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Home My WebLink About185-114Or i g i n a t e d : D e l i v e r e d t o : 1ͲMa r Ͳ24 Ha l l i b u r t o n A l a s k a O i l a n d G a s C o n s e r v a t i o n C o m m . Wi r e l i n e & P e r f o r a t i n g At t n . : Na t u r a l R e s o u r c e T e c h n i c i a n At t n : F a n n y H a r o u n 3 3 3 W e s t 7 t h A v e n u e , S u i t e 1 0 0 69 0 0 A r c t i c B l v d . A n c h o r a g e , A l a s k a 99 5 0 1 An c h o r a g e , A l a s k a 9 9 5 1 8 Of f i c e : 9 0 7 Ͳ27 5 Ͳ26 0 5 FR S _ A N C @ h a l l i b u r t o n . c o m Th e t e c h n i c a l d a t a l i s t e d b e l o w i s b e i n g s u b m i t t e d h e r e w i t h . P l e a s e a d d r e s s a n y p r o b l e m s o r co n c e r n s t o t h e a t t e n t i o n o f t h e s e n d e r a b o v e WE L L N A M E A P I # S E R V I C E O R D E R # F I E L D N A M E J O B T Y P E D A T A T Y P E L O G G I N G D A T E P R I N T S # D I G I T A L # E S E T # 12 Z Ͳ16 5 0 Ͳ02 9 Ͳ21 3 6 3 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 6 ͲFe b Ͳ24 0 1 23 B Ͳ10 5 0 Ͳ02 9 Ͳ21 3 6 8 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 9 ͲNo v Ͳ23 0 1 33 F Ͳ14 5 0 Ͳ02 9 Ͳ21 5 0 0 Ͳ00 n / a K u p a r u k R i v e r P l u g S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 4 ͲFe b Ͳ24 0 1 43 H Ͳ13 A 5 0 Ͳ10 3 Ͳ20 0 8 9 Ͳ01 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 1 1 ͲJa n Ͳ24 0 1 53 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 1 0 ͲDe c Ͳ23 0 1 63 H Ͳ33 A 5 0 Ͳ10 3 Ͳ20 5 7 8 Ͳ01 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 1 0 ͲDe c Ͳ23 0 1 72 A Ͳ10 A 5 0 Ͳ10 3 Ͳ20 0 5 6 Ͳ01 n / a K u p a r u k R i v e r R a d i a l B o n d R e c o r d F i e l d & P r o c e s s e d 2 6 ͲFe b Ͳ24 0 1 83 K Ͳ17 5 0 Ͳ02 9 Ͳ21 6 4 2 Ͳ00 n / a K u p a r u k R i v e r P a t c h S e t t i n g R e c o r d F i e l d Ͳ Fi n a l 2 ͲDe c Ͳ23 0 1 93 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r L e a k D e t e c t L o g F i e l d Ͳ Fi n a l 2 9 ͲDe c Ͳ23 0 1 10 3 K Ͳ24 5 0 Ͳ02 9 Ͳ22 9 3 5 Ͳ00 n / a K u p a r u k R i v e r M u l t i F i n g e r C a l i p e r F i e l d & P r o c e s s e d 3 0 ͲJa n Ͳ24 0 1 PL E A S E A C K N O W L E D G E R E C E I P T B Y S I G N I N G A N D R E T U R N I N G A C O P Y O F T H E T R A N S M I T T A L L E T T E R T O T H E A T T E N T I O N O F : Fa n n y H a r o u n , H a l l i b u r t o n W i r e l i n e & P e r f o r a t i n g , 6 9 0 0 A r c t i c B l v d . , A n c h o r a g e , A K 9 9 5 1 8 FR S _ A N C @ h a l l i b u r t o n . c o m Da t e : Si g n e d : Tr a n s m i t t a l D a t e : T3 8 5 8 0 T5 8 5 9 1 T3 8 5 9 0 T5 8 5 9 1 T3 8 5 8 9 T3 8 5 8 9 T3 8 5 8 8 T3 8 5 8 7 T3 8 5 8 6 T3 8 5 8 5 18 5 - 1 0 9 18 5 - 1 1 4 18 5 - 2 9 2 19 6 - 1 9 7 20 9 - 1 0 3 22 3 - 0 9 2 18 6 - 1 5 2 19 8 - 2 4 9 Me r e d i t h G u h l Di g i t a l l y s i g n e d b y M e r e d i t h Gu h l Da t e : 2 0 2 4 . 0 3 . 0 4 1 5 : 5 0 : 3 7 - 0 9 ' 0 0 ' 185 -1 1 4 3B Ͳ10 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3B-10 (PTD 185-114) Report of suspect IA pressure increase Date:Wednesday, November 15, 2023 8:13:56 AM Attachments:AnnComm Surveillance TIO for 3B-10.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Tuesday, November 14, 2023 12:12 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3B-10 (PTD 185-114) Report of suspect IA pressure increase Chris, KRU 3B-10 (PTD 185-114) was reported by Operations to be exhibiting suspect IA pressure increase. Operations attempted to bleed the IA pressure down multiple times, but the IA repressurized each time. The plan is for the well to be shut in and freeze protected as soon as possible. DHD will be mobilized to the well in the next few days to perform initial diagnostics. Any required paperwork for continued injection or corrective action will be submitted once the path forward has been determined. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 3B-10 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 3B-10 2023-08-27 2000 1000 -1000 IA 3B-10 2023-08-28 1400 900 -500 IA 3B-10 2023-11-07 2000 1100 -900 IA 3B-10 2023-11-08 1850 1000 -850 IA 3B-10 2023-11-11 2000 1000 -1000 IA 3B-10 2023-11-11 2000 1000 -1000 IA 3B-10 2023-11-12 2000 1000 -1000 IA 3B-10 2023-11-13 2000 1000 -1000 IA Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,950.0 3B-10 4/15/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set patches 3B-10 8/12/2023 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/11/2010 ninam NOTE: Mandrel @ 6534 - Water Injection Package 11/11/2010 ninam NOTE: Surf CSG Patch, straddle thread collar leak; 2'8" Patch OAL, top @ 3'9" below mandrel hanger 4/5/2008 lmosbor NOTE: WAIVER CANCELLED FOR T x IA COMMUNICATION -- REPAIRED 7/5/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.6 95.0 95.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 3,309.4 3,249.4 36.00 J-55 BTC PRODUCTION 7 6.28 23.6 7,232.2 6,413.4 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.7 Set Depth … 6,898.5 Set Depth … 6,136.3 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.7 23.7 0.07 HANGER 8.000 FMC TUBING HANGER 3.500 1,759.4 1,759.3 1.20 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out Flapper on 9/5/97) 2.810 1,801.7 1,801.7 1.33 GAS LIFT 5.390 CAMCO KBUG 2.920 3,105.4 3,062.4 22.60 GAS LIFT 5.390 CAMCO KBUG 2.920 3,901.5 3,763.0 35.30 GAS LIFT 5.390 CAMCO KBUG 2.920 4,430.7 4,182.1 38.13 GAS LIFT 5.390 CAMCO KBUG 2.920 4,830.6 4,496.5 38.24 GAS LIFT 5.390 CAMCO KBUG 2.920 5,278.2 4,844.0 39.48 GAS LIFT 5.390 CAMCO KBUG 2.920 5,696.7 5,173.2 37.59 GAS LIFT 5.390 CAMCO KBUG 2.920 6,104.7 5,493.8 38.08 GAS LIFT 5.390 CAMCO KBUG 2.920 6,525.6 5,830.0 35.88 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,562.9 5,860.3 35.53 SBR 5.625 OTIS SBR 2.937 6,576.0 5,870.9 35.41 PACKER 5.937 OTIS RRH PACKER 2.970 6,748.0 6,012.1 34.55 BLAST RINGS 4.500 BLAST RING 2.867 6,824.2 6,074.9 34.34 BLAST JT 4.500 STEEL BLAST JOINT 2.867 6,873.6 6,115.7 34.07 LOCATOR 5.625 OTIS LOCATOR SUB 2.937 6,875.3 6,117.1 34.06 PACKER 5.875 OTIS WD PACKER 4.000 6,890.3 6,129.6 33.97 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 6,897.9 6,135.8 33.93 SOS 4.500 OTIS SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,227.6 3,174.7 23.78 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIP WITH ANCHOR LATCH ASSY ( 21.91' OAL 1.60 I.D) TTS PIIP CPP3 5353 CPAL 35197 8/12/2023 1.600 3,250.0 3,195.3 24.04 PACKER - PATCH - LWR 2.725 PIIP LOWER PKR (5.08' OAL 1.625 I.D TTS PIIP CPP3 5039 8/12/2023 1.625 3,324.6 3,263.1 24.95 PACKER - PATCH - UPR 2.725 PIIP UPPER PACKER, SPACER PIPE & ANCHOR SEAL ASSEMBLY (31.91' OAL) TTS PIIP CPP3 5351 & CPAL 35127 8/11/2023 1.600 3,339.0 3,276.2 25.16 LEAK TBG LEAK IDENTIFIED BY EL ACOUSTIC LDL AT 3338' RKB 3/8/2023 2.992 3,354.6 3,290.3 25.38 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER WITH W-LEG, MOE = 3357' RKB, OAL = 4.01' TTS PIIP CPP3 5092 8/3/2023 1.625 7,030.0 6,245.5 33.87 FISH EQUALIZING PRONG HEAD LOST IN HOLE 5/10/2008 5/10/2008 0.000 7,031.0 6,246.4 33.87 FISH 1 1/2" DMY In rathole 7/3/1993 0.000 7,032.0 6,247.2 33.87 FISH 3 3/4" Metal Fingers (16); From Otis W-1 Test Plug No Problem w/ Fingers in GLM #12 (7/3/93); Fell to Rathole 5/26/1987 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,801.7 1,801.7 1.33 1 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,105.4 3,062.4 22.60 2 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,901.5 3,763.0 35.30 3 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 4,430.7 4,182.1 38.13 4 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 4,830.6 4,496.5 38.24 5 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3B-10, 8/13/2023 5:11:41 AM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 FLOAT SHOE; 7,230.5-7,232.2 FLOAT COLLAR; 7,147.7- 7,149.1 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 SOS; 6,897.9 NIPPLE; 6,890.3 PACKER; 6,875.3 LOCATOR; 6,873.6 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 PACKER; 6,576.0 SBR; 6,562.9 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 PACKER - PATCH - LWR; 3,354.6 PACKER - PATCH - UPR; 3,324.5 LEAK; 3,339.0 SURFACE; 30.7-3,309.4 FLOAT SHOE; 3,307.7-3,309.4 PACKER - PATCH - UPR; 3,227.6 FLOAT COLLAR; 3,219.3- 3,221.0 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 HANGER; 30.7-35.8 HANGER; 23.7 KUP INJ KB-Grd (ft) 35.51 RR Date 6/18/1985 Other Elev… 3B-10 ... TD Act Btm (ftKB) 7,250.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136800 Wellbore Status INJ Max Angle & MD Incl (°) 39.53 MD (ftKB) 5,200.00 WELLNAME WELLBORE3B-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: Flapper Locked Out Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,278.2 4,844.0 39.48 6 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 5,696.7 5,173.2 37.59 7 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 6,104.7 5,493.8 38.08 8 GAS LIFT DMY BK 1 0.0 7/3/1993 0.000 6,525.6 5,830.0 35.88 9 GAS LIFT DMY RK 1 1/2 0.0 2/17/2003 0.000 6,611.3 5,899.7 35.12 1 0 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,677.2 5,953.8 34.76 1 1 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,857.4 6,102.3 34.15 1 2 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,726.0 6,771.0 5,993.9 6,031.0 UNIT D, C-3, C- 4, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,795.0 6,805.0 6,050.8 6,059.0 C-1, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,841.0 6,848.0 6,088.7 6,094.5 UNIT B, 3B-10 7/9/1985 4.0 IPERF 5" Csg Gun; 120 deg. ph 6,954.0 6,996.0 6,182.4 6,217.3 A-3, A-4, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,002.0 7,022.0 6,222.3 6,238.9 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,040.0 7,045.0 6,253.8 6,258.0 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 3B-10, 8/13/2023 5:11:42 AM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 FLOAT SHOE; 7,230.5-7,232.2 FLOAT COLLAR; 7,147.7- 7,149.1 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 SOS; 6,897.9 NIPPLE; 6,890.3 PACKER; 6,875.3 LOCATOR; 6,873.6 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 PACKER; 6,576.0 SBR; 6,562.9 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 PACKER - PATCH - LWR; 3,354.6 PACKER - PATCH - UPR; 3,324.5 LEAK; 3,339.0 SURFACE; 30.7-3,309.4 FLOAT SHOE; 3,307.7-3,309.4 PACKER - PATCH - UPR; 3,227.6 FLOAT COLLAR; 3,219.3- 3,221.0 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 HANGER; 30.7-35.8 HANGER; 23.7 KUP INJ 3B-10 ... WELLNAME WELLBORE3B-10 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3B-10 KUPARUK RIV UNIT 3B-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 3B-10 50-029-21368-00-00 185-114-0 W SPT 5875 1851140 3000 1791 1794 1790 1792 240 540 540 540 OTHER P Brian Bixby 8/30/2023 MITIA post patch for SUNDRY # 323-251 and to MAIP for AIO 2B.067 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3B-10 Inspection Date: Tubing OA Packer Depth 840 3300 3160 3130IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230830153818 BBL Pumped:2.6 BBL Returned:2.6 Tuesday, October 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 99 9 9 9 9 9 post patch for SUNDRY # 323-251 AIO 2B.067 James B. Regg Digitally signed by James B. Regg Date: 2023.10.17 13:21:43 -08'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Tubing Patch Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7250'feet None feet true vertical 6428' feet 7030', 7031', 7032'feet Effective Depth measured 6950'feet 3228', 3248', 3325', 3356', 6576', 6875' feet true vertical 6179'feet 3175', 3193', 3263', 3290', 5871', 6117' feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 3-1/2" J-55 6898' MD 6136' TVD Packers and SSSV (type, measured and true vertical depth) 3228' MD 3248' MD 3325' MD 3356' MD 6576' MD 6875' MD 1759' MD 3175' TVD 3193' TVD 3263' TVD 3290' TVD 5871' TVD 6117' TVD 1759' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 323-251 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG ~ Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: PIIP Patch Packer Packer: Otis RRH Packer Packer: Otis WD Packer SSSV: Camco TRDP-1A SSSA Sfty Vlv Jan Byrne jan.byrne@conocophillips.com (907) 659-7224Staff Well Integrity Specialist 6726-6771', 6795-6805', 6841-6848', 6954-6996', 7002-7022', 7070-7045' 5994-6031', 6051-6059', 6089-6094', 6182-6217', 6222-6239', 6254-6258' measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) ~ Gas-Mcf MD ~ Size 95 ~ ~~ INJECTOR ~~ ~ measured TVD 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 185-114 50-029-21368-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0025633 Kuparuk River Field/ Kuparuk River Oil Pool KRU 3B-10 Plugs Junk measured Length Production Liner 7209' Casing 6413'7232' 3279' 95'Conductor Surface Intermediate 16" 9-5/8" 64' 3309' 3249' Burst Collapse Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:17 pm, Aug 28, 2023 Digitally signed by Jan Byrne DN: OU=Well Integrity, O=ConocoPhillips, CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorge Alaska Date: 2023.08.28 11:00:31-08'00' Foxit PDF Editor Version: 12.1.2 Jan Byrne DTTMSTART JOBTYP SUMMARYOPS 8/2/2023 ACQUIRE DATA EQUALIZED & PULLED 3-1/2" QUADCO RBP FROM 6600' RKB, BRUSH & FLUSHED TUBING WITH 50bbls HOT DIESEL, FOCUSED ON PATCH INTERVAL 3150'-3400' SLM, RAN 2.72" x 34.8' DUMMY PATCH DRIFT TO 4000' SLM, NO RESTRICTIONS, Ready for lower patch packer set. 8/3/2023 ACQUIRE DATA SET 2.725" PIIP LOWER PACKER W/ MOE @ 3357' RKB, CCL TO MID ELEMENT = 10.25', CCL STOP = 3346.75' MD, CORRELATED TO READ LDL LOG DATED 3/8/2023 AS PER PROCEDURE. JOB IS READY FOR SL. 8/7/2023 MAINTAIN WELL FREEZE PROTECT JOB CANCELLED, SEE LOG FOR DETAILS 8/11/2023 ACQUIRE DATA PERFORMED PASSING CMIT-TxIA @ 3000psi AGAINST LOWER PACKER @ 3357' RKB, SET 2.725" P2P PATCH & UPPER PACKER @ 3327' RKB (MID ELEMENT), PERFORMED PASSING MIT-IA @ 3000psi, IN PROGRESS 8/12/2023 ACQUIRE DATA SET 2.725" P2P LOWER PACKER @ 3250' RKB (MID ELEMENT), PERFORMED PASSING MIT-T @ 3000psi, SET PATCH & 2.725" UPPER PACKER @ 3230' RKB (MID ELEMENT), PERFORMED PASSING MIT-T @ 3000psi, JOB COMPLETE 3B-10 Tubing Patch Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,950.0 3B-10 4/15/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Set patches 3B-10 8/12/2023 scolem Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/11/2010 ninam NOTE: Mandrel @ 6534 - Water Injection Package 11/11/2010 ninam NOTE: Surf CSG Patch, straddle thread collar leak; 2'8" Patch OAL, top @ 3'9" below mandrel hanger 4/5/2008 lmosbor NOTE: WAIVER CANCELLED FOR T x IA COMMUNICATION -- REPAIRED 7/5/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.6 95.0 95.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 3,309.4 3,249.4 36.00 J-55 BTC PRODUCTION 7 6.28 23.6 7,232.2 6,413.4 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.7 Set Depth 6,898.5 Set Depth 6,136.3 String Ma 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.7 23.7 0.07 HANGER 8.000 FMC TUBING HANGER 3.500 1,759.4 1,759.3 1.20 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out Flapper on 9/5/97) 2.810 1,801.7 1,801.7 1.33 GAS LIFT 5.390 CAMCO KBUG 2.920 3,105.4 3,062.4 22.60 GAS LIFT 5.390 CAMCO KBUG 2.920 3,901.5 3,763.0 35.30 GAS LIFT 5.390 CAMCO KBUG 2.920 4,430.7 4,182.1 38.13 GAS LIFT 5.390 CAMCO KBUG 2.920 4,830.6 4,496.5 38.24 GAS LIFT 5.390 CAMCO KBUG 2.920 5,278.2 4,844.0 39.48 GAS LIFT 5.390 CAMCO KBUG 2.920 5,696.7 5,173.2 37.59 GAS LIFT 5.390 CAMCO KBUG 2.920 6,104.7 5,493.8 38.08 GAS LIFT 5.390 CAMCO KBUG 2.920 6,525.6 5,830.0 35.88 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,562.9 5,860.3 35.53 SBR 5.625 OTIS SBR 2.937 6,576.0 5,870.9 35.41 PACKER 5.937 OTIS RRH PACKER 2.970 6,748.0 6,012.1 34.55 BLAST RINGS 4.500 BLAST RING 2.867 6,824.2 6,074.9 34.34 BLAST JT 4.500 STEEL BLAST JOINT 2.867 6,873.6 6,115.7 34.07 LOCATOR 5.625 OTIS LOCATOR SUB 2.937 6,875.3 6,117.1 34.06 PACKER 5.875 OTIS WD PACKER 4.000 6,890.3 6,129.6 33.97 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 6,897.9 6,135.8 33.93 SOS 4.500 OTIS SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,227.6 3,174.7 23.78 PACKER - PATCH - UPR 2.725 PIIP UPPER PKR SPACER PIP WITH ANCHOR LATCH ASSY ( 21.91' OAL 1.60 I.D) TTS PIIP CPP3 5353 CPAL 35197 8/12/2023 1.600 3,247.6 3,193.1 24.01 PACKER - PATCH - LWR 2.725 PIIP LOWER PKR (5.08' OAL 1.625 I.D TTS PIIP CPP3 5039 8/12/2023 1.625 3,324.6 3,263.1 24.95 PACKER - PATCH - UPR 2.725 PIIP UPPER PACKER, SPACER PIPE & ANCHOR SEAL ASSEMBLY (31.91' OAL) CPP3 5351 & CPAL 35127 8/11/2023 1.600 3,339.0 3,276.2 25.16 LEAK TBG LEAK IDENTIFIED BY EL ACOUSTIC LDL AT 3338' RKB 3/8/2023 2.992 3,354.6 3,290.3 25.38 PACKER - PATCH - LWR 2.725" PIIP LOWER PACKER WITH W-LEG, MOE = 3357' RKB, OAL = 4.01' CPP3 5092 8/3/2023 1.625 7,030.0 6,245.5 33.87 FISH EQUALIZING PRONG HEAD LOST IN HOLE 5/10/2008 5/10/2008 0.000 7,031.0 6,246.4 33.87 FISH 1 1/2" DMY In rathole 7/3/1993 0.000 7,032.0 6,247.2 33.87 FISH 3 3/4" Metal Fingers (16); From Otis W-1 Test Plug No Problem w/ Fingers in GLM #12 (7/3/93); Fell to Rathole 5/26/1987 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,801.7 1,801.7 1.33 1 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,105.4 3,062.4 22.60 2 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,901.5 3,763.0 35.30 3 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 4,430.7 4,182.1 38.13 4 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 4,830.6 4,496.5 38.24 5 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3B-10, 8/22/2023 5:06:45 PM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 PACKER; 6,875.3 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 PACKER; 6,576.0 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 PACKER - PATCH - LWR; 3,354.6 PACKER - PATCH - UPR; 3,324.5 LEAK; 3,339.0 SURFACE; 30.7-3,309.4 PACKER - PATCH - LWR; 3,247.6 PACKER - PATCH - UPR; 3,227.6 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 KUP INJ KB-Grd (ft) 35.51 RR Date 6/18/1985 Other Elev 3B-10 ... TD Act Btm (ftKB) 7,250.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136800 Wellbore Status INJ Max Angle & MD Incl (°) 39.53 MD (ftKB) 5,200.00 WELLNAME WELLBORE3B-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: Flapper Locked Out Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 5,278.2 4,844.0 39.48 6 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 5,696.7 5,173.2 37.59 7 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 6,104.7 5,493.8 38.08 8 GAS LIFT DMY BK 1 0.0 7/3/1993 0.000 6,525.6 5,830.0 35.88 9 GAS LIFT DMY RK 1 1/2 0.0 2/17/2003 0.000 6,611.3 5,899.7 35.12 1 0 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,677.2 5,953.8 34.76 1 1 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,857.4 6,102.3 34.15 1 2 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,726.0 6,771.0 5,993.9 6,031.0 UNIT D, C-3, C- 4, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,795.0 6,805.0 6,050.8 6,059.0 C-1, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,841.0 6,848.0 6,088.7 6,094.5 UNIT B, 3B-10 7/9/1985 4.0 IPERF 5" Csg Gun; 120 deg. ph 6,954.0 6,996.0 6,182.4 6,217.3 A-3, A-4, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,002.0 7,022.0 6,222.3 6,238.9 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,040.0 7,045.0 6,253.8 6,258.0 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 3B-10, 8/22/2023 5:06:48 PM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 PACKER; 6,875.3 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 PACKER; 6,576.0 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 PACKER - PATCH - LWR; 3,354.6 PACKER - PATCH - UPR; 3,324.5 LEAK; 3,339.0 SURFACE; 30.7-3,309.4 PACKER - PATCH - LWR; 3,247.6 PACKER - PATCH - UPR; 3,227.6 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 KUP INJ 3B-10 ... WELLNAME WELLBORE3B-10 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Tubing patch 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A KRU 3B-10 Will planned perforations require a spacing exception?Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: KRU Kuparuk Oil Pool Kuparuk Oil Pool 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7250 6428 6600 Casing Collapse Structural Conductor Surface Intermediate Production Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name:Jan Byrne Contact Email: Contact Phone: 808-345-6886 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Jan.Byrne@conocophillips.com Well Integrity Specialist Tubing Grade:Tubing MD (ft): 6576/ 5871 & 6875/ 6117 1802 / 1802 Perforation Depth TVD (ft):Tubing Size: J-55 6899 5/15/2023 Otis RRH packer & Otis WD packer Camco TRDP-1A-SSA SSV STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025633 185-114 P.O. Box 100360, Anchorage, Alaska 99510 50-029-21368-00 ConocoPhillips Alaska, Inc Length Size Proposed Pools: TVD Burst PRESENT WELL CONDITION SUMMARY 5891 6600 MD 95 3249 6413 95 3309 7232 16 9.625 95 3223 Perforation Depth MD (ft): 77146 6726 - 7045 5994 - 6258 3.5 m n P 1 6 5 6 t Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-251 By Kayla Junke at 4:20 pm, Apr 24, 2023 Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.04.24 14:55:21-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne VTL 5/4/2023 X 10-404 DSR-4/26/23MDG 4/28/2023 X JLC 5/4/2023 5/4/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.05.04 13:27:38 -08'00' RBDMS JSB 050823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 24, 2023 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well KRU 3B-10 (PTD 185-114) to install a retrievable tubing patch over a known tubing leak and install a retrievable tubing patch proactively over a high percentage penetration in the tubing. Please contact me at 265-6471 if you have any questions. Sincerely, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Digitally signed by Jan Byrne DN: CN=Jan Byrne, E=jan.byrne@ conocophillips.com Reason: I have reviewed this document Location: Anchorage tower Date: 2023.04.24 14:54:32-08'00' Foxit PDF Editor Version: 12.0.1 Jan Byrne Well Work JusƟĮcaƟon & ObjecƟves (and date required if appropriate): 3B-10 has been idenƟĮed with a tubing leak at 3340' and the caliper reported a 74% penetraƟon at 3240'. This WWR is to patch over the leak at 3340' and proacƟvely patch over the 74% penetraƟon at 3240'. Risks/Job Concerns (Include DriŌ informa Ɵon on high deviaƟon wells, or wells with tag issues): • Need approved 10-403 sundry prior to seƫng patches. • Waivered for TxIA on gas, water injecƟon only. • Previous surface casing leak at 2'8" sleeved over. • Passed MITT and CMIT, but failed MITIA so leak appears one way only • LeakPoint report stated a tubing leak at 3340' with potenƟal leaks at 3335' and 3345'. Steps(Author: please include SSSV notes and note any future work required to capture rate beneĮt listed above (include esƟmated days/units in cost)): Relay or Slickline/Eline 1. Pull RBP from 6600'. 2. Brush and Ňush tubing focusing on patch set area ~3300'-3400'. 3. DriŌ with dummy patch 2.72" OD x 34' OAL (to be run in two secƟons ~4' & ~30') down to 3400'. 4. RIH with lower P2P and set mid element at 3357'. Correlate to LeakPoint LDL run 3/8/23. 5. SƟng into P2P with test tool and perform MITT to 3000 psi. Record TIOs. (if pressure communicates to IA perform CMIT TxIA, but all previous tests indicate leak is from IA to tubing only). Pull test tool. 6. RIH with upper patch assembly and sƟng into lower P2P. The patch should be 30' element to element seƫng the upper P2P at 3327'. 7. Perform MITIA to 3000 psi. Record TIOs. 8. RIH with lower P2P for second patch and set mid element at 3250'. Correlate to caliper run 4/11/23. 9. SƟng into P2P with test tool and perform MITT to 3000 psi. Pull test tool. 10. RIH with upper patch assembly and sƟng into lower P2P. The patch should be 20' element to element seƫng the upper P2P at 3230'. 11. SƟng into upper P2P with test tool and perform MITT to 3000 psi. Record TIOs. Pull test tool. 12. RDMO, turn well over to OperaƟons. 13. Once well is online and stabilized perform SW MITIA. Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: SLM 6,950.0 3B-10 4/15/2016 pproven Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Annotate Tbg Leak 3B-10 3/9/2023 bworthi1 Notes: General & Safety Annotation End Date Last Mod By NOTE: View Schematic w/ Alaska Schematic9.0 11/11/2010 ninam NOTE: Mandrel @ 6534 - Water Injection Package 11/11/2010 ninam NOTE: Surf CSG Patch, straddle thread collar leak; 2'8" Patch OAL, top @ 3'9" below mandrel hanger 4/5/2008 lmosbor NOTE: WAIVER CANCELLED FOR T x IA COMMUNICATION -- REPAIRED 7/5/2003 triplwj Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 30.6 95.0 95.0 62.50 H-40 WELDED SURFACE 9 5/8 8.92 30.6 3,309.4 3,249.4 36.00 J-55 BTC PRODUCTION 7 6.28 23.6 7,232.2 6,413.4 26.00 J-55 BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 23.7 Set Depth … 6,898.5 Set Depth … 6,136.3 String Ma… 3 1/2 Tubing Description TUBING Wt (lb/ft) 9.30 Grade J-55 Top Connection EUE 8RD ID (in) 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 23.7 23.7 0.07 HANGER 8.000 FMC TUBING HANGER 3.500 1,759.4 1,759.3 1.20 SAFETY VLV 5.937 CAMCO TRDP-1A-SSA SAFETY VALVE (Locked Out Flapper on 9/5/97) 2.810 1,801.7 1,801.7 1.33 GAS LIFT 5.390 CAMCO KBUG 2.920 3,105.4 3,062.4 22.60 GAS LIFT 5.390 CAMCO KBUG 2.920 3,901.5 3,763.0 35.30 GAS LIFT 5.390 CAMCO KBUG 2.920 4,430.7 4,182.1 38.13 GAS LIFT 5.390 CAMCO KBUG 2.920 4,830.6 4,496.5 38.24 GAS LIFT 5.390 CAMCO KBUG 2.920 5,278.2 4,844.0 39.48 GAS LIFT 5.390 CAMCO KBUG 2.920 5,696.7 5,173.2 37.59 GAS LIFT 5.390 CAMCO KBUG 2.920 6,104.7 5,493.8 38.08 GAS LIFT 5.390 CAMCO KBUG 2.920 6,525.6 5,830.0 35.88 GAS LIFT 5.750 CAMCO MMG-2 2.920 6,562.9 5,860.3 35.53 SBR 5.625 OTIS SBR 2.937 6,576.0 5,870.9 35.41 PACKER 5.937 OTIS RRH PACKER 2.970 6,748.0 6,012.1 34.55 BLAST RINGS 4.500 BLAST RING 2.867 6,824.2 6,074.9 34.34 BLAST JT 4.500 STEEL BLAST JOINT 2.867 6,873.6 6,115.7 34.07 LOCATOR 5.625 OTIS LOCATOR SUB 2.937 6,875.3 6,117.1 34.06 PACKER 5.875 OTIS WD PACKER 4.000 6,890.3 6,129.6 33.97 NIPPLE 4.540 CAMCO D NIPPLE NO GO 2.750 6,897.9 6,135.8 33.93 SOS 4.500 OTIS SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 3,338.0 3,275.3 25.14 LEAK TBG LEAK IDENTIFIED BY EL ACOUSTIC LDL AT 3338' RKB 3/8/2023 2.992 6,600.0 5,890.5 35.18 Bridge Plug Set 3.5" TTS RBP (2.72 max OD X 6.86' OAL) 4/26/2020 0.000 7,030.0 6,245.5 33.87 FISH EQUALIZING PRONG HEAD LOST IN HOLE 5/10/2008 5/10/2008 0.000 7,031.0 6,246.4 33.87 FISH 1 1/2" DMY In rathole 7/3/1993 0.000 7,032.0 6,247.2 33.87 FISH 3 3/4" Metal Fingers (16); From Otis W-1 Test Plug No Problem w/ Fingers in GLM #12 (7/3/93); Fell to Rathole 5/26/1987 0.000 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 1,801.7 1,801.7 1.33 1 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,105.4 3,062.4 22.60 2 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 3,901.5 3,763.0 35.30 3 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 4,430.7 4,182.1 38.13 4 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 4,830.6 4,496.5 38.24 5 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 5,278.2 4,844.0 39.48 6 GAS LIFT DMY BK 1 0.0 7/10/1985 0.000 5,696.7 5,173.2 37.59 7 GAS LIFT DMY BK 1 0.0 11/28/1987 0.000 6,104.7 5,493.8 38.08 8 GAS LIFT DMY BK 1 0.0 7/3/1993 0.000 6,525.6 5,830.0 35.88 9 GAS LIFT DMY RK 1 1/2 0.0 2/17/2003 0.000 6,611.3 5,899.7 35.12 1 0 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,677.2 5,953.8 34.76 1 1 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 6,857.4 6,102.3 34.15 1 2 INJ CV RK 1 1/2 0.0 12/11/2013 0.000 3B-10, 3/9/2023 3:45:56 PM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 FLOAT SHOE; 7,230.5-7,232.2 FLOAT COLLAR; 7,147.7- 7,149.1 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 SOS; 6,897.9 NIPPLE; 6,890.3 PACKER; 6,875.3 LOCATOR; 6,873.6 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 Bridge Plug; 6,600.0 PACKER; 6,576.0 SBR; 6,562.9 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 LEAK; 3,338.0 SURFACE; 30.7-3,309.4 FLOAT SHOE; 3,307.7-3,309.4 FLOAT COLLAR; 3,219.3- 3,221.0 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 HANGER; 30.7-35.8 HANGER; 23.7 KUP INJ KB-Grd (ft) 35.51 RR Date 6/18/1985 Other Elev… 3B-10 ... TD Act Btm (ftKB) 7,250.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292136800 Wellbore Status INJ Max Angle & MD Incl (°) 39.53 MD (ftKB) 5,200.00 WELLNAME WELLBORE3B-10 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: Flapper Locked Out Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,726.0 6,771.0 5,993.9 6,031.0 UNIT D, C-3, C- 4, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,795.0 6,805.0 6,050.8 6,059.0 C-1, 3B-10 7/9/1985 12.0 IPERF 5" Csg Gun; 120 deg. ph 6,841.0 6,848.0 6,088.7 6,094.5 UNIT B, 3B-10 7/9/1985 4.0 IPERF 5" Csg Gun; 120 deg. ph 6,954.0 6,996.0 6,182.4 6,217.3 A-3, A-4, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,002.0 7,022.0 6,222.3 6,238.9 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 7,040.0 7,045.0 6,253.8 6,258.0 A-2, 3B-10 7/9/1985 4.0 IPERF 4" Csg Gun; 120 deg. ph 3B-10, 3/9/2023 3:45:57 PM Vertical schematic (actual) PRODUCTION; 23.6-7,232.2 FLOAT SHOE; 7,230.5-7,232.2 FLOAT COLLAR; 7,147.7- 7,149.1 IPERF; 7,040.0-7,045.0 FISH; 7,031.0 FISH; 7,030.0 IPERF; 7,002.0-7,022.0 IPERF; 6,954.0-6,996.0 SOS; 6,897.9 NIPPLE; 6,890.3 PACKER; 6,875.3 LOCATOR; 6,873.6 INJECTION; 6,857.4 IPERF; 6,841.0-6,848.0 IPERF; 6,795.0-6,805.0 IPERF; 6,726.0-6,771.0 INJECTION; 6,677.2 INJECTION; 6,611.3 Bridge Plug; 6,600.0 PACKER; 6,576.0 SBR; 6,562.9 GAS LIFT; 6,525.6 GAS LIFT; 6,104.7 GAS LIFT; 5,696.7 GAS LIFT; 5,278.2 GAS LIFT; 4,830.6 GAS LIFT; 4,430.7 GAS LIFT; 3,901.5 LEAK; 3,338.0 SURFACE; 30.7-3,309.4 FLOAT SHOE; 3,307.7-3,309.4 FLOAT COLLAR; 3,219.3- 3,221.0 GAS LIFT; 3,105.4 GAS LIFT; 1,801.7 SAFETY VLV; 1,759.4 CONDUCTOR; 30.6-95.0 HANGER; 30.7-35.8 HANGER; 23.7 KUP INJ 3B-10 ... WELLNAME WELLBORE3B-10 C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\2023-04-11_22092_KRU_3B-10_CaliperSurvey_LogData_Transmittal_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 185-114 T37607 KRU 3B-10 50-029-21368-00 11-Mar-23Caliper Survey with log data Kayla Junke Digitally signed by Kayla Junke Date: 2023.04.19 08:57:28 -08'00' C:\Users\kmjunke\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\99RGP1KB\KRU_3B-10_08-Mar-23_LeakPointSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well #API # Log Description Log Date 22529 KRU 3B-10 50-029-21368-00 LeakPoint Survey 08-Mar-23 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ ______________________________________ Date received Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Wednesday, April 22, 2020 3:28 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 36-10 (PTD 18S-114, AIC) 26.067) Report of Suspect IA Pressurization Attachments: 313-10.pdf, 313-10 90 -day TIO 4.22.20.pdf Good Afternoon Chris, KRU water injector 3B-10 (PTD 185-114) is waivered for water -only injection under AIO 213.067. The well was found to have 1998 psi on the inner annulus last night 4/21/20 while in water injection service. The well has been shut in and freeze protected and the pressure was bled from the annulus. CPAI intends to perform initial diagnostics to review the well's condition. CPAI intends to leave the well shut in while the diagnostics are progressed and will submit the appropriate paperwork and/or notifications based on the results. Sincerely, Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549C&cop.com Cell: 907-331-7514 1 sara.e.carlisle@cop.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reg.DATE: Monday, July 8, 2019 P.I. Supervisor �iG 7(/ 11 (1 SUBJECT: Mechanical Integrity Tests (( {{ ConocoPhillips Alaska, Inc. 36-10 FROM: Guy Cook KUPARUK RIV UNIT 311-10 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry J,SR— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-10 API Well Number 50-029-21368-00-00 Inspector Name: Guy Cook Insp Num: mitGDC190628174502 Permit Number: 185-114-0 Inspection Date: 6/28/2019 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B -lo iTYPelnj w'TVD s7s Tubing 2873 2874 - - 2874 - 2874 - -- PTD 1831140' Type Test SPT Test psi 3000 - IA 740 3460 3340 3330 BBL Pumped: 4.1 'BBL Returned: 3.9 OA 540 690 700 700 Interval Notes: MIT -JA every 2 years to maximum anticipated injection pressure perA10 2C.067. Job completed with a Little Red Services pump truck and calibrated analog gauges. Monday, July 8, 2019 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Begg DATE: Friday,June 16,2017 P.I.Supervisor Reil 47417 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B-10 FROM: Matt Herrera KUPARUK RIV UNIT 3B-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-10 API Well Number 50-029-21368-00-00 Inspector Name: Matt Herrera Permit Number: 185-114-0 Inspection Date: 6/7/2017 Insp Num: mitMFH170609142713 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-10 " Type Inj W- TVD 5875 ' Tubing 2773 2773 " 2774 ' 2773 PTD 1851140 'Type Test SPT Test psi 3000 IA 1200 3475 - 3370 3360 - BBL Pumped: 3.6 - BBL Returned: 3.5 OA 520 • 590 590 590 • Interval REQVAR P/F P Notes: 3475 IA Test pressure per Operator.AIO 2B.067 r-- SCANNED AUG 3 0 2017, Friday,June 16,2017 Page I of 1 r 0 • C a o LC, r m Iaw Iv QX 9 Q O Q v M -. N 0 fL a) N yO W 0 W VI Y C F- C7 c,ZZ o a) rho >ro O�m V a . a, E O Q y co C O O C -5 w ~ co .,--� co > fl_ O Q 0 5 ❑ + c n N Q ❑ -i l7 co c0 c0 t0 c0 t0 c0 t0 t0 co O v E LE m Q G m 5" m p) = m 07 U O _ V1 Q 0 p '3' yB /- cc W Q Q Q Q Q Q Q cc n -0Q. a, N QV I 0 r- N M n Ccv >z > z < ❑ o EO Q 'F- Oa) a3 O ❑ o ❑ ❑ 0 ❑ ❑ ❑ ❑ N y L cr d J J J J J J J J J it > W W W W W W W W W �cp C to 0 C F- U. U.. LL. U.. LL LL LL LL U.. 3 a) E1'6 N O Q Q Q Q Q Q Q Q Q Q O_• .O �O F- ca C o Z 0) Q ZZZZZZZZZ v -0 '^ v ❑ LL LL LL LL LL LL LL LL LL a) C e a) — a1 O F • v CM E aj O p O Q ' N O_ a, 14.▪1 U N10 c 0 -0 v N a, a, cz Z '� o. LL ❑ ~ C co c G1 to) co ccorxa Q a, r ° > 4 i, 4 6. 0 o 0 0 >. a a a D Li. O CD O w J J J J W :Z a a Q Q Q LL LL BM m >- LU 2 LU '= 04 C.) Z le *1 a6 d 1 Id w O d1d(d ▪ co — J J J J J J J J J w .w ❑ 9 cc cc cc cccccccccc a`/ W W W W W W W W 4 _. own W > > > > > > > > y Z Y Y YccY Y Y Y Y E o aaaaaaa0-Y In co 0 ® Y• Y Y Y Y Y Y Y . C on T K X in O W +nom ❑ C C N •cr C C C C C u v K 0 O M O 0 0 0 0 0 r0 CV ' ` 0 0 0 0 0 0 0 0 0 V o 0 o 0 0 0 o 0 0 ra — Ems V Li. LL LL tp LL LL LL LL LL E F- F- U' N F- F- F- F- F- y re O 00000000 �/ t 1 O '^11.1 o � x Q < s.° =a o 0 0 0 0 o 0 0 0 u 0 0 0 0 0 0 0 0 0 I'.. CO N v, a o0 o v v M CO N M 00 N to M N Cr N k M M e- N CO N N O N N 0 e- N N 0 0.0 O rq N N N N N N N N N u ,-? n f T C) O M O T T C) C) O ,6 p NNNONNNNN vi 01 0 0 0 0 0 0 0 0 a, O O O O O O O O O In N N N N In N N N 3 a) 1C3.3 00 c 11 0 L ' Q' E v > u d7 W Y w , ',_ Q, I� a) 7 d �� ` �7' a �..� a t- O 1. ,_ In In 0 0 N as 1 L IL p - Z O N O O N O Y EQJ 1— " = C 0 J 6 m Q N a cc w >1 CO a �� d ,,.V.1 N M M t,.� M M M N Z a, cq 7 C cn Y .� '-I U N f9 ._ al co MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 24,2015 TO: Jim Regg �� P.I.Supervisor ` —t ZLl1 S SUBJECT: Mechanical Integrity Tests fief CONOCOPHILLIPS ALASKA INC 3B-10 FROM: Chuck Scheve KUPARIJK RIV UNIT 3B-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-10 API Well Number 50-029-21368-00-00 Inspector Name: Chuck Scheve Permit Number: 185-114-0 Inspection Date: 6/18/2015 Insp Num: mitCS150621103232 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-10 Type Inj W !TVD 5875 Tubing 2830 - 2830 2830 - 2830 • PTD 1851140 " Type Test SPT JTest psi 3000 - IA 1220 ' 3460 3400 • 3400 • Interval[RREQVAR _ IP/F P ✓ OA 450 500 - 500 500 . Notes: Tested per AIO 2B 067 SCANNED r,,*. i; Wednesday,June 24,2015 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg _ DATE: Wednesday,June 19,2013 P.1.Supervisor t I Z I 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3B-10 FROM: Jeff Turkington KUPARUK RIV UNIT 3B-10 Petroleum Inspector Src: Inspector Reviewed By: P.1.Supry L- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3B-10 API Well Number 50-029-21368-00-00 Inspector Name: Jeff Turkington Permit Number: 185-114-0 Inspection Date: 6/16/2013 Insp Num: mitJAT130616205502 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3B-10 , Type Inj W 'TVD 5875 IA 133 3400 - 1 3220 -I 3180 j PTD' Type Test SPT,Test psis 3000 OA 140 150 140 145 - Interval REQVAR P/F P Tubing i 2438 2438 2436 2439 Notes: AIO 2B.067. bbl diesel to fill. SCANNED FEB 2 0 2014 Wednesday,June 19,2013 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, June 22, 2011 Jim Regg P.I. Supervisor \'-'1�(t q0-3/, SUBJECT: Mechanical Integrity Tests L ` CONOCOPHILLIPS ALASKA INC 3B -10 FROM: Bob Noble KUPARUK RIV UNIT 3B -IO Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3B - 10 API Well Number: 50 029 - 21368 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110621154443 Permit Number: 185 - 114 - Inspection Date: 6/19/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3B -10 ''Type Inj. W TVD 5875 IA 732 1682 1658 1652 - P. T.D 1851140 • TypeTest SPT Test psi 1682 OA 420 500 500 500 Interval ' WRIST p/F P - Tubing 2811 2812 2810 2808 Notes: 2.1 bbls to pressure the IA up. f � C Wednesday, June 22, 2011 Page 1 of 1 Page lof1 • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 ©conocophillips.com] Sent: Sunday, April 03, 2011 2:50 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: CPAI Monthly Injector Report - March 2011 Attachments: CPAI Failed MITIA Monthly Data 03- 11.xIs Jim/Tom /Guy, Attached for your records is the ConocoPhillips March 2011 monthly injector report. Wells added to the report: 1B-11 - OAxOOA communication - SC leak °—� 3B -10 - TxIA communication on MI 'SS 5 — \ ` - 3G -I6 - OAxAtmosphere communication - SC leak Wells removed from the report: 2A -06 - P &A Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. APR 1 8 2 0 Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 4/17/2011 • ConocoPhillips Well 3B -10 Injection Data • Tbg Psi IA Psi OA Psi 4000 3500 • «u./"'.� .MO► 3000 «.�• ' ■1•1056• .2 2500 44. r a • • a 2000 r •• • 1500 e r MIN « 1000 4 r M • *M�• • � 500 my/ • '""" • tea .y • .MWMrr. 0 12/10 01/11 02/11 03/11 04/11 Date PTD# 185 -114 TxIA Communication on MI 03/20/11 -T &IC POTs passed 03/21/11 - IA DD test passed 1110 • ConocoPhillips Well 3B -10 Injection Data \ ♦ Water Injection O Gas Injection I 4000 3500 O 00 . • O O 00 �9 : 3000 0 .FP 2500 N , , , Q n: 2000 1500 1000 500 0 0 500 1000 1500 2000 2500 3000 3500 4000 Injection Rate, bwpd or mscfpd J Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) - Mar -11 2677 0 2804 375 775 30- Mar -11 2728 0 2785 375 775 29- Mar -11 2857 0 2767 375 775 28- Mar -11 2775 0 2736 375 700 27- Mar -11 3176 0 2680 375 700 26- Mar -11 1577 0 2396 375 700 25- Mar -11 1680 0 2401 375 700 24- Mar -11 1714 0 2378 375 700 23- Mar -11 1751 0 2343 375 700 22- Mar -11 1840 0 1370 375 550 21- Mar -11 0 0 1370 1700 300 20- Mar -11 0 0 2262 1700 300 19- Mar -11 0 3408 3624 2991 700 18- Mar -11 0 3459 3689 1850 600 17- Mar -11 0 3065 3636 2825 500 16- Mar -11 0 3101 3635 2900 600 15- Mar -11 0 3381 3635 2900 575 14- Mar -11 0 2954 3582 2900 500 13- Mar -11 0 1829 3488 2800 450 12- Mar -11 0 1077 3442 2800 400 11- Mar -11 0 1888 3550 2875 475 10- Mar -11 0 2859 3657 2950 600 9- Mar -11 0 3159 3675 2950 600 8- Mar -11 0 3320 3679 2950 650 7- Mar -11 0 3258 3674 2980 650 6- Mar -11 0 3121 3634 2900 550 5- Mar -11 0 2567 3581 2900 700 Page 1 of / • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Tuesday, March 22, 2011 10:16 AM To: Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: RE: 3B -10 (PTD 185 -114) Report of suspect TxIA comm Tom, It is possible the MI was drying out the seals. Another possibility is that over the life of the well, the natural movement of tubulars and internal parts of the wellhead, the seals had enough wear on them that it would begin to show minor communication, especially when on gas injection. It is not uncommon to torque the Iockdown screws and then achieve a passing packoff test sometimes repairing the communication on gas. Thank you. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 �. It `U'l l From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, March 22, 2011 9:52 AM To: NSK Problem Well Supv; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: RE: 3B -10 (PTD 185 -114) Report of suspect TxIA comm Brent, Thanks for the quick turnaround. It is acceptable to return the well to MI service and monitor as you plan. Is it possible that the MI is "drying out" the packoff seals? Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, March 22, 2011 9:38 AM To: Maunder, Thomas E (DOA); Regg, lames B (DOA); Schwartz, Guy L (DOA) Cc: CPF3 Prod Engrs; NSK Problem Well Supv; CPF3 DS Lead Techs Subject: RE: 3B -10 (PTD 185 -114) Report of suspect TxIA comm Tom, Jim, Guy Initial diagnostics were completed on 3B -10. The MITIA passed but the initial tubing packoff test failed. The tubing Iockdown screws were torqued to specification, further energizing the packoff and a passing test was achieved. The failing packoffs could have potentially been the communication path while on MI injection. ConocoPhillips requests permission to return the well back to MI injection and monitor the wellhead pressures. If any further evidence of communication is observed, the well will be put back on water injection and further diagnostics will be done at that time. The well will remain on the monthly report for a one month monitor period, it will be removed from the May report if no communication is evident. 3/22/2011 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reog@alaska.gov; doa. aogcc.prudhoe.bavaalaska.aov; phoebe.brookst8alaska.gov; tom.maunder(ctalaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD / UNIT / PAD: Kuparuk / KRU / 3B DATE: 03/20/11 OPERATOR REP: Ives/ Mouser - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3B -10 Type Inj. N TVD 5,876' Tubing 2,350 2,300 2,300 2,300 Interval O P.T.D. 1851140 Type test P Test psi 1500 Casing 1,310 3,000 2,900 2,880 P/F P Notes: Diagnostic MITIA OA 260 300 300 300 Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj_ TVD Tubing Interval P.T. D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I= Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 (Revised 06/2010) MIT KRU 36-10 Diagnostic 03- 20- 11.xis Page 1 of 1 • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, March 21, 2011 9:02 AM To: 'NSK Problem Well Supv'; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: CPF3 Prod Engrs Subject: RE: 3B -10 (PTD 185 -114) Report of suspect TxlA Comm Thanks Brent. Keep us advised on the diagnostics. Tom Maunder, PE Ada AOGCC From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Sunday, March 20, 2011 8:02 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; CPF3 Prod Engrs Subject: 3B -10 (PTD 185 -114) Report of suspect TxIA comm Tom, Jim, Guy Kuparuk WAG injector 3B -10 (PTD 185 -114) was reported to have suspect TxIA communication on MI injection. The TIO was 3693/2995/700. The well is being WAG'd to water for a minimum of 7 days. Initial diagnostics will include testing the tubing packoffs and an MITIA. Pending the results, additional diagnostics may be done using slickline and E -line. The well has been added to the monthly report. It is ConocoPhillips intention to submit a 10- 403 for repair or an AA for continued injection, whichever may be appropriate. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 3/21/2011 TRN_ANNL TRritiL_INI T ANNULUS PRESSURE TRENDS 500. 3000 WELL NAME WLKRU3B-10 . 3000 200. IL/ 3000. A ihi A A AAA AA. 1 I i A Adk T 3000. AAA AA m' 2700 # AAA A AA - ` 11 t I 3000. . , itiOn 2400 / / ilA i S o. 2100 AA * r \ 1 A-i ik 1800 AA A _ \"\\ r \ ,----/ A I A A 1500 A t-A-ALAAtikAAAA6WIL 1200 'i-A-AA-ak-A A A A A A • 900 U. ::T T r' j ili n11 1M:1114 %. 0. O. O. 300 ,,,,, 0. • 0 . PLOT START TIME MINOR TIME I PLOT END TIME 20-DEC-10 19:30 MAJOR TIME WEEK I:1 millimill PICK TIME 20 18:57:47 7D11! 4W BW 6M RT SC TAG NAME DESCRIPTION P LATEST Pril WL3B-10-CHOKE FLOW TUBING CHOKE 7777777 IlrPREV WELL DRILLSITE WELL Illf SCRATCH 44 FLOW TUBING PRESSURE 77777,7 3b 10 Wir SCRATCH_44 FLOW TUBING TEMP 7777777 il NEXT WELL Rg, 777777? IMF 7777777 ENTRY TYPE OPERATOR RN 777777? PM OPERATOR VERIFIED illir SCRATCH 44 INNER ANNULUS PRES 7'2? PM' SYSTEM AUTO ENTRY IMF SCRATCHI44 OUTER ANNULUS PRES 7777277 PI BOTH • • ~E~E~VEC APR p 5 2010 ConocoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 31, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: ®tl~GasCons.Ganr '~5~!{~' ~ ~-1 O s F ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and 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 March 2 and 21, 2010. The corrosion inhibitor/sealant was pumped March 27, 28 and 29, 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, MJ L veland 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 3/31/10 3A. 3B_ 3C. 3G_ 3H_ 31.3J_ 3M_ 3O 8< 3R P4D's 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 3A-02 50029214310000 1852050 Surface Na 26" n/a 4.25 3/292010 3A-04 50029214330000 1852070 SF Na 26" n/a 4.25 3292010 3A-07 50029214440000 1852230 SF n/a 25" n/a 4.25 3292010 3A-16 50029214920000 1852840 SF n/a 23" n/a 3.4 3292010 38-10 50029213660000 1851140 6'6" Na 6'6" Na 25.5 3282010 3C-11 50029213570000 1851020 SF n/a 25" n/a 4.25 3/272010 3G-08 50103201280000. 1900650 SF 0.65 27" 32/10 5.52 328201A 3G-09 50103201290000 1900670 SF 0.60 22" 32/10 4.67 328201-0 3G-22 50103201470000 1901420 SF n/a 22" n/a 4.25 328/2010 3H-01 50103200840000 1871100 SF Na 21" Na 4.25 3/282010 3H-03 50103200850000 1871110 17" 0.40 8" 321/10 1.7 3282010 3H-14B 50103200920200 2050210 SF n/a 23" n/a 3.4 3292010 31-02 50029215150000 1853080 SF Na 22" n/a 2.97 3/292010 31-10 50029219340000 1890370 39' 3.50 24" 3/21/10 3.4 3292010 3J-04 50029214000000 1851650 SF n/a 23" n/a 3.4 3/28/2010 3J-14 50029214960000 1852880 SF n/a 25" n/a 4.67 3/282010 3J-15 50029214970000 1852890 SF Na 22" n/a 3.4 3282010 3M-05 50029217060000 1870250 SF n/a 21" n/a 3.4 3/29/2010 3M-07 50029217080000 1870270 SF nia 22" n/a 4.25 329/2010 30-09 50029218250000 1880610 SF n/a 23" n/a 4.25 327/2010 30-16A 50029217960100 1880430 SF n/a 22" n/a 3.52 327/2010 3R-10A 50029222530100 1920310 SF n/a 21" n/a 4.25 3272010 3R-11 D 50029222480000 1920160 SF n/a 17" n/a 3.25 327/2010 3R-15 50029222580000 1920340 SF n/a 24" n/a 3.82 3/27/2010 3R-19 50029222690000 1920460 1" Na 21" n/a 5.1 3272010 3R-25 50029226220000 1951810 SF n/a 21" n/a 5.52 3272010 • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 12, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100~3~.t~~~9~~~~ ~~~~~ Yf. ~ 2.00 Anchorage, AK 99501 Dear Mr. Maunder: ~~ ~~~ \~ ~ ~d 3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and 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 starting March 13, 2008 and the corrosion inhibitor/sealant was pumped starting November 10, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, `~~~~~/, M.J. oveland 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 11/12/08 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3B-10 185-114 >25' 6.00 6'6" 10/30/2008 7.65 11/12/2008 3K-32 197-076 11' 1.80 12" 10/3/2008 2.00 11/12/2008 3R-11D 192-016 6" 1.00 11/10/2008 3R-12RD 192-014 16' 1.90 18" 10/6/2008 4.25 11/10/2008 3R-14 192-045 20" 4.50 11/10/2008 3R-17 192-005 20" 4.25 11/12/2008 3R-18 192-017 14' 2.10 20" 10/6/2008 4.25 11/12!2008 3R-20 192-022 9'4" 1.50 16" 9/11/2008 2.80 11/12/2008 3R-21 192-043 SF 1.70 11/12/2008 3R-22 192-039 14" 1.70 11 /12/2008 3R-26 195-187 13' 1" 2.25 11" 3/13/2008 2.25 11/10/2008 ~~~ ,.- .., / /~ .~ l °°~-.-___.._..__.__.._._. _ ._.. /~ V A%, ~~r~~~~~~i~~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~ JUL ~ 2Q08 Log Description NO. 4775 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE j~ 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE ~(7U 'g 06/26/08 1 1 1 G-05 12080389 LDL 06/27!08 1 1 3B-10 12061714 INJECTION PROFILE ~ G / 06/27/08 1 1 2L-327 12061715 SBHP SURVEY 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY ~ 'rg a- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY G 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY ` 06/29/08 1 1 2X-14 12080391 SBHP SURVEY 06/29/08 1 1 2X-11 12080393 SBHP SURVEY ~j- ~ 06/29/08 1 1 1G-09 12080401 INJECTION PROFILE U -~ 1 ~~ 07/05/08 1 1 2H-05 12080396 SBHP SURVEY ~° --- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY f 06/30/08 1 1 1 D-07 12080398 SBHP SURVEY - . ( - 07/02/08 1 1 2N-341 12061720 SBHP SURVEY .. O 06/30/08 1 1 3C-15 11982441 USIT / (a 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE ~ - 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE ~ p -(~ 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - 5 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • To: Jim Regg ~ 6 ~ t~c~• l l 7~~7~p P.I. Supervisor >rROlvt: Chuck Scheve Petroleum Inspector State of Alaska L~ Alaska Oil and Gas Conservation Commission DATE: Monday, June 09, 2008 SUBJECT: Mechanical Inteb~ityTests CONOCOPHILLIPS ALASKA INC 3B-]0 KUPARUK RIV UNIT 3B-10 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv •J~~- Comm Well Name: KUPARUK RN UNIT 3B-10 API Well Number: 50-029-2 1 3 68-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS080605132240 Permit Number: 18s-I I4-0 Inspection Date: 6/s/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! sB-lo iType Inj.+w ~ T~ !; ss~6 IA Io~o~ zszo / zaso zaso r 18s1140 SPT --~ i ~ T P.T. ITypeTest i I Test ps>< L ~ ~ _-f 1500 ~ 890 ~ OA 7zs -- - --- ~ 890 -T I 890 - -- ----- ' '-----------'---------- Interval oTr>ER p~F P /~ Tubing '~~ 1 1 so ~ I 1 so ~ 11 so 11 so ~~ i NOteS• Test performed post surface casing repair/ • e~r('~ -! ~~~ JUL .~ ~ 2008 Monday, .tune 09, 2008 Paee t of I 111\V JL-1V `1 1LII aV/ a1'TJ l~v~ulla iv aa~vv~avaa +.M1b~ + ~+~ Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: To: Cc: Wednesday, May 07, 2008 8:31 AM Regg, James B (DOA) '~ ~~h~~~~~0a NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs; Maunder, Thomas E (DOA); NSK Well Integrity Field Supv Subject: RE: KRU 3B-10 (PTD# 185-114) Return To Injection Jim, To clarify your points: 1) The Well Integrity Field Supervisor (Roger Winter) called and left a message on the ROGCC inspector's phone and did not receive a reply. This occurred on 3/22108, the day that welders removed the conductor. 2) CPAI does not plan to pursue an AA to continue injecting. There is no precedent for requiring AOGCC approval when the failed MITOA is believed to be due to a leakier. Based upon the passing MITIA and the fact that no fluids surfaced during the MITOA, we concluded that there is no communication between annuli. ~onri~ Please reply or contact me if you need additional clarification or have question and camments. ~~ Martin From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, May 02, 2008 4:52 PM ~ NEB MAY ~ ~ 2Qp~ To: NSK Problem Well Supv; Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: RE: KRU 3B-10 (PTD# 185-114) Return To Injection Martin - I've reviewed MITs you sent and info in your email; also the 10-404 received 4115/08. It is. acceptable toput the well on infection, Contact inspector to witness MITs after commence injection and conditions in well stabilize. Couple points of clarification would be appreciated - 1) No indication given if AOGCC Inspector was contacted to examine the damage, repair ops; 2) Work summary attached to 10-404 indicates several unsuccessful attempts to obtain a passing MITOA; explanation given is well was pumping through OA shoe (no leak detected at SC patch); you provided passing MITIA and MITT; will CPAI pursue an Admin Approval to allow the well to continue injecting with OA communication? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, May 02, 2008 2:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Fleckenstein, Robert) (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: KRU 36-10 (PTD# 185-114) Return To Injection 5/20/2008 au~v .+a.+ av ~a. a~~~ ...... a ~ .~ ~~~--.~__ _~ __ J_______ a.+ \,~ `~ . «MIT KRU 36-10 05-01-08.x1s» Jim/Tom, Kuparuk WAG Injector 36-10 (PTD# 185-141) has been shut in since March 18, 2005 due to a failed MITIA and a surface casing leak. The surface casing leak excavation and repair was completed on 4/10/08 and the well subsequently passed an MITT and MITIA. Results of the test are attached in the standard MIT report form. CPAI requests permission to return the 3B-10 to injection service and Normal status. We will schedule aState- witnessed MITIA once the well conditions are stabilized. If the future well performance indicates lack of integrity, appropriate action will be taken. Please contact me at your convenience if you have questions or comments. Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 5/20/2008 Page 1 of 1 • • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Sunday, May 04, 2008 4:11 PM To: Maunder, Thomas E (DOA) Subject: RE: 3B-10 (185-114) Surface Casing Leak Repair -AGAIN Attachments: SC band area (copy right).jpg; SC patch copy right).jpg Tom ~_~ ~~~-c~S ~1 r\S~~~' . ~~~~- y~ ~~ o ~ ~' 1 Attached are the photos for the 10-404. Yes the leak is at the top where the threads are visible. Also as an amendment to the 10-404. The State inspector was notified on 3/22/08 to witness the damaged threads. Witness was waived, my folks didn't record who waived it so I'm currently in the process of locating that information. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Ce11 (907) 943-1687 ~t~~~~~E®M~~ ~ 2D0~ From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 04, 2008 3:02 PM To: N5K Well Integrity Proj Subject: RE: 36-10 (185-114) Surface Casing Leak Repair -AGAIN Email is fine. From: Maunder, Thomas E (DOA) Sent: Sunday, May 04, 2008 2:50 PM To: NSK Well Integrity Proj Subject: 3B-10 (185-114) Surface Casing Leak Repair MJ, I am examining the 404 submitted for this recent work. The photo copies sent are black and white copies. Is it possible to send colored photos? B&W copies don't scan too well. I presume from the detail that the thread leak was "on top". Thanks in advance, Tom Maunder, PE AOGCC 5/5/200$ KRU 3B-10 (PTD# 185-114) Return To Injection Page l of 1 Re James B DOA • • 99, ~ ) From: Regg, James B (DOA) Sent: Friday, May 02, 2008 4:52 PM n ~ ~, ~} b To: 'NSK Problem Well Supv ;Maunder, Thomas E (DOA) ~~ ~/ ~~ Cc: NSK Well Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs ~~ Subject: RE: KRU 3B-10 (PTD# 185-114) Return To Injection Martin - I've reviewed MITs you sent and info in your email; also the 10-404 received 4!15108. It_is acceptable_to put the well_on injecton,_ Contact inspector to witness MITs after commence injection and conditions in well stabilize. Couple points of clarification would be appreciated - 1) No indication given if AOGCC Inspector was contacted to examine the damage, repair ops; 2) Work summary attached to 10-404 indicates several unsuccessful attempts to obtain a passing MITOA; explanation given is well was pumping through OA shoe (no leak detected at SC patch}; you provided passing MITIA and MITT; will CPAI pursue an Admin Approval to allow the well to continue injecting with OA communication? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, May 02, 2008 2:45 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Fleckenstein, Robert J (DOA); NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: KRU 3B-10 (PTD# 185-114) Return To Injection «MIT KRU 3B-10 05-01-08.x1s» Jim/Tom, Kuparuk WAG Injector 3B-10 (PTD# 185-141) has been shut in since March 18, 2005 due to a failed MITIA and a surface casing leak. The surface casing leak excavation and repair was completed on 4/10/08 and the well subsequently passed an MITT and MITIA. Results of the test are attached in the standard MIT report form. CPAI requests permission to return the 3B-10 to injection service and Normal status. We will schedule aState-witnessed MITIA once the well conditions are stabilized. If the future well performance indicates lack of integrity, appropriate action will be taken. Please contact me at your convenience if you have questions or comments. Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 5/2/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillipsAlaska Inc. ~~~ ~~z~~ Kuparuk / KRU / 3B-10 05/01 /08 Campbell - HES Packer De th Pretest Initial 15 Min. 30 Min. Well 3B-10 Ty e Inj. W TVD 5,876' Tubing 2,400 3,050 2,940 2,940 Interval O P.T.D. 1851140 T e test P Test si 1500 Casing 50 50 50 50 P/F P Notes: Diagnostic MITT OA 250 250 250 250 Well 38-10 T e In~. W TVD 5,876' Tubing 1,000 1,040 1,040 1,025 Interval O P.T.D. 1851140 T etest P Test si 1500 Casin 50 =X2,510 2,490 2,480 P/F P - Notes: Diagnostic MITIA OA 250 710 710 700 Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casin P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In~. TVD Tubin Interval P.T.D. T e test Test si Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N = Not Ihjecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes). MIT Report Form BFL 11/27/07 MIT KRU 38-10 OS-01-08.x1s t • ~ . ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 10, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite.100 Anchorage, AK 99501 L`~+~~~~ APR 1 5 2048 Alaska a~ & Gas Cons. Comm-~10n ~~rage Dear Mr. Maunder: Enclosed please find 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc.. we113B-10 (PTD 185-114, Sundry 305-394).. The report records the successful surface casing patch job. Please call M.J. Loveland or Perry Klein at 659-7043 if you have any questions. Sincerely, .•-°°~~ M.J. veland ConocoPhillips Well Integrity Project Supervisor Enclosure • • 3B-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 3/14/2008 Start excavation of well for Surface Casing repair. 3/20/2008 Using Wachs saw cut and removed 2 - 16" x 39" windows on conductor casing 12" from the. bottom of the Tanko top. 3/22/2008 4/5/2008 4/6/2008 4/10/2008 Remove 10' of conductor. Clean surface casing with grinder wire wheel for Kakivik. Super Suck 1' 7" of the diesel from the conductor and placed fire extinguisher powder on top of the 'ice & diesel then 5" of water and more fire extinguisher powder over the water for a barrier from the slag of welding. SC patch weld-complete.Purge nitrogen down annulus while welding.Patch welded as per M,E.specs.Weld a 6" and 3" .365" wall."double" wedding band - 8" above and below SC collar.Tie in a 1'-10 .365 "wall SC patch to straddle thread leak in collar.Total patch length 2'8". Top of patch located 3' 9" below mandrel hanger. 3f3-10 Normal up wellhead jewelry.lntial T/I/0=0/0/0. 112.5 AM Pressured up SC to1800. T/I/O=0/0/1800.1130AM T/I/0=0/0/1680.Represuured up to 1800.1145 AM T/I/O/=0/0/1610,repressured to 1800, START T/I/O/=0/0/1800.1200PM T/I/0=0/0/1610. 215PM T/I/0=0/0/1520.1230 T/I/O=0/0/1300.1245PM T/I/0=0/0/1100.Final T/I/0=0/0/0 MITOA test failed,however,no leaks @SC PATCH.Suspect pumping through outer annulus shoe. New conductor installed. Assist welders installing 9' 5.5 " of new 16" 62.5# API 5L Gr B Conductor casin . Summary External surface casin patch, 2'8" lon .and 3'9" below mandrel han er across thread leak. [~ ~ F~ECEiVEL~ STATE OF ALASKA APR 1 5 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIO~ka Oil & Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ~ Plug Perforations ^ Stimulate ^ Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 185-114 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21368-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 86' 36-10 ` 8. Property Designation: 10. Field/Pool(s): ADL 25633 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7250' ~ feet true vertical 6428' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length' Size MD TVD Burst Collapse Structural CONDUCTOR 95' 16" 95' 95' SUR. CASING 3223' 9-5/8" 3309' 3249' PROD. CASING 7146' 7" 7232' 6413' Perforation depth: Measured depth: 6726-71,6795-6805,6841-48, 6954-96,7002'22,7040-45 true vertical depth: 5994-6031, 6051-59,6089-95,6182-6217,6222-39,6254-58 Tubing (size, grade, and measured depth) 3-1/2" , J-55, 6899' MD. Packers &SSSV (type & measured depth) pkr= OTIS 'RRH' ; OTIS 'WD' pkr= 6582' ; 6884' SSSV= SSSV SSSV= 1770' 12. Stimulation or cement squeeze summary: ti ~F~, I~Att ~ 5 X008 Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA NA NA NA Subsequent to operation _ NA NA NA NA 14.'Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ' Daily Report of Well Operations _•X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q ~ WDSPL^ 17: I hereby certify that the foregoing is true and correct to the best of my kpowledge. Sundry Number or N/A if C.O. F~cempt: 305-394 contact Loveland/Klein .Printed Name MJ Love)a Title WI Project Supervisor Signature ,--- r ~h~ne 659-7043 Date 4!10/2008 _. ,,~ __ - ~ ~ ter'%(~Y~'~ `~ /G•aS Form 10 04 Revised 04/2004 ^ R I G I ~ A L ~ (~ Submit Original Only • • `§ J J~ ~~ ~~ ~ a ~~ F~~ - ~~ ~ ~ ~~ ~ 3 ~. e F ' A'V y~; ~~~ ~~'~~~~'d a A`~ ` ~ $~L `1 t ~.M 1~l: a}$ii S`Ff a..t et `d'• t .. y' i7% 3 , § a~~ -` ~~ t;vg ~~ 4~~~.x 3 a' <~I. ~~r°~l§g e . ~ #~z. i~ }a. ~ ~`~~~dt~i ~'.. 3 ~ 9 ~T4~ ~~~ t ~ ~ #' fa y # ~ ~ ~ ~ # ~{~} ~ ~' t;- ~ i ~ r,:}}, d.~r # ~ ., ~ ., ~_ ~ ~ '~: .~ ~~ ' D s s, c ', ~~~~ wy i 7 C t~ 7'TSir„ -: • • s.~,.~z,.r ~ ~, ~~- , .~~ :~- ~~ ~.~ ~. ~ _ ~~ 7 a m p ~ . '% M r P ~ ~ ~ v~ .. .~. s° , /,'t .~~ijthi~. ~f~~~ ~ ~ ~~.. '~ ;-, ~u~)wt'it;t b} Q~~»wcuRl+iliiErs ~aa~,~.a, , ' ~ ~ ~, ` ~~ ~4 , ~.<:l if he red Yra• puirli.hec! wiet~~urC , vxpe -~~~~ n eo~a~cnt t~~~roaioroi'i~8fi~a~ ,~t~~kn .. ~ ~~; . k ~ ,;. r ~ .. " "'~ ~ 9". .. ~, ~ ~« R'P ~R{ vY f ~ ~, Nu ~ e i(ûJn., rp ¡, i.H'I~.p lj ,L ",I '-IJ e A.,ASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR MJ Loveland Problem Well Supervisor ConocoPhillips Alaska, Inc, P.O. Box 100360 Anchorage, AK 99510 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU 3B-10 Sundry Number: 305-394 l€;S' --I \ If Dear Ms. Loveland: SO( 4~,~~~~~~;:r .. ,.1~b·~I.I"\J" 'I¡jt~¡,...' Wð Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, â!t¡1< Cathy P. Foerster Commissioner ""- DATED this2$ day of December, 2005 Enc!. e e RECEIVED DEC 2 6 2005 Alaska Oíl & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate D Waiver D Other D Alter casing 0 Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program 0 Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory D 185-114 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21368-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 86' 3B-10 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field / Kuparuk 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): 7250' 6428' Casing Length Size MD TVD Burst Collapse CONDUCTOR 95' 16" 95' 95 SUR. CASING 3223' 9-5/8" 3309' 3249 3950 2020 PROD. CASING 7146' 7" 7232' 6413 4980 4320 - Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6726-71,6795-6805,6841-48, 6954-96,7002-'22,7040-45 5994-6031, 6051-59,6089-95,6182-6217,6222-39,6254-58 3-1/2" J-55 6899' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= OTIS 'RRH'; OTIS 'WD' pkr= 6582'; 6884' SSSV= SSSV SSSV= 1770' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch 0 Exploratory D Development D Service 0 14. Estimated Date,for 15. Well Status after proposed work: Commencing Operations: January 30, 2006 Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG 0 GlNJ D WINJ D WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: McConnell / Loveland Printed Name MJ LO~ ~ Title: Problem Well Supervisor Signature ~~.J /"" Phone 659-7224 Date 12/24/05 / Commission Use Only Sund~~~er: L~q+ Conditions of approval: Notify Commission so that a representative may witness ,-"'J ):J - Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: R8DMS 8Ft .IAN 0 3 2006 - v.J",.\.\r... \' ~\ö ~ 0 ~~o-~~ ~C:.\~~ $ rt.~ \ S"b~q" '" n' APPROVED BY Date: /1.. - z,-;¡--£ Approv ..., ~ COMMISSIONER THE COMMISSION Form ~403 Re~7/2005 0 UP L f C Submit in Duplicate ATE SSSV 1770-1771, OD:3.500) PLUG (6576-6577, OD:2.810) PKR (6582-6583, 00:6.151) Perf (6726-6771) Perf (6795-6805) Perf (6841-6848) PKR (6884-6885, OD:6.151) NIP (6892-6893. OD:3.500) TUBING (0-6899, OD:3.500, ID:2.992) Perf (6954-6996) Perf (7002-7022) Perf (7040-7045) t ~ ] ...~ ~.r,.r:.JI .-.... ~~ þ-4 L...¥lI ~ ~ ~ WellT e: Orig 6/18/1985 Com letion: LastW/O: Ref Lo Date: TD: 7250 ftKB Max Hole 40 deg @ 5200 ,_._~_~Q.l~~~_ CANCELLED FOR Tx IA COMMUNICATION .~ --Zone'-";-Slatus!---¡:¡-Spj"-:-Date--- 6'j 5 --uNiT "'T - -'-" 45: 12" --'ji9'i1985 DC-4C-3i ¡ 6795 _ 6811!j 6051 - 6059 -.- ë-Í'" .. ; 10 I 12 \ 7/9/1985 IPERF 6841 _ 6848 6089 - 6095 ÚNIT'S, . 7 : 4 . 7/9/1985 IPERF 6954 _ 6996 6182.. 6217 'A4,A-3 ï 42 . 4 ,7/911985 IPERF 7002 _ 7U22 6222 - 6239 A-2 --.;---.... -"! - 2(ïï . 4- ï'7I9ï1985 IPERF 7040 _ 7U45 6254 - 6258 A-2 -'--;'-s-:¡--'j7iii1985 IPERF SâiWftMandrøt$NølYø$> _n_ .. _n.. _n____ -. ..... . .. - .. St I MD WD Man Man type V Mfr '---\rfypËí-'~\TOD--Lãtëh'-" Port Mfr I ¡ I I 111n8 Gumco KBUã-- i .... -----..·-DMY~IBK , 31168 Caml:o KBUG DMY . 1.0 -- "BK :1/68 Camc:o KBUG I DMY , 1.0 I BI( -118"/ Camc:o KBUG ¡ I DMY ! 1.0 BK -1501 Cilmco KBUG ; DMY . 1.0 BK -1849 Cumc:o KSUG , i DMY , 1.0 I BK 51/8 Cmnco KSt.JG i DMY ! 1.0 ¡ BK 5499 Cum(;o KSUa j I DMY ~ 5837 Cameo MMG-Iï DMY 1.5 RK T'::¡:': :N.J~c";!(JN PACKAGE -I""..'..,,· .."""""".""..".."..'..} .......... . ................... ............"......................,. MandrelsNaJ(~ :': »>«',,>""'" """"""""""""""""""""""'>«:::< TVI) Man Man Type V Mfr V Type V OD LE Mfr 5906 Camc:o MMG-II CV 1.5 R !j9611 Cllml:O MMG-II CV 1.5 R 6109 Cmnco MMG-II CV 1.5 R Igs, equip., :;);;JE"/VEt..RY> ',','" f[) Typo Description '/U SSSV Cameo 'TRDP-1A-SSA' (Locked Out Flapl 11 PBB Otis X NIPPLE PROFILE 71 PLUG 3.5" XX TUBING TAIL PLUG set 3/18/2005 ,76 PKR Otis 'RRH' 24 PKR Otis 'WD' 31 NIP Cameo 'D' Ni 36 SOS Otis 37 TTL H ~ALLSTRJNGS-- "~~"~~3;:~I~~=~~:t~p.uLKq~!" --- - .TYQ~ Wt ± 1~~{i!'-:-;-'- n" ~_n . n-nt-··.~!!r --.j..... __~~1~ -._._,JH~- Bottom- .- .-- . TVD--- :-- Wt-IGrade ,- =]-ª®:~~~=~;-.- - 6-1_37"'=::' n ii,3Õ ._L. _ J:!!~ . i REPAIRED ·tÿ¡;ë· IPERF TRO DI110 i nun 0.000 i 0 "1I1U/1985 O.ooo--·ö .-- 7/10/1985 0.000~~=-O--11í28/1981 0.000 I 0 7/10/1985 0.000 -:-- 0-- 1110/1985 0.000 ¡. -(= /110/1985 0.000' 0 11/28/1 !JH"} 0.000 0 1¡3/199:~ 0.000 0 2/111211()3 5" c.~iï.þun; 5~_GsJl..9un: 4" Csg ~UII: 4" Csg ~un; 4" Csg ßun: Comment 5" Csg Gun; 120 deg. ph Grade H-40 J-55 J-55 __L Thread $:a;;to········""'" , ¡ Rev Reason: Set TTP : Last !:Jp~~te: 3/22/2005 --[":Añgï~(1f.tS: 35 de Angle @ TO: 34 deg @ 6728 7250 . C·: ....' "·PhilP· AI, k ." . ortOCO .' Jps. .a$.~t e Inc. e KRU 38-10 '"' e e ConocoPhillips Alaska, Inc. Kuparuk WeIl3B-I0 (PTD 1851140) SUNDRY NOTICE 10-403 APPROVAL REQUEST 12/24/05 This application for Sundry approval for Kuparuk well 3B-I 0 is for the repair of a surface casing leak. The well is an injector, completed in June 1985. On March 18, 2005, liquids were observed at surface around the Tanko head while completing a MITOA. The AOGCC was notified of the problem that same day. Since the well already had known minor TxIA communication it was shut in and will remain secured with a plug until repaired. Diagnostics on 4/20/05 and 5/8/05 found the leak depth approximately 2-3' below the conductor top. The liquid leak rate is 4. gpm at 1550 psi. The conductor cement top was found at 25'. CP AI proposes to repair the casing leak by excavating and removing conductor as needed to expose the damaged surface casing for inspection and repair. Excavation casing repair jobs have historically been scheduled during the summer season when the ground is thawed. If the damage is limited to an area a few feet from the surface the excavation repair may be attempted this winter season. ~- With approval, repair of the surface casing will require the following general steps: 1. GCC approval 0 to repair the surface casin 1 a mechanic a . e excavation can be scheduled. ,,",-<!.c."~~"\.u:....\.\Q.~'\s. C!!.u:~:ç)'~'Ð\t.., ~c 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze O-%'\\"R.~\, \ protection cap. ~~~(,~t"'~\~ \'.f:.~ 3. Remove the floor grate and equipment from around the wellhead. !d9- <J1v.... 4. Excavate gravel away from conductor to ~5' -10' (may be more based on damage). \;)1.') 5. Install nitrogen purge equipment for the OA and conductor so that hot work may be ~ conducted in a safe manner. 6. Remove conductor casing and cement around surface casing for inspection and repair as needed. -¡"..7. Notify AOGCC Field Inspector of repair operation so they may view damage. 4( 8. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 9. QA/QC the repair and MIT-OA for a final integrity check. 10. Install anti-corrosion coating to exposed surface casing. 11. Replace the conductor and fill the void with cement and a water proof sealant cap to seal out water and oxygen. 12. Backfill as needed with gravel around the wellhead. 13. Remove plugs and return the well to injection. 14. File 10-404 report of repair with the AOGCC. ~ NSK Problem Well Supervisor 12/24/2005 3B-I0 (PTD 185-114) failed MIT ) ") , ,. :....... .':' '. '. .... ......... .. .... ..... . ...... S~~~~~~: .'3B-l~(~;~...}8?T,114~~ail~ìl\1rI' ..:..,.. ..... .' ... ....,... "'. ..:.......' ',':'..:...:.......:. .~~?J11:....Ì'iSI(..Pr?þ.lel;1·.Yr.~.11'·,·~:t1py::.~n'~.,6..1,7.@C8l)OCpphi~Jips.~çpll1? ])3~e: F;rhJ 8Mar2~p512:26:58,.Q9QQ· Tom, Injector 38-10 (PTO 185-114) failed a MIT IA with a slow linear leak held over a 45 minute period, as described over the phone by my DHD tech. I will not have the exact test data back from the field until after 5:30 pm this evening, but wanted to report the problem before the close of business today. As you may recall this well has been on our watch list since September 2004 when it was first reported as having suspect TxlA communication with frequent bleeds. Also please note that it passed a MITIA on 10106/04 and a MITT on 10105/04. The MITIA that failed today was completed as a diagnostic check up to ensure continued integrity of the well. As part of the check up a MITOA was also completed - which unfortunately also failed the pressure test with a similar slow linear leak. Since both tests failed we are shutting in and securing the well with a TTP today until further diagnostic can be planned. I will send the test results and a T/I/O plot after I receive the pressure data from the field. Let know if you have any questions. MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 SC/\NNED APR 2 (} 2005 1 of 1 3/21/2005 8:28 AM MIT KRU 3B-1O 03-15-05.xls ) ) Subject: MIT KRU 3B-IO 03-15-05.xls From: NSK Problem Well Supv <n1617@conocophillips.com> Date: Sat, 19 Mar 2005 12: 17 :08 -0900 To: Thomas Maunder <tom _ maunder@admin.state.ak. us> CC: Bob Fleckenstein AOGCC <bob_fleckenstein@admin.state.ak.us>,James Regg <jim _regg@adnrin.state.ak.us> «MIT KRU 38-10 03-.15-05.xls» Tom, Attached is the MIT IA and MIT T data for 38-10 (PTO 185-114). Please note that the MIT - T passed with a plug set in the P8R profile. The well is currently 81 and secure with the above mentioned plug. Also attached is a 6 month T 1110 plot. We are currently brainstorming repair options and will notify the AOGCC with our repair intentions in the future. Please let me know if you require any additional information MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 KRU 3D-10 Content-Description: MIT KRU 3B-IO 03-15-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 1 of 1 3/21/2005 8:28 AM Z 4 F-777.177.7 4AN,NULUS „PRESSURE „ TR ENDS !4000.; SC WELL NAME WLKRU3B -10 _ _ 200. 4000__ 4000. 3600 3000. . 3000. 4000. 3200 ._4000. A. -A I r I 2400 4 :– - ID 2000, -A-Ar I 16C:. i I 1 126. �� lie D, 000 I U-- — s — �■ s �� ! ■ - a a • - - . I i a au s II a in as 1, 400 Q. 0 1 Q. PLOT START TIME MINOR TIME PLOT DURATION 17- SEP -04 12:15 MAJOR TIME WEEK HRS PICK TINE. 17- MAR-OS Q5:47 =39 ®® ®®® m ®0® SC TAG NAME DESCRIPTION P - VALUE LATEST OM WL3B -10 -CHOKE FLOW TUBING CHOKE 20. DRILLSITE WELL -' SCRATCH 10 FLOW TUBING PRESSURE 2189. IIINEXT WELL 3B 10 - SCRATCH_10 FLOW TUBING TEMP 250. . PREV WELL • - 7777777 - 7777777 ENTRY .PE QPERATOR - ? ? ? ? ? ?? III OPERATOR VERIFIED - SCRATCH_10 INNER ANNULUS PRES 2462. Ili SYSTEM AUTO ENTRY - SCRATCH_10 OUTER ANNULUS PRES 450. III BOTH ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Well 38-10 Type Inj P.T.D. 1851140 Type Test Notes: Diagnostic MIT IA ConocoPhillips Alaska Inc. Kuparuk 1 KRUI 38 03118/05 8rake- ASRC; Landenglos - LRS S P Packer T.V.D. T est psi Tubing Casing Depth 5876 1500 Well 38-10 Type Inj N T.V.D. 5876 P.T.D. 1851140 Type Test P Test psi 1500 Notes: Diagnostic MIT Tubing with plug set @ 6576' Tubing Casing Pretest Initial 15 Min. 30 Min. 2150 2150 2150 2150 Interval 2500 3000 2900 2840 P/F 2400 1040 3000 1040 3000 1040 o F 3000 Interval 1040 P/F o P Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj TV.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test T est psi 1500 Casing P/F Notes: Test Details: TYPE I NJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test \~S/l ) 'A ¡¡\oJ ~ ~ E'" ~".i ('~) r:, G1J. fl'~ 2 0 Or., ""....,,'~ 1'\1, -' ¡-\ ¡- rl ,(, ~J ,~ MIT KRU 38-10 03-15-05.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover o = Other (describe in notes) 3/21/2005 ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~ q 101 (-z.Í 04- Email to:Tom_Maunder@admin.state.ak.us;8ob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.~~te.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 38-10 1 0106/04 Sauvageau/Rogers Packer Depth Pretest Initial 15 Min. 30 Min. Well 38-10 Type Inj S T.V.D. 5876 Tubing 1620 1620 1620 1620 Interval 0 P.T.D. 1851140 Type Test P Test psi 1500 Casing 1350 2500 2450 2450 P/F P Notes: Diagnostic MIT; Suspected T x IA communication reported 9/24/04. Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Well Type Inj T.V.D. Tubing Interval P.T.D. Type Test Test psi 1500 Casing P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas I nj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) a..'EF r,\,~q SCAN\~- t ,. 9. ')nni, 'Þ 'l.~%~ ~~ ~ ~ç~ b...~~ r¿,Vr' MIT Report Form Revised: 05/19/02 MIT KRU 38-10 1Q-06-04-1.xls 10/12/2004 ~s CÆJ II WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE: Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL ;;: BLUE LINE REPORT WELL DATE TYPE OR S I~ PRINT(S) OR CD-ROM ILM BLUE LINE Open Hole 1 1 1 gr-\Vl l)cJI 38-10 5-21-04 Res. Eva!. CH 1 1 1 Mech. CH Caliper Survey 1 Rpt or 2 Color Print Name: '::W tiij , ~ l'.J (~,ll'll Ük{,,-Vl( Date: q .J;') ~-y Signed: PRoAcri\i" Dil\GNOSJic SER\iins, IN(.., PO Box I ~b9 SJl\flORd rx 77477 Phone:(281) 565-9085 Fax:(28l) 565-1369 E-majl: pdsl~'mcmorylog.com Website: \\'\\'W.memorylog.com ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1987 Mr. Lonnie C. Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith' Subject' KRU Water Injection Well 3B-10 Status of Annulus Pressure ARCO would like to notify the AOGCC that the small tubing to casing leak On KRU water injection well 3B-10 has sealed itself. It is ARCO's opinion that increased water injection temperature from the start-up of the CPF-3 water injection pumps has caused downhole material to expand and therefore seal off the leak. A mechanical integrity test (MIT) was witnessed by AOGCC representative Bobby Foster on January 22, 1987 (see attached copy). Prior to start-up of the CPF-3 water injection pumps (mid December 1986) the 7" casing on Well 3B-10 was routinely bled down from 2500 psig to approximately 1500 psig. Water .injection temperatures prior to mid December ranged from 55-60°F using temporary waterflood pumps. After start-up of the CPF-3 turbine-driven water injection pump, injection water temperatures increased to 70-75°F through December and January 1987. Casing pressure was bled down to 1400 psig from 2325 psig after the start-up of the CPF-3 waterflood facilities and has remained consistently in the 1400-1700 psi9 range since that time. The pressure fluctuation between .1400-1700 psig appears to vary with injection water temperature (see attached table). A mechanical integrity test was performed on January 17,;1986 which was waived by the AOGCC. However due to casing leak problems in the past, ARCO requested the AOGCC witness the MIT. The AOGCC witnessed MIT was performed on January 22, 1987. It is ARCO's opinion that the very small leak prior to mid December 1986 has sealed itself due to the increase in water temperature and resulting expansion of downhole materials. Monitoring of injection water temperature and 7" casing pressure will continue, however we feel no additional testing is required at this time. If the tubing to casing leak reappears, as indicated by a rise ..~n casing,~ pressure to 2400 psi, ARCO will notify the AOGCC as required. ' ....... ~'~ If you have any questions, please contact me at 263-4490. Sincerely, K. S. Haaland Senior Operations Engineer KSH-pg:O006 Attachments ARCO Alaska, Inc. is a Subsidiary of AllanlicRichlleldCornpany RECEIVED i.~! I Z (I I i OIL AN0 GAS CONSERVATIO~ ~SSION , P~SS ~S P~ ....... ~ ............. t ~ ~ ~;~ 0 1~ ~~ ~ ~ ~ ~,'e_,~ I ,:~s~ 7':2~~-~., ~YC' .~~' /~ c - ~ ~ ,~ ~O ~/, ..~. 1700 t~0 170o }/~oO ' . ,,, , ~'L~ .............. ~ . . ,. , ,, ......... ~ ................ . E'i rF!VF~,r-,- --, "- ,, .. - ........ · ~ ~ 0 ~ I00~ .......... ....... ~ . _ _: '~I.~H ~ ~ 0~ ~~-~-~ . , , ......................... . Ill I I - I ' I I I ~ .~ ,,i . I . *"IXIB'XNg ~tN,I P M - MXSCI]~E ~~ OIItER .. ~C;AN. NED DEC 20.4AC 25.030(a) 20 AN~ 25.412(c) 20 AAC 25.252(d). Mr.L.C. February Page 2 Smith 24, 1987 KUPARUK WELL 3B-10 ANNULUS PRESSURE AND TUBING TEMPERATURE Date 12/8 12/9 12/10 12/10 12/11 12/12 12/13 12/14 .12/15 12/16 12/17 12/18 12/19 12/20 12/21 12/22 12/23 12/24 12/25 12/26 12/27 12/28 12/29 12/30 12/31 1/1 1/2 1/3 Annulus Pressure (psig) 2275 2325 1400 1600 1450 1525 1400 1325 1325 1325 1325 1475 1400 1275 1400 1325 1250 1430 1640 1650 1480 1720 1760 1750 1630 1700 1500 1400 Tubing Temperature (degree F.) Date 63 1/4 58 115 58 * 1/6 82 1/7 76 1/8 77 1/9 72 1/10 72 1/11 71 1/12 70 1/13 70 1/14 70 1/15 68 1/16 66 1/17 70 1/18 68 1/19 70 1/20 70 1/21 76 1/22 76 1/23 70 1/24 76 , 1/25 76 1/26 76 1/27 73 1/28 74 1/29 71 1/30 69 1/31 Annulus Pressure (psig) 1350 1390 1400 1500 1525 1800 1550 1550 1525 1525 1525 1520 2200 2200 2250 2250 2375 2350 2240 975 1040 1040. 975 930 970 800 750 780 Tubin Tempera (degree 69 69 70 70 73 75 72 73 71 72 73 72 76 72 72 72 76 74 72 78 77 74 73 72 73 70 69 70 g ture F.) ** Annulus bled to 1400 psig Mechanical Integrity Test (AOGCC waived) Mechanical Integrity Test (AOGCC Witnessed) Annulus Bled Down After MIT 6CANNED DEC 1 RECEIVED '2 6 1987 Alaska Oil & Gas Cons. Co~lmlaalon Al~hOrall. ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well_ Other_X WI to WAG Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 86 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__X Kuparuk Unit 4. Location of well at surface 8. Well number 5075' FNL, 436' FEL, Sec. 16, T12N, R9E, UM (asp's 518595, 5991323) 3B-10 At top of productive interval 9. Permit number / approval number 1283' FNL, 1429' FWL, Sec. 22, T12N, R9E, UM 185-114/ At effective depth 10. APl number 50-029-21368 At total depth 11. Field / Pool 1478' FNL, 3635' FEL, Sec. 22, T12N, R9E, UM (asp's 520684, 5989647) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7250 feet Plugs (measured) true vertical 6428 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 95' 16" 227 sx PF "C" 95' 95' SUR. CASING 3223' 9-5/8" lO0O sx AS III & 300 sx Class G 3309' 3249' PROD. CASING 7146' 7" 5oo sx Class G & 25O sxAS I 7232' 6413' Perforation depth: measured 6726-6771' 6795-6805; 6841-6848; 6954-6996; 7002-7022; 7040-7045 ii :. 5994-6031; 6051-6059; 6089-6095; 6182-6217; 6222-6239; 6254-6258 :~_ ~::"- ~ ~'." true vertical . :. .~, - : Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 6899' MD. ,~. - ' Packers & SSSV (type & measured depth) OTIS 'RRH' @ 6582' MD; OTIS 'WD' @ 6884' MD; CAMCO 'TRDP-1A-SSA' (LOCKED OUT FLAPPER ON 9/5/97) @ 1770' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Avera,qe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1943 550 2763 Subsequent to operation 1857 2400 3461 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil__ Gas __ Suspended __ Service _X WAG Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed C-'~,.~-~ ~' ~j~,,~,,~~'~"~ Title Production Engineering Supervisor Date Jeff A/pencer Prepared by Robed Christensen 659-7535 RBDMS BFL Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 3B-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 7/11/011Commenced EOR Injection REPORT OF SUNDRY WELL OPERATIONS !1. Type of Request: Operation Shutdown ..__ Pull tubing Alter 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at sudace 202' FSL, 438' FEL, Sec. At top of productive interval 1283' FNL, 1429' FWL, Sec. At effective depth 1441' FNL, 1604' FWL, Sec. At total depth 1480' FNL, 1647' FWLr Sec. 12. Present well condition summary Total Depth: Stimulate _... Plugging Perforate _ casing Repair well ,, Pull tubing Other X 5. Type of Well: Development _.__ Exploratory _ Stratigraphic ._ Service ~ 16, T12N, RgE, UM 22, T12N, RgE, UM 22, T12N, RgE, UM 22~ T12N~ R.9E~ UM measured 7 2 5 0' feet true vertical 6428' feet 6. Datum elevation (DF or 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3B-10 9. Permit number/approval number 85-114 // clO - 10. APl number 5o-029-21368 11. Field/Pool , Kuparuk River Oil Pool feet Plugs (measured) Effective depth: measured 71 47' feet true vertical 6343' feet Junk (measured) Casing Length Size Structural Conductor 9 5' 1 6' Surface 33 0 9' 9 5/8" Intermediate Production 723 2' 7" Liner Perforation depth: measured 6726'-6771', 6841'-6848', 6954'-6996', true vertical 5994'-6034', 6089'-6095', 61 82-6217', Cemented Measured depth True vertical depth 227 Sx PF "C" 9 5' 9 5' 1000 Sx AS III & 3309' 3248' 300 Sx Class "G" 500 Sx Class "G" 7 2 3 2' 6 41 3' 250 Sx AS I 7002'-7022', 7040-7045' 6223'-6239', 6254'-6258' MD TVD Tubing (size, grade, and measured depth) 3-1/2", J-55, 9.3#/ft Tubing with tail @ 6898' Packers and SSSV (type and measured depth) Otis RRH ~ 6582' and Otis WD ~ 6879'~ Camco TRDP.1A-SSA-SSSV @ 1770' 13. Stimulation or cement squeeze summary ..... ~' ~!~' ~ 14. Intervals treated (measured) ~-.~,. ~ ~ . .... ',~5~..~,- Treatment des~p~on in~uding volumes usa and ~nal pressure Re~r...nmtiva Oily Avera~a Pr~u~on or Ini~ion Da~'~,~?~ Oil-Bbl ~as-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecjuent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Service WATER INJECTION SUBMIT IN DUPLICATE ARCO Alaska Post O, .; Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipated Start Date 3B-10 Variance April, 1990 3C-03 Stimulate April, 1 990 3M-04 Perforate & Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments RECEIVED 'APR 12 !990 Al_asl~ 13il & Gas Cons, Commission ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany AR3B-6003-C STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program_ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance X Perforate _ Other 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 202' FSL, 438' FEL, Sec. 16, T12N, R9E, UM At top of productive interval 1283' FNL, 1429' FWL, Sec. 22, T12N, R9E, UM At effective depth 1441'FNL, 1604' FWL, Sec. 22, T12N, R9E, UM At total depth 1480' FNL, 1647' FWL, Sec. 22, T12N, R9E, UM RKB 85 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3B-10 9. Permit number 85-114 10. APl number 5o-029-21 368 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7250' 6428' Effective depth: measured 71 4 7' true vertical 6 3 4 3' Casing Length Size Structural Conductor 9 5' 1 6" Surface 330 9' 9 5/8" Intermediate Production 7 2 3 2' 7" Liner Perforation depth: measured feet feet feet feet Plugs (measured) Cement: 7147'-7250' Junk (measured) Fill ~ 7055' Cement~ Measured depth True ve~ical depth 227 Sx PF "C" 1 1 9' 1 1 9' 1000 Sx AS III & 3333' 3272' 300 Sx Class G 500 Sx Class G 7 2 5 6' 6 4 3 7' 250 Sx PFC 6726'-6771', 6841'-6848', 6954'-6996', 7002'-7022', 7040'-7045' MD true vertical 5994'-6034', 6089'-6095', 6182'-6217', 6223'-6239', 6254'-6258' TVD Tubing (size, grade, and measured depth 3-1/2" J-55, 9.3#/ft, Tubing Tail @ 6898' Packers and SSSV (type and measured depth) Otis RRH ~ 6582'~ Otis WD ~ 6879'~ Camco TRDP-1A-SSA ~ 1770' 13. Attachments Description summary of proposal ~ Request a sundry approval to continue injection "as is". 14. Estimated date for commencing operation April, 1990 16. If proposal was verbally approved Name of approver Detailed operation program _ BOP sketch_ 'Well History and Wellbore Schematic attached). 15. Status of well classification as: Signed Oil __ Gas __ Suspended _ Date approved Service _W at e r that the foregoing is true and correct to the best of my knowledge. ~"~. ~~ Title Sr. Operations Engineer FOR COMMISSION USE ONLY Injector Conditions of approval' Plug integrity __ BOP Test Mechanical Integrity Test_ Notify Commission so representative may witness Location clearance Subsequent form require 10- ~ ~,,.,,~r o,,/ed OOP¥ SIGNED BY ~~ ORIGINAL LONNIE C. SMITH Commissioner Approved by the order Commission IApproval No. Application for Sundry Approval for 3B-10 Attachment Kuparuk Well 3B-10 has a suspected tubing leak causing the tubing to 7" casing pressure communication. A sundry approval is requested to allow continued injection in the well "as is". The pressure communication in the well has been an intermittent problem. There is no sign of deterioration in the casing integrity to the formation. As described in the attached well history, we had informed the State of the well status whenever a significant change in the well occurred. The last time we informed the State was when a report of sundry was submitted in 6/89,' when the problem went away for 15 months. Since then, the situation resurfaced and the well recently passed a MIT witnessed by a State official. Previous attempts to locate and repair the leak have been unsuccessful. The tubing and casing pressures are being closely monitored. WELL 3B-10 History of the Tubing to Casing Pressure Communication 6/85 Well drilled and completed. 7-12/85 Put on production. 12/85 Converted to a water injector. Suspected a possible leak from the tubing to the 7" casing from higher than expected casing pressures. 2/86 A spinner/temp log inconclusive in detecting any leak, indicating the leak source to be very small. Casing pressure above 2000 PSlG at times. Bled down to 1000- 1500 PSlG on a regular basis. 11-12/86 The pressure communication problem first discussed with the State. Approval obtained to continue injection. The casing pressure up to 2375 PSlG. Passed a MIT. 2-3/8 7 The problem appeared to have gone away. 4/87 The casing pressure started to increase as before. 5/87 6-8/87 9-11/87 Application sundry to trouble shoot submitted to the State, The casing pressure remained Iow The leak ."resurfaced". 11/87 Explained the "on and off" situation to the State. DV's changed out. The bottom valve with oversized packing. The casing pressure still high. 2/88 The pressure communication went away again. The casing pressure down from 2500 to 1700 PSlG. 5/88 National pump skid supplying water to DS3B at a WHIP of 22OO PSlG CYC 4/O9/9O 3B-10 History (Cont'd) 11/88 Passed a MIT. 5/89 The casing pressure staying below 1700 PSIG since 2/88. 6/89 A Report of Sundry submitted to inform the State that the pressure communication problem no longer existed. 7/89 The pressure communication problem resurfaced. The 7" casing pressure excceeding 2000 PSIG up to 2500 PSIG. Bled annulus. Closely monitoring the pressure. 8- 1 1/89 The casing pressure averaging 1800-2200 (typically). 3/1 5/9 0 Passed MIT witnessed by State official. Present The casing pressure averaging 1800-2200 (typically). CYC 4/O9/9o KUPARUK WELL 3B-10 APl #: 500292136800 · SPUD DATE: 06/11/85 ADL LEASE: 25633 COMPLETION DATE: 07/10/85 PERMIT #: WORKOVER DATE: 85-114 ORIGINAL RKB: SURFACE LOCATION: 202'FSL,438'FEL,SEC16,T12N,RgE TOP OF KUPARUK: 1283'FNL,1429'FWt, SEC22,T12N,RgE TD LOCATION: 1480'FNL,1647'FWL,SEC22,T12N,RgE NI deplt~ are MD-RKB t~ ~ of equil=merit unless olherwise noted 85 TUBING SPOOL: 23.65 PAD ELEVATION: WELLTYPE: WATER INJECTOR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 95 9.625' 36# J-55 3309 7' 26# J-55 7232 3.5 9.3 J-55 EUE 6899 LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP-1A-SSA 2.81' 1765 SBR OTIS SBR 6576 PKR OTIS RRH 6582 PKR OTIS WD 6884 NOGO CAMCO 'O' NIPPLE 2.75' 6591 SHROUT OTIS 6890 L STN DEPTH MANDREL 1 1803 CAMCO KBUG 2 3107 CAMCO KBUG 3 3903 CAMCO KBUG ~11 4 4432 CAMCO KBUG 5 4832 CAMCO KBUG 6 5280 CAMCO KBUG 7 5698 CAMCO KBUG 8 6106 CAMCO KBUG 9 6529 CAMCO MMGII 10 6619 CAMCO MMGII 11 6685 CAMCO' MMGI! 12 6865 CAMCO MMGII 55 GAS UFT and FLOW INFORMATION VALVE PERFORATION DATA SIZE 1.o' 1.o' 1.o' 1.o' 1.o' 1.o' 1.o' 1.o' 1.5' 1.5" 1.5' 1.5' INTERVAL ZONE FT SPF PHASE 6726-6771 C3 45 12 120 6841-6848 B 7 12 120 6954-6996 A3,4 42 4 120 7OO2-7022 A2 20 4 120 7040-7045 A2. 5' 4 120 PORT SIZE ov DV DV DV DV DV DV DV DV CV CV CV COMMENTS SWS 5.5" HJ II SWS 5.5" HJ II SWS 4' HJ II SWS 4' HJ II SWS 4' HJ 11 MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 40 HOLE ANGLE THRU KUP: 35 LAST TAG DATE: 06/01/86 RATHOLE: 10 FISH/OBSTRUCTION: PBTD: PBTOSS: deg deg FINGERS DEPTH 24OO 7055 6865 7148 6256 REVISION DATE: 12/01/88 REASON: NEW SCHEMATIC 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 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 202' FSL, 438' FEL, Sec. At top of productive interval 1283' FNL, 1429' FWL, Sec. At effective depth 1441' FNL, 1604' FWL, Sec. At total depth 1480' FNL, 1647' FWL, Sec. 16, T12N, R9E, UM 22, T12N, R9E, UM 22, T12N, R9E, UM 22, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7250' feet 6428' feet Plugs (measured) 6. Datum elevation (DF or KB) 85' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number ~B-10 ii~-' ~; ¢~c ~- 9. Permit number/approval, number 85-114 ./ 7 ;- 3 5/'2 10. APl number 5o-029-21368 11. Field/Pool Kuparuk River Oil Pool feet Effective depth: measured 71 47' true vertical 6343' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 95' 16" 3309' 9 5/8" 7232' 7" measured 6726'-6771' 6841'-6848', 6954'-6996', true vertical 5994'-6034', 6089'-6095', 61 82-6217', Tubing (size, grade, and measured depth) Cemented Measured depth 227 Sx PF "C" 9 5' 1000 Sx AS III & 3309' 300 Sx Class "G" 500 Sx Class "G" 7 2 3 2' 250 Sx AS I 7002'-7022', 7040-7045' 6223'-6239', 6254'-6258' MD TVD 3-1/2", J-55, 9.3#/ft Tubing with tail @ 6898' Packers and SSSV (type and measured depth) Otis RRH @ 6582' and Otis WD @ 6879', Camco TRDP-1A-SSA-SSSV @ 1770' True vertical depth 95' 3248' 6413' : 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Reoresentative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 16. Status of well classification as: X Oil ~Gas Suspended __ Service WATER INJECTION 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,,/', ~)z.(~,..'l?-//'~ , Form 10-4~)4 Re~' 06/15/88 ? Date SUBMIT IN DUPLICATE Report of Sundry for 3B-10 Attachment Kuparuk Well 3B-10 no longer has a tubing leak problem that had caused the tubing to 7" casing pressure communication. As described in the attached well history, the tubing leak used to be an "on and off" situation. However, since 2/88, the problem appears to have gone away. We believe that the replacement of the dummy gas lift valves mainly helped the situation even though the pressure communication was not immediately eliminated after the slickline work. We will continue to monitor the casing pressure closely. WELL 3B-10 History of the Tubing to Casing Pressure Communication 6/85 Well drilled and completed. 7-12/85 Producing oil. 12/85 Converted to a water injector. Suspected a possible leak from the tubing to the 7" casing from higher than expected casing pressures. 2/86 A spinner/temp log inconclusive in detecting any leak. Determined the problem to be a minor one. Casing pressure above 2000 PSIG at times. Bled down to 1000- 1500 PSIG on a regular basis. 11-12/86 The pressure communication problem first discussed with the State. Approval obtained to continue injection. The casing pressure up to 2375 PSIG. Passed a MIT. 2-3/8 7 The problem appeared to have gone away. 4/87 5/87 The casing pressure started to increase as before. Application sundry to trouble shoot the problem submitted to the State. 6-8/87 9-11/87 The casing pressure remained Iow (500-1000)~.,.;i~_ , The leak "resurfaced" 11/87 Explained the "on and off" situation to the State. DV's changed out. The bottom valve with oversized packing. The casing pressure still high. 2/88 The pressure communication went away again. The casing pressure down from 2500 to 1700 PSIG. 5/88 National pump skid supplying water to DS3B at a WHIP of 2200 PSIG 1 1/8 8 Passed a MIT. 5/89 The casing pressure staying below 1700 PSIG since 2/88. A report of sundry to be submitted to inform the State that the well no longer has a tubing leak. KUPARUK WELL 3B-10 APl #: 500292136800 SPUD DATE: 06/11/85 ADL LEASE: 25633 PERMIT #: COMPLETION DATE: 07/10/85 WORKOVER DATE: 85-114 · SURFACE LOCATION: 202'FSL,438'FEL,SEC16,T12N,RgE TOP OF KUPARUK: 1283'FNL,1429'FWL,SEC22,T12N,R9E TD LOCATION: 1480'FNL,1647'FWL,SEC22,T12N,R9E NI depths are MD-FIKB t~ I~p of equipment unless otherwise noted ORIGINAL RKB: 85 CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ H-40 95 9.625' 36# J-55 3309 7' 26# J-55 7232 3.5 9.3 J-55 EUE 6899 TUBING SPOOL: 23.65 WELLTYPE: WATER INJECTOR LINER DETAILS SIZE WEIGHT GRADE TOP BTM TUBING JEWELRY ITEM TYPE ID DEPTH SSSV CAMCO TRDP- 1 A-SSA 2.81 ' 1765 SBR OTIS SBR 6576 PKR OTIS RRH 6582 PKR OTIS WD 6884 NOGO CAMCO 'D' NIPPLE 2.75" 6891 SHROUT OTIS 6890 PAD ELEVATION: 55 STN 1 2 3 4 5 6 7 8 9 10 11 12 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 1803 CAMCO KBUG 1.0' 3107 CAMCO KBUG 1.0' 3903 CAMCO KBUG 1.0' 4432 CAMCO KBUG 1.0' 4832 CAMCO KBUG 1.0' 5280 CAMCO KBUG 1.0' 5698 CAMCO KBUG 1.0' 6106 CAMCO KBUG 1.0' 6529 CAMCO MMGII 1.5' 6619 CAMCO MMGII 1.5' 6685 CAMCO MMGII 1.5' 6865 CAMCO MMGII 1.5' PERFORATION DATA INTERVAL ZONE FT SPF PHASE 6726-6771 C3 45 12 120 6841-6848 B 7 12 120 6954-6996 A3,4 42 4 120 7002-7022 A2 20 4 120 7040-7045 A2 5 4 120 PORT SIZE DV DV DV DV DV DV DV DV DV CV CV CV COMMENTS SWS 5.5' HJ il SWS 5.5' HJ II SWS 4' HJ II SWS 4' HJ II SWS 4' HJ II MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 40 HOLE ANGLE THRU KUP: 35 LAST TAG DATE: 06/01/86 RATHOLE: 10 FISH/OBSTRUCTION: PBTD: PBTDSS: FINGERS DEPTH 24OO 7055 7148 6256 REVISION DATE: REASON: 12/01/88 NEW SCHEMATIC ARCO Alaska, lnc Post Offic~ ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 2, 1988 Mr. C. V. Chatterton Alaska Oil and Gas Con~nission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 Conservation Order Number 198, Kuparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the first quarter of 1988. The data is provided in the form of separate zone surveys as or spinner logs listed in Attachment I. The spinner logs will be sent separately. Injection rates determined by separate zone surveys are also listed in Attachment I. If you have any questions concerning the information reported, please contact me at (907) 263-4978. Sincerely, ~. H. Kraly Operations Engineer MHK/SPT' pg:0163 Attachments ARCO Alaska, Inc. is a Subsidiary of AllanlicRIchlieldCompany STATE OF ALASKA ALA~..~ OIL AND GAS CONSERVATION CON ...... SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon F~ Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing C Time extension i; Change approved program ~ Plugging ~,. Stimulate ~ Pull tubing D Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 202' FSL, 438 FEL, Sec. 16, T12N, R9E, UN At top of productive interval 1283' FNL, 1429' FWL, Sec. 22, T12N, R9E, UM At effective depth 1441' FNL, 1604' FWL, Sec. 22, T12N, R9E, UM At total depth 1480' FNL, 1647' FWL, Sec. 22, T12N, R9E, UM 5. Datum elevation (DF or KB) RKB 85' 6, Unit or Property name Kuparuk River Unit 7, Well number 3B-10 feet 8. Permit number 85-114 9. APl number 50-029-21368 10. ?OO~uparuk River Oil Pool 11. Present well condition summary Total depth' measured true vertical Effective depth: measured true vertical 7250' MD 6428' TVD feet Plugs (measured) feet 7147' MD feet Junk (measured) 6343' TVD feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Liner 95' 16" 227 Sx PF "C" 95' MD 95' TVD 3309' 9-5/8" 1000 Sx A.S. III 3309' MD 3248' TVD 300 Sx Class "G" 7232' 7" 500 Sx Class "G" 7232' MD 6413' TVD 250 Sx A.S. I Perforation depth: measured 6726'-6771' MD, 6841'-6848' MD, 6954'-6996', MD 7002'-7022' MD, 7040'-7045', MD true vertical :: ~' ' 5994' -6034' TVD, 6089' -6095' TVD, 6182' -6217' TVD, 6223'-6239' TVD, 6254'-6258' TVD i.".~ ..., ~ :.~:,.~. Tubing (size, grade and measured depth) 3-1/2I', J-55, 9.3 #/ft., Tail @ 6898' MD ......... · _ Packers and SSSV (type and measured depth) OTIS RRH @ 6582'; OTIS WD @ 6879'; CAMCO TRDP-1A @ 1770 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Locate tubing to casing communication 13. Estimated date for commencing operation May 13, 1987 14. If proposal was verbally approved Name of approvingly. L. Smith Date approved 5/14/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed" Title Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Date ;.:.. o/. O '? Approved by the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate TELECOPY biO. (907) 276'-7542 December 5, 1986 Mr. R. A, Clausen AR.CO Alaska, Inc. P. O. Box 100360 Dmchorage, Alaska 99510-0360 Re: Proposal to continue injection into Kuparuk well 3B-10 Dear Mr. Clausen: I...te have considered your proposal to continue water injection into Kuparuk River Unit well 3B-10 as proposed in your December I, 1986 letter. We agree with your analysis that the tubing or packer leak is probably small and agree that continued water injection is probably safe. Your proposal to bleed the annulus down to 1500. psi and measure the time required for the pressure to build-up is reasonable, however, we believe that this should be done monthly rather than bi-monthly. You have our approval to continue injection as per your proposal provided the bleed-down and build up tests are conducted monthly and further provided that the test data secured to date and all ~ ~ V . future test data is t~.m.lj submitted to the commission l~en the leak increases sufficiently to be detected by tempera- ture and/or spinner surveys (the data must be timely furnished to us), we will expect you to submit a work-over plan on Application for Sundry Approvals, Form 10-403. Iz you have any questions please contact me or Blair Wondz.._!~ at 279-]433. ._ Si~%c'erel~, Lonnie C. Smith Co~nissioner dlf: i.LCS. 54 ARCO Alaska, Inc. Post Office Bo-,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 1, 1986 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission.~¢~. 3001 Porcupine Drive /~ Anchorage, Alaska 99501 ~h~-"~ ~ ,'~ ~ ~t~~' ear Lonnie' Subject- KRU Water Injection Well 3B-10 Tubing to Casing Leak Summary and P1 ans -~: Kuparuk River Unit Well 3B-10 was drilled in June 1985 and produced oil from July through December of that year. The well was shut in the last week of December 1985 and converted to water injection. Due to higher than expected seven inch casing annulus pressures, a spinner log was run in February 1986 in this well to look for a possible leak from the tubing to the seven inch casing annulus. The spinner log was inconclu- sive in detecting any leak. This is indicative of a very small leak. The well was returned to injection service with increased monitoring of the annulus pressure. The pressure has occasionally been lowered from 2500 psig to 1500 psig by bleeding off about thirty gallons of diesel. ARCO's opinion is that the annulus pressure present on this well is not a major safety problem. The casing is tested to 3500 psig before the production tubing is installed so it is sufficient for containing these pressures. Since the earlier attempt to locate the leak was unsuccess- ful due to its small size, we propose continued injection in this well and monitor the annulus pressure for any changes. In order to measure the size of the leak, the annulus pressure will be bled down every other month to 1500 psig and the time required for the pressure to buildup will be monitored. If the build-up time decreases substantial- ly to where the leak location can be determined, then a temperature and spinner survey will be done to determine the leak location and a workover plan developed to repair the problem. Sincerely, R. A. Clausen Senior Operations Engineer RAC'pg'0033 (MF) o41 1986 0il & Gas Coi'~-s, (;o~tmJssi0r~; ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Mr. L. C. Sm~ December 1, l~d6 Page 2 cc: T. M. Drumm M. L. Hagood D. S. Joiner S. I. Kerr M. R. Reinart D. Miller/K. Sherman L. Estrada/ L. Lash R. Sloan/K. Schaeffer AT0-1926 AT0-1120 AT0-1126 AT0-1148 AT0-1170 NSK NSK NSK File: KOE1.4-12 and Well File 3B-10 ARCO Alaska. Inc Post 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Well Completion Reports Dear Mr. Chatterton' Enclosed are the Well Completion Reports and gyroscopic surveys for the following wells' 2H-8 3B-10 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L159 Enclosures RECEIVED F E 0 2 8 198~ Alaska 0ii & Gas uon-.;, Comrmissior~ ARCO Alaska, Inc. ss a Subsidiary o; AtlanticRichfieldCompany STATE OF ALASKA ALASKA'~JiL AND GAS CONSERVATION CO~-rMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-114 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21368 4. Location of well at surface 9. Unit or Lease Name 202' FSL, 438' FEL, Sec.16, T12N, R9E, UN Kupaurk River Unit At Top Producing Interval 10. Well Number 1283' FNL, 1429' FWL, Sec.22, T12N, R9E, UM 3B-10 At Total Depth 11. Field and Pool 1480' FNL, 1647' FWL, Sec.22, T12N, R9E, UH Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 86' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. VVater Depth, if offshore 16. No. of Completions 06/11/85 06/1 6/85 06/18/85*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. PIugBackDepth(MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set I 21. Thickness of Permafrost 7250'MD,6428'TVD 7147 'MD ,6342 'TVD YES ~X NO [] 1770 feet MDI 1616' 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL/Cal, RFT, Gyro, CET 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 95 ' 24" 227 sx PF "C" 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 1000 sx AS Ill & 300 sx Class "G" 7" 26.0# J-55 Surf 7232' 8-1/2" 500 sx Class "G" & 250 sx 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) 7045 ' -7040 '~ 6848 ' -6841 "~ 3-1/2" 6898 ' 6582 ' & 6884 ' 7022 ' -7012 'f~ 6771 '-6751'I w/12 spf, 7012'-7002'~ w/4 spf, 6751 '-6731 ' 120© phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. / 6996'-6986'/ 90° phasing 6731'-6726' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6986 ' -6966 '~ N/A . 6966 ' -6954.~ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE "ir 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RFC !VED FEB 2 8 Alaska 0il & u,,,ls. Commission Anct~ora§e Form 10-407 * NOTE: Tubing was run and the well perforated 7/10/85. DAM/WC47 Submit in duplicate ,~ / Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. lop Upper Sand 6725' 5993' I Depth Hydro. Press. Shut-in Press. Base Upper Sand 6806' 6059' 6730' 3182 psi 3037 psi Top Lower Sand 6940' 6170' i 6749' 3192 psi 3054 psi , Base Lower Sand 7086' 6292' 6768' 3196 psi 3068 psi ~ 6801' 3210 psi 3012 psi 6956' 3278 psi 3054 psi 6972' 3281 psi 3057 psi 6982' 3275 psi 3064 psi 6992' 3279 psi 3084 psi i I 7015' 3294 psi 3235 psi 7043' 3305 psi NO SEAL 7042' 3300 psi 3246 psi 5560' 2714 psi TIGHT 5578' 2708 psi TIGHT 5633' 2735 psi 2228 psi 4442' 2250 psi TIGHT 3870' 2006 psi TIGHT 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date ~-2.J -~) 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 an~'th'i~' ?"~ ' . , . Iocat.~on (~:f the cementing tool. Item 27: .Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Ga~ Injection, Shut-in, Other-explain. Item 2~! 'If no cores tal~n; indicate "none". · . . Form 10-407 ARCO Alaska, Inc. Post Office Bi Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 1985 Mr. C. V. Chattert Alaska Oil and Gas 3001 Porcupine Dri Anchorage, AK 99 on, Chairman Conservation Commission ve 501 Dear Mr. Chatterton' Attached in dup following wells at Well Action licate are subsequent notices the Kuparuk River Field' Date Performed on the 2V-1 Conversion 2V-4 Conversion 2V-5 Conversion 2V-6 Conversion 2V-8 Conversion 3B-2 Conversion 3B-5 Conversion 3B-10 Conversion 3B-16 Conversion 3C-2 Conversion 3C-5 Conversion 3C-7 Conversion 3C-12 Conversion 12/18/85 12/19/85 12/19/85 12/19/85 12/18/85 12/29/85 12/29/85 12/29/85 12/29/85 12/30/85 12/30/85 12/30/85 12/30/85 If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-421 2. Nasl~ 0it & Bas cons, commission ._...... ~ 'Anchorage ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COIVFMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL i-IX OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. ROX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' T12N, R9E, UM 202' FSL, 438' FEL, SEC. 16, 7. Permit No. 85-11q 8. APl Number 50- 029-21 368 9. Unit or Lease Name KUPARUK R. I VER UN I T 10. Well Number 3B-10 11. Field and Pool KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KtJPARI IK R! VER O I L (RKB) ADL 25633, ALK 2566 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 [] 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 December 29, 1985 Kuparuk well 3B-10 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into both "A" and "C" sands. the 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~. ~'~- ~-~-~ ........ Title KUPARUK Date The space below for Commission use OPERAT IONS COORD I NATOR 1/23/86 Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo 0360 Anchorage, Alasl~a 99510-0360 Telephone 907 276 1215 December 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Cas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to field wells 3B-2 3B-5, 3B-10, 3B-16, 3C-2 · 3C-12 to water injection wells. If you have any questions, please call me at convert Kuparuk 3C-5, 3C-7, and 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD.ps. F i le Attachment (In Triplicate) RECEivED._ Alaska 0il & Oas Cons ' ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [~- OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 85-114 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21 368 4. Location of Well SURFACE LOCATION- 202' FSL, 438' FEL, SEC. 16, T12N, R9E, tJM 5. Elevation in feet (indicate KB, DF, etc.) 85' (RKB) 6. Lease Designation and Serial No. ADL 25633, ALK 2566 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 3B-10 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL 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 [] 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). It is proposed that Kuparuk well 3B-10 be converted from a producer a water injection well. The well has produced from both the "A" and "C" sands. Injection will be into both sands also. to ANT ICI PATED START DATE' January 1, 1986 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,/'~[c~-~ ~__,~,~.--,~-,~4~-----~ Title KIJPAR! IK The space below for Commission use OPERAT ! ONS COORD I NATOR Date. 12/6/85 Conditions of Approval, if any: Approved by. Approved · Rmturned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska. In~ Post Offi¢ lox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 10-15-85 TRA,~{S,:.iiTL'AL NO:5399 Al{CO ALASKA, KU P;.;{U K OPE P. ATiO[~S RECORDS CLERK ATO-!!15G P.O. ~OX 100260 TPJ~NSMi' '"" ~' iT4i A ~.: a~ ttERL",,' ,<E Th .<ECE!P'T ,Al.iD kEE'U:G~ O/~L SiGN ChL/CET FINALS/ SChL/ ON~ * iQ-~ '~ ,"~/%,'D~ 06- '~! k- 6 / CLL/VDL 06- 2V-!4 /C~L/VDL 0~- ~-5~ CbL/VDL- 0~- 'x3B- 6 ~ C~L/VOL '3s-7 / CL-L/VDL U6- -3m-!0w' CET LOG 06- Of,' E.,~Cli 0'2-85 RUN ~! 5900-8871 08-55 :{UN %1 6140-9146 02-85 ~,UN #! 5090-7056 0i-d5 ~iUN ~1 5500-7~90 01-85 RUN ~i 5900-8656 05-S5 ~UN ~;! 4690-7120 30-85 RUi; ~7! 4~40- ,_ 7 RECEi P':2 ACKi;OWLLDGED: CURRIER Ci!EV~',O~ ,~ ~i ~U'~'i Ui';: ~,~'. PA~',:,n~.,:~. ...... EXXON f'IiiLLIPS Oi~ J. RAT ~-IELL ARCO A~aska. Inc. l-~ ~ SuDs;C,ary of ANanhcRich;ield, CompanY ARCO Alaska, Inc. Post Office B~,..-100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-10 Dear Mr. Chatterton' Enclosed is a copy of the 3B-10 Well History (completion details) to include with the Well Completion Report, dated 8/28/85. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU11/L70 Enclosure ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO oi|and Gas Company ,~, Daily Well History-Final Report ]nstruclions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Reporr' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report comptetion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation ~f space is available. District ICounty or Parish Alaska I North Slope Borough Field Lease or Unit Kuparuk River APL 25633 Auth. or W.O. no. JTitle AFE 604402 I Completion Nordic 1 AP1 50-029-21368 IAccounting cost center code State Alaska IWell no. 3B-10 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete Date and depth as of 8:00 a.m 7/10/85 7/11/85 A.R.Co. W.I. 56,24g Date I otal number of wells (active or inactive) on this oat center prior to plugging and bandonment of this well out ' J Prior status if a W.O. / 1500 hrs. Complete record for each day reported 7" @ 7232' 7148' PBTD, RIH w/3½" compl string 10.3 ppg NaC1/NaBr Accept rig @ 1500 hfs,V/g/Sr. ND tree, NU & tat BOPE. RU WL, RIH w/4" csg guns, 4 SPF,--°90 phasing. Perf f/7045'-7040', 7022'-7002', 6996'-6954'. RIH w/5~" csg guns, 12 SPF, 120° phasing. Perf f/6848'-6841', 6771'-6726'. RIH w/perm pkr & tailpipe assy, set @ 6879'. 7" @ 7232' 7148' PBTD, RR 10.3 ppg NaC1/NaBr V RIH w/compl string. Set top pkr @ 6575'. Shear SBR. Set BPV. ND BOPE, NU & tat tree; OK. Displ well to crude. Tat SSSV. Shear out ball. RR @ 2400 hrs, -Tb~-t-C85~_g,[OlSC)j J Old TD PB Depth 7148' PBTD Released rig Kind of rig Ne','; TD Date 2400 hrs. -,///~/,~ ~ ~ ,Iv, Classifications (oil. gas, etc.) Oil Type completion (single. dual. etc.) Single Producing method Official reservoir namers) Flowing Kuparuk Sands Potentia~ test data Rotary Well no, Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct "~ ~k,,'~'~"- ........ i~;JF C 77~2~8~__.?, , ,~ ~ Drilling Superintendent For form p~rati .... d digribution,[:Oa W.S. UU'~t'~% ,~ ~, ~,: ~ ~" C ~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C . F ', iF,'" - Y/- .... [Number all daily well histo~ f ........... tively , e ~,w~U~ .~'~ Pagno. ' jas they are prepared for each well. / Di~i¢on ot AtlanticRIchlleld~mpany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08/29/85 TRANSMITTAL NO: 5311 RETURN TO: ARCO ALASKA, INC. KU PARU K OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ENGINEERING TRANSHITTED hLHLWITH AIiE THE FOLLOWING ITEMS· PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY 05' THIb TRANSMITTAL. FINAL P~INTS ~ -'~ 5" '~ ~ 2 '! 2" 5" (OPEN HOLE (ONE * OF EACH) SCHLUMBERGER -~......~ 3B-10 CYbERLOOK 06/17/85 RUN #1 5345-7150 REPEAT FOP~t. 'fESTER 06/17/85 RUN #1 3870-7043 DEN/NEU/G~, (RAW) 06/17/85 RUN #1 3309-7212 DEN/NEU/GR (RAW) 06/17/85 RUN #1 3309-7212 DEN/NEU/GR (PORO) 06/17/85 RUN #1 3309-7212 DEN/NEU/GR (PORO) 06/17/85 RUN #1 3309-7212 DIL/SFL/GR 06/17/85 RUN #1 3309-7238 DIL/SFL/GR 06/17/85 RUN #1 3309-7238 CYBERLOOK 06/10/85 RUN #1 7600-8325 DEN/NEU/GR (PORO) 06/10/85 RUN #1 7600-8349 DEN/NEU/GR (PORO) 06/10/85 RUN %1 7600-8349 DEN/NEU/GR (RAW) 06/10/85 RUN #1 7600-8349 DEN/NEU/GR (RAW) 06/10/85 RUN ~1 7600-8349 DIL/SFL/GR 06/10/85 RUN ~+1 3999-8372 DIL/SFL/GR 06/10/85 RUN #1 3999-8372 3B-U5 -'"~ CYSERLOOK 05/12/85 RUN ~1 7250-8065 DEN/NEU/GR (R~W) 05/12/85 RUN #1 3479-8088 DEN/N[~U/GR (RAW) 05/12/85 RUN #1 3479-8088 DEN/NEU/GR (PORU) U5/12/~5 ~UN #1 3479-8088 DEN/NEU/GR (PORO) 05/12/85 RUN #1 3479-8088 DIL/bFL/GR 05/12/85 RUN #1 3479-8114 DIL/SFL/G'R 05/12/S5 HUN #1 3479-8114 RECEIPT CYBERLOOK 06/19/85 RUN ,% DEN/NEU/GR (PORO) 06/19/85 RUN #2 27 DEN/[~EU/GR {POP, O) 06/19/85 RUN #2 27 DEN/NEU/GR (RAW) 06/19/85 RUN ~ DEN/NEU/GR (RAW) 06/19/~5 RUN # DIL/SFL/GR 06/19/85 RUN # DIL/~FL/GR 06/19/~5 RUN ~ ACKNO%~LEDGED: DISTRIBUTION: BPAE b. CURRIER CHEVRON D & 5~*BL D~<I.LLING*BL W. PASHER JOHNSTON EXXON HOBIL PHILLIPS OIL CL E IiK*BL J. RATH/4ELL* BL 2 2708-6684 08-6684 2 270~-668'%¢. 2 2708-6684 2 2708-6710 DATE' % \ STATE' OF ALASKA*BL~ SOHIO UNION K.TULIN/VAULT*FiLMS ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Bo~'100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 29, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3B-10 Dear Mr. Chatterton' Enclosed is the Well Completion Report for 3B-10. I have not yet received a copy of the Well History (completion details). When I do, I will forward a copy to you. Also, the bottomhole location, TVDs, and geologic markers will be submitted when the gyroscopic survey is received. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L37 Enclosure AI~CO Alaska, ira;, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~..- AND GAS CONSERVATION CF~ .... ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska, Inc. 85-114 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21368 4. Location of well at surface 9. Unit or Lease Name 202' FSL, 438' FEL, Sec.16, T12N, R9E, UN (approx) Kupaurk River Unit At Top Producing Interval 10. Well Number To be submitted when gyro is received. 3B-10 At Total Depth 11. Field and Pool To be submitted when gyro is received. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oi I Pool 85' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore i16. No. of CompIetions 06/11/85 06/16/85 06/18/85*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7250'MD 7147'MD YES []X NO [] 1770 feet MDI 1616' 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL/Cal, RFT, Gyro, CET 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 95' 24" 227 sx PF "C" 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 1000 sx AS Ill & 300 sx Class "G" 7" 26.0# J-55 Surf 7232' 8-1/2,, 500 sx Class ,,G,, & 250 x 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) 7022'-7012'( 6771'-6751'~w/12 spf, 7012'-7002' ~>w/4 spf, 6751'-6731' I 120° phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 6996' -6986' / 90° phasing 6731 '-6726'~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6986'-6966' / N/A 6966' -6954~,/ 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift,' etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ]GAs-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (corr) 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 . .Ai~sk~ (]ii & Gas Form 10-407 -k NOTE: Tubing was run and the well perforated 7/10/85. DRH/WC12 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, 30. GEOLOGIC MARKERS FORMATION TEsTs ' . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT: DEPTH GOR;and tire. Of each phase: To be submitted wl-~n gyro is received. N/A 31. LIST OF ATTACHMENTS We]] Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~:,,., r,~,g, ~L_~ t~_~ Associate Engi neet · _ '~LLLi-f__.t~.. Title Date ~-/-_~ -~-~ Signed /1 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 attachment~. - 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 .. ARCO Oil and Gas Company,¢'~' Well History - Initial Report - Daily Inatructions: Prepare end submit the "Initial Re~,t" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska IState County, palish or borough North Slope Borough Alaska, Lease or Unit ~Well no. Kuparuk River I ADL 25§33 -- I 3B-10 Auth. or W.O. no. JTitle AFE 604402 I Drill Parker 141 API S0-029-21368 Operator ARCO W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun [Date [Hour Prior status if a W.O. Spudded I 6/11/85 I 2015 hrs. Date and depth Complete record for each day reported as of 8;00 a.m. 6/12/85 6/13/85 6/14/85 6/15/85 thru 6117185 16" @ 95' 1509', (1414'), Drlg Wt. 9.4, PV 16, YP 20, PH 9.5, WL 14.6, Sol 7 Accept ri~ @ 1630 hrs, 6/11/85. NU diverter sys. 2015 hrs, 6/11/85. Drl & surv 12¼" hole to 1509'. 608', .2°, S29E, 608.00 TVD, 1.00 VS, .93S, .51E 1479', .1°, Nll.9E, 1478.99 TVD, 3.06 VS, 1.lOS, 3.09E S..pud well @ 16" @ 95' 3330', (1821'), C&C f/csg Wt. 9.4, PV 13, YP 14, PH 10, WL 14, Sol 7 Drl 12¼" hole to 2102', DD to 3330', C&C hole. 1978', 1.6°, S80E, 1977.92 TVD, 4.80 VS, 2.65S, 8.64E 2387', 13.1°, S51.4E, 2383.91TVD, 50.91VS, 26.23S, 44.63E 2699', 19.9°, S51E, 2683.72 TVD, !36.65 VS, 82.22S, 109.57E 3076', 22.1°, S49E, 3036.51TVD, 269.50 VS, 168.33S, 210.74E 3300', 24.3°, S44.5E, 3242.49 TVD, 357.36 VS, 229.17S, 274.28E 9-5/8" @ 3309' 3650', (320'), Drlg 8½" hole Wt. 8.6, PV 7, YP 3, PH 12, WL NC, Sol 2 22 std short trip, chain out of hole. RU & rn 76 its, 9-5/8", J-55 36# HF-ERW BTC csg w/FS @ 3309', FC @ 3217'. CmS w/1000 sx A III w/l/2# per sx cellophane flake, followed by 300 sx Cl "G" cmt w/2% S-1 & .2% D-46. Displ using rig pmp, bump plug. CIP @ 1600 hrs, 6/13/85. ND 20" diverter sys. NU & Sst BOPE. TIH w/BHA, tag FC, tst csg to 1500 psi. DO cmt % flt equip + 10' new formation. Conduct formation leak-off Sst to 8.6 ppg EMW. Drl 8½" hole to 3650'. 5504' 5970' 6378' 7155' 9-5/8" @ 3309' 7250', (3600'), Logging Wt. 10.3, PV 10, YP 7, PH 8.0, WL 7.8, Sol 13 Rotary drl to 4067', turbine drl 8½" hole to 7250' TD, C&C f/logs, 25 std short trip. RU Schl, rn DIL/SFL/SP/GR f/7244' - 3309' WLM, FDC/CNL/CAL f/7244'-4982', taking press w/RFT @ selected depths. 3671', 30.7°, S48.5E, 3571.60 TVD, 524.51 VS, 341.19S, 398.38E 4380', 38°, S52.6E, 4144.18 TVD, 941.41 VS, 611.24S, 716.02E , 36.9°, S52E, 5027.70 TVD, 1634.66 VS, 1031.71S, 1268.96E , 38.5°, S53.8E, 5396.40 TVD, 1919.00 VS, 1203.57S, 1496.23E , 36.5°, S52.3E, 5720.07 TVD, 2166.77 VS, 1352.88S, 1694.70E , 34°, S49E, 6353.58 TVD, 2616.33 VS, 1638.04S, 2042.47E The above is correct Signature For form pre'ration and~istributlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D I Date F[ Title Drilling Superintendent 00~lkl,i~J~,~'~aily well history f ........... tively Alaska Oil & Gas Cons. las they are prepared for each well. iPag~ no. ARCO Oil and Gas Company ,~, Daily Well History Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code State Alaska District ICounty or Parish Alaska I North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25633 Auth. or W.O. no. ~Title AFE 604402 I Drill Parker 141 AP1 S0-029-21568 IWell no. 3B-t0 Operator A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Spudded 6/11/85 Date and depth Complete record for each day reported as of 8:00 a.m. 6/18/85 6/19/85 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O, I 2015 hrs. 9-5/8" @ 3309' 7250', (0'), Prep to cmt Wt. 10.2+, PV 14, YP 7, PH 8.0, WL 8.8, Sol 12 RIH w/bit, wsh & rm 30' to btm, C&C, POH f/csg. RU & rn 180 jts, 7", 26#, J-55 HF-ERW BTC csg w/FS @ 7232', FC @ 4147'. Prep to cmt. 9-5/8" @ 3309' 7250', (0'), RR Cmt 7" w/500 sx class G w/KC1, 0.8% D-60, .29% D-468. Disp good rtns, recip pipe. CIP @ 0800 hrs. ND BOPE, NU & tst tree. RR @ 1630 hrs, 6/11/85. Old TO New TD 7250' (6/15/85) Released rig Date 1630 hrs. Classifications (oil, gas, etc.) 0il PB Depth Kind of rig 6/11/85 Rotary Type completion (single. dual. etc.) Single ProduCing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water % GOR Gravity Allowable Effective date corrected Signature For form pre~ .... , .... d(~istribud-onq see Procedures Manual. Section 10, Drilling. Pages 86 and 87, The above is correct Date F' ~_ Title 7~0~/~5~~ , ~ ~* ? ~.~'-. Drilling Superintendent AR3B-459-3-C all daily well histow forms Page 2 Divi~on of Atlanli~lchfieldCompiny ARCO Alaska, Inc. Post Office BOx 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3B-10 Dear Mr. Chatterton: Enclosed are the Well Completion Report and gyroscopic survey for 3B-10. I have not yet received a copy of the Well History. When I do, I will forward a copy to you. Also, the RFT data will be submitted when it is received. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/Lll Enclosures , : .ECEIVED A~aska 0ii & Gas Cons. Commission Anchorage ARCO ALaska. Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA-',.,.;_ AND GAS CONSERVATION CC..--..~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-114 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21368 4. Location of well at surface 9. Unit or Lease Name 202' FSL, 438' FEL, Sec.16, T12N, R9E, UN ~[LC, CATiONS[ Kuparuk River Unit At Top Producing IntervalIIV~.2,,FIED { 10. Well Number 1283' FNL, 1429' FWL, Sec.22, T12N, RgE, UN 1 i Surf, At Total Depth| 11. Field and Pool 1480' FNL, 1647' FWL Sec.22, T12N, R9E, UM t~'H' "~ , Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 86' RKBI ADL 25633 ALK 2566 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 115. Water Depth, if offshore 116. No. of Completions 06/11/85 06/1 6/85 06/18/85*I N/A feet MSL 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7250'MD,6428'TVD 7147'MD,6342'TVD YES I~X NO [] 1759 feet MDI 1600' (approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL/Cal, RFT, CET, Gyro 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 95' 24" 227 sx PF "C" 9-5/8" 36.0# J-55 Surf 3309' 12-1/4" 1000 sx AS III & 300 s~ Class G 7" 26.0# J-55 Surf 7232' 8-1/2" 500 sx Class G & 250 s~ 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) 7040' - 7045' 3-1/2" 6898' 6576' & 6875' 7002' - 7022' w/4 spf, 120° phasing 6954' - 6996' 26. ACID, FRACTURE, CEMENTsouEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6841' - 6848' N/A 6726' - 6771' w/12 spf, 120° phasing 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL' GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER~BBL OIL GRAVITY-APl (tort} Press. 24-HOUR RATE I~ 28. CORE DATA BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit co~ c~ .1~.~, ~ t~, ~-' ~ "i '~/ ~-'1~ ~' Ataska 0ii & G~s Cor~s. Commission Anchora!:;¢ Form 10~407 * NOTE: Tubing was run and the well perforated 7/10/85. TEMP/WC85 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT.dDEPTH GO'R,§nd~irhb of b~h ~hase. Top Upper Sand 6725' 5993' RFT data to be submitted when received. Base Upper Sand 6806' 6059' Top Lower Sand 6940' 6170' Base Lower Sand 7086' 6292' . 31. LIST OF ATTACHMENTS Cyrn.~_n?in S,,rv~v (?, nn,ni~..~) .- 32. I hereby certify~that the foregoing is true and correct to the best of my knowledge Signed~o ~,.'?J?L-,' ~J~,..L[.)©~.~' Title Associate Engineer Date [~/[~ '"~ /~::T // '- ._4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and i~ any ~tt~c~ent~. - 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 SUB. SURFACE DIRECTIONAL SURVEY r~UIDANCE r~.ONTINUOUS ['~OOL .. RECEIVED FEB 2 8 Alasl<a 0ii & Gas Cons. Commission Anchorage Company Well Name Field/Location ATLANTIC RICHFIELD cOMPANY 3B-10,~202' FSLI, 438' FEL~ S16~ T12N, R9E ,KUPARUK~ NORTH SLOPE, ALASKA Job Reference No_, 70691 Lo,q<3ed By;, LESNIE Date_ 31-JULY-1985 Computed 8~ ~OLA_~ GCT DIRgCTIONA[., SURVEY CIlSTOPER LISTING ARCO ALASKA, INC, 3B-lO KUPARUK NORTH SbOPE,AbASKA SURVEY DATFI 30 JUN 85 ENGINEER~ LESNIE METHODS nM COMPUTATION TOf)l., [,f]CATIObl: TAHC;FNTIAL- averaqed deviation amd azimuth ~,r~,.,mr,,',~, e ,':, ,'.,r 't n ,, . '-'m'~T'/. thlA'l" r',~.~n~'.,',q,~.'n I'l~Trl A TAi~C,I~.'I' aZTMII'I'I-I t'lF ,c;OUTH 49 DEG 7 N]~N EAST AI:~CO ALASKA, 'I'NC, 3R-10 KIJPAEIIK NOHTH SI,OPE,ALASKA CO~PUTATION DAT~: 30-JUL-fi5 PAG~ 1 DATE OF' ~URV£Y! 30 ,JUN 85 KELLY BUSHYNG £bEV{tT%ON{ 86.00 F~ ENGINEER{ ~ESNXE iNTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUR-SEA COURSE MEASiIRED VERTICAl, VERTTCAL DEV'YATION AZIMUTH DEPTH DEPTH DEPTH DEG MTN DK(; MTN 0 OU 0.00 'B6.00 0 0 N 0 0 F iO0:nO 100.00 14.00 0 10 ~ ]2 40 E ?00.00 200.00 114.00 0 30 N 5 50 E 300.00 299.9g 913.09 0 26 N 13 46 ~ 400,00 309.9o 313,99 0 21 N 12 48 ~ ~00.00 409.9° 413.99 0 5 H 71 4~ E 600 O0 599.90 ~13.99 0 6 S 65 5 ~ 700:00 699.90 613.99 0 16 S 89 11 ~ BOO O0 709,90 ?13.09 0 24 N 74 0 E 900:00 899.98 813.98 0 18 N 47 44 E 1000.o0 1100.00 1009 120o.00 1199 I]O0.nO 1299 1400.00 1399 150o.o0 1409 1600.00 15g9 1700.00 1609 1000.00 1709 1000.00 1809 909 99 013.98 99 1013.08 98 1113.08 98 1713,98 9~ 131].q8 ~ 1413,08 97 1~1 97 95 171. 05 92 1913.02 2000.00 1999 8~ lO13.~8 2100.00 2099 84 2013 94 2?00.00 7109 2]00.00 ?208 2400,o0 ?306 2500,00 2402 60~. O0 ?588 ~70:00 ~b83 2800.00 2777 2000.00 ~871 S 96 10 E ~ 78 4 E S 56 1 ~ s 57 29 E S 51 50 E S 50 42 E .q 49 41 E S 51 31E S 51 22 E 1 36 , 2 bi 2113.61 5 37 66 2712,66 9 51. 44 2310.44 14 11 81 2406,81 15 4q 8R 2~0~,R8 17 61. 2597,61 19 45 60 2691,60 20 4 37 2785,37 20 41 3oO0.nO 2964 5A 2~7A,58 71 43 3100 O0 3057 2~ 2971,22 ~2 3] 3200'00 3149 25 306].25 73 28 3]O0:nO 3240 63 3154.63 ~4 36 3400,o0 3330 99 3~44.99 ~6 2 3500,00 3420 25 3~34,95 ?7 37 3600,o0 ~508~14 3427,{~ 79 24 3700,n0 3504 43 35()R,43 31 lq 3900.00 367R:9~ 3597,02 ~3 3900.00 3761.55 3~75.55 35 l& ..q 50 30 W. $ 50 11 E S 48 36 r. $ 47 22 F $ 48 IS E $48 30 E $ 4~ 41 F. S 48 44 F S 48 57 E VE~TTCAL DOGLEG R~CTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST,. AZIMUTH FFET DEG/IO0 FEET FEET FE~ PEG MIN 0.00 -0.38 -1.35 -1.25 -0.~8 -0,58 -0.42 0.41 0.47 0.59 -0.68 -0,75 -0.93 -0.44 0.74 2.37 4.i8 6,27 8,74 14.91 75,74 1()3,4b 135,48 169,59 204,30 240.49 279,13 317,26 357,85 400.66 445.?3 493,43 543,94 597,43 65].74 0.00 0.08 0 21 0 20 0 20 0 30 0 07 0 27 0 36 0 O6 0 1 o 0 iT 0 15 0 O9 O, 6 0,68 0.29 0,21 2 4 25 3 93 4 24 0 24 3 69 1 O? 1 O0 1 31 8~ 1! I '/8 0.00 N O. 31 N 1.02 N I 85 N 2 51 N 2 93 N 2 92 N 2 84 N 92 N 28 N ,39 53 ~ , ~ 20 · , 16 i 91 48 72 49 325 ~ '4 ~ ~:6495 42 48 117 26 S 168 71 140 02 ~ 196 86 ~ 241 Se 54 34 245 50 S 41 ~ ~ ~ ~ 4R4 59 COMPUTATION D~E: ~0-JUL-85 PAGE 2 38-10 NORTH SLOPE,ALASKA DATE OP SURVEY1 30 JUN 85 KELLY BUSHZNG EL~VATtONI 86.00 PT 1NTERPObA?Eh vALUF$ FOR EVEN 100 FEET OF HEASURED DEPTH TRU~ SUR-$EA COUP$~ HEA~IIRFD V~R?IOA{, YEPTTCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG RIN PEG MTN 4000 O0 3842,29 ]756,~9 4100:00 3921,45 3B35.45 38 3 4200,00 4000,12 3q14,12 38 4]00.00 4078,79 3092.?9 38 7 4400,0O 4157,4q 4071.49 ]8 4 450~.00 42]b.14 4150,14 4600,00 m]14,44 4~28,44 ]8 21 4700,00 4393,22 4307,22 37 54 4800,00 4471,99 4~5,99 4900,00 4550,5~ 4464,51 38 ]0 5000.00 4628,52 4K42,52 38 50 5100 O0 4706,05 4620,05 ]9 1R 5~00"00 47~3,3~ 4~97,]2 ]9 ]~ 5~00"00 4860,38 4774,~8 39 28 5400:~0 49~7,98 4,851,98 ]9 5500,00 5016.67 4930,67 ]7 16 5600,00 5096,27 5010,22 37 24 5700,00 5175.57 508q,57 ~7 ]6 5800,00 5254,56 5~68,56 ~8 5 5900,00 53~3,0] 5247,03 38 27 610n:00 K489 74 5403:74 ]8 6?00,00 5568 67 5489,67 ]7 38 6~00,00 5648 14. 556~,~4 ~7 7 6400 O0 57~8 25 564~,~5 ~6 24 6500' ,00 ~808,90 572~,90 36 7 6600,00 5890,06 5804,06 ~5 11 6700,00 5972,11 5886,11 ~4 3R 6800,00 ~054,38 5968,18 34 28 6900,00 6137,18 6051,18 33 55 7000,00 6220,1~ 6134.16 3.3 52 7!00,00 6303,15 6217,1'5 33 52 7200,00 6386,17 6300,17 33 52 7250,00 6427,68 6341,68 ]3 52 VERTICAt, DOGLEG RECTANGULAR COORDINATEIS HDRIZ, DEPARTURE SECTION SEVERiTY NORTH/SOUTH EAST/WEST DIST,' AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN $ 49 ~ K 712.74 ~ 49 42 F 77],84 S 50 48 F 8]5.55 S 51 9 K 897.25 R 51 26 ~ ESR,gO $ 51 27 ~ 1020.61 S 51 39 F 1082,74 S 51 47 E 1~44,27 S 52 21 g 1~05,80 B 52 33 E 1267,62 ~ 52 47 E 1330,08 S 53 9 E 1393.08 S 53 34 E 1456.38 $ 53 44 E 1519,91 S 5 582.83 ~ 5~ 1~ 704,92 lg , ~765.68 $ 52 2~ K 1826,92 S 52 29 E 1888,80 S 52 13 E 1950,94 S 51 48 E 2012.88 $ 51 46 K 2074,~1 S 51 34 K 2134,84 S 51 29 E 2194,65 S 51 ~ E 2253.74 S 50 9 F 2312.12 S 49 44 F '2369,29 S 49 28 E 2426,13 $ 48 21E 2482.19 S 47 35 E 2537.95 S 46 48 E 2593,75 S 46 48 E 2649,45 S 46 48 £ 2677,30 1,65 0,88 0,24 530 0,40 569 0,17 608 0 72 646 0,81 685 0,22 723 0,36 761 0,68 799 0 73 0 22 0 38 1 49 0 83 0 35 0 44 0 29 0 o 0 64 0 82 0 81 0 59 0 74 0 58 0 82 0 4i 0 I 11 0:00 0,00 0,00 451 65 S 55 1 491 47 $ 598 83 S 645 70 $ 693 66 S 25 S 838 8 S 88 7 S 984 I , 72 E 713 01 $ 50 41 g 06 E 774 09 S 50 35 E 62 E 835 56 E 897 77 E 959 11E 102~ 87 E lo8 17 E 1144 75 g 1206 86 E 1268 82 iS 50 34 E iS S 50 35 F !4 $ 50 39 ~ )0 is 5O 42 E 18 15 50 45 E 77 is 50 48 E 36 S 50 51 g 26 1S 50 56 E 837 08 S 1034 875 912 950 988 1026 t063 11 5 62 S 59 S 123~ S 1334 49 S 1382 7t S 14 58 E 1330,81 S 51 1 E 05 E '393,~ S 51 ~ E 96 E t457.~- $ 5' lz E 37 E '521 03 & 51 19 E 72 E '584 07 is 5' 23 E 64 ~ '645 75 $ 51 25 E 61E 1706 34 $ 51 27 E 70 E i767 19 S 51 29 E 27 E '828 52 is 5' 30 g 42 E 1890 49 S 51 32 E 1213 11~27 1364 401 438 475 512 1549 82 S 15 80 S 1626 45 S 1674 74 S 1721 62 67 41 $ i856 22 S 1899 10 8 1942 78 E 195~,7~ ~4 90 E 2076 14 E 50 E 2136.83 i ~I 35 69 51 35 ':: 54 E 2255 83 8 51 35 E 71E 2314 23 33 2428 51 1586 39 S 1983,51 E 2539,87 S 51 20 E 1684 ]9 S 2024,4! E 2595,56 S 51 1~ E 1662 55 S 2065.05 g 2651.14 $51 9 E t681 63 S 2085,37 E 2678,93 S 51 7 E ARCO ALA~SKA~ TNC, 3R-10 NORTH $[o[~PE,AI,ASKA COMPUTATION D&TE: 30-JUL-B5 DATE OF SURVEY1 30 JUN 85 KELLY BUSHING £bEVATIONI ~NGIN££R$ LESNXE INT~RPOI, A?ED VALUF$ FOR EVEN {000 FEET OF MEASURED DEPT T~UF SUR-SEA COUPS~ ~E~SllRF[) VERTICAL VE~TTCAL DEVIATION AZIMUTH DEPTH D~PTH ~EPTH DEG MTN DEG MTN 86,00 F~ N O O F 0,00 N 40 21 ~ -0,41 S R6 10 F ~.~7 S ~0 39 F 240,49 S 49 ~ F 71~,74 S 52 47 F 1330,08 S 52 13 E 1950,g4 ~ 47 35 E 2537,q5 $ 46 48 E 2677,30 O,O0 0,11 1,00 i.65 0 73 0,64 0.00 0 O0 N 3 3 140 451 837 1213 1586 1681 0.00 bO N 2,57 E 4 19 N 11,06 E 11 02 $ i96,86 E 241 65 S 55ii72 E 0 O0 N 0 0 E 43 N 35 31 E 58 $ 54 34 r Ot $ 50 41 c 8i S 51 I E 73 $ 51 34 E 8'I $ 51 20 E 93 S 51 7 E o,oo 0,0o -86,00 0 0 1000.oo 9q9,gn 91~,q8 0 11 2000,~0 19q9,SR lq13,R8 1 36 3000.00 2964,5R 2RTR,58 21 43 4000,~l) ]84~.2q 375&,79 ]7 0 5000,00 4b~8 57 454~,52 ~8 50 6000 nO ~411:30 5]25,]0 ]8 27 7000'00 62~0,{~ 6134,{8 ]3 5~ VERTTC~L DOC, LEG RECTANGULAR CnORDINATE$ HORIZ, _DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST,~MZZ UTH FF~ET DEC,/! 00 FEET FEET COMPUTATinN DATE: 30-JUL=85 PAGE 4 A~C~ ALASKA~ TNC. 38-10 KUPARI~K NOHTH SLUPE~ALA$~A DATE OF SURVEYI ]0 JUN 85 KEbLY BUSHING EhEVATZONI ENGTNEERI INTERPOI,ATED VA[,UFS FOH EVEN 100 FEET OF SUB-SEA DEPTH 96,00 FT TRUE SUR-SEA COURSE MEASIIRFD VFRTICAI, VERTICAL DEVIATION AZIMUTH DEPTtt DKPTH DEPTH DEG MTN PEG MIN O.OO O.OO -86.00 0 0 N 0 O E 86.00 Rb. ON O.O0 0 17 N 30 17 £ 186.00 186,0N lOfl.O0 0 31 ~I 8 3~ F 286,01 2Rb. O0 200.00 0 27 N 14 37 E ~8~.01 3~b,O0 ]00,00 0 23 N 10 30 ~ 4~6.01 486.00 40n,O0 0 7 N 7 17 E 586.01 596.00 5oO,OO 0 6 S 69 4 E 686.01 b86.00 600,00 0 14 $ 83 2] E 786.01 7Rb. UO 700.00 0 23 ~] 78 15 E 886.02 886.00 RO0.O0 0 1~ , 48 30 F 10~6,02 1086 1186,02 11~6 1286,02 128b 1386,02 13Rb 1486.O2 1486 1586.02 1586 1686.~] ~68b 1786.05 178~ 1886.08 1886 986 O0 qO0,O0 O0 lO00,O0 O0 1]00.00 O0 O0 1IOn,nO O0 1400.00 O0 1500,00 On 1600,00 O0 1700.00 O0 1~00.00 lq86.11 198b O0 lqO0.O0 2086.15 ?096 2186,33 2196 2787,15 2286 238~.76 ?386 2492,92 2486 2596,q9 ~58b 270~.55 2686 2808,05 ~7R6 2915,6~ 2886 1 36 O0 200o,00 1 50 On 2100,00 5 3 OO 2200,00 9 20 OO 2300,00 13 44 O0 2400,00 15 49 O0 2~00.00 17 0 On 260n.o0 19 47 O0 2700.00 20 6 O0 2~00,00 90 3023,07 298b,00 2qo0,O0 21 55 3131,?0 30Bb,OO 3000,00 ~2 53 3~40.13 318b,00 31.00,00 ~3 50 3350,06 3286,00 3700,00 ~5 21 ~.45 ~386,0n 3300.00 76 58 3574;65 34n6,00 340n,O0 28 56 3690.15 35~6,00 3500,00 ~1 R 3808 47 3686.00 3600,00 ]3 27 3~30:05 ]7fl6,00 3700.00 ]5 47 4055.05 3~b,O0 3800,00 ~7 4~ $ 50 33 F. S 49 44 F S 47 4~ E S 47 49 E s 48 12 F. $ 48 26 E S 48 40 F S 48 44 F S 48 57 F S 49 18 E VERTTCAL DOGLEG RECTANGULAR COORDINATE8 HOR~Z, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST,~ AZIMUTH FEET DES/100 FEET FEET FE~T D~G MIN 0.00 0,00 -0.09 0,21. -0,31 0,27 o0.75 0,10 :1,08 0.21 -1.77 04 -1.03 ,37 '0.43 7 -0,41 :g.4 -0,75 -0,73 -0.52 0,53 2.13 3,92 0 lO 0 19 0 09 0 18 0 16 0 ~ 0 8'/ 0 26 0 14 0 O0 N 0 25 N 0 90 N 1 74 N 2 42 N 2 90 N 2 93 N 2 85 N 2 90 N 3 23 N 3 57 N 3 83 N 3 94 N 3 91 N 3 91 N 3 84 N 3 69 N 20 N 3 23 N 0,00 O~ 0,5! 0,67 0,74 0,86 1,10 1,67 2,22 2 54 E 2 71 E 2 65 E 2 50 E 2 39 E 2 35 E 2 51 g 3 48 E 5 52 E 7 98 E I. O, 9'1 34 3 O0 NN 15 26 14 lit ~ 3 05 16 2~ ". 21 3 3~ 29 4,75 ,.,o 6,34 8,6~ ~ 60 5,96 8,33 13.65 26,~0 46 53 73:80 102,60 136,]4 172.66 ?09,83 0 09 3 6~ 4 3O 0 26 3 $0 0 99 0 45 17 35 53 74 97 120 2 N 2 N t 55 N i~ 26 8 29 94 46 18 ~ 67 49 89 97 i 115 55 71 i i43 49 ,, iii O~ 210 t4 N 3 13 E 6 N ,? 49 E 53 38 i 41 97 S 249,07- 290,t8 333,36 428, 481,08 53~.85 60~,08 671,~1 746.20 071 I 08 I 21 I 36 l 1 82 I 91 145 47 S 203 49 E 250 15 S 54 26 E 291 18 S 53 51E 299 337 378 424 473 03 S 377 24 $ 420 96 $ 468 42'8 520 5t S 577 15 66 ~ 334 32 ~ 379 79 428 43 E 481 9 E 6 6 E 671 05 E 746 22 58 S 52 E ~1 SSl ]6E $ 51 17 E 46 8 $0 ]? E 38-10 KUPARI!K TRUE SUR-SER cnuRsF ~Eh$11RFD VERTICAl., VERTICAL DEVIATION AZIMUTH DEPTH D~PTH DEPTH PEG MTN PEG COMPUTATION DATE: 30=JUL-~5 PA~E 5 DATE OF SURVEY! 30 JUN 85 KELbY RUSHING EbEVATIUNI ENGINEERI bESNIE INTERPOLATE~ VAI,UFS FOR EVEN 100 FEET OF SUB-SEA DEPTH VERTTCAb DOGbEG RECTANGULAR COORDINATES HOR~'. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZiMUtH F~ET DEG/100 FEET FEET FE~ DEG s ~0 43 ~ 824,47 S 51 12 F S 51 30 r q81,23 ~ 51 44 E 1060,15 $ ~1 4~ F 1138 66 S 52 26 F 1216 78 S 52 33 ~ 1~95 92 S 53 6 E 1376 71 S 53 35 E 145~ 59 S 53 5 ~ 1540,77 4187.n5 3985.¢)0 3000.00 38 7 4309.16 4086.00 4000.00 38 7 4436,73 4195,00 4100.00 ~8 ~ 4563,66 4286.00 4900,00 38 30 4690.85 4386 O0 4]OO,O0 ]7 53 4817.P1 4480 O0 4400.00 38 9 4945,43 4586 O0 4500,00 38 41 5074.09 4bnb O0 4600,00 ]9 14 5203,48 4786 O0 4700,00 ]9 3~ 5333.08 4886.00 4800.00 39 5 5461,44 4986 O0 4000,00 ]7 44 5587 13 5086 O0 5000,00 37 22 5713 1,6 5186 On 5100.o0 37 39 5840 O1 5295 O0 5900,00 38 16 5967 69 5386 ON 5~00,00 38 30 6095 ~4 5486 O0 5400,00 38 R 6221. ~6 5586 O0 5500.00 ~7 20 634~ 38 5686 O0 5600,00 36 46 647~:66 5786,00 5700,00 6595,03 5885.00 5800.00 35 6716.88 59nb.00 5go0.O0 34 36 6838.~'? 60~6.00 OnOO.O0 34 695~,84 6186.00 6!00,00 33 52 7079,35 6286,00 o?O0,O0 3] 5? 7199,~0 6386.00 63(.)0,00 ~3 5~ 7250,00 6427,68 6]~,68 33 5~ $ 52 15 F 1621.08 S 52 16 E 1697.12 S 52 lq E 1773.71 S 52 2~ E 1851.61 S 52 27 g 1930,87 S 51 4~ E 2009,94 S 51 42 r 2087.52 SSl 25 F 2163.31 SSl lm F 2237.05 S 50 11F 2309.26 $ 49 45 E 2378,87 $ 48 57 E 2447,69 S 47 58 ~ 2515,04 S 46 49 ~ 258~,25 S 46 48 E 2649,34 $ 46 48 E 2677,30 0.39 0.49 0.'30 0.19 0.23 0.30 0,31 0.39 0.36 1,90. 3 08 0 53 0 42 0 38 0 42 0 73 0 64 0,85 0,71 0,90 o 0 8 0 39 0 58 0 O0 0 O0 86,00 FT 573 26 S 697 97 E . ,o, i ' 36 · 50 6~2 13 759 26 E 98 50 40 ' E , 44 , 50 768 O8 ~ 944 46 : so s2 914 26 137'92 , 51 12 963 07 i I .75 [ 459. , 204,18 t54{, ~ 5! 20 E 1011 83 1268, E $ 4 S 19 t622.{8 51 2 1058 43 S 1328, 1698,53 27 1105 41 ~ 1389,06 ~ 1775,22 ~ ~ 29 ,,,, o, ,,,,.,, oo 1576, 2011, 1298 05 1637.36 2089.47 2165,3~ 1391 16 1754. 1436 82 ~ 53 ~ I E 1810,51 2311, ~ 1863 75 2380.95 1916 15 1571 02 1966 52 2517, 16t6 51 ~ ~ O0 02 ~016 1662 47 2064 97 E 2651,02 A~Cn ALASKA, TN~o 3~-~o KIIPARI_IK NnATH S~,Ong,ALA~KA ~ARK~R TOP UPPRR SAND PBTD COHPU?ATI~N DATRJ 30-JUL-R5 1N?ERPO[,A?ED VALUES FOR CHOSEN HORIZONS PAGE DATE OF SURVEY1 30 dUN 85 86.00 r~ MRASUPBD nEPTH 6725,0~ 6940.00 70~6,00 7147,0~ 7250,00 nRIGYN= 202 FSL, 438 ?VD FROM KB SUB-SEA 5q92,69 6059.33 6170.36 6291.52 0342,17 6427.68 5906 69 5973 33 6084 36 6205 52 6256 17 6341 68 SURFACE LOCATZDN FEb. SEC 16 ?12Nm R9R, UM R£CTANGUbAR~CDORDZNATES NORTH/$OIJTH ~AST/WES? 1484.65 S 18 28 1619,05 $ IS 164;,~] $ 4~' 3R-10 KIIPARI1K NrJRTH $I,[3PE,ALASKA C~MPUTATZ~N DATKI ]O-JU6-B5 DATE OF SURVEYI 30 JUN KELLY BUSHING ELEVA~ONI ENGINEER= 86,00 FT ~ARK~R TOP UPPER 8AN~ BASF IIPPEP RANP BASF T,DWER SAND PnTD ~D 6'195,00 6940.0~ 70Rb,O0 7147.00 7250,00 SURFACE LOCk?ION nRTGIN= 202 FSL, 438 FEb. SEC 16~, ?S~N. RgE. UM · VD RECTANGULAR COORDINAT~ FRUM KB SUB-SEA NORTH/SOUTH ERSX/WE$T 5992.69 6059.33 6170.]b 6~91,52 6~42,17 6427,68 5906 b9 5973 33 6084 36 6205 52 6256 17 634~ 68 FINAL WET.L 6DCATTUN AT T~/l~ SUB-SEA MFASUrED VKRTICAL VERTTCAL DEPTH DKPTH DEPTH HnRIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MTN 7250,00 t427.6B 6341,6fl 2670,93 5 51 7 E SCHLUMBERGER O I RECT l ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3B- l 0 F I ELD KUPARUK COUNTRY USA RUN 1 OATE LOOOEO 30 JUN 85 REFERENCE 000070691 WELL NAME: 3B- 10 SURFACE LOCATION: 202' FSL, 438' FEL, S16, T12N, R9E, UM VERTICAL PROJECTION -BO0 0 0 . ~00 1000 1 ~00 ~000 ~$00 3(300 '.+-:'?4-=. eq-~..-'.'-+..?+."i-+"?*.-~'"-'*'+'+-~r-~~. ~. ~:~':~. '.'"+"~, ~.-'.'-'+'.~l"','t-:'-'?+-. '.'+'+.-~ ; ~ :"+'?-~'ff-~ ~ ~ i ? i ~ i ~'-t-, .~.?.~..v-~-1..~*.~-1~..~.~.~.?~.~7~r.~`....~7~7.~:~.~1.~}~.T~?~.T..v.1.. f-T-~ .?T.?-.?.}.-.~.T-...,..~...? ? , ? : '~ ? ? ! : ? ? .!.-J- ~ : : , ~ : . ~ ~ : · : ~ : ~ ...f-5-?-4...-~.-~-.%.~-.-~ ....... ?-? ....... 5..-½--.-.-..*.----.-~---.t ...... ,,---+--.?-.-.~--~.--?--?--..~--~-?-?-..~.. ?.-?..-?-. -.~--~---..?--..!...,---. .... ? ...... .-.-- ...... '~--.t.--,--,.-,----..t--? ........... ~...~ .............. ? ...... ? ........... ~.'-*- ................. PROJECTION ON VERTICAL PLANE 190. - 910. ~PI.F.O IN VERTICP~. OEP?HS HORIZ SCALE = I/S00 IN/FT 130. l,l:~r H 1~00 WELL NAME: 3B- 10 SURFACE LOCATION: 202' FSL, 438' FEL, S16, T12N, R9E, UM HORIZONTAL PROJECTION SCI:ICE -- 1/~00 IN/FT [ i I i i i i i ! i ! ~ { Iii! ~ ! ~ ! .: :, ~ ? ? ~ · · · ,~ ~ , = : ~ ; . = ; ; . , . . · ~~~?.U-T-W-; ~ .--,~.. q ~ ; , ~ , ; ;~ ~ ; :i ; ; ,~ ~ : : : : : : ; : : : ; ....~ : ; ; _~ : ; - ~ ~~ ! ; : ; , : ~ ; : ~ ; . . ' ; : ;: ~ ~ :: : ' ~: ~ : ; ~: .... ~ ~ .... ~~ .... : ~ s i ~ ! i ~ J~ · i i ~ ~ i ~ i i i iii: : : : . ; : ' ; : ; ..... ~~~ iii, ..... ~ ~ i, ~ ~i~ ..... ~~~~ ........ ~ .... ~ ..... : : : : ....... ~~yy : i i ~ i : : ~ ~ i i i ~~ : : : : '~'{"~'"J~'+'~"{--$l~'k!'-J"!-'~--5~'""'77Y"]: : :: [~ i i :'4': : : :_L~%..~-.L:...~.L..i...]...L--H(.-4--4..~ ...... +-.-} .......... ;'"?'5'j'"~ .......... t'-'"++"?'+"J":'"?'";.'"?' : : ....... l :...a...-._l ..{ .................................... y~.l. : : ;_~ ~ : : : : : . .I ~ ..... ~ ,.4 .............................. · "?F:"T"f"r":'":'": ...... : : : 7: : : :_.: ..... :.Z.:: i_%.~%-g~~++-+..[.-+-~-.?.-*-.*--+..-?~-'5"-{-: ...... ?"-r":'", .......... : ...... ?'":'": ...... :"'"'? ': · : · 4~5 ~:iii ::::::::::::::::::::::::::::::::::::::::: .... .... ; . ............ ............... *...:..-~--.,-.., ................ ZEE:: 7 ::::!: ..:_L~.~-..L;...~..~..:-+.-4-S:..~-~~+4-'~ ..... f~7-w~--~"m'-'~"t--:-:-r'~'"m-m":: :7: ' ~:: ::: -.~..;-: ...... ,.-.~..:.-.:-. OOO - 1000 -~ 0 G~ i 000 1 ~00 HE~T SUB. SURFACE DIRECTIONAL SURVEY F~UIDANCE ~]ONTINUOUS ['~OOL Company Well Name Field/Location Job Reference No_, 70691 Loqoed By; LESNIE ATLANTIC RICHFIELD COMPANY 3B-10,~202'. FSL, 438' _F_EL, S16, T12N, R~E. UM5 ,KUP ,ARUK~ NORTH SL,0PE, A~LASKA Oat__._~e 31-JULY- 1985 Computed 8~.' BOLAM ~ $~H6U~BERO~R ~ GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO AbASKA, INC, 3B-lO KUPARUK NORTH S60PE,AbASKA SURVEY DATE: 30 dUN B5 mETHODS n~· COMPUTATION TOr)6 bOC~TIOW: TANGFNTIA6- averaged deviation and azimuth !NTERPOLAT][UN: LIN~jAR VERTICAL SECTION: HORTZ. hiST. PROJECTED ONTO A TARGET AZIMUTH DF MOUTH 49 DEG 7 NIN EAST ARCO AbaSe'A, TN(', 3~-10 KI.!P~RIIK NORTH SLOPE,ALASKA TRUF ,KUR-SEA COItR~F ~EA$[IRFD V~RTICAL V~RTTCAL DEVIATION AZimUTH DEPTH DFPTtl DEPTH DEG MTN [.>EG MTN COMPUTATION DATE: 30-JUL-85 PAGE DATE OF SURVEYI 30 dUN 85 KELLY BUSHING EbEVAT%ONI ENGINEERI bE&NXE INTERPOLATED YALUE$ FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH ER&T/WEnT DISTi! AZIMUTH FFET DEG/$O0 FEET FEET FEET PEG MXN 0.00 0.00 -86,00 0 0 N 0 0 ~ 0,00 lo0,no lOO,O0 14,00 0 18 w ~2 4q E -0,10 20n,oo 200 00 114.00 0 30 , 5 50 ~ -0,~8 300,00 299:90 ~1~.09 0 26 ~ 1~ 46 E -0.81 400,00 309,9O 313,99 0 21 N 12 4R ~ -~,13 ~00,00 4q9,9o 413,99 0 5 H ~l 42 E -1,35 600,00 599,99 513,09 0 6 $ 65 5 F -1,25 ?00,00 699,99 61t,99 0 16 $ 89 11 E -0,98 ~00.00 799,99 713.q9 0 24 N 74 0 E 0,58 900,00 899,98 B13,08 0 18 N 47 44 E ~0.42 0 11 N 40 2i E -0,41 0 5 ~ 4 20 W '0,47 0 5 ~ 68 4~ W -0.59 0 4 S ~5 25 W -0,68 0 2 S ~4 25 W -0,75 0 ~ $ 1~ 27 ~ -0.73 0 21 S 49 34 E -0,44 1 I S 81 28 E 0.74 1 20 ~ ~7 41 F 2.37 I 2~ ~ ~7 36 E 4,18 100o oO 909,98 Ol] 98 110o'00 1.099 98 101]:08 1200~00 1199 98 1113,9B l~O0~nO 1299 98 171~,98 1400 00 1309 9~ 131].08 500:00 1409 ~ 141],08 ~600.00 1.599 151],08 1700,00 1699 97 1613,97 1800,00 1709 95 1713,~5 lqO0,O0 1809 92 1~13,02 $ 86 10 E 6.27 ~ 78 4 ~ 8,74 S 56 ! M 14,91. S 57 29 E 28,35 S 51 50 E 49.06 S 50 42 E 75,74 $ 49 4! E 103.4b $ 51 37 ~ 135, 48 $ 51 31 ~ 169,59 S 51 22 g 204,30 2000,00 1909 88 lO13,88 1 3& .21.00.00 2099 84 2013,a4 2 3 2~00 O0 ~109 61 2113,61 5 37 2300:00 ~208 66 271~,66 9 51. 2400 oO 9396 44 2310,44 14 11 2500 00 2402 81 2406,81 1.5 40 26OO O0 75~8 88 2~0~,88 17 ~ 2700 O0 2683 61. 2597,61 19 45 2800 O0 9777,b0 2691,60 20 4 2900.00 2871.37 2785.37 20 41 $ 50 30 ~ 240.49 $ 50 11 R 278,1.3 S 48 36 E 317,26 $ 47 22 E 357,85 S 48 4 M 400,66 S 48 18 ~ 445,73 $ 48 30 E 493.43 $ 4~ 41 E 543.94 S 48 44. F 597,43 S 48 57 E 653.74 3oO0.nO 2964,58 2~78,58 ?1 43 3100 O0 3057,22 2071.22 22 3] 3200 O0 3149,25 3063,25 23 28 3300 nO 3240,63 3154,63 ~4 36 3400 oO 3330.99 3244,09 26 3500 oO 34~0 25 3~34.75 ?7 37 3600 O0 3508 14 3422.14 29 24 3700:n0 3504 43 350~ 43 31 1 3~00,00 3678 97 359~02 3900.00 3761 55 3675.55 35 0 O0 0 08 0 21 0 20 0 29 0 30 0 O7 0,27 0,36 0,06 0,11 0,~8 O, ? 0,15 0,09 0 30 0 76 0 6~ 0 29 0 21. 011. 2 09 4 25 3 93 4 24 0 24 3 69 113 0 42 1 07 1 O0 I 31 I 30 1 83 111 1 49. I 91 i ,73 I 78 I 72 0,00 N O, 31 N 1,02 N 1 85 N 2 51 N 2 9] N 2 92 N 2 84 N 2 92 N 3 28 N 3 60 N 3:85 3,95 3 9t N 3 91 N 3 16 N 3 13 N 3 25 N 3 19 N 2 84 N 0 17 $ 7425 19 48 S 36 41 S 54 04 S 74 95 0,00 0,14 E 0 39 'E 0 53 E 0 69 E 0 74 E 0 88 E 1 17 E t 76 E 228£ 57 E 71 E 2 63 E 2 48 E 2 39 g 2 35 E 2 56 r, 3 72 E 5 85 Z 8 34 E i O6 E E 19 68 90 43 S 26 $ 168 07 E 02 E 06 E 05 75 E 52 E 170 71 ; 205 86,00 FT 245 34O ~7~ 412,95 S 507 02 S 196 86 E 241 50 S 54 ]4 g 92 E 279 15 $ 54 67 £ 316 96 S 55 8 35 61S 4 4 89 $ 464 69 E 358 41 E 401 Oi E 44' 9 E 544 79 g 597, 18 E 654 0 00 N 0 0 E 4 t6 E ARCO AbASKA, INC, ]R'tO KIIPARUK NORTH SLOPE,ALASKA COMPUTATION DATE: 30-JUL-85 PAGE DATE Or 8,URVEYI 30 JUN 85 KELbY BUS,HING EbEVATION{ ENGINEERI bESNXE 1NTERPObATED vAbUF$ F~R EVEN 100 FEET OF MEASURED DEPTH S 52 1~ E 1950,94 S 51 48 E 201~.88 S 51 46 E 2074,21 S 51 34 E 2134,84' TRU~ SUR-SEA COUPS~ UEASIIRFD VERTICAl, VERTICAL DEVIATION AZIMUTH DEPTN D~PTH DEPTH DEG MIN D~G MTN 40(')0.00 3842.29 ~756.99 ~7 0 $ 49 P E 712.74 4~00,o0 ]99~,45 3835.45 ~8 3 $ ~9 42 F 77~.84 4~00.00 4000.12 3~1~.~2 ]8 8 S 50 48 F 8]5.55 4]00.00 4078.7g 3o9~.79 ]8 7 S 51 9 E 897.~5 4400.00 4157 4Q 407~.49 ~8 ~ S 51 26 ~ 958.g0 4500.00 42]b:~4 4150,~4 ]8 17 $ 51 27 E X020.61 4600.00 ~3~4.44 4~28,44 38 21 S 5i 39 ~ 108~.74 4700.o0 ~393 22 4~07,22 37 54 S 51 47 E 1~44.27 4800,00 4471:9q 4385.99 ~8 7 S 52 21E 1205.80 4900.00 4550,5~ 4464,51 ]8 30 $ 52 ~] E 1~67,62 530n,00 4860.3~ 4774,~8 ~g 2~ S 53 44 E 1519,91 550n O0 5016.6~ 4g30 67 ~? 16 S 52 1~ E 1~44,42 560~00 5096.2~ 5~10~2 3~ 24 $ 52 1~ E' 1 04.92 5~00.00 ~175.57 5n8~,57 ~ ]6 ~ ~2 lg R 1765,88 5800 O0 5254 56 5~6~,56 38 5 N 52 2~ F 1826,92 5900~00 53~3~0~ 5~47,n3 ]~ 27 $ S2 2g ~ 1888,80 600~,00 5.4~1,3o 5325.~0 38 27 610 ,00 ~4~9.74 5403.74 38 6 6~00,00 5568,67 5489,67 37 3~ 6300.00 5648,14' 5569.14 37 7 6400.00 5728.2K 564~,~5 36 24 S 51 29 E 2194.65 6500.00 5808 90 572~,90 ]6 7 S 51 K E 2~53.74 6600 00 589(3:06 5~04.06 35 ].1 $ 50 9 E 2312.~2 6700'00 5972.1~ 5~86,11 34 3~ $ 49 44 F 2369.~9 6800:¢)0 R054,3~ 5968,38 34 2B S 49 28 E 2426,13 6900.00 6137,18 6051,{8 33 55 - S 48 21E 2482,{9 7000.nO 62~0,18 6134,18 33 5~ S 47 35 E 2537,95 7!00.00 6303.15 6217,~5 33 52 $ 46 48 E 2593,75 7~00,00 6386.17 6~00,17 ~3 5~ $ 46 48 ~ 2649,45 7250.00 6427.69 6~41,68 33 52 $ 46 48 E 2677,~0 86,00 FT VERTICAL, DOGbEG RECTANGULAR COORDINATES HDRXZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WES,T DXS,T,' AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MXN 1.65 0,24 0,40 0.17 0,72 0,81 0,22 0,36 0,68 0,73 0,22 0,38 1,49 0,35 0,44 O,2g ~,61 0 64 0 82 0 81 0 59 0 74 0 58 0 82 0 41 1 2t 0 ,53 1,11 0,00 0,00 0,00 49. 47 8, 59 53 8] S 645 646 66 S 90 685 25 S 8]8 723 48 8, 887 761 37 $ 935 799 07 8, 984 837 08 S 1034 875 04 $ 10 85 912 950 988 1026 1063 1100 11 62 S i! 59 8, 121 ~7 S 12 1 8, 133~ 49 8, 1382 43 96 8, 14810 718,1 1213 63 8, 152 0 8, 1626 1364 74 S 1721 1401 62 $ 1767 1438 1475 15!2 1549 1586 1624 1662 1681 65 8, 1812 47 8, 1856 22 S 1899 lO 8 1942 72 E 713'01 S 50 41 E 06 E 774 09 S 50 35 E 62 E 835 82 S 50 34 E 11 1 87 E 1083 17 E 1144 75 E 1206 88 E 1268 0 S 50 42 E 18 S 50 45 E 77 S 50 48 g 36 $ 50 51 E 26 S 50 56 E 58 E 1.330 81 S 51 I E 05 F, 1393 92 $ 51 6 E 96 E 1457 37 E 1521 72 E 1584 64 E 1645 61E 1706 70 E t767 27 E 1828 42 E 1890 36 $ 51 12 E 03 ,5 51 19 E O7 $ 5 1 23 g 5'1 25 E 34 S 51 27 g 19 IS 51 29 E S 51 30 E 49 ;5 51 32 E 78 E 1952 73 S 51 34 E 65 E 2014 75 8 51 35 E 90 E 2076 321:2 54 £ 2255 71£2 8t £ 2428 O4 £ 2484 14 IS 51 35 g IS 51 35" 69 8, 51 35 '~ 83 S 5! 35 E 23 S 51 3.t g 37 $5! $ 5 E 39 8, 1,983,5! £ 2539,87 S 51 20 E 39 8, 2024,41 1:2595,56 $ 51 15 E 63 8, 2085,37 g 2678, $ 51 7 E ARCO ALASKA, TNC, NORTH $[,[)PE,AT,ASKA TRUE S{JR-SEA C~UPSM ~EASlIRF{) VERTICAL VERTICAL DEVIATION AZIMUTH DEPTU D~PTH ~EPTH DEG M~N PEG M?N COMPUTATION D~TE: 30-JUL-B5 PAGE DATE OF SURVEYI 30 jUN ~5 KELbY BUSHZN~ EbEVAT~ON[ ENGINEERS hESNIE INTERPOLATED VALUES FOR EVEN ]000 f'EET OF MEASURED DEPT VERTiCaL DQGbMG RECTANGUbAR COORDINATES MO~g, SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST, FEET DEG/100 FEET FEET FEET N o o ~ 0,00 N 40 21 E -0,41 S ~0 3g ~ 240,49 ~ 49 ~ ~ 712,74 S ~2 47 ~ 1330,08 S 52 13 E 1950,94 $ 47 35 E 2537,g5 S 46 48 E 2677,30 0,00 0 00 -86,00 0 lO00.O0 9q9~gR 913.q8 0 11 2000,00 1999.8~ lg13,88 1 36 ]OOO.O0 2964.5~ 2~7R,58 21 4] 4000,00 38~2,2q 3756,79 ~7 0 5000.00 4~28.57 4542,52 38 5g 6000,~0 ~4~1,30 5325,30 38 27 7000.O0 6220.1~ 6~34.~8 33 52 72b0,00 64~7,b9 6341.68 33 52 0,00 0,11 O,ll 1 O0 I 65 0 64 1 11 0 O0 0 O0 N 3 bO N 2 57 E 4 3 19 N il O6 E 11 140 02 $ 196 86 E 241 451 65 S 551 72 E 713 837 08 S 1034 58 E 1330 1213 63 S 1529 7R E 1952 1586,3q S 1983 51E 2539 1681,6] $ 2085 37 E 2678 86,00 FT DEPARTURE AZIMUTH DEG MZN 0,00 E 0 O0 N O 0 E 43 N 35 31 E 5i N 73 54 E 58 S 54 34 ~ Oi S 5O 41 73 S 51 34 E 87 $ 51 20 E 93 S 51 7 E A~Cr') AbASKA~ TNC. 3IR- 10 KI, iPARI~K NORTH SLUPE, ALASKA ~RU~ SU~-5£A COUR$~ DEPT~.; D~PTH DEPTH DEG MTN D~G SIN COMPUTATION D~TE: 30-JUL-85 PACE 4 DATE Or SURVEY! 30 dUN 85 KEbLY BUSHING EbEVATIONI ENGINEER{ bESNXE INTERPOLATED YA[.U~S FOR EVEN 100 FEET DF SUB-SEA DEPTH VERTICAL DOGbEG RECTANGULAR COORDXNATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST RZZMUTH FEET FEET FEET' DEG SIN FEET DEG/IO0 / 0.00 O.On -86.00 0 0 N 0 0 E 0.00 0.00 0,00 N 86.00 86.00 0.00 0 17 N 30 17 E -0.09 0 21 0.25 N 186.00 186 On 100.00 0 31 ~} 8 3~ F -0.31 0~27 0,90 N 286,01. 2Rb~00 200.00 0 27 N 14 37 E -0,75 0,10 1,74 N ]86 O1 3~b. Oo ]00.00 0 23 ~ 10 30 ~: 1.08 0,21 1:42 W 486:01 486.0O 400.00 0 ? N 7 1~ ~ ~1.34 0,32 90 N 8 .o1 u 6.0o soo,no o 6 69 4 0,04 ]:91N 686.O1 686.00 600,00 0 14 $ 83 23 ~ -1,03 0,3~ 85 N 786.0! 7R6 00 700.00 0 23 N 78 15 E -0.64 0,10 ~:90 N 886.02 886:00 800.00 0 18 ~ 48 30 ~ -0.43 0,07 2] N 986 O0 qo0.O0 O0 1000.00 O0 1100.00 O0 l~0n.no O0 1]00,00 O0 1400.00 O0 1500,~0 O0 1600,00 O0 1700.00 O0 1800.00 0 12 W 38 4i ~ -0.41 0 6 ~ 3 13 ~ -0,46 0 5 ~ 57 57 W '0,57 0 5 S 72 51 W -0.66 0 1 $ 61 39 W -0,75 0 3 S 16 34. W -0,73 0 16 S 47 56 E -0,52 0 56 S 7b 4~ ~ 0,53 I 19 N ~B 40 E ~,1,3 1 2~ N ~7 20 ~ 3,92 1086.02 10~6 1186.02 11~6 1286 02 1.286 1386.02 1386 1486.02 1486 1586.02 1586 1686.O3 16R6 1786.05 178b 1886.08 1886 1 36 1 50 On 2100,00 5 3 O0 2200.00 9 2n On 2300,00 13 44 O0 2400,00 15 49 O0 2~00.00 17 0 O~ 2600.00 19 47 O0 2700 O0 20 6 O0 2~00~00 ~0 51 S 86 38 E 5 96 $ 8O O E 8:33 S 55 47 ~ 13,65 $ 58 0 E 26,20 S 52 25 K 46.53 $ 50 40 ~ 73.80 S 49 45 ~ 102,60 R 51 38 F 136,]4 S 51 31 E 172,66 $ 51 18 ~ 909,83 1986.11 198b O0 lO00.O0 2n86 15 2086 O0 2000.00 2186'33 ~lRb 2380,76 ~3~6 2492,92 2486 2596,q9 7586 270~,55 2686 280~,05 ~7~6 2915,6~ ~886 3023.07 2986 O0 2qo0,O0 ~1 55 3131.?0 30~b On 3000.00 22 53 3~40.13 31~6 O0 3100.00 ~3 50 00 3?00,00 ~5 21 on 3300,00 76 5R O0 3400.00 28 56 00 3500.00 tl n 00 3600,00 33 27 00 3700,00 ~5 47 O0 3800,00 ~'1 45 S 50 33 ~ 249,07- S 49 44 ~ 290 18 $ 47 4~ E ]33:36 S 48 12 ~ 428. O3 S 48 26 E 481,08 S 48 40 E 538,85 $ 48 44 ~ 60~.08 S 48 57 F 671,~1 S 49 18 E 746,20 3350,06 3286 3461,45 3386 3574.~5 34n6 3690.15. 3586 380~.~7 3686 3030.05 37~6 4055.05 3B~b 0 10 019 0 O9 0 18 0 16 0 0 87 0 26 0 09 4 3O 0 26 3 §0 0 99 071. I 08 1 21 1 36 1 88, 1 82 1 91 1 75 1 77 1 06 3,57 N 3,83 N 3.94 N 3 91 N 86,00 FT 3 91 N 3 84 N 3 69 N 3 20 N 3 13 N 3 23 N 3 22 N 292N 055N 6 296 S 17 48 18 53 ~ 18 53 N 88 18 E 29 24 g 29 90 S 77 54 46 O1 E 49 38 S 68 41 < 35 18 S 67 16 ~ 75 82 $ 62 20 E 99 O] $ 377 4] E 481 53 $ 51 36 ~ 337 24 $ 420 76 E £ 602 539113 51 17 78 473 51 S 577 05 E 746 46 S 50 37 E 0 00' E 0 O0 N 0 0 E 0 10 E O. 27 N 21 43 E 0 37 E 0 97 N 22 34 E 0 51 E 1 81 N 16 14 " 0 67 E 2 52 N i5 26 0.74 E 3 O0 N 14 18 E 0,86 E 3 05 N 16 20 E 1,10 g 3 05 N 21 7 E 1.67 ~ 3 35 N 29 _5! E 2,22 E 3 92 N 34 33 E 54 E: 4.38 N 35 2-8 E 71 E 69 N 17 E 50 £ ,64 98 E 8' 34 ,61 N 6~ 5 E lO 6~ E 4 N 3 E ARCO AL/~SKA, TNC, 3R'IO KIJPARIIK NORTH SLOPE,AI, ASKA COMPU?ATIDN DATEI 30-DUb-05 DATE OF SURVEY! 30 dUN 85 KELLY BUSHING ELEVATZONI ENGINEERI LESNXE INTERPOLATED VA[,UES FOR EVEN 100 FEET OF SUB-SEA DEPTH ~EA$I~RFD VFRTICAI, VERTICAL DEVIATION AZIMUTH DEPTH DFPTH OEPTH DEG MTN DF_,G MIN 4187.n5 398b.00 3qO0.O0 38 7 4309.16 4086.00 4000.00 38 7 4436.?3 41Rb. O0 4100.00 38 7 4S63.66 42~6.00 4?00.00 38 30 4690.~5 43,6 00 43on.00 37 53 4817.~! 4486 00 4400.00 38 9 4q45 43 45~6 00 4500.00 38 41 5074:09 4bRb O0 4600,00 39 14 5203 48 47~6 O0 4700.00 39 3~ 5333:o8 488b.0o 4800.00 39 5 5461 44 49~6 00 4000.00 37 44 13 5ORb O0 5000.00 37 22 OO 5100.00 37 39 00 5~00.00 38 16 00 5300.00 38 30 00 5400.00 38 O0 5500,00 .t7 2q 00 5600,00 36 46 O0 5700,00 00 5800,00 35 13 571 16 5186 5840 O1 52~6 5967 69 5386 6095 ~4 54~6 6221 86 5586 634~.38 5686 647~.66 5786 6595.03 5880 6716.88 59~6.00 5900.00 34 36 6830.27 6086.00 6n0o.o0 34 o 6958.84 6X86.00 6100.00 33 52 7079.35 6286.00 6~00.00 33 52 7199,80 6386.00 6300.00 33 52 7~50.00 6427.68 634~.68 33 5~ PAGE 5 86,00 FT ,. VERTTCAL DOGhEG RECTANGULAR COORDINATES HORXZ,,, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DXST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG ~XN $ 50 43 E 824.47 S 51 12 E 90~.91 $ 51 30 F S 51 44 E 1060.15 S ~1 45 E 1138 66 S 52 26 F 1216 78 S 52 33 E 1~95 92 S 53 6 ~ 1376 71 $ 53 35 E 145~ 59 S 53 5 E 1540,77 $ 52 15 F. 1621.08 $ 52 16 E 1697.12 S 52 lO E 1773.71 S 52 28 E 1851,61 S 52 27 E 1930.87 S 51 48 E 2009.94 S 51 42 E 2087 52 S ~1 25 E 2~63:~1 S 51 1~ E 2237,05 S 50 11 F 2309,26 $ 49 45 E 2378.87 S 48 57 E 2447.69 S 47 58 E 2515.04 $ 46 48 £ 2582.25 S 46 48 E 2649 34 S 46 48 E 2677:30 0.39 0,49 0.30 622 0,19 671 0,23 720 0,30 768 0,31 816 0,39 865 0,36 914 1,90 963 523 82 S 637 03 E 824 74 $ 50 34 E 573 26 S 697 97 E S 50 36 E 13 S 759 25 S 821 O0 S 882 08 $ 944 3O S 1007 20 S 107 26 S 113{ 07 S 1204 903 26 E 98 t3 E 106~ 76 E 1 ~ 39 E 12 6 92 E !377 75 E !459 18 E 1541 {~ S 50 40 E ~? S 50 44 i5 S 50 47 $ 50 52 E 61 S 50 58 E S 51 5 g 57 $ 51 !2 g gl S .5120 g 3 O8 0 53 0 42 0 38 0 0 64 0,85 0~?~ 0.90 01 1log~ 1105 1298 1345 1391 14116 41S t389 O1S 1450 36 $ 1513 O0 $ 1576 05 S 1637 8 S 1696 6 S i754 82 S 1810 19 E 1622 43 E 1698 06 E 177I 89 E 185 87 E 1911 36 E ~0 80 E 2165 §3 E 2239 51E 2311 38 $ 5! 24 E 53 $ 51 27 E 22 S 51 29 g SS1 IIE 80 S 51 35 E 47 S 51 35 ,33 851 3 o. 6 O. 8 0,39 0,5~ 0,00 0,00 1481,67 S 1863 1526,29 8' 1916 1571,02 S 1966 161 ,51 S ~Ot6 1662,47 8 2064 1681,63 8 2085 ,75 E 2380.~! $ 5~ 30 E ,15 E 2449. $ 5 27 E ,52 E 2517,0 S 51 22 ~ .02 ~ 2584.08 S 5' 1~ ' , 7 E 267 ,93 S 5! 7 g ARC(n ALASKA, TNt. KIIPARIIK NI~RTt4 Si,OPE,ALASKA UAPKER TOP UPPFR SAND BASF I]PPE~ SAND 7'DP bnwFR SAND BASF t,O~E~ SAND COHPUTATI~N DATE: 30-jUL-R5 PAGE 6 DATE OF SURVEYI ]0 JUN ~5 KELhY BUSHING E~EVATXONt 86,00 FT INTERPOI,ATEh VALUES FAR CHOSEN HORIZONS M~ASbPED DEPTH FROM KB nRIG]N= 202 FSL, 438 SUB-SEA SURFACE LOCATION AT R£¢TANGUL, AR Ct)ORPtNAT~$ NORTH/SOUTH EAST/WEST 6725.00 6806.00 6940 O0 70~6,00 7147,00 7250,00 509~.69 6059.33 6170.]6 6291,52 b342,17 6427,68 5906 bq 5973 33 6084 3~ 6205 52 6256 17 6341 68 1514,42 S 02 1563,99 $ 1958 1619,05 S 2018 1642,33 S 2043 1681,63 S 2085 40 E E' KIJPARUK NORTH $I, OPE,A[,ASKA C~MPU~A~ION DATF~ 30-jUL-B5 PAGE DATE OF SURVEYt 30 dUN B5 KEbLY BUSHING £bEVATZON{ ENGINEERI LESNZE 86,00 FT ~ A R K F, 61 TOP UPF~R SAND BASF llPPEP SANL) TOP LPW~.'t.R SAND BASF I, OWER SAND P~TD Tn MEASURED FR~ KB 7~5i00 5992.69 B¢~6 O0 6050.33 ~940 O0 6170.]6 7086.00 6~9i.52 7147,00 634~.17 7250,00 6427.68 SURFACE t, OCA'riON ~]R{GIN: 202 ESL, 438 FEL. SEC i6~ ?12N., RgE, UM TVD RECTANGUbAR COORu~NATES SUB-SEA NORTH/8OU~H 5906 69' 5973 33 6084 36 6205 52 6256 17 6341 68 1484 65 6 1514 42 $ 156] 99 S 168! 63 S 1~67 28 E 40 E 20i8 72 g 2043 E FINAL WEI,L TRI,.IF SUR-SEA MEASURED VERTICAL VERTICAl, DEPTH DEPTH DEPTH HDRIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7250,00 6427,68 6341,6~ 2678.93 $ 51 7 E ,, , SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY- ARCO ALASKA INC WELL :3B- 10 F ! ELD KUPARUK COUNTRY USA RUN 1 DATE LOOOED 30 JUN 85 REFERENCE 000070691 WELL NAME: 3B- 10 SURFACE LOCATION: 202' FSL, 438' FEL, S16, T12N, R9E, UM VERTICAL PROJECTION -~00 0 0 . ~00 1000 isoo zooo ~oo ~ooo ~oo r L ~ :.- i :- i ; i i i i .: ~ i i .: :'T--t'..: :.:? .?-t --t-.t--~.-..*-.---?? ? 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' [ ! ! ~ i i i i i i ~ .4~..i. ..... 4,...,i-4--.i.-,t-4-.;,.-,~--.b- .-4-4....4...,k- +-hH+f.+H-;:-.-~-~+~-,+i, J J [ [ [ [ i ii I I il l ii i-.f-+f++--,-f-+-H2~H+,..-H++--H-H~ +H--i'.;--+.H+- '-?.-P-.'.*-.f": .~. f-d---':*-?!-Hf"t"~'~ '"??'."~ .-~.-' "~:' [ J :: { ~ [ ~ [ [ [ i'.-~,~' t.' ~ ~ i ~ :: i"i' t"'?f""~'ff ....... t'~.:-f"t'"t'ff-+?' _.t 4-..~ 4- '.-.4-,; 4 :~; .,i-~~- ' ~- ~ -4-; ,~ ,; ,~-~-11--4-4-.4-4 --.~.i-4-.4-- ~' : : ~.i~--i-4..4-,~ -4 4-4-~ 4 .-;....;- ,i-- · i...~..4. ~ ;--;...*.-; ..... ;...; ..~. ~ ..... i--4..4-. ~ .... ;...~...~.,.~.,. · -.,~-J....-~.?-t---~-?--?-.~ ..... ?-?-.-?-.-?-.-+.-?-.-.+---..t--?.-.-?-?---?--.?--i.-?~,~.--~. -?--- ~ ? : ...,~?..? ...... t.~.~?..?...1...?..l?..~_? ...... ?_~...?,.?_?..l?...?...,.~~ ...... ?"'?'"?'"~'"t'"?"'?l"?l"?''' ''?'""'r'"?''?"J" ?'"?--'~"'? .-bbbb:...--:--.:---:--;---:---:.--~-.-~---:-.bb:-:..: ..~.b~--.bb:..-~-:l+'..14..~ '4.~-4--:---:.:-i4-.-~-~44:4 ...... :.:..:..:..-:.'..b:l:.-.:l ':'''':'ll:'l'bLi''~'':'''i ....... ~'''!4'';''Ll:'''~''':'''il'' %'H'+'i--''t'''H ....... H'''f''H--'t+fi ..... H''H'''H':'~--~::::'--h--hH--H--f'i+f''['f''f''f+'H''f+': .... H--.f..f.-?.-.f.'H..,.%t-H."f"f'%.t ::::::::::::::::: :::::::::::::::: ::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::: -BO0 0 SOO 1000 1500 2000 2S00 3000 E~T Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. 'OP'ERATOR~ WElL NAME/AND NUMBER · Date · Required Date Received Remarks Completion Report ye~~ f _~ _~.~ ~~. Samples ' Mud Log _ Core Chips Core Description Incli~ation Survey ARCO Alaska, In¢ Post Office ~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NU:5292 tLETURN TO: ARCO aLASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED kECEIPT AND KUPARUK WELL PRESSU lB-1. 05-30-S5 ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE lB-2. 05-30-85 ~lB-4- ' 05-16-85 ' 1C-4 07- 24- 8 5 CAMCO 1C-6-' 07-25-85 CAMCO - 1D- 8 -~ U 7- 3 0- 8 5 CAMCO --1H- 3 07- 30- 85 CAMCO ~' lQ-13'~ 06-24-85 CAMCO ~'lQ-14-~'~ 06-23-85 CAMCO "lQ- 15' O 6- 2 1- 8 5 CAMCO ~'lQ-16~" 06-21-85 CAMCO ~ 1R- 5'~ ~ 07- 05- 85 CAHCO 1R-6 --~ 07-06-85 CAMCO / ~' IR- 7~ 07- 06- 8 5 CAMCO -1R-8 ' 07-08-85 CAMCO ~2A-2-'' 07-04-85 OTIS ~2W-7- 07-26-85 DRESSE~{ ~2V-3 07-11-85 OTIS ~-2W- 15"' 08-04-85 OTIS 3B-1 06-14-85 ???? 3B-2~-" 06-14-85 CAMCO 3B-3''~ 06-28-~5 OTIS ~3B-3' 06-15-85 CAMCO --3B-4- 06-15-85 CAMCO ~3B-5 -" 06-26-85 CAMCO ~ 3 B- 6'" 06- 26- 8 5 CAIn]CO --3B- 7- 06-28-85 CAMCO 3B-7~ 06-27-85 CAMCO ~ 3B-8~ 06-28-85 OTIS --3B- 9~' 07-18- 85 CA~CO ~3B-10 .... 07-20-85 CAMCO ~3B-11 -- 07-20-85 CAMCO ~3B-12--~ 07-21-85 CAMCO 3B-13. 05-29-85 OTIS ~'3B-14 05-29-85 OTIS RECEIPT ACKNOWLEDGED: HEREWITH RETURN ONE SIGNED RE REPORT--ENVELQPE FACE DATA CAMCO '~3B-15 CAMCO 3B-16---~ CAMCO ~ 3C-11~" DISTRIBUTION: LLING W. PAShER JOHNSTON EXXON IL* PHILLIPS OIL* CLERK J. RATHMELL* COPY OF THIS TRANSMITTAL. 05-28-85 OTIS 05-28-85 OTIS 07-29-85 CAMCO BPAE* DRI B. CURkIER L. CHEVRON* ~B D & M* NSK ': ~!¢.sk¢ Oi! & 6~s Cons. commLsion D~: Al2.sk¢ ~~2~ STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alask,3 Inc. ~s ,3 Subsidiary of AllanticRJchfieldCompany STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO~-~-iISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: JJaska 0~:1 and Cas Ccn,,:erv,~tion Ce~m~dssior SOO1 Porcuvine Drive Receipt of the following material /¢=: / which was transmitted via is hereby acknowledged: DATED: Copy sent to sender YES NO _~ STATE OF ALASKA ALASKA oiL AND GAS CONSERVATION CO~,i~ISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 Oua: State ska Oi~ and r,.. ,-- ~a2- k.onservaacn Co~s~o~ 300] ~orcupine Drive Receipt of the following material which was transmitted via ~i/ is hereby acknowledged: qUANTITY RECEIVED: DATED: Copy sent to sender YES NO Z_ ARCO Alaska, Inc. Posl Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-08-85 TRANSMITTAL NO: 5285 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING ~xE CO~xDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~ ACKNO~LEDGE JF~ANSMITTED HEREWITH ARE THE FOLLOWING IT~/4S. ~ECEIPT AND RETURN ONE SIGNED COPY OF THIS TKANSMITT~L. BOX 1 OF 2: 3PEN ~OLE LIS TAPES PLUS LISTINGS (ONE COPY OF EACH) ~C-11 06-23.-85 RUN %1 4427.5-8881.5 REF #70597 ~C-10"' 07-02-S5 RUN ~1 1785.0-8987.5 ~EF #7U620 ~C-9 -~" 07-10-85 }{UN ~1 3920.0-8332.5 REF #70642 ~C-7~ 07-31-85 RUN #1 4617.5-8747.5 REF #7U706 ~B-14- U3-20-85 RUN #2 3280.0-6~03.5 H~F #70229 ~B-12" 07-03-85 RUN #1 4021.5-8261.5 kEF #70641 3B-11~' 06-26-85 RUN #1 2190.5-9257.0 REF #70598 3B-10~ 06-17-85 RUN #1 3273.0-7270.5 ~EF #70555 3B-9-'-- 06-10-85 RUN #1 2092.0-8415.0 REF #70634 2Z-15'" 06-19-85 RUN #1 2658.0-6620.0 REF #70562 2Z-14/ 06-28-85 RUN #1 3876.0-8334.0 REF #70600 !Z-13~ 07-05-~5 RUN #1 4180.0-8538.5 REF #70639 iZ-12-'- 07-20-85 RUN #1 4409.0-9412.5 REF #70661 ~Z-11,* 07-27-85 RUN #1 3531.5-7534.0 REF #70704 BOX 2 OF 2: !PER_HOLE LIS TAPES PLUS w-16~-~' 01-28-85 RUN # ~V-14'/ 05-16-85 I~UN .V-12~f 04-22-85 RUN U-10~ 04-11-85 RUN U-7/ 03-1-9-85 HUN a-13/~ 07-16-~5 RUN R-13'/ 07-27-85 RUN R-12 ~ 07-20-85 RUN #1 R-11 ~ 07-13-85 RUN #1 R-10~''/ 07-06-~5 RUN #1 R-9// 06-28-85 RUN #1 R-7/ U6-04-~5 RUN #1 LISTINGS (ONE COPY OF 1 3116.0-7038.5 KEF 1 3047.0-7 086.5 REF 1 3960.0-9265.0 REF 1 2972.0-7063.0 liEF 1 3594.5-8179.5 REF &3 7649.5-8160.0 liEF 3940.0-8578.0 REF 3935.0-8277.5 3810.0-7213.5 2991.0-8738.0 REF 3991.5-8131.0 REF 0045.5-7103.0 kEF ~ 7 0436--- REVISED ~ 7~ 614---REVI SED # 7 0613---REVISED # 7 0612---kEVI ~ED # 7 0505---iiE'VISED --' #70645 #70702 #7~660 #7U643 #70640 #70601 #70509 ECEIPT ACKNOWLEDGED: PAE · CURRIER .iEVRON & M D~<ILLING L. JOHNSTON MOBIL NSK CLERK DISTIiIBUTION: W. PASHER EXXON PHILLIPS OIL J. RATHMELL DATE: -- -~,, ~ons. Commission STATE OF ALASK'A*-'~ SOHIO UNION K.TULIN/VAULT TO: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 transmitted via is hereby acknowledged: Alaska Oil and Ca~ Conrerx'afion Commission Ancl~or;i:e, Al:t~Xa 99~01 Receipt of the following material which was QUANTITY DESCRIPTION /CCC--' RECEIVED: DATED: Copy sent YES EO sender STATE OF ALASKA ALASKA ~:iL AND GAS CONSERVATION CO~';.~iSSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: State_ o{ .Maska AlaSka 0]1 and C::: Conservation Commission 3001 Porcupine Drh'c Anchorage, Alaska 99501 RE: Receipt of the following material which was transmitted via .,,,~f.,.~ // is hereby acknowledged: ~UANTITY DESCRIPTION RECEIVED: DATED: Copy sen: to sender ARCO Alaska, Inc. Post Office Bo. 3360 Anchorage, AlaSk~ 99510-0360 Telephone 907 276 1215 June 15, 1985 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 the June monthly reports for the following wells' 3B-9 3C-11 2V-16 9-33 L2-20 3B-10 3C-12 2Z-14 9-34 L2-24 3B-11 1R-7 2Z-15 11-8 4-13 3B-12 1R-8 2Z-16 11-13 11-5 3C-10 1R-9 4-30 L1-10 11-6 (workover) (workover) (workover) If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L63 Enclosures RECEIVED 3 U L 1 5 19~5 'Alaska Oit & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCornpany STATE OF ALASKA ALASKA O,.- AND GAS CONSERVATION CO,~.~,IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-114 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21368 202' 4. Location of Well at surface FSL, 438' FEL, Sec.16, T12N, RgE, UM (Approx) I6. Lease Designation and Serial No. ADL 25633 ALK 2566 5. Elevation in feet (indicate KB, DF, etc.) 85' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3B-10 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. June ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2015 hrs, 6/11/85· Drld 12-1/4" hole to 3330'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7250'TD (6/16/85). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7147'. Secured well & RR ¢ 1045 hrs, 6/18/85. Arctic packed on 7/4/85. 13. Casing or liner rgn and quantities of cement, results of pressure tests , 16" 62 5#/ft, H-40, weld conductor set ~ 95' Cmtd w/227 sx PF "C" 9-5/8" 36 O#/ft, J-55, BTC esg w/shoe ~ 3309' Cmtd w/lO00 sx AS III & 300 sx Class O 7" 26 O#/ft, J-55, BTC csg w/shoe ~ 7232' Cmtd w/500 sx Class C & 250 sx AS I 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/7244' - 3309' FDC/CNL/Cal f/7244' - 4982' RFT (depths not available at this time) 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED. I~~'~~ TITLE Associate Engineer DATE NOTE -Report this form 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 the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP/MR76 Rev. 7-1-80 Submit in duplicate June 3, 1985 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3B-10 ARCO Alaska, Inc. Permit No. 85-114 Sur. Loc. 202'FSL, 438'FEL, Sec. 16, T12~, R9E, l~. Btmho!e Loc. 1478'FN~, 1503'FWL, Sec. 22, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for pe~it to drill the above referenced well. If coring is conducted, a brief description of each core and a one cubic inch size chip from each foot of recovered core is required. Samples of drill cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying e×cept experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS.46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Mr. Jeffrey B. Kewin .. Kuparuk River Unit 3B-10 -2- June 3, 1985 To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment befot-e the surface casing shoe is drilled. ~fhere a diverter system is required, please also notify this office 24 hours prior to com~nencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. .... p!ease give this In the event o~' suspension or abandonment, ~_ office adequate advance notification so that we may have a witness present. Very tru%y ..~rs, .~"'~ / , / /: t wi I/ ,; ~ / ~ _..-'1 //~, ~. ~ .. //?.-: . .. /~ \ '/ , 1.'//.',6,/~ : /,?! ' "----~ >' "--'l~';/ ,' Chairman of Alaska Oil and Gas Conservation Cormmission BY OR_DER OF 17!E COPR4ISSION Enclosure cc: Department of Fish & Game, Habitat Section w/o enct. Department of Environmental Conser~ation w/o encl. Mr. Doug L. Lowerv ARCO Alaska, Inc. Post Office Go.. ~00360 Anct~orage, Alaska 99510-0360 -Felepiione 907 276 1215 May 22, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3B-10 Dear Mr. Chatterton: Enclosed are: o We estimate spudding this well on June 15, 1985. questions, please call me at 263-4970. Sincerely, An application for Permit to Drill Kuparuk 3B-10, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore A proximity plat Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment If you have any Area Drl lng Engineer JBK/TEM/tw PD/L96 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany RECEIVED MAY 2 8 !985 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA L _ AND GAS CONSERVATION CO-.~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. 2. Name of operator DRILL [-~X REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPNIC [] SINGLE ZONE [] MULTIPLE ZONE~ ":" -;2'3 /~=~ ..~ ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 202' FSL, 438' FEL, Sec.16, T12N, R9E, UM (APp¢ox') At top of proposed producing interval 1259' FNL, 1250' FWL, Sec.22, T12N, RgE, UM At total depth 1478' FNL, 1503' FWL, Sec.22, T12N, RgE, UM 9. Unit or lease name ~ ~"t Kupa ruk Ri ver.l~,'~ 10. Well number . '.¢2~,'0; 3B-10 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool "5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. i RKB 85', PAD 55' ADL 25633'ALK 2566 i 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 3B-9 well 60~ ¢ surface feet 16. Proposed depth (MD & TVD) 7221' MD, 6455' TVD 18. Approximate spud date 06/15/85 14. Distance to nearest property or lease line miles 202' ~ surface feet 17. Number of acres in lease feP. t 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 34 o (see 20 AAC 25.035 (c) (2) 19. If deviated (see 20 AAC 25.050) 2837 KICK OFF POINT 2157 feet. 3247 21 psig@ 80°F Surface psig@_ 6291 ft.-TD (TVD) 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) 24" 16" 62.5# H-40 Weld 80' 29' I 29' 1091 109' ± 200 cf i 12-1/4" 9-5/8" 36.0# J-55. BTC 3286' 29' 29' 33151 3246' 920 sx AS Ill & HF'ERW ~ , I 290 sx Class G 8-1/2" i 7" 26.0# J-55 BTC 7193' 28' I~ 28' i 7221~ 6455' 260 sx Class G blend I ' [ HF-ERW I [ I 22. Describe proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7221' MD (6455' TVD). A 20", 2000 psi annular diverter will be installed on the 16".conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak sands at approximately 3315' MD(3246' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure is 2837 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Selected intervals will be logged. The well will be completed by the workover rig with 3-1/2", 9.2#, J-55, 8rd tbg. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be (see attached sheet) 23. I hereby certify that the foregoing is true and correct to the best of my knowledge SIGNED ( TITLE Area Drilling Engineer DATE Samples required []YES Permit number APPROVED BY Form 10-401 Rev. 7-1-80 CONDITIONS OF APPROVAL Mud log required I Directional Survey required I APl number []YES [~O I ~(---F~S [-INO [ 50-- 0 Lq - ?.-'f ~, ~ Approval date I ~/~-'-'~ [' /5*'r ),.~l ~/~ ~"-~6/n3/%5 ~I SEECOVER LETTER FOR OTHER REQUIREMENTS ( // ' ///~OMMISSIONER DATE June 3, 1985 ' '-' ~'--~ ~ ~'/'. k' ~ V//~/j~/'~ by order of the Commission ~TEM) PD/PI~96 ' '""----/~- ~-- / Submit in triplicate / PERM)T TO DR)LL 3B-lO installed and tested upon completion of the job. 3B-lO will be 60' away from 3B-9 at the surface. There is . also a close approach at 1060'MD of 54'. Top of cement for the production string will be placed at $635'MD, approximately IO00'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x ?" annulus will be left with a non-freezing fluid during any interruptions in the ~isposal process. On completion of disposal injection, the 9-$/8" x 7" annulus will be downsqueeze Arctic packed with approximately 200 sx of Class G cement and sufficient Arctic pack to place the cement/pack interface below the permafrost. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED Alask~ ~ & Gas Cons. (.~oF,_,~rnission Anchorage .,, ~, ~ .... I : ' '.' · ' : · l-~-: ..... .-~.-: ~ .... ,?' --~'~ ..... :- .... ; ........... ~ .......... 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T~29'1 TMD-?022: DEP-24541-j-'-~ ·:' : +.i '-.'-: ':_ · , ...... f ~ :, ,, ; ~ , .. :_~. -_~_~_~_~ ;- · ..... i ~ - -',4 - - ~ ~ : ~ ' ~ ' ' ~ - - - --: · I -" ~ . , _ . ~ ~..~.-~ l_-: ~ -- ~.._~:'-:-, '.- _~-_._ '; : ~ i ........... - .... ---,4 -- .,~.~"~ ...... , s f-:-:.-' I::' :-.~ ..... , ...-:':.i.J-~ ;--.~ ..... :::?,_ .......... ' --'-'--I ': .r.. _;.I_,~_~ .._:.~...___:_,_,_~. ~ ~ : ~_? ~ , : - .., . , ,. , . , . ~_~_.._: _: ...;_-,.4__.; .... ,;_AFif-:.hT,~..~,A_~,~.4~.!. ._---._~_..,~._~.4..--! _: .~_._- -,,-~,, .:__::.-_ 4_:... :_, .~:-_::_f .... -.-:__:..,~-_-_, ._-_~_ ~_..~ .,_ :_.-.:-~''- . - . . .... · ....... ;, ........... ...... . ..... ¥ ....... ;... ~. ...... ,,._ ............................ , ....... : -- ' ........ -' , ~'--'. ~ ~-: ..... ;- :HQF~ZONTA~OJEOTI ' "tN _ j , ' .t ,_ .,'-; · Surface Diverter System 16"-2000 psi Tankco starting head. lankco quick connect ass¥. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool ~/10" side outlets, 10" ball valves, hydraulically actuated, w/10" lines to reserve pit. Valves to open automatically upon closure of annul ar preventer. 20" 2000 psi annular preventer. 20" bell nipple. mml i 1 . Maintenance & Ooeration Upon initial installation close annular preventer and verify ~hat ball valves have opened properly. Close annular preventer and bl~ air through diverter lines every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. )f necessary, manually override and close ball valve to upwind diverter line.. Do not shut in well under any circumstances· Conductor RECEIVED Oil & Gas vons, Commission 7 6 5 DI A(~N #1 .L~_.~f ~ PSI F~A BOP STAC~ !. 16' - 2QO0 PSZ~TAhI<CD ~I~ ~ ~. !1'- ~~I X I~'--~~ ~~~ _ A~AT~ ~AC~~ TEST J 4 2 Jl 12.,. 15, 14. !~/8' BOP STACK TEST FILL BSP STACK AhD 00~ ~N3FCZ.D W~TH A~IC D3F. SD_ OEO< THAT ALL LO::X DONN SC:EEl, S I N t'~_.LFE~ At~ F'LLLY ;~ETP. ACTE~ SEAT TEST PLUG IN YE;LLI-EAD ~4'ITH I~INS J'r AhD ~',JN ]N LtX~ L3hE VALVES ADJACF~ TO BCP STACX. ALL P~~ LIP 'TO 250 PSI AhD HOLD FD:~ I0 MIN. IN- C~ PRE~ TO 3000 PSI -AND N:Z.D FOR I0 I~N. BLEED P~ TO 0 PSI. L3hE VALVES. CLOSE TCP PIPE RA~ AhD HCR VALVES ~ Kill AND CHOKE LIb,ES. 'r~ T0.250 PSI AND 5330 PSI AS 3N ~ 4. C~Ih,LE TESTII~ ALL VALVES,. LIN='~- AhD C~ W4rITH A ~50 PS~ LC~ AhD 3CX)O P~) HIGH. 9'~T A~ IN s'rE~ 4. tx:) ~T .P~_?~ T~rr A.~ ~ T~AT FLI~tlCIN l bSl CrO<,E$ i~At FLr~_Y CL Clcer_NTCP PIPE ~ AN~ CLOSE BOTT~ PIPE P,A~. TEST BOTTC~ PIPE RA~ TO 250 PS) AhD ~ PSI. (:PEN EK)TTOM PIPE RA~ BACK OUT RL~ JT-AND Q.C~ BLIh,D RA~ AhD TEST TO ~50 PSI AhD 3000 PSI. ~ BL]kD RA~ AhD I~:T'RIEVE TEST i=~ I~ ~JRE I~FO_D AND LIhE. S A~ FLLL CF I~EZINOi FLUIEX SET ALL VALVES IN EP, ILL3t~ PO$ITI~ 9--c. ST ~'rA~IP~ VALVE~ Km~Yo K~LY C:OC~ DR~LL PIPE SAFETY VALVE, AhD 3I~ID~ BCP TO 250 PSI AND FEN~ S]G% AhD SEhD TO ER]LLII~ PERF(3:~ COV~ E~ TEST AFTER NIPPLIhtD UP AhD ~EEKLY ~ FLI~]CNALLY t~.RATE ~ DAILY. ARCO Alaska, Inc Post Office u-~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ~iay 20, 1985 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3C Pad Wel 1 s 1-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L113 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AllanlicRichfieldCompany N O R T H SEC. II SEC. 14 DRILL SITE $-C ~o~:,.:~oo, AS- BUILT CONDUCTOR LOCATIONS WITHIN SECTION 14~ TI2N~ 'R9E~ U.M.~ ALASKA NOTE: COORDINATES ARE ALASKA STATE PLANE ZONE 4. SECTION LINE DISTANCES ARE TRUE. HORIZONTAL POSITION PER LHO 8 ASSOC. MONUMENTS 19-1 8 19-2. VERTICAL POSITION PER LHD 8 ASSOC. TBM OPI6~ ~ DOC. 125. *WELL NO. 6 INFORMATION PER DW6. NO. NSK 9.05.$05dl. ¥ = 5~995~835.15 WELL I x= 528,205.68 596"FNL, 1366'FEL Lot. : 70°23'58.955'' Long.= 149°46' 13.622" Y = 5,995,893.73, WELL 2 x= 528,193.14 537' FNL, 1378'FEL Let. : 70°23J59.532" Long.: 149°46' 15.983' Y = 5,995~952.43 WELL 3 x= 528,~80.60 478'FNL~ 1390'FEL Lat. : 70024'00. I10" Long.: 149°46' 14.$45" ¥ = 5~996~ 011.07 WELL 4 x= 528,168.12 420' FNL, 1402'FEL Lot.: 70°24'00.687' Long.= 149°46' 14.703" Y = 5~996,086.$5 WELL 5 x= 528,52o.~6 346~FNL, 1050'FEL Lat. = 70°24'01.414" Long.= 149046'04.380" Y = 5~996~027.76 WELL 6' x= 528,532.8:5 404' FNL ~ 10:58'FEL Y = 5~995~969.11 WELL 7 x= 528,545.24 463'FNL~ 1025'FEL Lo't. = 70024'00.837" Long.= 149°46'04.015" Lat. = 70024'00.260'' Long.= 14.9°46'0:5.658'' Y= 5~995~910.44 Lat. = WELL 8 x--528,557.71 Long.= 5?__2'FNL ~ 1013' FEL 70023' 59.68:5" 149°46' 0:5.299" Y= 5,995~ 372. 49 Lot. = WELL9 x= 528,672.61 Long.= 1060'FNL ~ 901' FEL 70o23,54.387, 149o45' 59.99:5'' Y= 5~995~$14.06 Let. = WELL I0 x=528,685.04 Long.= 1119'FNL ~ 889' FEL 700 23' 5:5.812" 149o45,59.636, Y: 5~995~255.22 Lot. : WELL '11 x=528,697.61 Long.= 1177'FNL~ 876'FEL 7002:5'53.23:5" 14904.5'59.274" Y = 5,995, 196.51 Lot. WELL 12 x= 528,?]o.~9 Lo,g.= 1236'FNL, 864.' FEL 70023'52.655'' 149°45'58.912" Y= 5~995,121.:53 Lat. = WELL 13 x= 528,:558.~0 Long.= 1310' FNL~ 1217' FEL 70023'5 I. 929" 149°46'09.235' Y = 5,995~ 180.01 WELL 14 x= 528,:545.6:5 1251' FNL ~ 1229' FEL Lot. = 7002:5'52.506" Long.-' 149046'09.594" Y = 5~995~238.66 WELL 15 x= 5~8,3:53.o7 l193'FNL~ 1241'FEL Lot. : 7Oo23'53.084" Long.: 149046'09.956" Y= 5~995~297.32 WELL 16 x= 528,~20.55 1134' FNL~ 1253'FEL Lot. = 70°23'53.661" Long.= 149°46' 10.316" CERTIFICATE OF SURVEYOR: RE~,STEREO AND L,~ENSEO TO PRAOT,¢E L.NO .._~.tCr.. OF SURVEYING IN THE STATE OF ALASKA ,~JNI DTHAT MADE BY ME OR UNDER MY SUPERVISION, AND THAT ALL DIMENSIONS AND OTHER DETAIL~ ' ~ ~ .49~ BSSDI], 3340 Arctic Boulevard, Suite 201, Anchorage, Alaska 99503 SURVEYED FOR: DATE MAY 14, 1985 DRAWN J. DAVIS FIELD BOOK 8501 Joe' NO. 85029 ARCO Alasko~ Inc. KUPARUK PROJECT ........ ......., .... F. ROBERT BELL ~E~E~ ~o~: ALASKA OILFIELD '-:-....~ No. ~-s : SERVICES ' ~CH~CKED J. HE~MAN ARCO Alaska, Inc Post Office bo^' 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Hrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' Conductor As-Built Location Plats - 3B Pad Wells 5-8, 9-12 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU5/L70 Enclosure If ARCO Alaska, Inc. Is a Subsidiary of AllanlicRichlieldCompany ~.. 4O 30 2o t0 15 DRIL_~-SITE 3'BCONDUCTORS AS BUILT LOCATIONS WELL 5 Y= 5,992,109.75 X= 5t8,519.96 989' FSL Lot. 70° 23'22.6108" Long. 149° 50' 57.665" 5t0' FEL WELL 6 Y = 5,992,049. 98 X= 518,525.71 929' FSL Lot. 70° 23'22.0228" Long. 149°50'57.~01" 504' FEL WELL 7 Y=5,991,990.26 X-'- 5t8,53t. 34 869' FSL Lot. 70° 23'21.4553" L o n g ..t 49° 50' 57.34 !" 499' FEL WELL 8 Y= 5,991,930.53 X= 5t8,536.99 810' FSL Lat. 70° 23'20.8476'' Long..149o50'57.179" 493' FEL WELL 9 Y=5,99t,383.04 X= 518,589.15 262' FSL Lot. 70 o 25't 5.4613" Long. 149° 50'55.69P_.'' 444' FEL WELLIO Y= 5,99t,325.38 X= 518,594.95 202'FSL Lot. 70°23' t4.8744'' Lo rig. 14 9 050' 55.528" 438' FEL WELL 11 Y= 5,9 9 !, 263.67 X= 518,600.61 142~ FSL Lat. 700?.3' 14.2870" - Lon g,.149° 50'55.365" 433' FEL WELL 12 Y = 5,991,204.02 X = 5t8,606.24 85' FS L Lot. 70°23' 13.7001" Long. t49°50'55.205' 428' FEL LOCATED IN PROTRACTED SECTION 16, TOWNSHIP 12 RANGE 9 E., UMIAT MERIDIAN. COORDINATES ARE A.S.P., ZONE 4. SECTION LINE DISTANCES ARE TRUE. HORIzoNTAL POSITION PER LHD'S ON PAD PILING CONTROL PK'S N 26+ 45 N 13+55 E 11 +70 E 11+70 VERTICAL POSITION PER LHD'S ALCAP TBM'S $B-It858-1;h O.G. ELEVATIONS INTERPOLATED FROM S/C DWG CED- 9800- 3001 /~ HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND bBII LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION AND THAT ALL DETAILS ARE CORRECT AS OF FEB. 17, 1985 FOR WELLS 5-12. ARCO Alaska, Inc. "~' "' Kuporuk Project North Slope Drilling DRILL SITE 38 CONDUCTOR AS-BUILT LOCATIONS Dote:Feb. 22,1985 Scole: AS SHOWN Drown By: O~W. Dwg. N~ NSKg.05.302d~ CHECK LIST FOR NEW WELL PERMITS Lease & Well No. /~!~ ~!o Company . /~~ ITEM APPROVE DATE YES NO REMARKS < 2) Loc Q~-'~u f' % 5'~ "~' (/2 thru 8) (3) Admin ~ r- ¥5' ~'~ (9 thz;u 12) 10. (10 and 12) 12. (4) Cas ~. I~..~~ -.~q-~,.S~ (13 thru 21) (5) (22 tnr~ 26) 13~ 14. I5, I5. 1'7. _8, !9. ',2~ 3, ~5. '7. · ... Is the permit fee attached .......................................... . _ ,/ · !. Is well to be located in a defined pool ............................. ~_~ 3. Is well located proper distance from property line .................. ~. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ ~ ..... Is__~ell_to_~e_de~iated_.an~_is~ellho~e__plat_includet ........................ /. Is operator the Only affected party . ................................ ~_/~ 3. Can permit be apProved before ten-d'ay wait ............. ; ............ Does operator have a bond in force .................................. Is a conservation order needed. ...................................... ~...t~ '~ IS admin±stratSve approval'needed ...... ~ ........................... Is' the lease number. approPriate ..................................... Is conductor string provided ~'. ..... ~ ................................ Is enough'cement used to c±rculate on conductor and surface ....... Will' cement'ti~ in surface and 'intermediate or production strings Will"cement cover al'l':known productive horizons- .,; ..... Will surface casing protect fresh water zones ..... Will all casing give adequate safety in collapse, tension and burst.. _~_d/ IS this well to be kicked off from an existing'wetlbore ' . .... .... 'Is Old w~'tlbore abandonment procedure included on 10'403 · %s adequate wallbore separation proposed ........... ~ ..... · .......... · I§'a di~erter system required ' ' ' Are'necessarY'diagramS of diverter and'BOP equipment attached .... ~../~ Does BOPE~have sufficient pressure rating -"Test to ~~ -psig .. Does the choke manifotH comply w/AP1 RP'53-(Feb.78) - Is the presence of H2S gas probable ................................. Additional requirements'. ............................................ Additional Remark~':'/~v~z~ ~0~/~/ $~' ~ '~'q I .. ! Geology: Eng i~e er i_ng: WVA~[ MTMz~~ HJH'~ J AL ~/:.~'-,,.~- ....... rev: 03/13/85 6.011 :" '" ' -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. ~ .... S CH:~UM5 ER,SE R ..... m L;iS ?~,P~E V .E R, i F I C A T ,Z 0 ,~ :L I ,S'T ,I N ~S LVP ~lO.HO~ VERIFICATION tIS'TiNG ?A~f I -~ R,~fL HEADER ~ SERVICE NA~E :EDIT DATE :55105125 3R iG.IN : RE2L N4ME CONTINjATiDN ~ :01 PR~VIO5S REE~. : COMMENTS : g~ TAPE HEADER g~-' SERViCi NAME :EDIT DATE :85/05/28 ORIGIN TAPE N~MF :0555 CONTiN~JATI 3N PREVIDJS T~PE : COMMENTS : · ~ FILE HE,&OER ~ FILE NAM,E :EDIT .001 SERVICE NAME : V E R S I 0 N ~ : DATE : MA×%MUM LENGTH : 102~ FILE TYP'~ : PR~V!D~S FILE : g* iNF2RMATI~N REC3RDS ~g MNEM CO NT.~EN'T S CN : AR WN : 3B FN : KU RANG: T G ~ N: Z g SECT: t6 CQ~N: ST .~T: CTRY: US C0 ALASK~ PARUK SLOP~ MN:~M CO~Ti=N'TS P R E S: ~NI T T ¥ P E 000 000 0 O 0 ,000 0 '00 ,000 000 000 000 TYPE OO 0 CA'TE OOO GO0 000 000 000 000 000 OOO .000 CATE 000 01,5 O0 5 00 '7 002 O0'3 OO g 0 O 6, 0,03 S 11 :00 ! 065 065 LYP OlO.HOZ V~-RIFICATISN LISTING :~ SCHLL~MBZR~R ~ ~ .~LASKA CgMPUTi"~G C'ZNTER X~ COMP~NY : ATL4NTIC RZCH=i~L2 CO'~P1NY WELL = 3,5-10 FieLD : KUP.~RgK COUNTY : N~RTH SLOPE BOROUGH STAT~ = ALASKA JO5 NU~.BER AT &CC: 70555 RUN :~I, DATE LDG.GE2: 17 LD?: L.B. SUDNEY CASING TYPE FLUID DENSITY VISC3SITY PH FLgID LGSS 9.62.5" ~.' 3309' LSND 10.3 ~-~/G 41~.0 S 8.5 6.0 C3 -~iT SZZ~ RMF R~C R~ A'T 5 H T TO ,: 3.500 = 4.150 = I. ~'6 3 £~ 62.0 ~ 6Z.O C,F LVP OIO.HOg VERIFIgA'TI2N LISTING ~.~SE 3 THIS DATA HAS NOT 'SEEN ~,~PTH S~iFT,~D- ~VERLAYS FIELD PRINTS ~ SCHLUMSE'RGER L2GS iNCLUDE~ WiTH THiS M~G',~ETiC TAPS: ~ ~ DU~L INDdCTi~N SPHERICALLY F2C:JSED L'~G (D, IL) ~: ~ C,~T~ AVAILABLE: 3309' T~ 7238' "~ ~ C~MPENSATED NE~TRON LOG (FDN) ~ ¢ DAT~ ~V~ILA~LE: 5309' T2 7212' ~ ~:~ D.~TA FORMAT REC2RO ENTRY BLDC~S TYPE ,SIZE 2EPR C3DE E~TRY 9 ,~ 65 ,.!iN 16 DATUM SPECIFI,C~TIOW 5L2CKS MNEM SERVICE SERVICE UNiT API APi API ~P.I FILE SIZE SPL REPR P R ~ C ~E S S iV? 019.M02 VERIFICATION LISTING iD ORDER N LOG T DEPT FT O0 SF~.U Ji~_ 3HMM O0 ZLD DIL ']H~M O0 TLM DZ.' 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DRHB NPHI 29.2969 NCNL 2178. DEPT 6~00.0000 SFLU :5. SP -26 2969 GR 7¢. ~HgB Z..~551 DRHO NPHI 3,3.3~96 .NCNL 2452. DEPT 6700.0000 SFLU SP -21.9687 GR ll~- ~HO8 2.5605 DRH~ NPHi 30.0781 NCNL 2~38. '9375 2500 2500 0352 68'?5 1714 OOOO 3509 6250 1362 0000 0625 6875 1191 O00O 95,3.1 1875 0'72.8 OOOO 7578 18'75 0t07 9297 i250 O000 SR NR~T FCNL .ILD 2R NR~T FCNL NR~T FCNL SR NR 4T I'LD NR~'T FC~:L ~R N R .4 T .FC I:L D · ~; R NR ~T 3. 11 !. -999. -999. ~ 65. 5. 93. 581. 'Z. 7 ~. 3. 809. ~297 2500 5777 b875 0254 OOOO 62,5,0 ?07O 0313 68'75 ~70 :5000 i ;8 75 7793 5703 L875 0078 5000 TO3,1 12.50 OOOO I ,L M CAi i RNRA C Al. i RNRA I L M RNRA .I L M C A.L I RNRA .I L M C A L I CALl RN~A I L M C A L I RNRA 3.353,5 7.6328 -9'99.25,P0 ~Z 3.0~.10 3.'?285 5..i?i9 9.7,3~4 5.0391 9.56 g 5 £. :6, 75, 8 7..7~22 9°0625 :3.54.3 O Z. 92 i 9 LVP O!O.H02 VEqIFISATI~N L.iSTZ'NG PA3E 5 2. EPT 650,0.0000 SFLU SP -i~.3906 JR 10'9. 2H35 2.3125 3RHO NP~iZ ¢$.:0¢69 NCNL 1533. DEPT 5509°0000 SFLU SP -29.0156 RH38 2.3T89 DRHO NPHi ~0.1855 NCNL 1831. OEOT 6~00.0000 SFLO 3P -18.5553 GR 170. RHO6 2.37?0 DRHO O. ~Pgl ~2.~805 NCNL 1'.~12. 2EPT 6300.0000 SFLb SP -20.0000 GR lOS. RH3B Z.3496 NPHi 49.1699 NCNL 1799. 2EPT 6200.0000 SFLU SP -25..23~4 ~R 119. ~H~E -999.2500 ORHO NPHI -999.2500 NCNL -999° D,EPT 6100.0000 SFLU SP -17.3906 GR 12~. RHDB -~99.£500 ORH~ -999. NPHI '-999°2500 NCNL -999. DEPT 6~OO,.O000 SFLU ~. SP -25.~3'75 GR 98. RHD8 -~99.,Z500 DRNO -99'9. NP~I '-~99.2500 NCNL -999. gEPT 5300.0000 SFLU SP -1:1.,2656 GR i0.5. ~HO~ -~99.Z500 DRHO -~9~. NPHI -~9~ 2500 N:CNL DEP'T 5?00.0000 S,FLU ,SP -!3.~%453 GR 119. R'H~B 2.2793 ~RH.D 0,. NPHI 40.2832 NCNL 1830. DEPT 5500.0000 SFLU 1. 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Z300 2300 ~93Z 1250 2500 ~023 ZSOO ZSO0 5270 1875 2500 2500 0000 2500 5625 Z300 9277 6230 3809 3000 18'95 :1500 33.32 DO00 30,29 3750 4434 0080 7422 58'7.5 52!~3 5000 06,25 '30~3 5000 ~ 96 CALl RNRA iLM CA.L.i RNRA i L M C AL I iLM gAL1 RNRA CALI RNRA iLM CALi CALI RNRA ILM CALl RNRA ILM CALl RNRA CA!L.I RNRA 3.~1£1 9375 3.Z8~I 10.257~ 3.3000 -~99.2500 3. %531 10.2031 -999.2500 3.28 .i 3 -999. 2500 3.?031 10.23~,4 3.31.W$ 3:. 0938 t0. 3906 3.3. 2 ~, g 2. ,~ 6 Z 5 ~. 1933 3.3945 3.~.Zli 3 37Z3 3..~727 LV'P OiO.HOZ VERIFICATi:3N LISTING RAGE S SP -25. 2031 RHiSB 2o ZOTO :3R rio NP.Ii 4_1.59~J2 NCNL OEPT 3300.0000 SFLU SP -88.8125 GR RH'35 2.10'16 DR,HO NP,-i i 51.3056 NCNL DE'PT .}, Z73. DO00 SFLU ,~P -89. 1875 ~R RH.~5 -999.2500 DR mF..J NP H'f. -~9'9.2500 fiCNL *-:*: FiLE TRAIl_ER FILE N&M~ :EDIT .001 SERVICE NAME : VERSIO,~ ,~ : :2ATE : MAXIMU~ LENGTH : ~T LE 'TYPE : SERVICE NAME :'EDIT DATE :85/05,/,28 gRIG:iN :OODO 'TAPE. NAME :0555 CONT,IN~AT~DN ~ :01 NEXT T~PE ~AME : COMMENTS :' 5000 SR 0.0332 NR~T !5~,~.OOOO FC~L 2. L~2 Sr. !~-3 62.3125 1526.3000 FC~JL 2.3~13 ZL3 56.3750 GR -999.2500 ~R~T -999.2500 FC~L ~*.5000 3.6259 15.~i56 15.5000 .56.5750 -99'9.Z500 -99~.Z500 RNRA CALl RNRA CALl 11.5'9'06 2000.00~0 3..~023 9.0391 *~ RESL TR&ILER :~ SERVICE NAME :EDIT DATE ORIGIN : R~L NAM~ : CONTiNdA.'Ti,,~N ~ :01 NEX'T REEL NAME CgMMENTS :