2.875" ID) j shoe @ 79' 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 10 -3/4" 45.5# K -55 3 -1/2" Camco gas lift mandrels @ 2702', 4424', 5642', 6376', shoe @ 2305' RKB and 6957' RKB. - III Service CTU to ====I Baker 80 -40 3 -1/2" PBR @ 7017' RKB, 20' long (4" ID) squeeze annulus Z Baker FHL packer @ -7041' RKB (4.0" ID) 3 -1/2" Camco 'D' nipple @ 7093' RKB (2.813" min ID) - —_ C -sand perfs — — 7088' - 7175' 3 -1/2" R3 CTD KO joint @ 7198' - 7240' RKB (7" collars @ 7207', 7254' ELM) KOP @7190' �\ s \ ` \ \ - Existing Completion - \� \ Baker 2 -7/8" x 7" 'DB' packer @ 7244' ELM (7253' RKB) (3.25" KOP @ 7215' VA \ \ ID) a \ \ \ VA \ \ \ 8 ft sand on top of plug. 11 - - - ' VA 2 -7/8" Otis 'XN' nipple w/ plug @ 7271' RKB � \` \ (2.25" min ID, No -Go) — i `` \ ` • `\ \ \ . tf , \\ \ A -sand perfs 1 \` I1E- 28AL2 -01, A5 East 1 E- 28AL1, A5 West 7318' - 7328' MD I TD = 11,100' 7345' - 7366' MD I ' \ \ TD = 8,450' 1 E -28A, A4 West I E- 28AL2, A4 East TD = 11,100' (Billet @ 7,500') 7" @267#6K2 - 55 R shoe B TD = 8,450' (Billet @ 7,500') _� K • • Page l of 1 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). J 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. T-- - r. TT 7 TTTTDThTT DT TT(_ «DT: T11? T A /(,1')(11') , I STATE OF ALASKA ALSA OIL AND GAS CONSERVATION COK.SION REPORT OF SUNDRY WELL OPERATIONS �. 1. Operations Performed: Abandon n Repair w ell E Plug Perforations f P erforate s Other )--°,+!'�. (. )! "' r • Alter Casing r Pull Tubing F • Stimulate - Frac r Waiver r Time Extension F Change Approved Program f Operat. Shutdow n r Stimulate - Other I Re -enter Suspended Well T 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development i✓ . Exploratory r • 182 -158 3. Address: 6. API Number: Stratigraphic Service fi 50 - 029 - 20832 - P. O. Box 100360, Anchorage, Alaska 99510 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651 ' 1 E -28 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool . 11. Present Well Condition Summary: Total Depth measured 7665 • feet Plugs (measured) none true vertical 6679 feet Junk (measured) none Effective Depth measured 7547 feet Packer (measured) 7041, 7253 true vertical 6562 feet (true vertical) 6080, 6282 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 114 114 SURFACE 2271 10.75 2305 2183 PRODUCTION 7599 7 7629 6644 Perforation depth: Measured depth: 7088 -7175, 7318 -7328, 7345 -7366 SCANNED JUN 1 8 2013 True Vertical Depth: 6125 -6208, 6345 -6354, 6371 -6391 Tubing (size, grade, MD, and TVD) 3.5, L -80, 7258 MD, 6288 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FHL PACKER @ 7041 MD and 6080 TVD PACKER - BAKER 'DB' PACKER @ 7253 MD and 6282 TVD NIPPLE - CAMCO 'DS' NIPPLE @ 501 MD and 501 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 72 404 2580 — 233 Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E • Development I✓ Service r Stratigraphic I — 16. Well Status after work: • Oil 1.7 Gas f WDSPL E Daily Report of Well Operations XXX GSTOR f__ WINJ E WAG r GINJ F SUSP E SPLUG E 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: none Contact Brett Packer (&.265 -6845 Email J. Brett.Packer @conocophillios.com Printed Name J. Brett Packer Title Wells Engineer rett Signature � '� e _ Phone: 265 -6845 Date / (,./ t /1F i'' ag4e7 RBDMS JUN 11 DI* Form 10 -404 Revised 10/2012 ) 4 1 3 Submit Original Only d KUP • 1 E -28 Conoc 01 Well Attributes Max Angle & MD TD Inc; Wellbore APUUWI Field Name Wellbore Status lncl ( °) MD (ftKB) Act Btm (ftKB) Alaska, 500292083200 KUPARUK RIVER UNIT PROD 44.44 4,100.00 7,665.0 +.., Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date _ ... SSSV: NIPPLE 195 9/26/2011 Last WO: 5/30/2013 39.00 10/7/1982 Well Centel '. - 1 E -28, 6/7/2013 6:30:54 AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod By End Date Last Tag: SLM 7,402.0 9/4/2012 Rev Reason: WORKOVER osborl 6/7/2013 Casing Strings HANGER, 30 ° Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.060 34.0 79.0 79.0 65.00 H WELDED ` Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 33.9 2,304.9 2,182.5 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD)... String Wt... String .. String Top Thrd PRODUCTION 7 6.276 30.4 7,629.3 6,644.1 26.00 K -55 BTC ar Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 2013 I 31/2 2.992 29.6 I 7,034.0 I 6,073.5 9.30 L -80 I EUE CONDUCTOR - Completion Details 3479 Top Depth IF (ND) Top Inc! Nom,... Top (ftKB) V") ( °) Item Description Comment ID (in) 29.6 29.6 -1.74 HANGER FMC TUBING HANGER w /PUP 2.992 NIPPLE, 501 501.0 501.0 0.06 NIPPLE CAMCO 'DS' NIPPLE 2.875 7,011.2 6,051.8 18.00 SEAL ASSY BAKER LOCATOR/SEAL ASSEMBLY w/ 7 -ft space out 2.990 77' Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 2013 3 1/2 2.992 7,017.4 7,258.4 6,287.6 9.30 L -80 EUE 8rd Mod Selective Completion Details SURFACE, Top Depth 342,305 • (TVD) Top Inc, Nomi... Top (ftKB) (RKB) I Item Description Comment ID (in) 7,017.4 6,057.7 18.01 PBR BAKER 80-40 PBR 2.980 GAS 2,70 LIFT 7,040.5 6,079.7 17.47 PACKER BAKER 'FHL PACKER 2.900 2 7,093.2 6,129.9 17.97 NIPPLE CAMCO 'D' NIPPLE w/ RHC Plug installed with Ball & Rod 2.812 lig 7,251.0 6,280.5 17.07 SEAL ASSY BAKER 80-32 LOCATOR /SEAL ASSEMBLY 2.400 Tubing Description ing 0... String ID ... p (ftKB) Set Depth (6... epth (ND) ... String Wt... String ... g Top Thrd GAS LIFT, . TUBING WO 1995 I Str 2 7/8 I 2.441 I 7o 7,252.7 I 7,283.3 I Set D 6,311.4 I 6.50 I L - 80 I Strin EUE8rd 4,424 IIII Completion Details Top Depth (ND) Top Inc! Nomi... i IIII Top (ftKB) (ftKB) 1 ° ) Item Description Comment ID (in) 7,252.7 6,282.1 17.05 PACKER BAKER 'DB' PACKER 3.250 GAS LIFT, s,642 7,256.3 6,285.6 17.01 SBE BAKER SEAL BORE EXTENSION 3250 llllllI 7,271.3 6,299.9 16.82 NIPPLE OTIS 'XN' NIPPLE w/2.313" PROFILE 2.250 IN 7,282.5 6,310.7 16.76 SOS BAKER SHEAROUT SUB (SHEARED) 2.375 GAS LIFT. { Perforations & Slots 6,376 Shot IN Top (ND) Btm (TVD) Dens WI Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (sh -• Type Comment 7,088.0 7,175.0 6,125.0 6,207.9 C-4, C-3, C-1, 10/6/1982 8.0 IPERF UNIT B, 1E -28 GAS 09T7 7,318.0 7,328.0 6,344.7 6,354.3 A -5, 1E -28 10/6/1982 8.0 IPERF 7,345.0 7,366.0 6,370.6 6,390.7 A -4, 1E -28 10/6/1982 8.0 IPERF IIII Stimulations & Treatments Bottom }}}_�� Min Top Max Btm Top Depth Depth SEAL Depth Depth (ND) (ND) 7.011 ,011 (ftKB) (ftKB) (ftKB) (ftKB) PBR, 7.017 Type Date Comment 7,088.0 7,366.0 6,125.0 6,207.9 FRAC 10/25/1995 FRAC FLUSHED TO COMPLETION WITH 10 PPA AT PERFS ( 2BBLS SHORT OF TOP PERF W/ 16 PACKER. 7,041 BBLS OF DIESEL PAST THE SWAB VALVE). H PUMPED A TOTAL OF 119279# OF PROPANT, 118404# IN THE PERFS AND 875# IN W.B., 9368# OF 20/40, 104203# OF 12/18, 7777# OF 10/14. 7,088.0 7,366.0 6,344.7 6,390.7 FRAC 10/25/1995 FRAC FLUSHED TO COMPLETION WITH 10 PPA AT PERFS ( 2BBLS SHORT OF TOP PERF W/ 16 BBLS OF DIESEL PAST THE SWAB VALVE). NIPPLE, 7693 -- II9 PUMPED A TOTAL OF 119279# OF PROPANT, IPERF, t. OF 20/40, 1042039 OF 12/18, 777 #1OO 100/14368# 7.088-7.175 FRAC, 7,088 :... Notes: General & Safety End Date Annotation 10/18/1995 NOTE: WORKOVER 9/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER, 7,2 MI SEAL ASS53 V, zoom: 7,251 I t SBE, 7,256 Mandrel Details Top Depth Top Port NIPPLE, 7,271 S... (TVD) Incl OD Valve Latch 5i40 TRO Run N... Top (ftKB) (ftKB) (°) Make Model (in) Sery Type Type tin) (psi) Run Date Com... 1 2,702.3 2,503.5 37.19 Camco KBMG 1 GAS LIFT SOV BEK 0.000 0.0 5/29/2013 80S, 7,263 2 4,423.7 3,788.5 39.99 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 3 5,642.1 4,800.6 29.92 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 IPERF, I II �� 4 6,375.5 5,456.0 22.32 Camco KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 1 GAS LIFT DMY BK -5 0.000 0.0 5/29/2013 7,318 FRAC.7,318 5 6,956.9 6,000.2 18.07 Camco KBMG IPERF, 7,345 -7,366 PRODUCTION, 30- 7.629 . A - TD, 7,665 1 E -28 Pre -Rig Well Work Summa DATE SUMMARY • 4/26/2013 (PRE RWO): MITOA- PASSED, T POT - PASSED, T PPPOT- PASSED, IC POT - PASSED, IC PPPOT- PASSED, OC POT - PASSED, OC PPPOT- PASSED. FUNCTION TEST T, IC & OC LDS'S: ALL FUNCTIONED PROPERLY. 5/13/2013 BRUSHED & GAUGED TBG TO 5600' SLM W/ 2.29 GAUGE RING; SET 2 7/8 SLIP STOP CATCHER @ 5516' SLM & PULLED OV @ 5011' RKB. IN PROGRESS. 5/15/2013 PULLED GLVs @ 4212' & 2424' RKB. SET DVs @ 2424', 4212' & 5011' RKB. PULLED SLIP STOP CATCHER @ 5516' SLM. RAN BRUSH & GAUGE ASSEMBLY TO XN NIPPLE @ 7281' RKB. TOOLS HUNG UP @ 5950' SLM WHILE POH. PUMPED DSL DOWN TBG, FREED UP TOOLS. BRUSHED & FLUSHED TBG TO 7281' RKB; TBG OPEN TO 2.29 ". IN PROGRESS. 5/16/2013 SET 2.31 XX PLUG @ 7247' RKB. RAN 2.31 CHECK SET, CONFIRMED PLUG SET. SET 2 -7/8" CATCHER ON PLUG. PULLED DV © 6932' RKB. FLUID PACKED TBG & IA WITH DIESEL. MIT TBG x IA 2500 PSI, PASSED. IN PROGRESS. 5/17/2013 PULLED CATCHER ON 2.31 XX PLUG @ 7247' RKB; PULLED 2.31 XX PLUG @ SAME. TAGGED @ 7422' SLM, EST. 8' FILL. MEASURED BHP @ 7304' SLM: 2868 PSI. SET 2.31 XN PLUG @ 7281' RKB; CONFIRMED PLUG SET WITH CHECK SET. DUMP BAILED 8' OF SILICA SAND ON XN PLUG @ 7281' RKB. SET CATCHER SUB ON SAND @ 7273' RKB. READY FOR BPV. • • ConocoPhillips Time Log & Summary We /Mew Web Reporting Report Well Name: 1 E - 28 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/24/2013 2:00:00 AM Rig Release: 5/29/2013 1:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/23/2013 24 hr Summary Release Nordic rig 3 from 1Y -19 at 10:30 hrs, Breakdown exsisting 11" 5M Class III BOP stack for inspection and Pick up New 11" 5M class III BOPE. Move Nordic rig 3 from 1Y-Pad to 1E Pad. 10:30 19:00 8.50 MIRU MOVE OTHR P Break down 11" 5M BOP stack to go in for inspection. Restack New 11" 5M BOPE 19:00 00:00 5.00 MIRU MOVE MOB P Move Nordic rig 3 from 1Y Pad to 1E- Pad. 05/24/2013 ** *Rig accept 02:00 ** *.Rig up tanks,flow back iron, pressure test iron & lubricator pull BPV and kill the well. Reverse circulate 319 bbls of 9.3 brine, recovering 190 bbls pumping 4.5 bpm @ 650 psi. NFT - well of vac, install BPV, ND tree, NU BOPE with new BOPE components. Pumping 10 bbl /hour down IA. Total lossed for 24 hours = 153 bbls 00:00 02:00 2.00 MIRU MOVE MOB P Arrive on location @ 12:30. Call pad operator spot rig over well. 02:00 05:00 3.00 MIRU WHDBO RURD P ** *Rig Accept 02:00 hrs * * ** Spot cuttings tank, rig up kill tank iron, called out FMC for BPV. 600 psi under BPV. 05:00 06:00 1.00 MIRU WHDBO MPSP P PJSM, Load lubricator, MU to tree and pressure test @ 1,000 psi - good test. Pull BPV, laydown lubricator. Open up well 420 SITP, 430 SICP, 150 SIOAP. 06:00 08:30 2.50 MIRU WELCTL PRTS P Test hardline @ 250/3,500 psi - 2" High pressure hose failed - pin holes in body. Take out of service and replace. Continue to PT - Good test. 08:30 11:00 2.50 MIRU WELCTL KLWL P PJSM on well kill. Reverse circulate 319 bbls of 9.3 ppg Brine @ 4.5 bpm @ 714 psi while maintaining 620 psi back pressure on choke manifold w/ 120 bbls recovered with 9.3 ppg brine back to surface. 11:00 11:30 0.50 MIRU WELCTL OWFF P Monitor well for flow - well on vac 11:30 12:00 0.50 MIRU WHDBO MPSP P Dry rod BPV. 12:00 13:30 1.50 MIRU WHDBO NUND P Held PJSM, ND Tree and inspect lift threads in hanger - Good. 1IIU FMC-__ Blanking plug 13:30 22:30 9.00 MIRU WHDBO NUND P NU "New" 11" 5M Class III BOP stack and install rams in all three cavaties. RU choke and kill lines. Grease choke and WC valves on stack. Page 1 of 6 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 22:30 00:00 1.50 MIRU WHDBO BOPE P PJSM - fill stack and lines - Begin pressure test - 250 / 5000 psi. New BOPE equipment installed on stack. Tighten flanges after leak off on first body test. 05/25/2013 Complete BOPE test, Pull blanking plug & BPV. M/U Landing joint, BOLDS, unland hanger 60K, pull seals ?Rim PBR 125K, back to 85K upweight. Circ2X well volume, TOOH with decompletion string. Corroded Tubing & collars starting @joint 161', roughly 2400' from TD. Total losses for 24 hours = 187 bbls 00:00 01:30 1.50 MIRU WHDBO BOPE P State test Witnessed by Jeff Turkington 250 / 5000 psi. BOPE testing. Failure of Valve stem #6 on test II, greased re -test pass. Continue with BOPE testing. 01:30 07:00 5.50 MIRU WHDBO BOPE T ** BOPE exceeding 12 hour billable service ** Continue with BOPE testing. 250 / 5000 psi & 250/3500 psi on annular. 2 7/8" - 3.5" test joints. 07:00 08:30 1.50 COMPZ RPCOM MPSP P Pull Blanking plug, fluid dropping in stack. Pull BPV 08:30 09:00 0.50 COMPZ RPCOM OTHR P MU landing pup joints. 09:00 10:00 1.00 COMPZ RPCOM PRTS P Service and Pressure test IA valve @ 250 / 5,000 psi - failed High pressure test. Will change after barriers are in place. 10:00 10:30 0.50 6,987 6,959 COMPZ RPCOM PULL P BOLDS, unland hanger @ 60k, pull seals from PBR 125k, pull hanger o ri floor @ 85k up wt. 10:30 12:30 2.00 6,959 6,959 COMPZ RPCOM CIRC P _Reverse circulate @ 2 bpm @ 60 psi, took 16 bbls to fill hole before seeing returns at shakers. High Losses. SD and switch to conventional circulation @ 3 bpm @ 330 psi, Stage up 4.5 bpm @ 520 psi, 9 bpm @ 1,950 psi. Reduce rate back to 3 bpm @ 330 psi to manage fluid losses while circulating surface to surface w/ 114 bbl lost to formation. 12:30 13:00 0.50 6,959 6,959 COMPZ RPCOM OWFF P Monitor well for flow w/ 28 bbl losses 13:00 14:00 1.00 6,959 6,959 COMPZ RPCOM OTHR P Evaluate flow paddle issues prior to continuing to POOH 14:00 00:00 10.00 6,959 0 COMPZ RPCOM PULD P _ POO_H w/ 2 -7/8 decompletion string from 6,959 -ft. Joint 151 started to see corrossion, extensive wear /corrossion on joint 161. Roughly 2400' from TD down to packer assembly. 05/26/2013 P/U Packer fishing BHA # 1 80/32 retrieving tool, TIH down to 6978', latch into PBR and attempt to shear FHL pins. No luck sheared fishing tool. TOOH to P/U BHA # 2 Itco Spear, TIH latch into fish @ 6976' - Pull 60K over each time after jars fired. Total of four hits to release FHL packer. P/U 20ft and circulate B/U and work out packer gas from well. Circulated through choke /degasser on first B/U then open for second B /U. Total pumped 731 bbls, total losses for 24 hours = 377 bbls. Page 2 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 0 0 COMPZ RPCOM PULD P lay down Sal assembly and break down for shipment. Clean up rig floor, change equipment for 3.5" DP and BHA # 1 (fishing BHA) 02:00 03:00 1.00 0 210 COMPZ WELLPF PULD P PJSM - P/U BHA # 1. 03:00 08:30 5.50 210 6,951 COMPZ WELLPF TRIP P TIH with BHA #1 while PU 3 -1/2 DP to 6,951-ft 08:30 10:00 1.50 6,951 6,978 COMPZ WELLPF FISH P MU jt #210 and screw in TD. 130 UP wt, 110 DN wt. Circulate @ 162 gpm @ 568 psi. Wash down to 6,978 -ft and engage PBR. Pull 20k OSW and bleed jars, straight pull to 55k osw in attempt to shear FHL - let sit for 10 minutes - no shear. relax and attempt to shyear again as 1st attempt - no luck. Atempt to RH release, 4 rds w/ 3,400 ft/lbs of torque - work torque - no luck. Recock jars and attempt to shear at 50k over pull - no luck - spear jumped out of latch up - was able to relatch - bleed jars and straight pull to 60k OSW - no luck - recock and set jars off again and sheared fishing tool. 10:00 15:00 5.00 6,978 0 COMPZ WELLPF TRIP P POOH and stand back BHA #1 - Baker PBR spear sheared. 15:00 15:45 0.75 0 0 COMPZ WELLPF OTHR P Set wear ring 15:45 16:15 0.50 0 224 COMPZ WELLPF PULD P PU and RIH w/ BHA #2 to 224 -ft 16:15 18:00 1.75 224 6,900 COMPZ WELLPF TRIP P Trip in hole w/ BHA #2 from 224 -ft to 6,900 -ft 18:00 18:30 0.50 6,900 6,900 COMPZ WELLPF SVRG P Crew change and service rig 18:30 19:30 1.00 6,900 7,241 COMPZ WELLPF FISH P Weight check - P/U 130K/ Dwn 110K. Roll pump as sting into fish, pressure up, stop pumping. Depth 6976' - spear 6979' Set down 5K, P/U 180K - good indication. Set down 10K, P/U 60K over - jarring. Max pull 70K over packer came free on fourth lick. P/U 20ft with upweight 137K. 19:30 00:00 4.50 7,241 7,020 COMPZ WELLPF CIRC P Circ 1.5 X well volume.Took 17 bbls to fill the hole, started to get packer gas back to surface. SICP 60 psi / SIDPP 10 - circulate out packer gas through choke, divert 30 bbls to Kill tank of initial packer gas /diesel. Pumping 3 bpm @ 760 psi. Continue with full B/U through choke /degasser - 395 bbls pumped with 200bbls losses. Circ additional B/U through low pressure line. Total pumped = 731 bbls. Total losses = 387 bbls. Page 3 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/27/2013 2a hr summary TOOH with fishing BHA #2 and recovered packer assembly. P/U BHA # 3 - 7" scraper assembly. TIH down to 7258', circulate well volume. TOOH, lay down BHA # 3, P/U new FHL packer assembly with 40' joint of R -3 tubing. 24 hour losses to formation = 384 bbls 00:00 01:00 1.00 7,020 7,020 COMPZ WELLPF CIRC P Complete circulating B /U. Blow down Top drive, set up rig floor for tripping pipe. Losses = 30 bbls / hour static. 01:00 04:00 3.00 7,020 360 COMPZ WELLPF TRIP P PJSM - TOOH with packer assembly BHA #2. Pumped total 60 bbls while TOOH. 04:00 06:30 2.50 360 0 COMPZ WELLPF PULD P PJSM - laying down BHA # 3- fish at surface. 06:30 08:30 2.00 0 248 COMPZ WELLPF PULD P PJSM, Pickup and RIH w/ CSG scraper assy to 248 -ft 08:30 10:15 1.75 248 7,022 COMPZ WELLPFTRIP P RIH w/ BHA #3 from 248 -ft to 7,022 -ft 10:15 12:45 2.50 7,022 7,258 COMPZ WELLPF PULD P PU and RIH from 7,022 -ft to 7,248 -ft PU 130k , SO 110k. MU TD and wash down at 4 bpm @ 520 psi, locate top of packer at 7,251 -ft and fell in to 7,258 -ft had 100 psi. PU off bottom and circulate Surface to surface. 12:45 15:45 3.00 7,258 248 COMPZ WELLPF TRIP P POOH to 248 -ft. 15:45 20:15 4.50 248 0 COMPZ RPCOM PULD P Lay down BHA & P/U Packer assembly. 20:15 00:00 3.75 242 5,500 COMPZ RPCOM TRIP P RIH with FHL packer and 40ft R3 tubing on drillpipe. 05/28/2013 Set Baker 3 -1/2" FHL Packer Assembly at 7027', Shear out of PBR at 7004'. Set VR Plug and change out IA Valve- Test 250/5000 psi good. Slip and Cut Drill Line. POOH with DP and RIH with 3 -1/2" Completion String, locate, space out, and prepare to circulate CI Sea Water. 00:00 02:00 2.00 5,500 7,257 COMPZ RPCOM TRIP P TIH with FHL packer assembly. Roll pumps lightly to locate seal assembly, presure up to 200 psi @ 7253'. Bleed off pressure and no go 10K down at 7259' 02:00 05:30 3.50 7,257 7,257 COMPZ RPCOM PACK P P/U weight 128K / Dwn weight 108K. P/U above space out and circ 25 bbls of corrossion inhibitor to spot behind assembly. Leave 5 bbls in tubing for Space out on mark, drop ball /seat. Pressure up to 2,800 - set packer - packer pins sheared @ 2,200 psi. PT IA @ 1,500 psi for 15 minutes - good test. Pressure up to 2,500 psi (31,416 lbs of force) and pull 10k osw and shear out of PBR. 124k up wt / 115k dn 05:30 07:30 2.00 7,257 7,257 COMPZ RPCOM OTHR P Set VR plug and change out IA valve SN# 779323 w/ 349273 work conducted by rig crew and valve shop crew. PT IA against VR plug at 250/5,000 psi for 15 minute. Good test, Pull VR plug. 07:30 09:45 2.25 7,257 6,997 COMPZ RPCOM SLPC P Slip and cut 84 -ft of drill line. Service draw works. Page 4 of 6 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:45 14:30 4.75 6,997 0 COMPZ RPCOM PULD P POOH laying down 3 -1/2 DP from 6,997 -ft and lay down seal assy 14:30 15:30 1.00 0 0 COMPZ RPCOM OTHR P Change over from 3 -1/2 DP equipment to 3 -1/2 TBG equipment 15:30 22:00 6.50 0 6,982 COMPZ RPCOM PULD P PJSM, PU, MU and RIH w/ 3 -1/2 ", 9.3 #, L -80, EUE 8rd AB Mod tubing completion as per run order to 6982 -ft 22:00 23:00 1.00 6,982 7,040 COMPZ RPCOM RCST P Up wt 94k #, Dwn 84k #. Circ with Charge Pump and Locate Seals at 7011'- down on Pump. Tag No -Go at 7040'. 23:00 00:00 1.00 7,040 7,005 COMPZ RPCOM HOSO P Space out. MU Hanger and Landing Joint. Up 94k #, down 84k #. RIH to 7005' and prepare to Circulate CI SW. 35/29/2013 Reverse Circulate /spot 180 bbls CI SW below SOV. Land FMC Gen IV Hanger. Test and chart Tbg 2500 psi - good, Test and chart IA 3000 psi- good. Shear out SOV at 2701'. Perform 30 minute NFT- no flow. Set BPV — arid fait from beTow- good. ND BOPE. NU 7- 1/16" 5M x 3 -1/8 " 5M DSA and 3 -1/8" 5M Tree. Pull BPV Set TWC and Test Voids and Tree 250 / 5000 psi- good. Pull TWC. Pump 95 bbls diesel FP through SOV at 2701'. Install 'IS" BPV. RDMO. 00:00 01:30 1.50 7,005 7,005 COMPZ RPCOM CIRC P PJSM. Reverse Circulate 60 bbls SW, followed by 180 bbls CI Sw (1% CRW132), Chase with 75 bbls SW. ICP 530 psi. 500 psi FCP. 01:30 02:00 0.50 7,005 7,033 COMPZ RPCOM HOSO P PJSM. RIH and Land Hanger. RILDS. Up 97k #, dwn 85k #. 02:00 04:00 2.00 7,033 0 COMPZ RPCOM PRTS P PJSM. RU and Test Tbg to 3000 psi for 10 minutes and chart- good test. Bleed down Tbg to 2500 psi. Test IA to 3000 psi for 30 minutes- good test. Bleed pressures to 0 psi. Ramp up IA pressure and shear out SOV at 2500 psi , establish circ rate 2 bpm at 370 psi. 04:00 04:30 0.50 0 0 COMPZ RPCOM OWFF P Montior well for 30 minute NFT- good. RD Test Equipment. 04:30 05:00 0.50 0 0 COMPZ WHDBO MPSP P Set BPV anf PT from below to 1000 psi. Good test. 05:00 06:30 1.50 0 0 COMPZ WHDBO NUND P Rig down Test Equipment and Nipple Down BOPE. 06:30 08:00 1.50 0 0 COMPZ WHDBO NUND P NU 7- 1/16" 5M x 3 -1/8" 5M DSA, 3 -1/8" 5M tree - verify tree orientation w/ DSO -Mike Sheffler /Brian Wooley 08:00 08:30 0.50 0 0 COMPZ WHDBO MPSP P Dry rod BPV and Install TIC. 08:30 09:00 0.50 0 0 COMPZ WHDBO DHEQ P RU and test voids @ 250 / 5,000 psi –Good test. RU and test tree @ 250/5,000 psi and chart.- -good test. RD test. 09:00 09:30 0.50 0 0 COMPZ WHDBO MPSP P Pull TWC 09:30 10:30 1.00 0 0 COMPZ RPCOM FRZP P PJSM, RU and pump to 95 bbls of diesel at 2 bpm 750 ICP, 1,030 FCP 10:30 11:00 0.50 0 0 COMPZ RPCOM MPSP P Install BPV 11:00 11:15 0.25 0 0 COMPZ RPCOM SISW P Secure well and dress tree. SITP = 0, SIIAP =0, SIOAP =300 Page 5 of 6 _ • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 13:00 1.75 0 0 COMPZ MOVE RURD P Pull Nordic rig 3 off 1E-28, remove mats, clean cellar and review environmental hand over w/ DSO - -sign off. Release Nordic Rig 3 @ 13:00 hrs Page 6 of 6 21,919 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 12, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Static Bottom Hole Pressure Survey: 1E-28 Run Date: 9/9/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -28 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20832 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 20832 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: \'� ?`�r i f Signed: 461' ~~ ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~1VE[~ Alaska C~ ~ Gas Ctrs. Cemxas~i~,n ~$;iG~i'~t~88 ~g~~a Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7th, 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7116110 1A,1 C,1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/8/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1C-03A 50029205350100 2070630 SF n/a 16" Na 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" Na 2.4 717/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" Na 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" Na 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 717/2010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" Na 2" Na 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" Na 3" Na 1.7 7/7/2010 1 E-28 50029208320000 1821580 4" n/a 4" Na 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" Na 7" Na 2.5 7/8/2010 Sc~luntbepglJl NO. 3887 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . 'f"ÀNMt=L ~"'·f"'.'~' '..;~ ~:) '/ ,:, Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1~ d -1~~ Field: Kuparuk Well Job# Log Description Date BL Color CD rW 'j 1E-1Ð2 11211600 INJECTION PROFILE 06/23/06 1 1Y-12 (REVISED) 11235362 INJECTION PROFILE OS/20/06 1 1 E-105L 1 11213766 INJECTION PROFILE 06/20/06 1 1B-18 N/A PRODUCTION LOG W/DEFT 06/25/06 1 1J-164 11213765 INJECTION PROFILE 06/19/06 1 1 C-25 1102601 SCMT 06/24/06 1 3M-22 11213770 PRODUCTION PROFILE W/DEFT 06/26/06 1 2M-12 11213771 PRODUCTION PROFILE W/DEFT 06/27/06 1 1Q-12 11285929 MEMORY INJECTION PROFILE 06/24/06 1 1Y-07 11285928 MEMORY INJECTION PROFILE 06/23/06 1 1D-125A 11213778 INJECTION PROFILE 07117/06 1 2K-14 11213777 PRODUCTION PROFILE W/DEFT 07/16/06 1 1 C-20 11213775 FBHP SURVEY 07/14/06 1 1J-156 11216308 USIT 07/10/06 1 2K-06 11213773 INJECTION PROFILE 07/12/06 1 2K-22 11249925 LDL 06/06/06 1 1F-15 11249910 INJECTION PROFILE 06/05/06 1 1 E-36 11235375 PRODUCTION PROFILE 07/13/06 1 2K-17 11249923 PRODUCTION PROFILE/DEFT 07/04/06 1 1 H-04 11320991 INJECTION PROFILE 07/03/06 1 1 D-1 0'1 N/A INJECTION PROFILE 06/27/06 1 2Z-U 11249930 LDL 07/11/06 1 1D-106 N/A INJECTION PROFILE 06/26/06 1 2M-21 11320987 PRODUCTION PROFILE 06/29/06 1 2W-01 11320985 PRODUCTION PROFILE/DEFT 06/14/06 1 1E-28 11320986 PRODUCTION LOG 06/28/06 1 1J-101 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 Please sign and return one copy ofthis transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 07/24/06 e e ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 12, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-28(Permit No. 82-158) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 1E-28. The original 3-1/2" single completion was pulled and the wellbore was cleaned out. A 2-7/8" selective single completion was re-run. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Petroleum Engineering WSI/skad r mum vh2D FEB 1 4 1~6 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ~ AL.~ · OIL AND GAS CONSERVATION COMN,,..~ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~--~ GAS ~ SUSPENDED r--] ABANDONED [~ SERVICE r'~ 2 Name of Operator 7 Parmlt Number ARCO Alaska~ Inc 82-158 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20832 4 Location of well al surface 9 Unit or Lease Name 187' FNL, 640' FEL, Sec. 21, TllN, R10E, UM ~ I Kuparuk River Unit At Top Producing Interval 10 Well Number i "1 E-28" At Total Depth ! .... 11 Field and Pool 2575' FNL, 2403' FWL, Sec. 21, T11N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lease Designation and Serial No. RKB 106', Pad 72'I ADL 25651 ALK 469 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, If offshore J16 No. of Completions September 26, 1982 October 4, 1982 10/18/1995 (recompleted)J NA feet MSLJ 2 17 Total Depth (MD.TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 7665' MD & 6677' TVD 7547' MD & 6562' TVD YES L..J NO lXlI NA feet MDI = 1380' ss APPROX 22 Type Electdc or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT' GRADE TOP BTM HOLE SIZE CEMENT F~CORD 16" 62.5# H-40 SURF. 114' 24" 254 sx AS II 10.75" 45.5# K-55 SURF. 2305' 13.5" 1500 sx AS III & 250 sx AS I 7" 26# K-55 SURF. 7629' 8.75" 610 sx Class G & 41 bbls AS I 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) 2-7/8" 7293' 7003' & 7262' 7346'- 7366' MD 4 spf 6369'-6388' TVD 7088'- 7175' MD 8 spf 6123'- 6206' TVD 26 ACID,, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7346'-7366' 9368# of 20/40, 104203# of 12/18 7777# of 10/14, 119279# total 118404# in perfs, 875# in wellbore 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift, etc.) I Shut in Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD !~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. FEB 1 4 199G ORiOINALAlaska Oi, & Oa~ Con~ ...u.,,'mssion Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. GEOLOGIC ~RS 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 Kuparuk C 7086' 6121' Bottom Kuparuk C 7175' 6206' Top Kuparuk A 7302' 6328' Bottom Kuparuk A 7414' 6435' FEB 1 4 Alaska Oil & Gas Cons. Commission Anchorage 31. LIST OF ATTACHMENTS Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGINAL Date' 1/29/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT REMEDIAL AND COMPLETION OPERATIONS ~~~v~O Page: 1 FEB 1 4 1996 Alaska 0~! & Gas Cons. Commission Anchor~e WELL:lE-28 RIG:NORDIC WELL ID: 998427 AFC: 998427 TYPE: -- STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD: START COMP: BLOCK: FINAL: WI: 0% SECURITY:0 AFC EST/UL:$ 450M/ 600M API NUMBER: 50-029-20832-00 10/10/95 (1) TD: 7665' PB: 7547' SUPV:DCL DAILY: 10/11/95 (2) TD: 7665' PB: 7547' SUPV:DCL DAILY: 10/12/95 (3) TD: 7665' PB: 7547' SUPV:DLW DAILY: 10/13/95 ( 4,) TD: 7665' PB: 7547' SUPV:DLW DAILY: 10/14/95 (5) TD: 7665' PB: 7547' SUPV:DLW DAILY: 10/15/95 (6) TD: 7665' PB: 7547' SUPV:DLW DAILY: 10/16/95 (7) TD: 7665' PB: 7547' SUPV: DLW DAILY: MOVE MW: 0.0 Move rig from 2A-18 to 1E-28. Rig on location at 0600 hrs. $22,121 CUM: $22,121 ETD: $0 EFC: $472,121 KILL WELL MW: 8.5 SW Accept rig @ 0800 hrs 10/10/95. Kill well with 8.5 ppg seawater. $22,800 CUM: $44,921 ETD: $0 EFC: $494,921 PULL & L/D 3-1/2" BTC TBG MW:12.5 UNKN Continue well kill circulate 8.5 ppg seawater around. Pumped 60 bbls of diesel down flowline for freeze protection. Test BOPs and annular. Check well for flow well dead. Pull and L/D 3-1/2" BTC tbg. $34,761 CUM: $79,682 ETD: $0 EFC: $529,682 M/U 3-1/2" DP RIH W/FISHI MW:12.5 LSND Continue to pull and L/D 221 jts and cut off 3-1/2" tubing. M/U Baker fishing tools. RIH with 3-1/2" DP. Top of fish @ 6922' $32,93~ CUM: $112,615 ETD: $0 EFC: $562,615 RIH W/OVERSHOT TO FISH PK MW: 0.0 Work over fish and rotate to release packer. POOH. Recovered no fish. Change overshot grapple and rerun. POOH. Recovered cut off tbg of 16.04' and SBR 24.53'. $34,852 CUM: $147,467 ETD: $0 EFC: $597,467 RIH W/ C/O ASSY MW:12.5 LSND RIH with fishing assembly. Trip jars one time released packer. L/D fishing tools and fish. $35,864 CUM: $183,331 ETD: $0 EFC: $633,331 CIRC @ 7547' PBTD MW:12.5 LSND Run in hole with BHA %3 to 7267'. Wash from 7267' to 7299'. Gas to surface. Cleanout from 7299' to 7547' PBTD. Run Baker 7" storm packer and set 5' below well head. Test pack off to 3000 psi for 15 minutes. OK. Pull Baker 7" storm packer. CBU to check for gas. $59,562 CUM: $242,893 ETD: $0 EFC: $692,893 Date: 1/29/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 2 10/17/95 (8) TD: 7665' PB: 7547' SUPV:DLW DAILY: RUN 2-7/8" COMPLETION MW:12.5 LSND Continue CBU. No gas. Run 4-1/2" perf gun, 4 spf, 180 deg phasing. Perf from 7346' - 7366' 20' total. Run Baker packer assembly. Set top of pkr ~ 7244'. Run 2-7/8" tubing completion. $68,448 CUM: $311,341 ETD: $0 EFC: $761,341 10/18/95 ( 9) TD: 7665' PB: 7547' SUPV: DCL DAILY: RUN 2-7/8" COMPLETION MW: 0.0 SW Finish RIH with 2-7/8" completion equip. Test tubing to 2500 psi. OK. Test casing to 2500 psi. OK. Test packoff to 5000 psi. Test tree. Freeze protect. Secure well. Release rig @ 0600 10/18/95. Move rig to 2Z-12A. $152,081 CUM: $463,422 ETD: $0 EFC: $913,422 End of WellSummary for We11:998427 FEB 14 199G Alaska Oil & 6a.~ Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box~*;o0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 1, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. . WELL ACTION Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) Other (SSSV) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering RECEIVED FEB - 7 1994 Alaska Oil & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 Report of Well Sund./'-"perations Page 2 bxc: V. L. Ferguson P. A. Biilingsley Well Files FTR020196 ATO-1228 ATO-1431 (w/o attachments) (w/o attachments) (Form 10-404 only) (w/o attachments) Subject: Report of Sundry Well Operations, 1B-05(sssv), 1E-28(sssv), 1L-02,08(sssv), 1Q-05,06(sssv) Original + one copy to AOGCC (one -sided copy) FF.~ - 7 ~994 Gas Cons. commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS ~SERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate Plugging_ Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service N, R10E, UM R10E, UM R10E, UM 4 7 feet 6 2 feet 4. Location of well at surface 187' FNL, 640' FWL, Sec 21, T11N, R10E, UM At top of productive interval 2468' FNL, 2529' FWL, Sec 21, Tll At effective depth 2557' FNL, 2434' FWL, Sec 21, T11N, At total depth 2578' FNL, 2410' FWL, Sec 21, T11N, 12. Present well condition summary Total Depth: measured 75 true vertical 65 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-28 g. Permit number/approval number 62-158/93-349 10. APl number 50-029-20832 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth' measured 7 3 6 3 true vertical 6386 feet feet Junk (measured) None Casing Length Structural Conductor 7 9' Surface 2 2 6 5' Intermediate Production 7 5 9 2' Liner Perforation depth: measured 7088'-7175', true vertical 6123'-6206', Size Cemented Measured depth 79' 2303' 7629' 1 6" 254 SX AS II 10-3/4" 1500SXASIII& 250 SX AS I 7" 610 SX Class G & 41 Bbls AS I 7318'-7328', 7345'-7366' 6343'-6352', 6369'-6389' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7015' Packers and SSSV (type and measured depth) Pkr: Baker FHL @ 6965'; SSSV: Otis °K' Valve set at 324# @ 1898' 13. Stimulation or cement squeeze summary Installed sub-surface, spring controlled safety valve in production well. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A True vertical depth 79' 2180' 6644' RECEIVED FEB - 7 1994 AJaska 0il & Gas Cons. Commission Anchorage 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 7 2 8 516 4124 1250 198 Subsequent to operation 7 2 8 516 4124 1250 198 15. Attachments Well Schematic 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned '~~~ ~~ Title Senior Engineer Service .ql II::tl~alT I!~1 rll 1131 I~ATI: ~ Well: I E-28 ARCO ALASKA INC. - KUPARUK FIELD Spud Date: 9 - 2 6 - 8 2 Completion Date: 1 0 - 7 - 8 2 Maximum Hole Angle: deg. @ Original Rig RKB: 26.9 All depth are RKB MD to top of equipment. 4 5,6 APl# 50-029-20832-00 C Sand: OPEN A Sand: OPEN MD Well Type: OIL Tree Type: FIVIC Tree Cap Type: Tree Cap Size: Tree Cap O-ring ASN: Last Workover Date: Jewelry 1 SSSV: K-VALVE 324# @ 60 on B-7 LOCK SERIAL# K-318@ 1898 2 SBR: BAKER ELA @ 6938' 3 PKR: BAKER FHL @ 6965' 4 NOGO: CAMCO'D' NIPPLE 2.750" ID @ 7003' 5 SHEAROUT: BAKER@ 7014' 6 TUBING TAIL @ 7015' Minimum ID: 2.750" NOGO Casing and Tubing Size Weight Grade Top Bottom Description 1 6" 6 5 # H- 40 0 79' CASING 10.75" 45.5# K-55 0 2303' CASING 7.0" 2 6 # K-55 0 7629' CASING 3.5" 9.3 # J- 55 0 7015' TUBING Gas Lift Information Depth Stn# Valve Type SZ. 2124' 1 GLV 1" 4483' 2 GLV 1" 6242' 3 GLV 1" 6585' 4 DV 6902' 5 DV Perforation Data Interva,! SPF Date 7088-71 75 8 1 0-06-82 7318-7328 8 1 0-06-82 7345-7366 8 1 0-06-82 l,,atch port Sz. AID# Date Run BK 1 2/64" 1 0/6/90 BK 12/64" 1 0/6/90 BK 1 6/64" 1 0/" Zone C-SAND A-SAND A-SAND Comments RECEIVED FEB - 7 1994 Comments: PRESSURE ON 10" Gas Cons. Commission Anchorage LASTTD: 7363' ON 7.23-85 PBTD:7910' PBTDSS: 6333' LAST REVISION DATE: 5-10-93 ARCO Alaska, Inc. ~--~'~,~ Post Office B'<. 360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 15, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission '3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' AttaChed in triplicate are multiple Applications for Sundry Approval on the following Kuparuk wells. Well Action ~'"¢..011B-05 ~--" 15,31E-28 9tf--- I'~Ol L-02 ~q-vs~ 1 L-08 9~f-- at~ 1Q-05 ¢'4'" Z,~8 1Q-06 Variance Variance Variance Variance Variance Variance Anticipated Start Date If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments Gas Cons. commission, Anchorage ARCO Alaska, Inc. is a Subsidiary o! AtlantlcRichfieldCompany S~I'ATE OF ALASKA "'~" ~ OIL AND GAS CONSERVATION C, OMMI~,.~ON APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown Re-enter suspended well 1. Type of Request: Alter ca'rig _ Repair wel'~_ Plugging _ Tirn~ extension _ Stimulate _ Change approved program _ Pull tubing _ Variance ~( Perforate _ Other _ 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) I Development ARCO AI;.~ka. Inc. Exploratory _ RKB 106 feet 3. Address ~ Stratigraphic P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 187' FNL, 640' FEL, Sec. 21, T11N, R10E, UM At top of productive interval 2468' FNL, 2529' FWL, Sec. 21, T11N, R10E, UM At effective depth 2557' FNL, 2434' FWL, Sec. 21, T11N, R10E, UM At total depth 2578' FNL~ 2410' FWL~ Sec. 217 T11Nr R10Er UM 12. Present well condition summary Total Depth: measured 7 5 4 7 feet true vertical 6 5 6 2 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1E-28 9. Permit number 82-158 10. APl number so-029-20832 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None Effective depth: measured 7 3 6 3 feet true vertical 638 6 feet Junk (measured) None 13. 14. 16. Casing Length Size Structural Conductor 7 9' 1 6" Surface 2265' I 0-3/4" Intermediate Production 759 2' 7" Liner Perforation depth: measured 7088'-7175', true vertical 6123'-6206', Cemented 254 SX AS II 1500 SX AS III & 250 SX AS I 610 SX Class G & 41 Bbls AS I 7318'-7328', 7345'-7366' 6343'-6352', 6369'-6389' Measured depth 79' 2303' 7629' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 7015' Packers and SSSV (type and measured depth) Pkr' Baker FHL @ 6965'; $SSV: Camco TRDP-1A ~ 1898' Attachments Description summary of proposal .~. Detailed operation program _ Install sub-surface, sprin~ controlled safet)f valve in production well Estimated date for commencing operation 15. Status of well classification as: 1993 O, ~[ Gas _ If proposal was verbally approved Name of approver Date approved Service True vertical depth 79' 2180' 6644' RECEIVED DEC 2 1 1995 AtBska Oil & Gas Cons. Commission Anchorage BOP sketch Suspended _ Signed jr foregoing is true and correct to the best of my knowledge. ~ Title Sr. Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test _ Location clearance w Mechanical Integrity Test_ Subsequent form require 10-1~c~ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By David W, Jnhn.~t_nn Commissioner Approved Copy Returned Date I/~'o/? ~ SUBJVlIT IN TRIPLICATE Attachment I '~"~ Request for Variance Kuparuk Well 1E-28 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval for a variance to install a subsurface, ambient-type safety valve in Well 1E-28. This valve replaces the original subsudace safety valve which has failed. The replacement valve operates by remaining open until flowing well pressure falls below a predetermined limit. Should such an event occur, the valve automatically closes, thus preventing uncontrolled flow. This valve, refered to as a storm choke, does not require a hydraulic control line from the surface to the subsudace valve. Its fail-safe design as normally-closed provides the same level of protection. Attached is a schematic of the "K" valve, an Otis Engineering storm choke. RECEIVED DEC 2 1 199~ Alaska 0it & Gas Cons. Commission Anchorage Attachment 2 Storm Choke Schematic OPEN CLOSED · WELL · INTERNAL PRESSURE CHAMBER PRESSURE HOUSING PIN HEAD ) RING TEFLON RING PISTON SPRING ROD SPACER BODY SPRING DETENT RING BALL GASKET SET SCREW CAP SCREW GASKET Figure 1 - Otis "K" Valve RECEIVED DEC 2 1 1993 Alaska Oil & Gas Cons. Commissio~ Anchorage 1, Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X 2. Name of Operator 15. Type of Well: I Development ARCO Alaska. Inc. Exploratory 3. Address I Stratigraphic P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 187' FNL, 640' FEL, Sec. 21, Ti1N, R10E, UM At top of productive interval 2468' FNL, 2529' FWL, Sec. 21, T11N, R10E, UM At effective depth 2578' FNL, 2410' FWL, Sec. 21, T11N, R10E, UM At total depth 2578' FNL, 2410' FWL, Sec. 21, T11N, R10E~ UM 12. Present well condition summary Total Depth: measured true vertical 7 5 4 7 feet 6 5 6 2 feet X Plugs (measured) $. Datum elevation (DF or KB) 106' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1 E-28 /'~?--(~ '~'~'¢, ~-- 9. Permit number/approval number 82-158 / Verbal per L. Smith 10. APl number 50-029-20832 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7 3 6 3 true vertical 63 8 6 feet feet Junk (measured) Casing Length Size Structural Conductor 7 9' I 6" Surface 2303' 10 Intermediate Production 7629' 7" Liner 3/4" Cemented 254 Sx AS II 1500 Sx AS III & 250 Sx AS I 610 Sx Class "G" & 41 Bbls AS I Perforation depth: measured 7088'-7175', 7318'-7328', 7345'-7366' true vertical 6123'-6206', 6343'-6352', 6369'-6389' Tubing (size, grade, and measured depth) 3 1/2" 9.3 Ib/ft, J-55, 7015' MD RKB Packers and SSSV (type and measured depth) MD TVD Measured depth True vertical depth 79' 79' 2303' 2180' 7629' 6644' FIopetrol "PB" Valve (Storm Choke) @ 1898'; Baker FHL Packer @ 6965' 13. Stimulation or cement squeeze summary A storm choke was initially installed 1-9-87 due to SSSV failure. The current valve was set and tested 6-17-88(see attached). Intervals treated (measured) Treatment description includin~l volumes used and final pressure 14, Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (6-88) 502 449 2871 1 376 294 Subsequent to operation (6-88) 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 709 295 1784 1306 340 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 '~0-404 I::~v' 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Subsidiary of Atlantic Richfield Comp.~ WELL SERVICE REPORT ~..WELL CONTRACTOR · C_~c~ ~ IPBDT I FIELD-DISTRICT-STATE IOPERAT~ON AT REPORT TIME DATE -- i-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. I Chill Factor I Visibility Wind Vel. Report °FI °FI~ miles ~WELL ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Com~p~'~ ""*"ONTRACTOR . ,EMARKS FIELD- DISTRICT - STATE C_PF.-I/i~P,. 0 oPeRATION .~T REPORT TIME WELL SERVICE REPORT IDAYs I DA~.~E - ~ 2'3(3 I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor I Visibility I Wind Vel. Report °F "F! miles I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION C0~,[%!ISSION 3001 Porcupine Drive Anchorage, Alaska 9-c501 (907) 279-1433 TO: RE: Receipt of the following material which was transmitted via is hereby acknowledged: QUANTITY Copy sent ~er YES, ' ~ ~'-~ STATE OF ALASKA ~ ALL. _(A OIL AND GAS CONSERVATION CO ..... tlSSION REPORT-OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] t/ CANCELLAT I ON OF REQUEST Alter Casing [] Other j~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 106' Feet 3. A~d~es~ 6'~uparuK Klver unl~ ~'.u. ~ox 100360 Anchorage, AK 99510-0360 ~nit o[P. rgpert~ n~me 4. Location of well at surface 187' FNL, 640' FEL, Sec.21, TllN, R10E, UN At top of productive interval 2468' FNL, 2529' FWL, Sec.21, T11N~ R10E, UN At effective depth -- At total depth 2578' FNL~ 2410' FWL, Sec.21, T11N~ RIOE~ UN 11. Present well condition summary Total depth: measured true vertical feet Plugs (measured) feet 7. Well number 1E-28 8. Approval number N/A 9. APl number 50-- 029-20832 10. Pool Kuparuk River Oil Pool Effective depth: measured true vertical feet Junk (measured) feet Casing Length Size Cemented Measured depth The work described in our Sundry Notice, dated 1/17/85, has not been done and is not scheduled to be done in the immediate future. Therefore, please cancel our request to perform a workover on this well. True Vertical depth Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED OCi' I 6 Alaska 0ii & was Cons. Cum,,l~ulu, Anchorage 13. N/A Prior to well operation Subsequent to operation RePresentative Daily Average ProdUction or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments None Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~' ~-~J!/J~..A Form 10-404 Rev. 12-1-85 ' Title Associ ate Engi neer (JG) SW02/103 .. Date in Duplicate~ Submit ARCO Alaska, Inc. ' Post Office Bu,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 13, 1987 Mr. L. C. Smith Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' As a follow-up to our telephone conversation on December 23, 1986, this letter is to document your approval of the use of a storm choke or K-valve in Well 1E-28. As we discussed, Well 1E-28 has a subsurface leak in the hydraulic line and would require a workover to repair. If you have any questions, please call me at 263-4935. Sincerely, V. L. Ferguson Senior Operations Engineer VLF'pg-0102 RECEIVED Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Attachment ! ! Page g Drill Site 1H Well No. ~'lH-3 ~lH-4 ~1H-7 ~1H-8 Log Date 8/]6/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site 1E Well No. Log Date IE-1A NS/lg/81 1E-2 ~8/17/81~-2 _'~1/17/84/ 1E-3 ~'10/18/81~, -11/7/81/ ',,8/4/80\ .~ 1E:'4'~'I ~1 ~/~ ]E-5 ~10/27/81~ ~11/12/81/ ~1E-7 ~/18/81~ ~]o/zs/s~/~ ~11/1/8 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/SZ 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-Z7 ~0/31/8~ 11[-30 ~0/16/82 Drill Site 1G Wel I No. "~1G-1 'XelG_2 "~1G-3 '~1G-4 % 1G-8 log Date 9/7/82 ' 9/25/SZ',,, 9/28/82/ 12/8/84× 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. ,Log Date 1F '4 IF-1 2/19/83 F-2 2/3/83 F-3 1/31/83 "lF-4 5/29/83 %lF-S . 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/19/82"x9 ,,, 5/7/83... '"i~,~ RECEiVi "/' FEB 2 1 198G Alaska Oil & Gu emns. Oommisslon Anchorage KUPARUK ENGINEERING TRANSMITTAL # ~ ¢ Z/(~ .' TO' ~~/~L~- FROM: D. Fay A11 isDn DATE- ~....>~..~,~..,}.,..~._. /~, /¢~'z/ ~,IELL NAME- see below Transmitted herewith are 'the following' PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,.P~~ PHOTOCOPY Well Run Descript ion Date J. R~'~T ACKNOWLEDGED '~'~PLEASE RETURN RECEIPT TO- DATE: J-AN ARCO ALASKA, I NC. Alaska Oil 8, Gas Cons. Commission ATTH- D. FAY ALLISON - ATO/1115-B An;~orage P. O. BOX 100360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office Be,,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 17, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-28 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-28 to a selective single completion. Since we expect to start this work on February 4, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Dril ling Engineer JBK/PJA/tw SN/LO07 Enclosures RECEIVED ,;AN ] ? 985 Alaska Oil & Gas ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Addres~ P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 187' FNL, 6/+0' FEL, Sec.21, T11N, R10E, UM COMPLETED WE LLX~ OTHER [] 7. Permit No. 82-158 8. APl Number 50- 029-20832 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-28 1 1, Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i l Pool RKB 106' J ADL 25651 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing J~[ Other J~r Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-28 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. The well will be completed as a single selective and 5000# wellhead equipment will be installed. 4. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost inte~Wal. A 5000 psi WP wi'reline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: February 4, 1985 14. I hereby/C~ify that the foregoing is true and correct to the best of my knowledge. // ,~ // //~C//~.~~ Title Area Drilling Enqineer Signed ~ ~--- -. _ The spac~bbelo~w~or~Co~mission use Date /~7/~ /' / Conditions of Approval, if any: Approved by COMMISSIONER Approved Copy Returned _ By Order of the Commission Date____// -/ 0~'- ~C>..~ Submit "Intentions" in Triplicate (PJA) 5N/012 Form 10-403 mo,, -/_~_~n and "Subsequent Reports" in Duplicate October 12, 198.3 Mr. Charles I-3ouse Kuparuk Operations Coordinator ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 9951C- · Subsequent Re~orts, Sundry k.~otices and Reports on Wells (Form 10-403) Dear Mr. Eouse~ For the following list of "~otice of Intention To:" Sundry }~:'otices and Reports on Wells (form 10-403) this o£fice does not have on record the "Subsequent Report of~" defining the action taken on the approved intention. Please advise this office by Subsequent Report of the disposition of the intention. We 11 ARCO Da te Brief ~EescriDtion o~ Intent!o_n ~uparuk 1-B 1 10-22-82 Clean out wel lhore with coiled tubing unit. Kuparuk W~-I 08-05-82 Inject water. Kuparuk 1E-28 09-23-82 Change kick-off deptL. Fuparuk 04-2i-8~ Change surfac~ casing settin~j dept~'-... Sincerely, / ×(' ., ./ . :.. .... ~_'- iz~ -- . ~.. · -"Lonnie C.' S~ith Commis s lone r LC&/t~J}i =lc~ 105:D1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~,MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-158 3. Address 8. APl Number P..O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20832 4. Location of Well SURFACE LOCATION' 187' T11N, R10E, UM FNL, 640' FEL, SEC. 21 BOTTOM HOLE LOCATION' 2578' FNL, 2410' FWL, SEC. 21, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) J 6. Lease Designation and Serial No. 106' (KB) I ADL 2~;651 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1E-28 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation ~] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On January 3, 1983, Kuparuk River Unit Well 1E-28 was stimulated with 109 bbls of 12% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 4000 psig and the maximum tubing pressure was 1000 psig. 128 MCF of nitrogen were injected via the coiled tubing to aid in cleanup. Following the cleanup period the well was switched to the CPF. The post-acid well test showed this well producing 3000 BOPD. MAY 0 5 I983 AI2sK~ 0ii ~: Gas Cons. C0mmis~i0,~ Anchorage 14. I hereby certify_that the foregoing is true and correct to the best of my knowledge. Signed Title OPERAT IONS The space below for Commission use COORDINATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL . . TO: Wi'lliam Van Allen FROM: D. W. Bose/ShelbS J. Matthews Transmitted herewith are the following- PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FIMM, T -'TAPE,~ ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/311 P[O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office BOx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 6, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-28 Dear Mr. Chatterton: Enclosed is a subsequent Sundry report for the subject well. you have any questions, please call JoAnn Gruber at 263-4944. Si ncerely, P. A. VanDusen District Drilling Engineer PAV/JG2L53' 1 lm Enclosure If RE£EIVED APR I 1 19B3 Alaska Oil & Gas Cons. Commissior] Anchorago ARCO Alaska, Inc, is a subsidiary of AttanticRichfieldCompany STATE OF ALASKA ,~ ALASKA ~IL AND GAS CONSERVATION C~.,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage~ AK 99510 4. Location of Well Surface: 187' FNL, 640' FEL, Sec. 21, T11N, R10E, UN 5. Elevationinfeet(indicate KB, DF, etc.) -- !06' RKB 12. 6. Lease Designationand SerialNo. ADL 25651ALK 469 7. Permit No. 82-158 8. APl Number 50- 029-20832 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-28 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ' Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Spudded well ~ 0230 hfs, 09/26/82. Drld 73-1/2" hole to K0P (1000'); continued drlg 13-1/2" hole to 2325'; ran, cmtd and tstd 10-3/4" csg. Drld 8-3/4" hole to 7540'; ran logs. Continued drlg to 7665' TD; ran, cmtd and tstd 7" csg. Ran Gyro/CBL. Perforated well. Ran 3-1/2" completion assembly. Secured well and released rig @ 0930 hfs, 10/07/82. 14. I hereby ~,e~y that the foregoing is true and correct to the best of my knowledge. Signed Title Area Dri 11 ing Engi neet The spaceL~AY~l"'~r C/~mmission use Condi~"ns of ApProval, if any: RECEIVED APR ]. J ]983 Anchorage Date By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 GRU2/SN19 Submit "Intentions" in Triplicate and "Subsequent Reports" in Dup!icate TO: William VanAlen Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PLVASE NOTE: BL- BLUELINE, S- SEPIA, F- FIIA~, T- TAPE, ATIN: ~~ L. J~S~ - ~311 P. O. ~X 360 -Alaska 0il & Gas Cons. Commission ~0~, ~ 99510 Anchorage ARCO Alaska, Inc..x~% Post Office B~. ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 23, 1983 Mr. Lonnie Smith State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re' Subsequent Reports, Sundry Notices, Your Letter 10-12-83 Dear Mr. Smith: I have researched the wells you asked about and the status is as follows: Well ARCO Date Comments Kuparuk i-Bi 1-8-83 A change notice was prepared. Copy dated 1-8-83 is attached. The clean out attempt was never done. Kuparuk 1-H1 4-21-82 This well number was changed to 1H-5. See attached notices for 1-H1 and 1-H5. Kuparuk 1-E28 9-23-82 Subsequent notice was prepared 4-5-83. See attached copy. Kuparuk WSW-1 8-5-82 I am collecting the injection dates and volumes. I will submit the subsequent notice within two weeks. Please call me at 263-4527 if you have any Charles K. House Kuparuk Operations Coordinator CKH/kmc questions. RECEIVED NOV 2 $1983 Attachments cc: W.L. Crandall/M.D. Schall R. S. May R. A. Ruedrich A~RC~as~asubsidiary°fAtlanticRichfieldC°mpany 7-',, STATE OF ALASKA -'~ ALASKA C.,_ AND GAS CONSERVATION CO.,.MISSION SUNDRY HOTICES AND REPORTS ON WELLS 1. DRILLING WELl_ El COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-158 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50929-20832 4. Location of Well SURFACE LOCATION' 187' FNL, 640' FEL, SEC. 21 T'11N, R10E, UN BOTTOM HOLE LOCATION' 2578' FNL, 2410' FWL, SEC. 21, TllN, R10E, UM .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (KB) I ADL 25651 9. Unit or Lease Name KUPAP, UK RIVER UNIT 10. Well Number 1E-28 11. Field and Pool KUPARUK RIVER F[ELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ]~] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other J~ Pulling Tubing ' [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to acidize Kuparuk River Unit Well .1E-28 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have shown marked improvements following acid treatments. The treatment will consist of 4578 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressu.re will be limited to 4000 psig and the tubing pressure will be limited to .1500 psig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. During cleanup the well will be produced to tanks on location. the cleanup the well will be produced to CPF1. Following Expected start date' December 3, 1982. Subsequent Work Reported on Form No,/O-/'/-~L'~ Dated ~'~~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The s_p~a.c_e_?~__,~ for Co~m._missi_on use Conditions ~'~ Approval, if any: KUPARUK Title--OP-F-~T I[~-!S COORD ! NATOR By Order of Approved by COMMISSIONER the Commission Date Form 10-403 L"~ ~, 7_1 Submit "Intentions" in Triplicate and "Subsequent .Reports" in Duplicate TO: William VanAlen Transmitted herewith are the following: PLWASE NOTE ~~ D. W. Bose/Lorie L. Johnson F - FII/~, T - TAPE, PC - PHOTOCOPY RECEIVED PT.VASE RETURN RtI2E~ TO: At:C'O AIASKA, INC. ATIST: LOR~- L. JOHN~ - AFA/..¥11!tska 0il & Gas Cons. CommissiQ~t P. O. BOX 360 Anchorage ANCHORAGE, AK. 99510 /' D. W. Bose/Lorie L. Johnson Transmitted hert~,ith are the following: o -. RECEIVED ARCO ' ~* ~~ska OiJ & Gas Cons. Commission A~: ~~ L. J~S~- ~chorage P. O. ~X 360 ~0~, ~. 99510 ARCO Alaska, Inc. Post Office Bo,, ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 October 25, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-28 Well Completion Report Dear Mr. Chatterton- Enclosed are the well completion report and gyroscopic survey for the 1E-28. If you have any questions, please call JoAnn Gruber at 263-4944. Sincerely, P. A. Van Dusen District Drilling Engineer PAV/JG'sm Encl osures GRU2/L25 ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany , STATE OF ALASKA ~'%/1 ALASKA~ AND GAS CONSERVATION C ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-158 , 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20832 4. Location of well at surface 9. Unit or Lease Name 187' FNL, 640' FEL, Sec. 21, T11N, R10E, UN ,.LOCATIONSI Kuparuk River Unit At Top Producing Interval VERIFIED t 10. Well Number 2468' FNL, 2529' FWL, Sec. 21, TllN, R10E, UM Sure. r~'_~, j 1E-28 At Total Depth jR. H.__~ 11. Field and Pool 2578' FNL, 2410' FWL, Sec. 21, TllN, R10E, UM ~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKB ADL 25651, ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 09/26/82 10/04/82 10/07/82 N/A feet MS L 1 17. TotalDepth(MD+TVD) 18.PlugBackDepth(MD+-rVD) 19. DirectionalSurvey I 20. DepthwhereSSSVset I 21.ThicknessofPermafrost 7665'MD,6676'TVD 7547'MD,6562'TVD YES FX-I NO [] 1898' feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR./Cal/FDC/CNL, BGT, 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 79' 24" 254 sx AS II 10-3/4" 45.5# K-55 Surf 2303' 13-1/2" 1500 sx AS III & 250 sx /~ I 7" 26.0# K-55 Surf 7629' 8-3/4" 610 sx Class G & 41 bbls AS I 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) 7345' -7366' 3-1/2" 7014' 6965' 7318' -7328' 7165'-7175' 26. ACID, FRACTURE, CEMENT' SOUEEZE, ETC. 7145'-7166' 8 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7125'-7146' 7105' -71 26' N/A 7088 ' -7109' ' 27. N/A PRODUCTION TEST , Date First Production I Me~hod 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 ~ FioTM Tubing Casing Pressure CALCULATED OI L-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) 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 O,ST ~" Al.~l:a Oil ,~. Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC5 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 7089' 7174' 7302' 7416' TRUE VERT. DEPTH 6124' 6205' 6327' 6436' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling Histor¥~ Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~'~~ Title Sr. Drilling EngineerDate 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". DS 1E-28 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0230 hrs, 09/26/82. Drld 13-1/2" hole to 2325'. Ran 58 jts, 45.5#/ft, K-55, BTC csg w/shoe @ 2303'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 1725 psi - ok. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS, cmt & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 7540'. Ran DIL/SFL/SP/GR/Cal/FDC/CNL. Ran BGT. Cont drlg 8-3/4" hole to 7665' TD (10/04/82). Ran 164 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 7629'. ~~_0~ sx_~C~lass G. Instld 7i' packoff & tstd to 3000 psi - ok. Ran Gyro & CBL - good bond. Perf'd 7345'-7366', 7318' -7328', 7165' -7175', 7145' -7166', 7125' -7146', 7105'-7126' & 7088'-7109' w/8 spf. Ran 3-1/2" completion assy w/tail @ 7014' & pkr @ 6965'. SSSV @ 1898'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. Disp well to diesel. Dropped ball & set pkr. Closed SSSV & set BPV. Secured well & released rig @ 0'930 hrs, 10/07/82. JG:sm 10/18/82 GRU2/DH13 0 1E-28 (SEC21 I<UF'ARUK TllN RI¢ COP DATE · · BO:5~ uYRO.:.:,,L, OP I L .... k RVEY ::,...lOB: NUMBER. BOSs-1611 ,'"-, MEASURED VERTI DoG.JLEO,:'~ ,. EVERIT, · TES VERT I C:AL 200, ..:, }0 14()0 1450 , 1900 20C) 0 2 5 (] 0 26()0 1E-28 (oE_..-1 I<UPARt.IK TllN RIOE) , · , · COMPUTATION DATE OCTOBER:~ 06, 1982 BOSS GYROSCOF'IL] SLIRVEY JOB' NUMBER ,..~. ~ ... 16.1 (' MEASLIRED DoG-'LE~ ,~EVERI~T:¥: ~ .' :'~ORDINATES VERTICAL. ':?70, 4':? 1034;/:,'i ,:, 700 :3800 '-- ' : 1432..22 4:3 0 0 4. 4 ()0 1777.50 i 84,4.4,7 48 (') 0 4?CK) 4172'11: ': 4066.11 34 48 ' :g :4o'29 W: 0,, 36 1501'5':) S 0.37 ; 1544. ';'....,:.":' ::,'-' 1478.42 W '08C), 2 :l :3:3. 17 ( SASURED VERTICAL. ,ULAR IOINATES' VERTICAL 6000 '51112 6100 5202 .~i W, '27<"15.87 W 2750.70 6600 566:1 1[£--28 ('F;EC21 T11N RIOE) · OCTOBER ~ 06, ~ 1982 ~ ii i~ ~ dOB NUMBER r..-,,~,-. · KUPARUK ~ ~ "?~ ~,~ :~ ~,.; ~, . . ~ ~, ~' '~ ~ . , , :: ~, ~ ~ ~u~o- 16.1 1S TRUE · 7c, 6... 6676 0 0 1E-28 (SEC:21 TI1N RZOE): ' '' COMPUTATION. DATE I<UPARLIi< · , :/. OCTOBER '06,: ::1~82 706 806 E, o6.0 1 B 08 1411 1 BO6. O0 1406.00 · , TRUE ,:. 2090 2212 2 ~ o6i~o0 ;, 0 0 ' · · · :-.-.,~x.,...:%:.-.:, ...:...:, $:- -.-..:,-.,-...x...:-.-,.-.~,~.-.-&c :~.~., ..-,... i,~-.~.- ..,-..... ~.. ..~ ,~ x - · - ~ - .:c . - .~.~..:. ,,-.~.:..× .> '.~..-. ~.,,:...x,~ ................ ~ .............. ~-~.~ .... .~..~. -~---, .................................. ~ . .. ',~.., - ~ ..... ~. ................ .~ ...... t.;. .......... ,...~ .... ........... ~ ........ ,..~..~ ........... ~....~,.× ............... ~ ........... '-' I-''~' . .' ; COMPUTATION DATE 1E-28 (.:,E...,.:! T:I. iN RIOE) .... KUP~RUK OCTOBER. 06~ ! .9.~2 , ' dOD NUMBER BOSS-16 ~ ~ 6 · , 4574 46':77 4006, O0 541'" ,:, 4606 ::::::::::::::::::::::::::::::::::::::::::::: 1E-..',_ (._EU-'I Tl lN RIOE) COMPUTATION DATE- KUPARLIK 6:E:60 , 7 4,::, c:, .': THE i',IEAR~ 0 0 0 7174 · 7 3A2 : 6:326; ,SA 0 0 0 TI 1N RI(3E · 215)6.92W 22C)6.49W BOss G-yroscoPiC :SUrvey- S..-, Boss-161i6 '~ - : _- (187FNL 640FW_/,) . . .. · Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · ' 'Operator, W~i~ N~e a~d- Number Reports and Materials to be received by: // --~'~-_~ ~ate · Required '.., Date Received Remarks Completion Report Yes / Well History Yes Core~s __ .... /,:~.~,.~ . Core Description _.Registered Survey Plat 7~..~ , , Inclination Survey · · Directional Survey YLt~-S --'P / ~ , _ , , Drill Stoa Test Reports --- Produ ~.ction Test Reports Digitized Data y~ ~ ARC~) Alaska,. Inc. .......... Post Office Bo)~ -~ Anchorage, Alas,,a 99510 Telephone 907 277 5637 October 14, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT'. State Reports Dear Mr..Chatterton' Enclosed are monthly reports for September on these drill sites' 1-19 18-6 1-20 18-7 6-21 1E~28 6-22 1E-29 13-16 1E-30 13-34 1F-6 1G-2 1G-3 WSW-3 WSW-4 Also enclosed are well completion reports for: 2-26 1G-1 6-20 14-15 (completion report &subsequent sundry report) 1E-17 1F-5 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG'llm Enclosures GRU2/L15 Gas Cons. Ccmrnis]ion ARCO Alaska, Inc. is a subsidiary of AtlanlicRichfieldCompany ~. STATE OF ALASKA ALASKA ( .~ AND GAS CONSERVATION CC' ~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well X~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-158 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20832 FNL, 640' FEL, Sec. 21, T11N, R10E, UM 4. Location of Well 187' at surface 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 6. Lease Designation and Serial No. ADL 25651 ALK 469 9. 'Unit or Lease Name Kuparuk River Unit, 10. Well No. 1E-28 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. September ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks .~ Spudded well ~ 0230 hfs, 09/26/82. Drld 13-1/2" hole to 2325'; ran, cmtd & tstd 10-3//+" csg. Drld 8-3//+" hole to /+760' as of 09/30/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressur9 tests 16" 62 5#/ft, H-40, weld conductor set @ 79' 10-3//+", /+5.5#/ft, K-55, BTC csg w/shoe @ 2303'-. Cmtd w/25/+ sx AS II. Cmtd w/1500 sx AS III & 250 sx AS I. SEE DRILLING HISTORY 14. Coringresumeandbriefdescription None 15. Logsrunanddepthwhererun None to date 16. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED ( /~-,~' ~J ~~ TITLE ................. DATE ~ NOTE--Repo~on~this is required for each calendar month, regardless of the status of operatiOns, and must be filed in duplicate with the Alaska Oil and Gas//conservation Commission by ~l~d ~t)qjv~ lib~ succeeding month unless otherwise directed. Form 10~04 Submit in duplicate DS 1E-28 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 0230 hrs, 09/26/82. Drld 13-1/2" hole to 2325'. Ran 58 jts, 45.5#/ft, K-55, BTC csg w/shoe @ 2303'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 1725 psi - ok. NU BOPE & tstd - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS, cmt & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 4760' as of 09/30/82. JG'llm 10/07/82 GRU/DH11 TO: William VanAlen DATE: /0// ! Transmitted herewith are the follc~ing: D. W. Bose/Lorie L. Johnson PLFASE NOTE: BL- BLUELINE, S - SEPIA, F- FILM, T- TAPE, PC - PHOTOCOPY A~: PdH2EIPT TO: DATE: Oo~' 1 4 1 '82-- ATIN: LORIE L. JOHNSON - AFA/311 P. O..BOX 360 ANCHORAGE, gl<. 99510 MEMOR -NDUM Sta e of Alaska Cha~ --~ TO: C ~ Thru: Lonnie C. Smith Commissioner FROM: Bobby 'Foster ~~-~' Petroleum. Inspector DATE: Octok]er 4, 1982 FILE NO: 108/M TELEPHONE NO: SUBJECT: Witness BOPE Test on ARCO's 1E-28 Sec. 21, TllN, R10E, UM Permit 82-158 Mg__nday,. Septembe. r~ 27,_ 19.8_2.- I traveled this date to Prudhoe Bay to witness the-upComing BOPE test on ARCO's 1E-28. Tuesday, September 28, 1982.- The BOPE test began at 4:45 p~m~" and wa~ c0nC:lUd~d a.t---~..15 p.m. As the attached BOPE report shows there were no failures. In summary, I witnessed the BOPE test on ARCO's 1E-28. STAT~ OF ;d,ASKA A~-~KA OZb & GAS CO;;$ERVATIO;I COt.lt.~-~,SZON B.O.P.E. Insl:ection Report Well ~ ~--- -- ~~' s.=, Drilling Contracto.~ /~g/-~J 'Rig Location, General ACCU:IULATOR SYSTEM Well Sign f~ 'Eull Charge Pressure~gP~) psig _. General Housekeeping BOPE Stack Annular Preventer. Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves · Check Valve / ';Pressure After Closure /~ ~- psig :.200 psig Above Precharge Attained: !!Full Charge Pressure Attained:___~__min , !! i~.. Controls Master. _ ;I Remote ~~ Blinds switch cover~ Test Pr'es~re~ Kelly and Floor Safetv Valves ~O ~Upper Kelly . / Test Pressure . ~~ ~Lower Kelly / Test Pressure ~ , Ball Type ] Test Pressurq ~ C ~~ }~Inside BOP / Test Pres~re , - ~,~ .~ Choke ~,lanifold,,o~3 Test Pressure l~No. valves 'Adjustable Chokes /. /-- FO~ }lydrauically opera~ed choke ~ T~st Time //~ hrs .... 3 / Test Results: Failures Repair or Replacement of failed equipment to be made within._ Inspector/COmmission office' notified. days and Remarks Distribution orig. - AO&GCC cc -. Operator cc - Supervisor ARCO Alaska, Inc. ~ Post Office b,.,, 360 Anchorage, Alaska 99510 Telephone 907 265 6375 E. M. Pringle Vice President September 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-28 Dear Mr. Chatterton: Attached for your review and approval is a Sundry Notice for Kuparuk 1E-28. This Notice addresses a revision to the directional program. kick-off depth is being changed from 2300' to 1000' to avoid crossings with Well's IE-1A and 1E-29. The target bottomhole location remains unchanged. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK:sm Attachment The ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA~JIL AND GAS CONSERVATION C(~,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELLX~ cOMPLETED WELL [] OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, AK 99510 4. Location of Well At Surface: 640' FEL, 187' FNL, Sec. 21, T11N, RIOE, UM At total depth: 2776' FEL, 2807' FNL, Sec. 21, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF, etc.) 72' Pad, 106' RKB 6. Lease Designation and Serial No. ADL 25651 ALK 469 7. Permit No. 82-158 8. APl Number 5o- 029-20832 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-28 11. Field and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations' [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans F~ Repairs Made [] Other [] [] Other [] Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The kick-off depth is being changed from 2300' to 1000' to avoid crossings with Wells 1E-29 and 1E-lA. The surface location and target bottom hole location remain unchanged. Because the final hole angle has been reduced from 45°± to 34°±, the proposed total depth has been changed and is now 7571' MDj 6566' TV~. As originally proposed, the 10-3/4" casing will be set at 2200' TVD, but its measured depth will be 2293'±. The 7" casing will be set at 6566' TVD (7571' MD). The closest well crossing is with 1E-29 and occurs at the surface (120'). Revised directional and proximity plats are attached. 14. I hereby certif~,y that the foregoing is true and correct to the best of my knowledge. Title Senior Drilling Enqineer Signed / //(/ / ~ / _ _ The space b.~WSw f~r Comr/~ission use Condition,s/of Approval, if any: ORIGINAl. BY LOIIIIII~ Approved by COMMISSIONER By Order of the Commission Approved 7opy Returned - ,, Form 10~,03 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate i ..... ..... .... ....... ................ ,-=, .............................. I..: ............ i -~'-~x :ill :~ , :_=:-: :-:-~-: ..... -+=-.~ i: i ~ ~ .......................... ' __: :.: :_.::.::_- . · · ,13 ..... . , ,; ,: , --!~,!~'[; ..... /~SURf~RL'E:: ...... : .... ~-:--:: ~ ~ iii !~ :' -~-+4-:-:- --' '-:,.'f, -.~--~------;- ..... ~---,-,.-,- --.:-...,-L01:]0~ ::l'(l~lP - T'vn.;.;.r,'lnnT~rl;;Tnllfl-rl='P;,lr? T-~=- ~-~ :--1-,~ .I-:-~ ~--~T~--:---~-~-:+-~.-~ ..~-: ---:/~-:--:--~-= .... ,. T-: .... ; ...... '!-'- ...... ~- ...... t--~-- ........... '---~----I-=-~-I '!'.='-+i'i ~ili i i~i :~ i . _'_,_ ~-,,'-': .......... :__.~ ..... ._ ---:'F' .... = .... ~--'-,;.--~I:F3E-~_f~If.~.F~,~~ .. I ~ . ii ..,.i i ; ~ ' i' ' ~ -~ :,/' :'' --=-~.: ~ : ..... "' ?~ ' .' ' :';., a,,, : '~. ;~ ~,; .~ :,~:.i ............. _= ...... -=.. l.-:-...--,- "-.1': 1.].'::_:_:.'_-_-. :~.~.='--:Z~-:.:::_'_~_ ..... T:, !:; --!-TTZZ~' ~ !'. '. i-i ! ! i !; ' i ii i J i i ' i~ i' *! '~; :T-_.T_/_LZ.Z..:_-7._T_':: ?-fi-T:.:: ................ ' ...... i~ ..... -= .... ~ .... 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' ' ....... ___4- ..... , : , ,.' ..... , [ ~ { ' i [ j il' ~ ~ [ 1/~ . ~[ /~i~d", j~Z ~ I [ ;i i ~ ' J I ~ i ~1 jjt i J J ! i ~ [ i JIlL lijJ [:..[Jjl I!~i1~ I 11 Ill i ~ I I llli : ...... Z ~I~'~i~ f ~ F~i : i , ' . I i i. ! I i i i : :' : -'' i ii iii iii ' i i i: ]--i-i I i 'ii~ ii ii i l/i~ ~/ZIi JZiil [~ti i, !I ill ill i:'l i~ I . I I ~il I i1,' , *.;~e:i i i i~ ~ ! i~ ~I [ I I I I i~ i ! I 1 .i~ ~ i: : *iI[[~!i ,:~,~ ::, ,~:: , ' ~''' ' Z~ '': :.~:' ~!I[ ill [I:1 [ I ;111 I ~'I: j ' : : i i [ i j j j j ~- iIIi i i ' :: ! i : iZVi ~j ~ J.i~ IL l.[ ii ' .. ,~ , , " ,- - ?-ii f iii ~: : , [ i ili l i: i iZ/i I ii !.l/ :_ ~ I_./ i :~ll i i : ii i I il ill :' " ~ i i~ ~; i ~ i, :, ~,: ~ i i i .... ~ ~ -' ' ~ :' i i i ,ill,' i I i ~ i ~ i i ...... i I I I I i I' ~ ' , . ~ ~ -.-~ ~l!~ ~.:~: ii: i ! ~/: i ~ ~ ~ i i ~ i ~ ..... ~ I: .,~ .... ~ i[~, ........ ,~_ ~ ~ ~ ,, : ~ ~ iI :, i ~ :: ~ ~ ~ I :: I ', i ~- "::' ,~ ',i~ [ ~i1~ ~'Ii~ Ii!: i~_~ 11~ Ii Sept~ber 20, 198~ Mr. Jeffrey B. KeWin Senior Drilling Engineer ARCO Alaska, Inc. P. O, Box $60 Anchorage, &laska ~uparuk ~tver Unit AH~ Alaska, Inc. Peri t ~o. Sur. LOC. ~F~, I~'FNL, Sec. ~1, Tll~, RlOB, ~. ~ole Loc. Dear ~r. Kewin~ EnclOSed is the approved application for perr~it to drill the above re fereneed ~el I. Well samples and a mud log are not required. A continuous directional survey is ~equtred as per 20 AAC 25.050(b)(5). If available, a tal~e eontainin~ the dit~ittzed 1o~ infoemation shall ~ submitted on all lo~s fo~ copying except experi~ntal locs, velocity surveys and dieter surveys. S/any civets in Alaska and .their draina/~s systems have been classified aa important for the spawning or migration of anadr~us fish. Operations in these areas are subject to A8 16.05.$70 and the ~e~ulations pr~ul~ated thereunder (Title 5, Alaska A~intstrative Code). Prior to co~encii~ operations you ~y be contacted by the Habitat Coordinator's Office, Depart~nt of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter $, Article ? and the regulations promulcated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to c~eneing operations you may be contacted by a representative of ti~e Depart~nt of ~nvironmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior tO e~nein,~ installation of the blowout prevention ~qui~ent so that a representative of the Co~lssion ~ay be p~esent to ~itness testinC of the equipment before the Jeffrey B. II'awls Kuapruk River Unit -2- September 20, 1982 surface easing shoe is drilled. Wt~ere a diverter system is required, please also notify this office 24 hours prior to ccauneneing equipment installation so that the ~isston 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 wi tness present o Vf~y..._t ruly C. '~ O'RDER OF THE, CO?,~MISSION Cha i rman o f Alaska Oil and Gas ~nse~ation ~ission Ene I o su re ce: Department of'Fish a Oe~ne, Habitat Seetion w/o enel. Department of Environmental Conservation w/o anal. CVC: be ARCO Alaska, Inc. Post Office B,. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 13, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-28 Dear Mr. Chatterton' Enclosed are- An application for Permit to Drill Kuparuk 1E-28, along with a $100 application fee. .- A diagram showing the proposed horizontal and vertical projections of. the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1E-1, 1E-29, and 1E~4. - , . o A discussion of wellbore crossings, '' o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. o A map showing the location of the well, as staked. If you have any questions, please call me at 263-4970. Sincerely, Senior Drilling Engineer JBK/JG:llm Enclosures GRU1/L94 .R.E'EE IVED Alaska 0il & Gas Cons. Con]mis,ion anGhorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA (..~, L AND GAS CONSERVATION CO,,,MISSION I ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL :~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. AddressRECEIVED P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 639. FL,. 185. F,,. Sec. 21. Tl1,. R10E. UM SEP i 5 ]982 Kuparuk River Unit At top of proposed producing interval 10. Well number 2543' FEE, 2521' FEE, Sec. 21, m11N, R10E,UM Ala~0il& GasCons, C0~nmJssi0~1E-28 At total depth Anchorage 11. Field and pool 2826' FEL, 2869' FNL, Sec. 21, T11N, R10E, UM Kuparuk River Field 5. Elevation in ~et (indicate KB, DF etc.) 6. Lease designation and serial no. Kuparuk River 0i 1 Pool 72' PAD, 106' RKB ADL 25651 ALK 469 12. Bond information (see 20 AAC 25.025) Peoeral insurance Company Type Statewide Surety and/or number ~8088-26-27 Amount $500~000 .... 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 Miles NW Deadhorse miles At surface, 185 feet E-lA well 57~ ~ 2139' MD feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 7897'ND~ 6542' TVD feet 2560 09/25/82 , " 1~. If deviated {see 20 AAC 2[.050) 20. Anticipated ~ressures 25~7 psi~0°F Surface KICK OFF POINT2300 feet. MAXIMUM HOLE ANGLE 46o o (see 20 AAC 25.035 (c) (2) 2916 psig~ 6095 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 2~" 16" 65~ H-40 Welded 80' 35' I 35' 115' ~ 115' 250 cf · 13-1/2" 10-3/4" 45.5~ K-55 BTC 2167' 33' I 3'3' 2200'~12200' 1100sx AS III + I ~ I 250ex AS II '8-3/~" 7" 26~ K-55 BTC 7866~ 31~ II 31 ' 7897~ 165~2~ 760ex Class I I _ i 22. Describe proposed program: ARCO A]aska~ Inc.~ proposes to drill a Kuparuk River F~e]d development well to approx. 7897~ HD~ (65~2~TVD). Selected intervals will be logged. A 20"~ 2000 psi annular diverter will be installed on the 16" conductor while d~]]ing the surface hole. A 13-5/8"~ 5000 psi~ RSRRA ROPE stack will be installed on the 10-3/M~ surface pipe. It w~]] be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Naximum expected surface pressure is 2567 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The well will be completed with 3-1/2"~ 9.2~ J-55 buttress tbg. Non-freezing fluids be ]eft in uncemented annu]i through the permafrost interval. Selected interva]s wi]] be perforated within the Kuparuk formation and reported on subsequent reports. A downho]e safety valve will be installed and tested upon completion of the job. · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ~~~x~ /~~ TITLE Senior Drilling Engineer DATE The space be~f°~~~e CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required APl number ~YES ~O ~YES ~O ~ES ~NO 50-- O .... Permit number Approval date ~~~~//~9~/8~ SEE COVER LETTER FOR OTHER REQUIREMENTS I ,_ ~ ~ - ~ ~ by order of the Commission / Form 10-401 GRU1/PD53 Submit in triplicate WELL LAYOUT DRILL SITE 1E As-Staked Reference: Field Book 82-05, SR Drawing 22988 Wel 1 No. Northi ng+ 1E 27 5959281.870 1E 28 5959401.860 1E 29 5959521.850 1E 30 5959641 .'840 Easting+ FNL* FEL* ,= 549890.750 305' 640' 549890.75D 185' 639' 549890. 750 65' 638' 549890. 750 5225' 637' + Alaska State Plane Coordinates Zone 4 * Distance from north and east section lines. Range l0 East, Umiat Meridian, Alaska. Township ll North, Section 21 21 21 16 SEPt 5 Al~.sk~ 0il & Gas Cons. Commission i , I ! I ~ : ] I J .j J I i ' j j4' Ii !_~_~,4--.~ -4-i,--.L4--.L~--L-4---4--L-4--i---4-~---~ .............. ~ ...... ~ i ~ ~T%~' :'' , i I : ~ i ~ ~ ~ ~ ~ , _~_.~ ~ ~ I ~ ~ ~ ;1. ~ ~ , , ~ ~ , ~ .... I ~ .... ~. i ~ i ~ 4 I i [! I ~Fi ~ I I t ! I I I i I i , , . , ~ ~ , i i ] 1 i~, t I i i I i i ~', ' : '~' ii!~ i~ i~ ~ i .:¢: , ! ~!i~l ~! , I , ! ii .i ~i i,, I, ~ ; ~ 'iii. Ii i!11i111 iliii!i II!Iii!1 ii1!illi ilili!il li!!llll 'I~11 I ~iilil i l{l', I i : I i~i ;:-J._ ........ ... ,!1 ;~ I iq-ii iiii iii,! ' ' ~!~ L-~T~'~fl~ ' .. I , , I I I ~ ~ ~ i ! ! ~ I i i ! I 11 i ~ i I ! i ! i I I i i i I I I ~ . ~ J i I I i i I I i i i I I ]~ !_~ I' , , I I illi -~',' ' ' ~' ~ I Ii ,,,- '~ ' ' ...... ~', I ~, I . ~ I , , I I. I I I I I t ~ ~ ~ I ! ! t ~ i !_~ ' ~ '' ~ ~ ~ ~ ~' : ' i. I J i ! , I ~,, ~ .~4 ~ I .] i -~!il ilia- ~', i ' jj ii i 111i I II I i ,i I i - i . ; J ill '-~ ~IIi . , , i i , ! ilil II~I il t II I II i t ill i I !~ !~I! J~i L ;.iii ~ Ii ...... . .... ='"'""~~ , .~i~ ,,, ,,,, ..... ,-~ ,~, ~&, '~'~ ~ ~ ~ ~.~,,, ~,- _ uitt ,,--~ )~R~i It ~ ~I. ti i!li tili i lil~ II ilti ! I i I! il!, i~II '~i ~ i-~t-~... , ~ i ! -;iii..i,. 12_i1~__ i ' t '. ~ i i ~_L ~i~i il!l i i i i ~] i. iil~ i J ! Ii 'iii ~lll .......... I ], I I I i I I itl i i ! i I ~:~iIi~Ull ~l ! ! I 1 I ~ / I -' i ~l~ !'~'' ~="~ '~'~'~- ' '' ' ' ' '' '"' ' ]~ i2~ I ~ ~ i LI i J.l.!_i A.[~ I_ L i , , ~-i~ 1 ~ t I ! I i I i ~ !~il ~t ~',~i ~'r'r~ ,, -'~z~'~- i i ri ~l~ J~li i l ii' .... i~l I 1 i ~ J JI i ~ ~ , L ,- i~ -T=] - i i ~ i i.i J. ' ..... ; : ~ ~ i i I_L J ! I l.__!J ._L_L ] i i_L~ i I I i J i i -i% ! i I I i i i t I i i i ! I ~ i !-F~ i i i -i-lq I i i-F! -i-q i-i- T~qq FFi i t ! i ILI · ' ' f ' ' I I 1 I I -'~ , , , , , . , t ~1,, ~ : I i: ~, , Ifil. iiJl. Iili i~i!, 1~' ~- "~1~ ; '-~, ~ i iili 1 "~ I i I ! ! I i I i i I I i i I ! i ~i i i ~ Lt ~ i i i I ~ -~ , --,:, , , -~;, ~ -~ , ~~Ir~~~ ~;I :~~;, ,. ~-, :--,% ~ --fl-~-F ,, ,,,, ., ' J ' ' ' i ' ~ ' - ' i ' ~J ~ J, , ~~~ ~ J~ I J, j J J I I J i t , j ,,- Ii,J- -' .... i .............X~~ Ii 'li ,, ,~ j 'i, , ...... ~ ! ~'~'E'L' - ~ i j / i i ~ , ?, ~ I ! i i~, i i ,~, ~,, ..... ,~,~ ,,~2~- i I i I i'! ! i j I ' i i i i i ~ I l ' ' , t1,. , I~! ~i, ~ ' 14~~J II j iij J li ' i ' I ' t i /~ ~ '"' '~ ~'"--i'~'~""-~4i~ i'll i~. ~" '"~- '[' ..... I ~ ' i ~ %~ ~ ' '~ ~ I ~ I- ]~ ~ ii ~' i' ', i I, t 'TT:i I i ii i _,,, i , ,,,, i i ! i."T:i, ; , J , . J ~ .... , ':- ' ~ [ ~ i; ,_L,~!g~ n~]i~'~f~i~ii~nT ANALYSIS OF 1E-28/1E-1A WELL CROSSING NOTE: Refer to the attached Proximity Map The proposed Well 1E-28 will cross the existing Well 1E-lA by a distance of 57' at a measured depth of 2139'. This distance was calculated using the gyro multi-shot survey on 1E-lA and assuming that Well 1E-28 will be drilled vertically to its kick-off depth of 2300', Well 1E-lA has an ellipse of uncertainty of 100' across its major axis at the depth at which the crossing occurs. Well 1E-28 will have a cone of uncertainty 14' in diameter at the depth of interest. The areas of uncer- tainty for the two wells will therefore just intersect, but will not over- lap. Because the areas of uncertainty in the directional measurements just intersect, ARCO proposes that the following procedures be used to drill Well 1E-28: 1. As the 13-1/2" surface hole is drilled vertically to 2139', single shot surveys will be taken to ensure that the hole has not deviated in the wrong direction. 2. If calculations show that an intersection of 57' or less is to occur, then a jetting assembly will be run between 1500' and 2000' to impart a small angle (3°+) in a westerly direction. The distance of 57' corresponds to the inter- section of the areas of uncertainty. 3. Well 1E-lA will be shut-in if calculations show that a crossing of 57' or less is to occur. This distance cor- responds to the intersection of the areas of uncertainty. Upon shutting in 1E-lA, casing and tubing pressures would be monitored until a safe crossing is evident. In addition to the above precautions, the on-site rig personnel and supervi- sors will continuously monitor all parameters as the interval of interest is drilled. With respect to 1E-28 and 1E-29, the closest distance between these wells is 120' and occurs at the surface. From the KOP down, the directional plans on these wells diverge. JEO:llm 09/13/82 ONI/AWC3 Surface Diverter System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. '20" bell ~ipple. 16" Conductor Maintenance & Operation 1. Upon initial installation close annular preventer and verify that 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 over- ride and close ball valve to upwind diverter line. Do not shut in well under an.s circumstances. ~3-5/8" 5000 PSI RSRRA BOP STACK~'-,, RNNULRR PREVENTOR 9 BLIND RRHS 8 · o 1. 16" Bradenhead 2. 16" 2000 PSI x lO" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 6000 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 . ACCI~,iULATOR CAPACITY TEST le PIPE RRHS 7 :3' DRILL] 'SPOOL e le PIPE RRHS :3' 4. - CHECK AND FILL ACC~IULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCLt-IULATOR PRESSURE IS 3000 PSI WITH 1500 PSI O0'A~LSTREN4 OF THE REGULATOR. OBSERVE TINE TH~q CLOSE ALL UNITS SIHULTA~IE- OUSLY ANO RECORO THE TIFUE ANO PRESSURE Rg'tAZN- lNG AFTER ALL UIIITS ARE CLOSED WITH CHARGING PU~ OFF. RECORO ON IAOC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONOS CLOSIIIG TIME AI~O 1~00 PSI · .RE)qAINTNG PRESSURE. · 1:3-518' BOP STACK TEST FILL BOP STACK A~{D MANIFOLD WITH ARCTIC DIESEL. CHECK THAT ALL NOLO 0OWN SCREWS ARE FULLY RE- TRACTED. PREDETERi4INE DEPT)i THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEJB, O. RI. ITt IN LOCK OOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER RIlO CHOKES AflO BYPASS VALVES ON i~IIFOLO. TEST ALL COMPONE:~TS TO 250 PSI AND HOLO FOR 10 MINUTES. INCREASE PRESSURE TO 1800 PSI ANO NOLO FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVFJITER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLO FOR 10 MINUTES. CLOSE VALVES. 0IRECTLY UPSTRE~! OF CHOICES. BLEEO OOWNSTREA~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST RDLAINING U~TED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAH OF VALVE ANO ZERO PSI DOWNSTREAM. BLEE0 SYSTEM TO ZERO PSI. - ' OPEN TOP SET OF PIPE RA~4S ANO CLOSE BO1TOM SET OF PIPE RAIVLS. INCREASE PRESSURE TO 3000 PSI ANO HOLD FOR 10 IIINUTES. BLEEO TO ZERO PSI. OPEN BOTTOI4 SET OF PIPE RJqPJS. BACK OFF RUN- NING JOINT AND. PULL OUT OF HOLE. CLOSE BLZNO RA~,LS AND TEST TO 3000 PSI FOR 10 [4INUTES. BLEEO TO ZERO PSI. OPEN BLINO RAHS AHO RECOVER TEST PLUG.. MAKE SURE IqA21IFOLO Ail0 LINES RRE FULL OF ARCTIC OIESEL AN0 ALL VALVES ARE SET IN ORILLItlG POSITZ0tJ. TEST STANOPIPE VALVES TO 3000 PSI. TEST KELLY COCKS NIO INSIDE BOP TO 3000 PSI WITH K0~IEY PLeIP. RECORO TEST INFO~4ATION ON BLOWOUT PREVET(TER TEST F'0RH SIGN AriO SENO TO DRXLLING SUPER- VISOR. PERFORI4 COUPLETE BOPE TEST 0lICE A WEEX AJJO FUNCTIOflALLY OPERATE BOPE DAILY. RESERVE PIT GYRO MARKER .~E-9 120' 200' .(~IE-IO 120' E-I! 120' 120' .~E-12 120' 120' *120' E-i$ '~ ~2o' ~_ ~IE-,4 120' · g ~2o' m.~E-15 120' ~ 120' <~ ~E-16 120' J 120' 190' 119.17 IE-30 IE-29 120' 2"x2"x8' BLACK POST 5,958,638 549, 7 I 0 = 150'----* RESERVE PIT -0.75' A! ~ESERVE PIT DENOTES WELL SITES FUTURE WELL SITES i i JAtlanticRichfieldCompany 'DATE )RAWN~ JDwg. No. 5.17-17C DRILL SITE "E" 'AS STAKED WELLS "1E-27 to "IE-30" PREPARED BY BOMHOFF I~ ASSOCIATES, INC. ANCHORAGE ALASKA 8/10/82 SCALE, I"= ZOO' KH CHECKED~ R.R.K. · 2,£ Lc:,~g__q-.: (,,fl,~c, .~G,4~_.~.44G,' 'qt' ARCO Alaska. Inc, Kuoaruk Prelect date' ---, 12 I¢~' ~,.,,,, iN scale. drawn by ~,j..,:_~ dwg no. 'N';K-] le'5.-~,~ ~ Lease & Well No. /~, ~ ~. / f-~"~ CHECK LIST FOR NEW WELL PERMITS Company ITEM (1) Fee (2) Loc APPROVE DATE (~ thru 8) 3. 4. 5. 6. 7. 8. (3) Admin ~/~"- ~-(j~'t~' (~ thru 11) C 4 ) C a s g Y~ f-/~-~ · (1~ thru 20) (21 thr6 24) . 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is the permit fee attached .... · ............................. · Is well to be lOcated in a defined pool ................. 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 .. ............. , ....... . condUctor tring provided Is , S Is enough cement used to circulate on condUctor and surface ......... Will cement tie in surface and intermediate or production :!:]:g.: !..~ Will cement cover all known productive horizons ............ Will surface Casing protect fresh water zones ..................... Will all casing give adequate safety in collapse, tension and burst. 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 BOP equipment attached . Does BOPE have sufficient pressure rating- Test to ~-~z~ ;gi~ ~. Does the choke manifold comply w/API RP-53 (Feb.78) .................. R~A~S Additional requirements ............................................. ~ Additional Remarks: 0 Geolosy: Engineering : ,cs WVA ~_ JKT ~'-- RAD rev: 08/19/82 INITIAL GEO. UNIT ON/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. GVP OlO,H01 VERIFICATION ** REEL HEADER DATE :82/i0/ 6 ORIGIN : REEL NAME CONTInUaTION PREVIOUS REEb CO~ENTS :SCHLUMBMRGgR ~f~Lb SMRVICf~S M[ML~)%APE ** TAPE HEADER ** DATE :82/10/ 6 ORIGIN :F$1A TAPE NAME : CONTINUATION ~ :01 PREVIOUS TAPE : COMME~TS :SCHBUMBERGER '~MLG SERV!C~iS FIKb[)TAPE ** FIb,E HEADER, FIbE NAME :SERV!C.001 SER NA~E :. :. ~AXI~IJ~ bENGTH : 1024 PREVIOUS FIL'~ $~ INFORMATION R ORDS . ~ , .~:: ~,. :? :::.: : .,. ~ ~ ,~,. ~ ~ ~ ~ ')'? : ~ : . ~0 Ab KUPARUK VERIFICATION LISTING PAGf: 2 .... SCM LU ALASKA COMPUTING CENTER C0~PAN~ : SOHIO ALASKA PETRObCU~ CO~PA~'J¥ ~ELL = 1E'28 FIELD : ~UPA~0~ COUNTY = NORTH SbOPE BOROUGH STATE : RUN #1, DATE LOGGED: 3~0CT 82 bVP 010 MOl VERIFICATION LIS~I G PaoE 3 PH = FbUID LOSS c 5,4 C3 RM = 3,690 g 58 0 DF R~F ~ 3.470 ~ 58 0 DF RM AT BHT ~ 1,§77 ~ 14 , DF MATRIX SANDSTONE $* DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE EEPR CODE ENTRY 4 I 6~ ~ 4 73 6O 9 66 0 MNE~ S~S~VICF~ SERVICM !J[,~IT API APl API ..PI flbg SIZE PROCESS SA~,~PbE ~P]~R b~:V~b COPE 4 I 6~ 4 0 NPHI FDN LVP OIO.HO1 VERIFICATION LISTING PAGE 4 ** DATA DEPT 7~68,5000 sp 22.7813 G~ DRHO -0,0908 CAb! 6,8125 2,966~ .Lb~ 2 4~24 153'7500 NPHI 4~589~ 2,1602 ",~C~L ?530,0000 1,0128 G~ 153.750~ NRAT 0 , 9297 DEPT 7500,0000 SFt, u SP -22,9844 g~ DRHO 0.1611 RHOB CALX 10,2500 R~A 1,9600 IbM 1,714d 98.6250 [,~PHI 41.5527 2,3965 NCNb 1781,0000 3,8198 (;~ 98.675~ lLb 1,6963 FCNL 480,7500 DEPT 7~00 0000 SFLb SP -29:0156 G~ DRHO 0,2749 RH[}a CAbI 10,0156 RNRA 3,7383 IbM 3.173~i 86,8125 NPHI 36,32at ~.3887 ~C~[, 1947,09{'~) 3,5602 GR 86.8125 I bi) 3.2 32 ~ NRAT 3,226~ DEPT 7300,0000 SFLO -2~ 5156 G~ SP , ~ ~ DRHO ,1..548: R O~ CALl 10.0234 R~P~ 3.3398 ILM 2.7461 93,2500 ~PHI 39.0625 2~3984 ~CNL 1988,000o 3,6593 G~ 93.2b('~ I hD 2. U055 ~,: R A T 3. FCNL 549. CALl 6.4297 I'LN{ 6.05[;6 2.9,052'7 ' 2,4395' t~C~!.., 2508,0:')00 2;.;~6!8:5 .G~:.i~ 75,7500 I L,L; 6.42 ! q NRAT 2 7520 7100,00OO!i~'SF. D0 5!5 9687 GR 62 5156 Rf'J~A 3 7000 0 a R A T 22518, 0000 FCNL 660~ 5000 .. 87 .)., I ,..~[) I. 7 61 7 -g99 999 SP CALl 10 6 LVP 010,H01 V£RIFiCA'IIO~ blSl'I G PAGE 5 DRHO -999,2500 RHOa =999,2500 ~,)CNL -999 CALX 9.8672 RNR.~ -999,2500 GR 127~6875 DEPT 6500 0000 SFbU 3.4688 IbM 2.9707 SP -25:4375 G~ !45,5000 ;,~PH! -999,2500 DRHO -999,250-0 ~HOB -999,2500 ~CN5 -999.2500 C~LI 9.8gB4 R~A -999.2500 G~ DEPT 6400,0000 SFLLi 2,3691 ILt.~ 2.4531 SP '-32,1250 GR i[52,1250 NPHI -999.2500 DRHO 999.2500 R~O~ -999,2500 ,',~CNL -999,250n CA~I 9~8828 RNR~ -999.2500 GR 152,125o DEPT 6300 O000 BFLU 1,2422 I5.~ 1.1924 SP -24:4375 G~! ,!24,7500 ~PHI DRHO -999,2500 RHOB .999~2500 NCNL -99 2500 CaI~I 9,6016 Ri~R ~ -999,2500 (_~I{ 124.75o0 DEPT 6~00, SP 27. DRHO -999, CAS! I0. D£PT 6100. · Sp '25, CA.L I 9 ' F C~b -999.25~:0 IbD 2.9277 NRAT NRAT -999.25U0 FCNL -999.259C ILD 1.2178 PRAT -99'.3.25()C FCNL -999. 250C: 0000 SFLd 3.0645 IL~ 1,6104. 421'9 "I56;2500 NPHI -999,,25~i~ 2590 RHt]F -999,2500 ~'~C~L -999;250..) ' 500 NRA!.~ :999,2500 ~CN!_/ 9Q9o25~C 0:0:00:: ',~ ~8:E:LO 3,7:10:9 : 'ILM 2,, 2441 IbD 2. i 3 ~t 7 6563 G~ 144,o000 NPHI -999.2500 N~AT 250.0.'.: :'; :~::~:9:~g9.2~50:. 0 :' : :"99'9: ;: :2.5:00 F C:N L 6094 RNRA -999,2500 G~ 144,0009 · ~'~:'~ ':~:~':~,~? ~'L:' ~' ' ' [:~:1~:~5~ ~.'~:'I ', :., ~99:9~'~:500 "999,250'0 ~'~66 ......~i,]~'~"~ "'~'9'~9',~'~50'[~ N'~NL '999,2506' FC.N[~ '999.2'50r~ ¢~bI DRHO -999 S 2. 8164 It.~ 2 847'7 i£.~0 2.8203 :ALI: I 0 D R H 0 LYP OlO.MO1 VERIFICATION LISTING SP -32,5625 GR !00,8750 r,~' PHI -999,2500 DRHO -999.2500 RHO8 -999.2500 NCNL -999.2500 CALl !0,656.3 R~:RA -999,250r) (;~ ]00,875,) N.q AT -999.2 ~C b -999.250(~ DEPT 5400,0000 SFLU 3,8750 SP -32.5313 GR 84.9375 NPHI -999.250o DRHO -999,~500 ~HO~ -999.2500 NC~L -999.2500 CALI I0,2813 RNRA -999.2500 GR 84.9375 l L O 2. NRA ~ -999. 2500 F' C ~'.. i. -999, DEPT 5300,0000 SFLU 2,2988 IL~ 2.392b ~P .-34,0625 GR 96 8750 i~PH! -999,25U0 DRHO 999.2500 RHOB -999:2500 NCNL -999.2500 CALl 10,3516 }{NRA -999,2500 GR 96.~750 ILO 2,43] 6 D R A"? - 99"~, 25 (3 f'. FCNL -999,2500 DEPT 5200,0000 SFI~!.I 2,3574 I[,,~ 2 507~ 15P -36,~813 GR 86,81~5 hPHI -999:2500 DRHO -999,2500 RHCJB -999 2500 NCNb '999.250o CALI 10.0703 RNR~ -999:2500 GR 86.8125 lbo 2,5879 NRAT -999,2500 FCmL -999,25u0 , DEPT 5100 0000 SFLU: 3.1133 ILR 3,32~2 SP .-39,2813 GP . 9!,0625 DRHO ,999,250'0 ~ 999.;2500 ~C:NL CALI 10,5391 N'NRA -999,2500 GP g!,Oh25 ILD 3,4570 I,,RA'.t' -999.25un FCNL -999,2500 5000, '999 .:' 10; 0000 SFt, U 4,0469 IbM 4.28~3 2.590 ;.'.:.: :G:R 11915 ~:i::3 1 25 : N:P:H'I. ,: '".9 99 · 25 0 0 ~500 Ri'.iO[:~ ,9.99,2500 NCNL -999,2500 ~6':09~ :<,~ :~;~ ~::~ ?'?:;' ~: ~9:9~9 ~ ~5~0'0:~' ~:GR':? ~ : ': ~ .'~:5':3 ! bD 4.507 .'R A T -999 "~ 5:00 CNL '999 ~ SP AL1 DE] DRHO bV~ 0lO,MO! 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