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182-193
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 3800 2210 2212 2201 2204 260 1050 1000 980 REQVAR P Kam StJohn 5/21/2024 MIT-IA to MAIP per AIO 2C.049 OOA = 260/320/320/340 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 1C-10 Inspection Date: Tubing OA Packer Depth 1150 4215 4125 4110IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240522122558 BBL Pumped:1.6 BBL Returned:1.6 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9MIT-IA AIO 2C.049 James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:02:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 1800 2213 2213 2208 2189 190 380 360 360 REQVAR P Kam StJohn 5/21/2024 MIT-OOA to 1800psi per AIO 2C. 049. OOA = 160/2015/1940/1890/1870 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 1C-10 Inspection Date: Tubing OA Packer Depth 1200 1230 1225 1220IA 2185 360 45 Min 1220 60 Min Rel Insp Num: Insp Num:mitKPS240522123303 BBL Pumped:1.5 BBL Returned:1.5 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 9 9 9 9 9 MIT-OOA AIO 2C. 049 OOA = 160/2015/1940/1890/1870 James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:07:10 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 2, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/02/2024 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 1800 2189 2196 2201 2209 210 2020 2005 1995 REQVAR P Kam StJohn 5/21/2024 MIT-OA to 1800 psi per AIO 2C.049 OOA = 210/335/340/365 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 1C-10 Inspection Date: Tubing OA Packer Depth 1160 1570 1550 1550IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240522123049 BBL Pumped:0.9 BBL Returned:0.9 Tuesday, July 2, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 MIT-OA AIO 2C.049 James B. Regg Digitally signed by James B. Regg Date: 2024.07.02 13:04:37 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 1800 2397 2396 2398 2405 105 2010 1980 1970 REQVAR P Brian Bixby 5/23/2022 MITOA as per AIO 2C.049 Retest for 5/17/22 inconclusive test. OOA Pressures 105psi pre-test, 225psi Initial, 225psi 15 minute reading, 225psi 30 minutes reading. 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 1C-10 Inspection Date: Tubing OA Packer Depth 803 1249 1229 1223IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220524130244 BBL Pumped:0.9 BBL Returned:0.9 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 9 MITOA AIO 2C.049 James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 12:24:09 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 1800 2416 2413 2413 2405 404 580 576 570 REQVAR P Matt Herrera 5/17/2022 MIT-OOA Performed to 2000 by Operations per AIO 2C.049 OOA - 370/2000/1920/1880 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 1C-10 Inspection Date: Tubing OA Packer Depth 1220 1264 1249 1231IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518141449 BBL Pumped:1.1 BBL Returned:1.1 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 MIT-OOA AIO 2C.049 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 14:01:18 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 1800 2409 2409 2406 2405 380 2005 1990 1980 REQVAR I Matt Herrera 5/17/2022 MIT-OA Performed to 2000 by Operations per AIO 2C.049. Fluctuating tubing pressure and injection temps caused test to be run out an additional 30 min. Results were inconclusive OOA 220/ 335/ 345/ 350/368/370 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 1C-10 Inspection Date: Tubing OA Packer Depth 1181 1564 1549 1542IA 2403 1970 45 Min 1527 2406 1960 60 Min 1514 Rel Insp Num: Insp Num:mitMFH220518140449 BBL Pumped:0.7 BBL Returned:0.7 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 MIT-OA AIO 2C.049. Results were inconclusive James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 13:58:07 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-10 KUPARUK RIV UNIT 1C-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-10 50-029-20865-00-00 182-193-0 W SPT 6346 1821930 3800 2415 2415 2422 2421 417 1180 1157 1147 REQVAR P Matt Herrera 5/17/2022 MIT-IA Performed to MAIP per AIO 2C.049 OOA 285/340/340/340 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 1C-10 Inspection Date: Tubing OA Packer Depth 1150 4170 4120 4115IA 45 Min 60 Min Rel Insp Num: Insp Num:mitMFH220518140044 BBL Pumped:1.5 BBL Returned:1.5 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 AIO 2C.049 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 13:55:43 -08'00' 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:Regg, James B (OGC) To:Well Integrity Specialist CPF1 & CPF3 Cc:Wallace, Chris D (OGC);Earhart, Will C;DOA AOGCC Prudhoe Bay Subject:RE: KRU 1C-10 (PTD 182-193) Inconclusive SW MITOA result Date:Wednesday, May 18, 2022 2:29:03 PM Without evidence of stabilizing pressure, the result could also be deemed a failure, but I think “inconclusive” is the correct call here due to the low total pressure loss (2.2%) during the test. Retest of the OA is required. If retest is inconclusive/fail, well must be immediately shut in unless CPA provides a reasonable work plan and timeframe to address the leak off. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, May 18, 2022 1:32 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-10 (PTD 182-193) Inconclusive SW MITOA result Jim, I wanted to follow up on the 1C-10 MITOA “inconclusive” test result. It has been so long since we have had an inconclusive test result that no one recalls the normal process that takes place after. Matt Herrera advised that the well may be left online while you reviewed the data and made a decision on the test result. This email is to notify you that the well does remain online and we standby awaiting your final decision. Please let us know at your earliest convenience what is expected for the well. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 KRU 1C-10 (PTD 182-193) Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1810050 Type Inj W Tubing 2448 2450 2453 2459 Type Test P Packer TVD 6266 BBL Pump 1.2 IA 890 1800 1715 1705 Interval 4 Test psi 1567 BBL Return 0.9 OA 487 547 540 537 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1810250 Type Inj W Tubing 2530 2531 2532 2512 2514 Type Test P Packer TVD 6326 BBL Pump 1.4 IA 500 1800 1765 1740 1725 Interval 4 Test psi 1582 BBL Return 1.2 OA 182 197 199 200 199 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821850 Type Inj W Tubing 2468 2469 2471 2468 Type Test P Packer TVD 6205 BBL Pump 0.8 IA 460 1800 1750 1730 Interval 4 Test psi 1551 BBL Return 0.7 OA 290 370 370 370 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821930 Type Inj W Tubing 2415 2415 2422 2421 Type Test P Packer TVD 6346 BBL Pump 1.5 IA 1150 4170 4120 4115 Interval V Test psi 3800 BBL Return 1.5 OA 417 1180 1157 1147 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821930 Type Inj W Tubing 2409 2409 2406 2405 2403 2406 Type Test P Packer TVD 6346 BBL Pump 0.7 IA 1181 1564 1549 1542 1527 1514 Interval V Test psi 1800 BBL Return 0.7 OA 380 2005 1990 1980 1970 1960 Result I Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1821930 Type Inj W Tubing 2416 2413 2413 2405 Type Test P Packer TVD 6346 BBL Pump 1.1 IA 1220 1264 1249 1231 Interval V Test psi 1800 BBL Return 1.1 OA 404 580 576 570 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2060010 Type Inj W Tubing 2528 2529 2533 2538 Type Test P Packer TVD 6245 BBL Pump 1.0 IA 580 1800 1730 1720 Interval 4 Test psi 1561 BBL Return 1.0 OA 333 455 416 395 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1982290 Type Inj W Tubing 2555 2555 2562 2555 Type Test P Packer TVD 6417 BBL Pump 1.1 IA 865 1800 1750 1740 Interval 4 Test psi 1604 BBL Return 1.0 OA 420 535 535 535 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 1C Pad Matt Herrera Beck / Borge 05/17/22 Notes: Notes: Notes: Notes:MITOA to 1800 psi per AIO 2C.049 OOA 220 335 345 350 365 370 FTP's & Temp Fluctuation 1C-05 1C-06 1C-10 1C-10 1C-10 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMech anicall In tegri tyy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 1C-09 Notes: 1C-14A 1C-15 MITOOA to 1800 psi per AIO 2C.049 OOA 370 2000 1920 1880 Notes:MITIA to MAIP per AIO 2C.049 OOA 285 340 340 340 Form 10-426 (Revised 01/2017)2022-0517_MIT_KRU_1C-pad_6wells_mh 9 9 9 9 9 QR2$SUHVVXUH VWDELOL]DWLRQ MEU 9 05/17/22 MITOA to 1800 psi per AIO 2C.049 1C-10 1990 1980 1970 1960 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 11, 2020 TO Jim Regg P.I. Supervisor �fl SUBJECT: Mechanical Integrity Tests l ConocoPhillips Alaska, Inc. 1C-10 FROM: Guy Cook KUPARUK RIV UNIT I C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Sup, -TEP-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC -10 Insp Num: mitGDC200507153140 Rel Insp Num: API Well Number 50-029-20865-00-00 Inspector Name: Guy Cook Permit Number: 182-193-0 Inspection Date: 5/6/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-10 Type Inj w TVD 6346 T�ubing 2279 2 2279 2277 PTD 1821930 Type Test, SPT YP Test sl, T P 3800 IA 225 4170 4140 4130 BBL Pumped: 1.9 "BBL Returned: 1.9 -- � 1200 �-- 1180 — 1180 - �- -1- Interval� REQVAR LPIF P -OA --21s - Notes: MITIA to MAIP per AIO 2C.049. OOA = Pretest 160, Initial 230, t5 Minutes 230, 30 Minutes 230. Testing was done with a Little Red Services pump truck and calibrated gauges. � Monday, May 11, 2020 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission _ To: Jim Regg 2�� `�, f ��2c%20 DATE: Monday, May 11, 2020 P.I. Supervisor �� SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, lnc. 1410 FROM: Guy Cook KUPARUKRIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By-:�y� 6� P.I. Supry — NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 Insp Num: mitGDC200507154443 Rel Insp Num: API Well Number 50-029-20865-00-00 Inspector Name: Guy Cook Permit Number: 182-193-0 Inspection Date: 5/6/2020 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J TVD I 6346 Tubing' zzss � zzss 2282 - I zzsl - .- YP PTD 1821930 Type Test SPT ,Test psi 1800 IA 210 565 565 565 � -- _ - - — -- - -- BBL Pumped: 1.3 BBL Returned: I OA 35 2025 2015 2010 - Interval REQVAR P/F P Notes: MITOA to 1800 per AIO 2C.049. OOA =Pretest 110, Initial 240, 15 Minutes 250,30 Minutes 260. The well was bled back to 200 psi instead of 35 psi. Testing was done with a Little Red Services pump truck and calibrated gauges. Monday, May 11, 2020 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Monday, May 11, 2020 j P.I. Supervisor �� j �l SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IC -10 FROM: Guy Cook KUPARUKRIV UNIT IC -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IC -10 API Well Number 50-029-20865-00-00 Inspector Name: Guy Cook Permit Number: 182-193-0 Inspection Date: 5/6/2020 Insp Num: mitGDC200507155027 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min } g 2285 PTD 1821930 - Type Test SPT Test psi 6346 Tubing zzza zz�z zzal — Well 1C -lo Type Inj w •' - p ' lsoo IA zzo - zzo _ zzo - 220 — BBL Pumped: 1 7 ;BBL Returned: 1.a OA 30 ao. ao ao - Interva( REQVAR P/F P J Notes: MITOOA to 1800 per AIO 2C.049. OOA = Pretest 0, Initial 2005, 15 Minutes 1945, 30 Minutes 1915. The well was bled back to 100 psi instead of 0 psi. Testing was done with a Little Red Services pump truck and calibrated gauges. 11 Monday, May 11, 2020 Page 1 of I MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg C� DATE: Friday,June 01,2018 P.I.Supervisor I l ri � p (lir SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-10 FROM: Austin McLeod KUPARUK RIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry, E-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Austin McLeod Permit Number: 182-193-0 Inspection Date: 5/29/2018 Insp Num: mitSAM180529143804 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j is-lo -Type Inj T W 'TVD 6346 " Tubing 2497 ' 2506 2509 2512 - PTD 1821930 Type Test SPT Test psi 3800 IA 955 4205 - 4147 4133 ' BBL Pumped: 1L4 BBL Returned: 1.4 OA 41 - 695 - 658 - 643 - Interval REQVAR P/F P Notes: MIT-IA to Maximum anticipated injection pressure.AIO 2C.049.2 year cycle.Docket No:AIO-17-033.OOA pressures as follows:Pretest-141. Initial-18O. 15 min-178.30 min-159. r- JUN b Zn scatte Friday,June 01,2018 Page 1 of 1 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,June 01,2018 P.I.Supervisor ' \ Cl' 6/ / SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. IC-10 FROM: Austin McLeod KUPARUK RIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm • Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Austin McLeod Permit Number: 182-193-0 Inspection Date: 5/29/2018 Insp Num: mitSAM180529145600 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IC-10 • Type Inj W TVD 6346 - Tubing 2513 - 2514 - 2518 - 2501 - 2501- 2502 - PTD 1821930 Type Test SPT Test psi 1800 IA 1135 1606 ' 1660 - 1686 - 1676 - 1682 - BBL Pumped: I " BBL Returned: I - OA 50 2000 - 2060 - 2080 - 2080- 2080 - Interval REQVAR P/F P Notes: MIT-OA to 1800 psi.AIO X.049.2 year cycle.Docket No:AID-17-033.OOA pressures as follows:Pretest-130.Initial-255. 15 min-270.30 i ' min-285.45 min-295.60 min-310.After OA pressures stablized,decided to hold for another 15 min to verify thermalling was a factor on first 30 min II SCANNED JtiN '6 1018 Friday,June 01,2018 Page 1 of 1 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday,June 01,2018 TO: Jim Regg / P.I.Supervisor 1 1 b(I I-I s SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-10 FROM: Austin McLeod KUPARUK RIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry )— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Austin McLeod Permit Number: 182-193-0 Inspection Date: 5/29/2018 Insp Num: mitSAM180529152120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well lc-to • Type Inj W TVD 6346 Tubing 2502 2502- 2503 - 2503 - PTD 1821930 - Type Test SPT Test psi 1800 " IA 1211 . 1247 . 1222 • 1198 ' BBL Pumped: 1.5 T BBL Returned: 1.4 ' OA 75 ' 240 - 240 • 235 Interval -- REQVAR P/F P Notes: MIT-OOA to 1800 psi.AIO 2C.049.2 year cylce.Docket No:AIO-17-033.OOA pressures as follows:Pretest-200.Initial-2010. 15 min-1950.30 min-1920. 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Q O N J N W 0 W Z M 0, M 0 V E (o N ,� ��+ A a N w co) N N y) Z a) O O G ca y E E N3 a H a a - FO O - • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, September 13, 2017 11:16 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: Report of possible OAxOOA communication 1C-10 (PTD 182-193) Update 9-13-17 Attachments: 1C-10 90 day TIO 9-13-17.JPG - Chris, The passing witnessed MITIA was performed on August 17, 2017. The 30-day monitor of 1C-10 is coming to an end and results are inconclusive. While the OOA and OA pressures have not maintained good dP over the last month,the OA appears to be more susceptible to thermal fluctuations due to change in injection rate and pressure and thus pressure convergence may only be coincidental. CPAI would like to extend the monitor out an additional 30 days. An MITOA and MITOOA and packoff testing will be performed and pressures will then be manipulated to simultaneously allow for more thermal fluctuations to exist while still being able to conclude whether there is in fact communication or not. Please let us know if you disagree with the plan forward. Attached is an updated 90 day TI00 plot. Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Mobile Phone(907)943-0170 SCANNED P 2 'r From: NSK Well Integrity Supv CPF1 and 2 Sent: M. •day,August 14,2017 9:36 AM To:Wallace, . ris D(DOA)<chris.wallace@alaska.gov> Cc:Senden, R.Ty <R.Tyler.Senden@conocophillips.com> Subject: Report of pos ., e OAxOOA communication 1C-10(PTD 182-193)8-14-17 Chris, KRU WAG injector 1C-10(PTD 182-193) i • •laying possible signs of OAx00A communication after attempts to establish a dP between the two annuli would n. •old. OA and OOA pressures appear to be slowly converging. The well was recently returned to water injection on 8-5-17 a' - aving been shut in since 5-8-17. The well did display slow IAxOA communication and had been AA'ed for that prior to i 013 RWO during which an additional 5.5"casing string was installed. Thus the previous IAxOA would now effectively bet •AxOOA communication if confirmed. The workover did not address the communication therefore it is not unexpec •• to see signs of communication develop. However the well is still in the process of achieving stabilization afte - •ving been brought online recently and the pressure response may simply be a thermal phenomenon. But because of the kn. n history with the well, I thought it best to report the possible problem sooner rather than later. The well had been shut in during its pad testing and is now past its 4 yr MIT date. Therefore when t - well reaches stabilization a witnessed MITIA will be performed. We will be manipulating OA and OOA pressures and •nitoring for 30 days. There is currently a DNE of 150psi on the OOA which is our standard. But we will allowing the OOA • essure to rise above its DNE during the monitor period. In addition to the MITIA which is required,an MITOA and MITOOA . •d 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,August 21,2017 P.I.Supervisor ,Z,41 6�Z] (]-7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1C-10 FROM: Brian Bixby KUPARUK RIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Brian Bixby Permit Number: 182-193-0 Inspection Date: 8/17/2017 Insp Num: mitBDB170817164509 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well j 1C-10 ' Type Inj W' TVD 1 6346 Tubing 1542 - 1545 1546 1547 PTD 1821930 Type Test SPT Test psi 1586 • IA 505 2800 - 2770 - 2765 BBL Pumped: 1.2 BBL Returned: i 1.2 " OA 130 705 - 682 676 — — Interval 4YRTST P/F P Notes: OOA-Readings 165/195/195/195 % ANNE ) 0 Monday,August 21,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Monday, August 14, 2017 9:36 AM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler Subject: Report of possible OAxOOA communication 1C-10 (PTD 182-193) 8-14-17 Attachments: 1C-10 2-week SCADA snapshot 8-14-17.1PG; 1C-10 schematic.pdf; 1C-10 90 day TIO SCADA snapshot 8-14-17.JPG Chris, KRU WAG injector 1C-10(PTD 182-193) is displaying possible signs of OAxOOA communication after attempts to establish a dP between the two annuli would not hold. OA and OOA pressures appear to be slowly converging. The well was recently returned to water injection on 8-5-17 after having been shut in since 5-8-17. The well did display slow IAxOA communication and had been AA'ed for that prior to its 2013 RWO during which an additional 5.5" casing string was installed. Thus the previous IAxOA would now effectively be the OAxOOA communication if confirmed. The workover did not address the communication therefore it is not unexpected to see signs of communication develop. However the well is still in the process of achieving stabilization after having been brought online recently and the pressure response may simply be a thermal phenomenon. But because of the known history with the well, I thought it best to report the possible problem sooner rather than later. The well had been shut in during its pad testing and is now past its 4 yr MIT date. Therefore when the well reaches stabilization a witnessed MITIA will be performed. We will be manipulating OA and OOA pressures and monitoring for 30 days. There is currently a DNE of 150psi on the OOA which is our standard. But we will allowing the OOA pressure to rise above its DNE during the monitor period. In addition to the MITIA which is required, an MITOA and MITOOA and packoff testing will be performed if pressures continue to demonstrate signs of communication. A followup email will be provided at the conclusion of the monitor period. Please let us know if you disagree with the plan forward. Attached is the schematic and 2-week and 90 day SCADA snapshots of the trend plots,with OOA pressure data. Kelly Lyons/Brent Rogers Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907) 659-7224 Mobile Phone (907)943-0170 SCANNED AUG 2 17 NZ 1 STATE OF ALASKA ALAIDA OIL AND GAS CONSERVATION COASION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon E Repair well I✓ Rug Frforations f Perforate ""' Other (-° Alter Casing ;ri Pull Tubing f Stimulate - Frac f Waiver E Time Extension F Change Approved Rogram EOperat. Shutdow n '""" Stimulate - Other E Re -enter Suspended Well 1 --- 2. Operator Name: ✓ 4. Well Class Before Work: 5. Permit to Drill Number: ✓ ConocoPhillips Alaska, Inc. Development r Exploratory r 182 -193 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic j Service ✓ 50- 029 - 20865 -00 7. Property Designation (Lease Number): ✓ 8. Well Name and Number: ✓ ADL 25650 1C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): ✓ none Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9002 feet Plugs (measured) 8182 true vertical 7118 feet Junk (measured) 8744 Effective Depth measured 8890 feet Packer (measured) 8015, 8136 true vertical 7018 feet (true vertical) 6239, 6346 Casing Length Size MD TVD Burst Collapse CONDUCTOR 65 20 99 99 SURFACE 2533 10.75 2567 2284 PRODUCTION 8945 7 8977 7096 SCAB LINER 8066 5.5 8098 6312 RECEIVED APR 302013 Perforation depth: Measured depth: 8278'- 8304', 8308' -8344' JU True Vertical Depth: 6473'- 6496', 6500' -6532' SCANNED Tubing (size, grade, MD, and TVD) 3.5, L - 80, 7991 MD, 6217 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 8015 MD and 6239 TVD PACKER - OTIS HCL PERMANENT PACKER @ 8136 MD and 6346 TVD NIPPLE - CAMCO 'DS' NIPPLE @ 495 MD and 495 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 4189 Subsequent to operation shut - 14. Attachments 15. Well Class after work: ✓ Copies of Logs and Surveys run Exploratory E Development la Service F Stratigraphic E 16. Well Status after work: ✓ Oil E Gas E WDSPL 1 Daily Report of Well Operations XXX GSTOR r WINJ ; WAG ii GINJ I SUSP E SPLUG I 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 313 -030 Contact Jonathan Coberly 265 -1013 Email Jonathan.Coberly a(�conocobhillips.com Printed Name Jonathan Coberly Title Wells Engineer Signature 414(..--- c / Phone: 265 -1013 Date Lill — /3 1 � YLJ �7�� Form 10 -404 Revised 10/2012 RBDMS MAY - 12013 - x' 1121/3 Submit Origina Only KUP • 1C -10 1 • Conoc 0 Well Attributes Max Angle & MD TD Wellbore APUUWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (ftKB) Aaska, Inc. OarloroPfi9p6 500292086500 KUPARUK RIVER UNIT INJ 57.82 4,100.00 9,002.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date - -- SSSV: NIPPLE Last WO: 4/18/2013 41.00 11/29/1982 Well Con69: -1C-10 4/23/2013 103932 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,395.0 3/3/2013 Rev Reason, WORKOVER osborl 4/23/2013 HANGER,3 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 20 18.940 34.0 99.0 99.0 92.00 H - 40 WELDED 3 r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 103/4 9.950 34.4 2,567.0 2,283.9 45.50 K -55 BTC 13.375x10.75" @102 p Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.3 8,976.9 7,095.6 26.00 K -55 BTC 9.625x7" @ 71' Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd - - .. SCAB LINER 5 1/2 4.950 30.7 8,097.8 6,312.0 15.50 L -80 BTCM Liner Details t Top Depth ( i (ND) Top Intl Nomi... Top (ftKB) (ftKB) 0) Item Description Comment ID (in) 7,979.9 6,207.9 28.57 SBE BAKER 5" x 20-8 80-40 SBE 4.000 CONDUCTOR. 9 ___, _ 7,998.3 6,224.0 28.40 XO Reducing 5" BTC -M Box x 3-1/2' EUE 8rd Pin Crossover 2.910 349 8,014.9 6,238.7 2824 PACKER BAKER PREMIER PACKER w/ TC -II threads 2.990 1 8,071.7 6,288.9 27.71 NIPPLE CAMCO 'X' NIPPLE w/ RHC plug installed 2.812 8,089.5 6,304.6 27.55 OVERSHOT BAKER POORBOY OVERSHOT 2.990 Tubing Strings NIPPLE, 495 Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... Str ... String Top Thrd TUBING WO2013 I 31/2 2.992 I 30.8 I 7,990.5 I 6,217.2 9.30 I L -80 IBT Completion Details Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) 0 Item Description Comment ID (in) 30.8 30.8 0.88 HANGER 11 "x 3 Tubing Hanger TCIA / with 3" Type H BPV 2.992 SURFACE 4 13.375x10.75• 7 ,983.1 6,210.7 28.54 SEAL ASSY Baker GBH - 22 Locator sub 8 80 Seal Assembly 3.000 41102, 342,587 _ Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... M Sng ... String Top Thrd TUBING WO 1990 5.8 I 4.750 I 8,091.4 I 8,135.5 I 6,345.5 J GAS LIFT, Completion Details k „: , , 7,930 Top Depth IIIIII (TVD) Top Intl Nomi... gm NM Top (ftKB) (ftKB) 0) Item Description Comment ID (in) 8,110.4 6,323.3 27.31 Overshot SBR OTIS SBR OVERSHOT/SEAL ASSEMBLY 4,750 8,134.5 6,344.7 27.16 SLICKSTICK 3.813 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (5... epth (TVD) . String Wt... String ... String Top Thrd TUBING Original I 3 1/2 2.992 I 8,135.6 8,199.4 I Set D _ 6,402.4 I 9.30 I J -55 I BTC SEAL ASSY, = Completion Details 7,983 Top Depth (TVD) Top Intl Nomi... Top (ftKB) (ftKB) 0) Item Description Comment ID (In) 1-I 8,135.6 6,345.6 27.16 PACKER OTIS HCL PERMANENT PACKER 4.000 all 8,182.0 6,386.9 26.88 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,193.9 6,397.4 26.81 TBG Release VANTAGE TUBING RELEASE 2.750 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth 6, (ND) Top Intl Top (ftKB) (ftKB) 0) Description Comment Run Date ID (in) 8,177.0 6,382.4 26.91 CATCHER CATCHER 3/7 /2013 0.000 8,182.0 6,386.9 26.88 PLUG 2.75" CA -2 PLUG SET IN NIPPLE 3/7 /2013 0.000 8,744.0 6,888.9 26.91 FISH Vann Gun Left in Hole after initial Perf. 1/12/1983 0.000 Perforations & Slots shot Top (ND) etm (TVD) Dens Top (ftKB) Btm(ItKB) (ftKB) (ftKB) Zone Date Oh- Type Comment SCAB 1 - 809 8 8 ` 8278.0 8,304.0 6,472.7 6,496.0 C-4, 1C -10 1/12/1983 4.0 IPERF MN ® 8,308.0 8,344.0 6,499.6 6,531.7 C -, C -3, C -2, 1/12/1983 4.0 IPERF 10 -10 Overshot SBR, 6.170 Notes: General & Safety End Date Annotation 3/24/1990 NOTE: WORKOVER PACKER, 8,136 _..• 11/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 PLUG. 8,182 NIPPLE, 8,182 ,.'. IIII TBG Release. 8 194 Nu IPERF, _ ; Mandrel Details 8,278 -6,304 - Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run N... Top (ftKB) (ftKB) 0) Make Model (in) Sery Type Type (in) (psi) Run Date Com... IPERF, 1 7,930.3 6,164.6 29.03 CAMCO KBG - 2 - 9 ' 1 GAS LIFT SOV DCK - 2 0.000 0.0 4/18/2013 8.308-6.344 _ -- FISH. 8,746 PRODUCTION 9.625x7" e 71 %32-8,977 • TD, 9,002 • • 1C -10 Pre -Rig Workover Well Work Summary • DATE. SUMMARY 1/3/2013 (PRE RWO) : POT -T (PASSED), PPPOT -T (PASSED), POT -IC (PASSED), PPPOT -IC (PASSED), POT -OC (PASSED), PPPOT -OC (PASSED), FUNCTION TESTED LDS'S(1 IC LDS STUCK) 1/26/2013 (PRE -RWO): FUNCTION STUCK IC LDS. ALL IC LDS'S ARE FUNCTIONAL. 3/4/2013 TAGGED @ 8395' SLM. MEASURED BHP @ 8311' RKB: 3255 PSI. IN PROGRESS. 3/5/2013 WEATHER DELAYED START; SET SLIP STOP @ 1842' SLM AND LOCKED OUT TRDP 1A -SSA @ 1801' RKB. ( PERFORMED PRE & POST CLOSURE TESTS CONFIRMING SSSV LOCKED OUT ) . IN PROGRESS. 3/6/2013 PULLED SLIP STOP @ 1842' SLM. JOB SUSPENDED FOR HIGH WINDS. IN PROGRESS. 3/7/2013 SET 2.75" CA -2 PLUG @ 8182' RKB. PT TBG TO 2500 PSI AGAINST PLUG. SET CATCHER @ 8177' RKB. PULLED DV @ 8160' RKB. CMIT TO 3000 PSI ( PASS) READY FOR E /L. 3/27/2013 SHOOT STRING SHOT WITH MID -SHOT AT 8085' CCL TO MID SHOT 5' CCL STOP AT 8080'. IN 3/28/2013 CUT TUBING WITH 2.5" RCT AT 8085' CCL TO CUT 9.4' CCL STOP AT 8075.6' JOB COMPLETE • • ConocoPhillips Time Log & Summary We(Mew Web Reporting Report Well Name: 1C -10 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/4/2013 11:00:00 PM Rig Release: 4/20/2013 1:30:00 AM Time Logs Date From To Dur S, Depth E. Depth Phase Code Subcode T Comment 04/04/2013 24 hr Summa MIRU on 1C -10, Accept Nordic Rig 3 @ 23:00 hrs. Rig up, Berm up and spot equipment 22:00 23:00 1.00 MIRU MOVE MOB P Move rig to 1C -10, Pull over and set down. Level rig. Accept rig @ 23:00 hrs 23:00 00:00 1.00 MIRU MOVE RURD P Rig up and spot equipment. Berm up rig and cuttings box. X4/05/2013 Continue to RU, Berm Up and spot equipment, Load pits w/ 570 bbls of 9.6 ppg NaCI /Br, Pull BPV, Change hole over to 9.6 ppg KWF. Set BPV and test at 1,000 psi from below. ND Tree, install Blanking plug, NU BOPE. 00:00 05:30 5.50 MIRU MOVE RURD P Continue to Spot equipment, RU circ. lines, Load Pits with 10.0 ppg NaCI /Br. 05:30 07:30 2.00 MIRU WHDBO MPSP P PJSM, PU Lubricator and Lub out FMC 'ISA' BPV. Obtain pressures: 10 psi TBG, 180 psi IA, 250 psi OA. 07:30 08:30 1.00 MIRU WHDBO PRTS P PT Lines 250/3500 psi, BDHL 08:30 10:00 1.50 MIRU WHDBO SFTY P Pre -Spud Meeting, PJSM, Prepare to Circulate Kill Weight Fluid 10:00 12:00 2.00 MIRU WHDBO CIRC P Circulate 30 bbls 10.0 KWF NACI /KCI /NaBr concoction down IA through open GLM at 8060' taking returns up Tubing at 2 bpm. ICP 600, FCP 440. Holding 150 psi BP. (note: tested CA2 plug at 8182') Swap over to Pump down Tubing taking returns up IA at 4 bpm. ICP 490, FCP 920 psi, holding BP on choke. Total 330 pumped with —326 returned. 12:00 13:00 1.00 MIRU WHDBOOWFF P Perform NFT, Monitor from open 1502 and plastic bag slightly expanding and contracting with occasional fluid trickle. Shut in Tbg and IA with less than 10 psi. 13:00 15:30 2.50 MIRU WHDBO CIRC P Reverse Circulate 71 bbls to pits through degasser at 2.5 bpm at 220 psi. Swap over and Circulate 285 bbls at 2.5 bpm through degasser at 230 psi. No losses. 15:30 16:30 1.00 MIRU WHDBOOWFF P NFT on Tbg and IA. No Flow. 16:30 17:30 1.00 MIRU WHDBO MPSP P PJSM. Set BPV, PT from below to 1000 psi- pumping down IA. Good test. 17:30 18:00 0.50 MIRU WHDBO NUND P RD and BD Hoses in Cellar. Page 1 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 19:00 1.00 MIRU WHDBO NUND P PJSM, ND Tree and remove Hanger Threads and install MIRU WHDBO MPSP P Inspect Han 19:00 19:30 0.50 p g Blanking Plug. 19:30 23:00 3.50 MIRU WHDBO NUND P Remove trip hazards and congestion from work area and Old Tree from behind cellar. Set 13 -5/8" 5M BOP Stack, when installing head bolts it was found that there was no way to MU to API standards due to well head flange was 1/2" thicker (4 -7/8") than (4- 7/16 ") Standard API. Gather 16 - 1 -5/8" x 15" bolts. 23:00 00:00 1.00 MIRU WHDBOOTHR P Continue to load 3 -1/2" DP in pipe shed. J4/06/2013 Continue to NU BOPE. Test 13 -5/8" 5M BOPE with 3 -1/2" and 5 -1/2" Test jts. at 250 / 3,500 psi. Pull BPV, MU landing jt. 00:00 04:00 4.00 MIRU WHDBO NUND P NU 13 -5/8" 5M BOP 04:00 06:00 2.00 MIRU WHDBO BOPE P Conduct Initial BOP test 250 / 3,500 psi w/ 3 -1/2 and 5 -1/2 Test Joints. Shell test against blind rams - found Blanking Plug leaking - returns thru IA valve. Attempt to test CM - found Valve to be leaking. Pull blanking plug and inspect. Grease CM. 06:00 14:30 8.50 MIRU WHDBO MPSP T Replace lost Dovetail Seal, repack Ball and Seat and reset Blanking Plug. BP leaking a second time. Replace second lost Seal, No FMC Reps available to hot shot Second Plug. Repack and drain Stack to attempt to keep any Debris from interfering with Ball Seat and reset. Still leaking- Try ramping up with Mud Pumps to seat Ball. Pull BP and still have Seal. FMC rep in Deadhorse gathering new Plug and Seals and heading West. Drain Stack again and attempt 4th time with Dovetail Seal upside down, and still no test. Pull out and 3rd Seal missing. Drain Stack and reattempt 5th time with 4 -1/2" Oring on top of BP Shoulder. No pass. RD Blanking Plug and start testing Choke. Page 2of11 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 20:00 5.50 COMPZ RPCOM PULD P Start testing Choke while waiting on BP. New Test Plug arrives from Deadhorse. New Plug equiped with Dovetail Seal with Oring on Blanking Plug Shoulder. Different size Oring than previous run. (Oring Size information requested and to be furnished) Test Plug holding pressure.. Continue testing BOPE. RD Test equipment. 24 hr to AOGCC @ 12:51 hrs on 4 -4 -13 and Right to witness was waived by Jeff Jones @ 7:25 hrs on 4 -5 -13 via phone 20:00 23:00 3.00 COMPZ WHDBO MPSP P PJSM, Pull Blanking plug had flow from under BPV. Close blind rams and RU hose to IA back to CM. Circulate 20 bbls of KWF down TBG thru BPV @ .75 bpm. Tap into BPV, and release valve. 23:00 00:00 1.00 COMPZ RPCOM OTHR P MU Landing jt and screw in Top Drive, BOLDS. X4/07/2013 BOLDS, Un -land tbg hanger, hanger not functioning properly. Circulate while waiting for Eline. RU and RIH w/ Eline, cut and pull TBG from 223 -ft. RIH and engage overshot. RU and preparing to RIH w/ 2.5" OD RTC 00:00 03:30 3.50 8,085 8,085 COMPZ RPCOM PULL T Continue to BOLDS, Unland hanger @ 100K fell back to 80k free travel for 2 -ft. Began to pull over to 110k w/ block wt. Observed down thru the BOP stack and seen that the Hanger pack off assembly was not moving with the TBG string. Stop the job and call Town Engr to discuss operations. FMC supervisor was notified. Decision was made to reverse circulate while waiting for E -Line crew to cut TBG again © 8,085 -ft± and again at 100 -ft. 03:30 08:00 4.50 8,085 8,085 COMPZ RPCOM CIRC P RILDS, Reverse circulate @ 2 bpm 08:00 09:00 1.00 8,085 COMPZ RPCOM PULD P PJSM, LD Landing Joint, BDTD. MU 2 - 10' 3 -1/2" EUE Pups to Hanger 09:00 12:00 3.00 COMPZ RPCOM ELNE P PJSM, MIRU Eline 12:00 14:00 2.00 COMPZ RPCOM ELNE P RU HES Eline, MU RCT Cutter. RIH and Cut Tubing at 220'. POOH and RD Eline. 14:00 14:30 0.50 COMPZ RPCOM PULD P LD 3 -1/2" EUE Landing Joint. MU 3 -1/2" IF Landing Joint Page 3 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 18:30 4.00 0 222 COMPZ RPCOM PULL P PJSM. Attempt to pull Hanger 3 times to 85k #. BOLDS. Pull Hanger with Tubing cut at 220'. Up wt 57k# (including 35K# Blocks) with no over pull. Complete Hanger comes to Rig Floor. Control Line comes to Floor and appears to still be attached to SSSV. POOH laying down hanger w/ 4 -1/2" LTC x 3 -1/2 DSS HTC, 1 -jt 3 -1/2, 9.3#, J -55, DSS HTC Tubing, 3 -1/2" DSS HTC x 3 -1/2" EUE 8rd X -O sub, 2 - 3 -1/2 ", 9.3#, J -55, EUE 8rd Pup joints (15.09, 6.10 -ft), 3 -1/2 ", 9.3 #, J -55, EUE 8rd Box x DSS HTC Pin crossover sub, 5- full joints of 3 -1/2, 9.3 #, J -55, DSS HTC Tubing, 1 cut joint of 3 -1/2, 9.3#, J -55, DSS HTC Tubing - 11.87 -ft. 18:30 20:00 1.50 0 0 COMPZ RPCOM OTHR P Offload 3 -1/2 De completion and load 15 joints of "New" 3 -1/2 ", 9.3#, L -80, EUE 8rd Tubing. Drift and Tally. 20:00 21:00 1.00 0 8,085 COMPZ RPCOM FISH P PU, MU and RIH w/ 5 -3/4" Bowen overshot w/ 3 -1/2" GR#6112 and 3 -5/8" Mill control on 7 joints of 3 -1/2, 9.3 #, L -80, EUE 8rd Tubing plus 6 -pup jt. X -O to 3 -1/2 IF and working joint. Tag @ 227 -ft and Engage fish @ 229 -ft and pull up to 120k. Land in slips @ 115k. Break off 3 -1/2 IF working joint. 21:00 00:00 3.00 8,085 8,085 COMPZ RPCOM ELNE P PJSM, RU Eline to RIH w/ 2.5" RTC. X4/08/2013 RIH w/ Eline to 8,085 -ft and attempt to cut TBG with 20k osw. RD Eline, POOH w/ tbg to last 52 jts. MU baker storm packer RIH to 100 -ftt. 00:00 02:45 2.75 8,085 8,092 COMPZ RPCOM ELNE P RIH w/ 2.5" OD RCT cutter and RIH to 8,100 -ft, Correlate and get on depth. Set CCL @ 8,082.5 -ft and cut @ 8,092 -ft. w/ pipe in slips @ 115k. Had to cycle wirerline jars 3 times, POOH and RD E -line. CCL showed signs of cut @ 8,085 -ft. 02:45 05:00 2.25 8,092 7,860 COMPZ RPCOM PULL P Pull pipe out of slips. Wt still @ 115k, Close annular and pressure up to 1,500 psi 3 times seen 5k loss every cycle. Open annular and had pipe movement @ 115k. BDTD. Continue to POOH to overshot, Lay down fish and break down OS. 8rd Top sub gaulded. Page 4 of 11 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 10:00 5.00 7,860 7,020 COMPZ RPCOM PULL P Change out elevators and continue laying down 3 -1/2 ", 9.3 #, J -55 Atlas Bradford DSS HTC tubing f/ 7,860 -ft to 7020'. Pulling out at 110k# (including 35k# BW), Completion String hanging up intermittently. Line up and pump down Tubing taking returns up IA. Able to fluff and pull. Hanging up at with 30k# overpull at 7020' and stacking out RIH. 10:00 12:00 2.00 7,020 7,020 COMPZ RPCOM CIRC P Mix and spot 200 bbls SW with 1 ppb Flowzan and 0.6% SafeLube. Pull free and new up weight 2ok# lighter —90k# and pulling smooth. 12:00 15:30 3.50 7,020 6,300 COMPZ RPCOM PULL P POOH with 3 -1/2" Completion to SSSV at 6300'. Recover all of the Control Line and total of 31 Of 37 Stainless Steel Control Line Bands. 15:30 16:00 0.50 6,300 6,300 COMPZ RPCOM PULD P Rig Down Camco Spooler and Clear Floor. 16:00 17:30 1.50 6,300 5,100 COMPZ RPCOM PULL P Continue POOH with POOH with 3 -1/2" Completion 17:30 19:30 2.00 5,100 5,100 COMPZ RPCOM PULD P Stap, Tally and KO Decompletion. 19:30 23:30 4.00 5,100 2,740 COMPZ RPCOM PULL P Continue POOH for a total of 197 jts of 3 -1/2" Completion 57k up 56k dn wt 23:30 00:00 0.50 2,740 2,840 COMPZ WHDBO PACK P PJSM, PU, MU and RIH w/ 7" Baker Storm Packer assy on top of 2,740 -ft of 3 -1/2 ", 9.3 #, De completion (22,000#) 04/09/2013 Continue MU, RIH and set Storm Packer at 98'. Test @ 2,500 psi and perform NFT- Good. ND BOPE. Allow Casing to grow 4 -1/2 ". ND and Remove 13 -5/8" x 13 -5/8" Tubing Head. Install new 9 -5/8" Mandrel Packoff in Casing Head. Push Casing back down with BOP Stack weight 40k# and RILDS. Nipple up new 13 -5/8" x 11" Casing Head for new 5 -1/2" Casing String where the Tubing Head used to be. Test Packoff to 5000 psi- good test. 00:00 01:15 1.25 2,840 101 COMPZ WHDBO PACK P RIH and set top of packer @ 101 -ft and center of element @ 110 -ft. W/ tail at 2,840 -ft 57K up wt, 56K dn wt. 01:15 03:00 1.75 101 101 COMPZ WHDBO PRTS P PT Storm packer @ 2,500 psi - lost 150 psi in 25 minutes, bump back up to 2,500 psi - lost 100 psi in 15 minutes. Drain Trip tank, plus choke and kill line. NFT - Good 03:00 06:00 3.00 0 0 COMPZ WHDBO NUND P PJSM. ND BOPE 06:00 10:00 4.00 0 0 COMPZ WHDBO NUND P ND Tubing Head and Casing wants to grow. Change out Tubing Head Studs. ND FLow Riser to allow room for Casing Growth. 10:00 10:30 0.50 0 0 COMPZ WHDBO NUND P Rack Back BOP Stack and allow Casing growth. Grows 4 -1/2 ". 10:30 12:00 1.50 0 0 COMPZ WHDBO NUND P Continue to ND and Remove 13 -5/8" x 13 -5/8" Tubing Head. Page 5 of 11 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:00 15:00 3.00 0 0 COMPZ WHDBO NUND P Install new 9 -5/8" Mandrel Packoff in 13 -5/8" x 13 -5/8" Casing Head and pushed Casing Back down with BOP Stack weight 40k #. RU Come -along in Cellar for last 1/4" to RILDS. 15:00 17:30 2.50 0 0 COMPZ WHDBO NUND P Load new 13 -5/8" x 11" Casing Head to Cellar and NU new Casing Head for the new 5 -1/2" Casing String where the Tubing Head used to be. 17:30 19:30 2.00 0 0 COMPZ WHDBO NUND P Rig up and P -test Packoff to 5000 psi for 15 minutes. Passed. 19:30 00:00 4.50 0 0 COMPZ WHDBO NUND P Clean bolts and N/U 13 5/8" 5M XO spool & BOPE 04/10/2013 Pull storm packer and decompletion string from 2740', inspection of the cut tubing indicates top cut, 6ft fish left in hole. P/U BHA #4 with 5 3/4" Overshot with 3.5" grapple. RIH, drifting 3.5" DP, the drift was dropped down the string while handling joint # 66 (2340'). POOH standing back to inspect BHA for the drift. 00:00 03:30 3.50 0 0 COMPZ WHDBO NUND P Continue to NU BOPE. 03:30 04:30 1.00 0 0 COMPZ WHDBO BOPE P Install test plug & shell test 250/3500 psi. 04:30 07:30 3.00 0 0 COMPZ WELLPF PULD P P/U BHA #2 & RIH 98' to top of Storm Packer 57K up. P/U weight 60K. Let the elements relax. P/U 100' and circ B/U at 4 bpm, 130 psi. Off Load Baker Tools. 07:30 08:00 0.50 2,740 2,740 COMPZ WELLPFOWFF P NFT, Well is static. 08:00 10:00 2.00 2,740 2,740 COMPZ WELLPFCIRC P Start Pulling Tubing and Tubing and IA appear to be out of balance. Shut in and test CA2 Plug to 1000 psi - good test. Circulate another 120 bbls of 9.9 ppg Brine at 4 bpm, 130 psi. 10:00 15:00 5.00 2,740 0 COMPZ WELLPF PULL P NFT, Static. Start to pull Tubing from 2740'. Up 55k# laying down 3 -1/2" Decompletion- strapping and tallying every 45 Joints. 15:00 15:30 0.50 0 0 COMPZ WELLPF PULD P PJSM. Change out Floor Equipment 15:30 16:00 0.50 0 0 COMPZ WELLPF PULD P PJSM. Install Wear Ring 16:00 17:00 1.00 0 0 COMPZ WELLPF PULD P PJSM. MU BHA #4 Baker 5 -3/4" Overshot with 3 -1/2" Grapple 17:00 20:30 3.50 0 2,340 COMPZ WELLPF TRIP P PU DP and RIH with BHA#4. While TIH on joint # 66 ( 2340') the drift was not found at surface. 20:30 23:00 2.50 2,340 2,340 COMPZ WELLPF FISH T Stand down with crew, search rig floor and pipe shed. No luck locating drift. Call town to discuss plan forward. Discussion of drift size was 1- 3/4" X 15" or 2 - 1/8" X 12 ". Not known which was ran in hole. 23:00 00:00 1.00 2,340 1,800 COMPZ WELLPF TRIP T POOH slowly, standing back and drifting 3.5" DP. 04/11/2013 Recover 2 -1/8" drift from BHA. RIH with BHA #4 -Baker 5 -3/4" Overshot with 3 -1/2" Grapple to 8087'. Tagged up, worked string down to 8091'. Pickup with 4K overpull- subsequent trips to tag smoother. POOH to inspect BHA for 6' Tubing Stub Fish. H2S Muster - " "Drill only** Page 6 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 1,800 0 COMPZ WELLPF TRIP T POOH to inspect BHA for dropped drift. 02:00 02:30 0.50 0 0 COMPZ WELLPF PULD T Recovered 2 -1/8" drift on top of jars. 02:30 04:00 1.50 0 0 COMPZ TRIP T PJSM - M/U BHA and RIH. 04:00 06:00 2.00 0 4,015 COMPZ WELLPFTRIP P Back on regular time - PJSM - P/U singles and drifting with 2 1/8" drift to 4015'. 06:00 09:00 3.00 4,015 4,015 COMPZ WELLPF CIRC P Circulate 4 bpm- 280psi while drifting DP in PipeShed. Circulate 573 bbls with no losses. 09:00 14:00 5.00 4,015 8,081 COMPZ WELLPF TRIP P PJSM. PU DP and RIH from 4015' to 8081'. Up 153k #, Down 100 k #. 14:00 14:30 0.50 8,081 8,091 COMPZ WELLPF FISH P MUTD, Up 155k #, Down 100k #. RIH to 8087' and tag. Turn DP 1/2 turn and ease back down and see weight bobble as we made it down to 8091'. Pull up and see 4k# overpull and drop off to normal up weight 153k #. RBIH and tag at 8091' without seeing weight bobbles. 14:30 15:00 0.50 8,091 8,051 COMPZ WELLPF OWFF P PU to 8051'. BDTD, NFT- Static. 15:00 21:30 6.50 8,051 3,941 COMPZ WELLPF PULL P PJSM, POOH from 8049' Pulling wet. 21:30 22:30 1.00 3,941 3,941 COMPZ WELLPF SFTY P Pull Full H2S muster with after action review. Document findings and areas of improvement. 22:30 00:00 1.50 3,941 1,900 COMPZ WELLPF PULL P Continue POOH 04/12/2013 Inspected BHA from first fishing trip, No fish, one metal band recovered. BHA packed off with sand, schmoo, clay material up into the jars. Decision made to try same BHA pumping while on bottom to clean up debris. TIH - pump 5 bpm @ 810 psi on bottom, circulate 3 bottoms up, indication look like fish is latched. POOH - no fish, BHA was clean. P/U BHA # 6 with 6" wash over shoe & 7" casing scraper. 00:00 01:00 1.00 1,900 235 COMPZ WELLPF PULL P POOH to surface 01:00 02:00 1.00 235 0 COMPZ WELLPF PULD P Lay down BHA - No Fish. Recovered one more metal band. Overshot & jars packed full of clay, sand, downhole debris. Discuss with town, fishing hand next run due to excess fill in tool. 02:00 02:45 0.75 0 209 COMPZ WELLPF PULD P P/U BHA #5. 5 3/4 overshot with 3 1/2 grapple & pump out sub. 02:45 09:00 6.25 209 8,080 COMPZ WELLPFTRIP P TIH to 8080'. Up wt 153k #, down 98k #. Circ 5 bpm @ 840 psi. 09:00 10:00 1.00 8,080 8,095 COMPZ WELLPF FISH P Continue RIH pumping 6 BPM at 990 psi. Pump pressure increased to 1090 psi at 8092' and continue to 8095' and No -go out. Pump pressure decreased to to 990 psi. Weight bobble indication of grapple going over the Fish. PU and rotate 1 turn to right and RBIH and smooth on weight indicator. PU 8', rotate another turn to the right and retag same spot. 10:00 15:00 5.00 8,095 210 COMPZ WELLPF TRIP P POOH to inspect overshot. Page 7 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 1.00 210 0 COMPZ WELLPF PULD P PJSM. LD BHA. No fish. Metal mark gouge on bottom of BHA Cut Lip and no indication of marks on the inside of Grapple. 16:00 21:30 5.50 0 0 COMPZ WELLPF OTHR T Finish load, strap, and tally of 5 -1/2" while waiting on additional section of Washpipe for Scraper run. Tools left Deadhorse @ 20:00 hrs. 21:30 22:30 1.00 0 0 COMPZ WELLPF PULD P PJSM - Make up BHA # 6 wash pipe, mill shoe and casing scraper. 22:30 00:00 1.50 0 2,240 COMPZ WELLPF TRIP P RIH with DP 04/13/2013 Tag fish @ 8095 with wash over shoe - Try to wash over - no luck. Mill top of fish for 1ft. P/U and try to wash over again set down 10K with no luck. POOH, inspect BHA. Mill had light wear on bottom of shoe with little to no wear on the inside. Set test plug, BOP test waived by Chuck Scheve. 00:00 03:00 3.00 2,240 8,080 COMPZ WELLPF TRIP P TIH with wash -over BHA. 03:00 05:00 2.00 8,095 8,086 COMPZ WELLPF MILL P Establish SCR 65 psi © 40 SPM. P/U weight 148K, TIH weight 118K, Set down @ 8095' Weight 100K. P/U to 8085' Increase pump rate to 6 bpm @ 1100 psi. Try to wash over fish, no luck. Set down @ 8094'. P/U to roll over fish. RPM 20, torque 3300 psi. Stalled @ 8094'. Twice same spot. P /U, increase to 50 RPM, torque 4700psi. - setting down 1 -2K. Mill 1ft. Stop P/U and try to drift over fish again, no luck. Tagging 1ft deeper 8096' 05:00 06:00 1.00 8,086 8,086 COMPZ WELLPFCIRC P Circulate 6 bpm at 1140 psi while discussing with town eng. 06:00 07:00 1.00 8,096 8,086 COMPZ WELLPF OWFF P Dry tag at 8096'- set down at 10k #'. PU to 8086' and BDTD. 07:00 12:30 5.50 8,096 540 COMPZ WELLPF TRIP P POOH from 8086'- up wt 150k# to 540'. 12:30 14:00 1.50 540 0 COMPZ WELLPF PULD P At 540'. NFT - static. PJSM. LD BHA #7. Some wear on bottom of the Mill, no marks inside. Recover some Steel Band Parts =-1 band. 14:00 15:15 1.25 0 0 COMPZ WELLPF MPSP P PJSM, PULL Wear Ring, Drain Stack and Install Test Plug. 15:15 21:15 6.00 0 0 COMPZ WHDBO BOPE P PJSM. Test BOPE 250 / 3500 psi with 3 -1/2 and 5 -1/2 Test Joints. State Rep Chuck Scheve waived witness on 4/13/13 at 9:11 AM via email. Completed up to 3.5" test joint. No failures. 21:15 00:00 2.75 0 COMPZ WHDBO BOPE P Make up /torque X -overs on 5.5" test joint and complete final 4 tests. 04/14/2013 Complete BOP test, RIH with BHA # 7 5 3/4" overshot with 3.5" extension grapple, tagged TOF @ 8096'. P/U and rotate down over fish to 8100', good indication over fish, POOH - 5ft fish recovered. RIH to wash over 3.5" completion stump from 8099' - 8115', POOH sideways. 00:00 01:00 1.00 0 0 COMPZ WHDBO BOPE P Complete BOP & Drawdown test. 01:00 02:00 1.00 0 0 COMPZ WHDBO SEQP P Pull test plug and set wear ring. Page 8 of 11 Time Logs • • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02:00 03:00 1.00 0 211 COMPZ WELLPF PULD P PJSM - P/U BHA #7 - 5 3/4" overshot, overshot extension, 3.5" grapple & pump out sub. 03:00 06:00 3.00 211 8,045 COMPZ WELLPF TRIP P TIH with BHA # 7. 06:00 08:30 2.50 8,045 8,045 COMPZ WELLPF SLPC P BDHL, Changeout, PJSM, Slip and Cut Drilling Line 08:30 10:00 1.50 8,045 8,100 COMPZ WELLPF FISH P Continue RIH Circulating at 6 bpm at 910 psi. Up 140k #, 104k# down. tag at 8096'. PU to 8086' and start Rot at 25 RMP at 3500 ft -lb, 117k #. Work easily down to 8100'. Observe no overpull. Pick up and RIH Rotating 50 rpm and tag same spot 8100'. Dry tag again at same spot. 10:00 10:30 0.50 8,100 8,054 COMPZ WELLPF OWFF P POOH from 8100 to 8054'. BDTD. PJSM, NFT- static. 10:30 14:30 4.00 8,054 506 COMPZ WELLPF PULL P POOH from 8054', up 145k #. 14:30 15:00 0.50 506 0 COMPZ WELLPF PULD P At 506', perform NFT- static, PJSM, LD BHA #7. Recover 4.6' of 3-1/2" Tbg Stub Fish. 15:00 16:00 1.00 0 0 COMPZ WELLPF PULD P Clean and clear Floor. Load Baker Tools. 16:00 17:00 1.00 0 240 COMPZ WELLPF PULD P PJSM. MU BHA #8, Baker Washover Assembly. 17:00 22:00 5.00 240 8,080 COMPZ WELLPF TRIP P TIH with BHA # 8. Stop right above 3.5" stub. Up weight 148K, down 100K. 22:00 00:00 2.00 8,080 8,115 COMPZ WELLPF WASH P Establish pump rate 6 bpm, 1100 psi. Slowly work string down over 3.5" stub. Saw small weight bobble @ 8099', 40 psi increase in pump pressure to 1140psi @ 8100'. Continue down to 8115', make three passes while pumping 6 bpm @ 1100psi. Circ B/U to ensure well is clean of debris. 04/15/2013 POOH sideways with DP. Clear rig floor & Rig up Eline. Complete Gyro and Caliper logs from 8091' to surface. 00:00 00:30 0.50 8,115 8,115 COMPZ WELLPFCIRC P Completed pumping B /U. Flow check - good. 00:30 08:15 7.75 8,115 360 COMPZ WELLPF TRIP P POOH sideways with 3.5" DP, kick out DP. 08:15 08:30 0.25 360 360 COMPZ WELLPF OWFF P At 360', check well for flow- static. 08:30 09:30 1.00 360 0 COMPZ WELLPF PULD P Pull and LD Collars, LD BHA, PJSM, pull Wear Ring 09:30 11:00 1.50 0 0 COMPZ EVALWE ELOG P PJSM, RU HES Eline 11:00 17:30 6.50 0 0 COMPZ EVALWE ELOG P Eline logging Gyro from 8060' to surface. 17:30 20:00 2.50 0 0 COMPZ EVALWE FLOG P Calibrate tools, PJSM for rigging up on Caliper run. 20:00 00:00 4.00 0 0 COMPZ EVALWE ELOG P Caliper log from 8060' Page 9 of 11 • I Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04/16/2013 24 hr Summary RIH with 5 1/2" completion string, tagged top of tbg stub @ 8092'. Set down 10K for shear screws, No -go out @ 8100', P/U to 8092' and reverse circulate 55 bbls of inhibited brine followed by 25 bbls of gelled diesel. Space back outon tubing stub, drop 1 5/16" ball & rod. Set and test packer 4200psi, test 5 1/2" X 7" ann 1500 psi, draw down test. Set RBP @ 50', test to 1500 psi. ND BOPE. 00:00 01:00 1.00 0 COMPZ EVALWE FLOG P Rig down E -line. Set up floor for handling 5 1/2 "casing string. 01:00 13:00 12.00 8,100 COMPZ WELLPF PUTB P PJSM - P/U 5 1/2" Casing string average toque 4000 #. TIH tag top of tubing stump @ 8096 ft. sheared down with Poorboy over shot. With do y 10 k. and tag down with no /go. 13:00 16:00 3.00 COMPZ RPCOM CIRC P PJSM and rig up Liitle Red to reverse circulated 52 bbls of 9.6 # corrosion treated brine followed by 22 bbls of gelled Diesel @ 1.5 BPM @ 250 psi. 16:00 18:00 2.00 COMPZ RPCOM PACK P droped ball & rod pressured up on packer to 4200 psi. Premier paker set @ 8013 center of elements. bled off 7 " annulas from 1050 psi to 0 psi lost 200 psi on 5.5 csg. pressure back up to 4200 anfd held for 10 mins. 18:00 19:00 1.00 COMPZ RPCOM PACK P pressure test 7 " X 5.5 " annulas to 1500 psi and chart. bleed off pressure anf N/F for 30 mins. 19:00 22:00 3.00 COMPZ RPCOM MPSP P PJSM - M/U Baker RBP with 3.5" pipe. RIH to 50', set and pressure test to 1500 psi /15 minutes. Bleed down and perform no -flow test. Hold PJSM for ND BOP's while doing the no -flow test. Get tools and equipment ready. 22:00 00:00 2.00 COMPZ WHDBO NUND P Start ND BOPE & loading 3.5" completion string. 04/17/2013 Set 5 1/2" casing, cut 28.64' on joint # 189, set in emergency slips. Install & test casing pack off, install TBG head, test 250 /5000psi. N/U BOPE, change ram configuration & test 250/3500 psi. 00:00 01:00 1.00 COMPZ WHDBO NUND P ND BOPE 01:00 02:30 1.50 COMPZ WHDBO HOSO P String weight 155K - P/U 20K over to 178K, 12" stretch. Install Emergency slips and cut 28.64' of joint number 189. Rig down FMC. 02:30 06:00 3.50 COMPZ WHDBO NUND P Break flanges loose between lower pipe rams, DSA & Flow crosss. Sit back down, break off top flange, rack back stack on stump. Remove lower DSA. 06:00 07:30 1.50 COMPZ WHDBO PRTS P Install and test pack off 250 / 5000 psi. 07:30 20:30 13.00 COMPZ WHDBO NUND P remove picture nipple and install 11" X 13 5/8" Xover spool install BOPE and change ram configuration to VBR ram on Bottom and blind rams on top in double gate. Page 10 of 11 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 COMPZ WHDBO BOPE P Test BOP's and flange connections 250/3500 psi. leaking from flanges in cellar. Continue M/U flanges. 04/18/2013 Complete BOPE test 250/3500 psi. P/U and TIH with 3.5" completion string. Engage seals @ 7979', no-go, P/U for space out. Circulate 200 bbls of inhibited SW. Land & space out with 7.4' of allowance for future subsidence, land 11" X 3.5" tubing hanger. Tested tubing to 3000psi, IA to 3500 psi, followed by a no -flow for 30 minutes. Pressure up and shear SOV @ 1780psi. Pull landing joint, test two way CV to 1000 psi. 00:00 02:00 2.00 COMPZ WHDBO BOPE P Complete testing BOP'S 02:00 03:00 1.00 COMPZ WELLPF PUTB P Prep for 3.5" completion run, clea up rig floor & shed. 03:00 04:30 1.50 COMPZ WELLPF MPSP P PJSM - M/U and retrieve RBP. 04:30 18:00 13.50 COMPZ RPCOM RCST P Start P/U 3.5" completion string. engaged PBR @ 7979 ft droped in to no go . spaced out tubing install hanger. 18:00 21:00 3.00 COMPZ RPCOM CIRC P Crew change - PJSM - Circulated well over to corrosion treated sea water pumping 3 bpm. 21:00 22:00 1.00 COMPZ RPCOM THGR P Up weight 105K, Dwn weight 77K, Pump 1/2 bpm and locate seals assembly. Good indication, stop pumping. Drain the stack and land the tubing hanger 10.5' on seals. Total of 7.4' space out to no -go. RILDS 22:00 00:00 2.00 COMPZ RPCOM PRTS P Set up lines and P -test the final string. Tubing 3000 psi / 15 min. Good. Bleed down to 2500 psi - test IA to 3500 psi / 30 minutes - pass Bleed down to zero and perform 30 minute no flow test. 04/19/2013 ND BOPE, NU new 3 1/8" 5K tree. Pressure test 250/5000 psi. Freeze protect well with 60 bbls diesel - 2200ft. Set BPV, RDMO 00:00 01:30 1.50 COMPZ RPCOM MPSP P Bump up IA and shear out SOV @ 1790psi. Pull landing joint and set Two Way Check. Test to 1000 psi. - good. 01:30 11:30 10.00 COMPZ WHDBO NUND P PJSM - ND BOPE stack, remove all BOPE ram components for cold stack. 11:30 17:00 5.50 COMPZ WHDBO NUND P NU tree and test to 250 / 5000 17:00 20:00 3.00 COMPZ WHDBO FRZP P RU Little Red Hot Oiler service to pump 52 BBLs of diesel to freeze protect well to 2200 ft. U -tube well. 20:00 00:00 4.00 COMPZ WHDBO MPSP P Set BPV, test tree to 5K, bleed down. Secure cellar & prep to move rig. 04/20/2013 Continue swapping 13 5/8" back to 11" BOPE stack. Rig Release at 01:30 HRS. Travel to 1D pad. 00:00 01:30 1.50 COMPZ MOVE NUND P Pull off well, Remove 13 5/8" stack. COMPZ * * * ** *Rig Release * * * ** Page 11 of 11 V OF 7•4 • 0 s v THE STATE Alaska Oil and Gas i L1. j ° ALASKA Conservation Commission GOVERNOR SEAN PARNELL ,,. -• 333 West Seventh Avenue pF Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Jonathan Coberly Wells Engineer R 1 ���� ConocoPhillips Alaska, Inc. SLp�N�,ED �A \q P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1C -10 Sundry Number: 313 -030 Dear Mr. Coberly: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, °-1-64 Cathy P. oerster JJ�� Chair T� DATED this U day of February, 2013. Encl. a l I�i� �:AVGV STATE OF ALASKA 1k, AL�:A OIL AND GAS CONSERVATION COM ION t A'' JAN 2 4 2013 APPLICATION FOR SUNDRY APPROVALS �'� 20 AAC 25.280 �� 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair w ell 1✓ - Change Approved Program E Suspend r Rug Perforations r Perforate r Pull Tubing 14• Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing j:. • Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 182 - 193 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20865 - 00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? 71"aAtvA3 Will planned perforations require spacing exception? Yes r No IW KM. 1C 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25650 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9002 7118 8890' 7018' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 65 20 99' 99' SURFACE 2533 10.75 2567' 2284' PRODUCTION 8945 7 8977' 7096' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): • 8278' 8304', 8308' - 8344' • 6473' 6496', 6500' - 6532' 3.5 J - 8199 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - OTIS HCL PERMANENT PACKER • MD= 8136 TVD= 6346 SSSV - CAMCO TRDP -1A -SSA MD =1801 TVD =1696 12. Attachments: Description Summary of Proposal 17 ' 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch r Exploratory ]- Stratigraphic r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/23/2013 Oil r Gas E WDSPL r Suspended t 16. Verbal Approval: Date: WINJ r GINJ r WAG Abandoned (— Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jonathan Coberly @ 265 -1013 Email: Jonathan .CoberIvAconocoohillips.com Printed Name Jonathan Cober Title: Wells Engineer Signature PC(...)\ Phone: 265 -1013 Date I/ Irt1201 C Commission Use Only Sundry Number:51 (3 ,5/\ Conditions of approval: Notify Commission so that a representative may witness ✓ ✓vv Plug Integrity r BOP Test 'f" Mechanical Integrity Test r Location Clearance r b � 3 R DMS FEB 11 201' Other: 50 p i_cs l "v ..J 5 77 6 p 5- L / 1 Spacing Exception Required? Yes ❑ No [i Subsequent Form Required: / a , d D - , APPROVED BY Approved by: / ,i7Q�j� -- -COMMISSIONER THE COMMISSION Dater $ l Approved application is valid for 12 months from the date of approval. s ) `�ti,r Z !$ J �,t:'� \ ,� J ,� Su b Form and Submit F Atta e c o R� r GTrt°12 ! ! ,ko ,;,��,; R1L0�t N AL .,7-y __ • RECEIVED JAN 2 4 2013 Conoco Phillips �,� Alaska AO P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 January 23, 2013 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Injector 1C -10 (PTD 182 -193). 1C -10 was completed into the Kuparuk C -sand interval in 1982. A workover in 1990 replaced the tubing above the packer. 1C -10 is an injector that provides pressure support to producing wells 1C -02, 1C -24, 1D -01, and 1D -04A in the Kuparuk C -Sand. 1C -10 ceased miscible gas (MI) injection in October 2007 due to an inner annulus by outer annulus gas communication through the production casing threads. The well is currently waivered and injecting water. By bringing MI back online, it is expected that oil production in the offset producers will increase and result in incremental oil recovery in the area over the remaining life of the injector. The last MITIA and MITOA passed on 5/19/2012. A CMIT TxIA is planned to occur during pre -rig well work. To bring MI back online in this well, the well has been identified as a candidate for a rig workover. The plan for this rig workover is to install a new 5 'h" casing string with a packer and to replace the existing 3 'h" tubing string above the packer. The new casing string will provided the needed pressure barrier to gas and liquid from the formation. The most recent SBHP in the Kuparuk C -sand taken on 8/13/2011 measured 4,057 psi at 6,502' TVD is equivalent to a 12.0 ppg equivalent mud weight. An updated Kuparuk C -sand pressure will be obtained during pre -rig work to calculate the necessary KWF required for the job. However, since the reservoir will be isolated during the rig workover with a plug, seawater will be the workover fluid used. If you have any questions or require any further information, please contact me at 265 -1013 or Jonathan.Coberly@conocophillips.com. Sincerely, Jonathan Coberly Wells Engineer CPAI Drilling and Wells • • IC-10 Rig Workover, P &R Tubing/Install 5 1 /2" Casing (PTD #: 182 -193) Current Status: Kuparuk well 1C -10 is a Kuparuk C -sand injector. The well is currently injecting water to provide pressure support to surrounding producers. MI is shut in due to IA x OA communication to gas. Scope of Work: Pull 3 ' /2" tubing, inspect the 7" casing, install new 5 'h" casing w/ packer, and install new 3 'h" tubing. General Well info: MASP: 2,400 psi Reservoir pressure/TVD: Kuparuk C -Sand — 4,057 psi / 6,502' (12.0 EMW) measured 8/13/2011 Wellhead type /pressure rating: FMC ARCO PBU Gen II, 4 1/16" 5M top x 13 5 / 5M btm Nordic 3 BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -OA — passed on 5/19/2012 MIT -IA — passed on 5/19/2012 POT - T/PPPOT -T /POT - IC/PPPOT - IC/POT - OC/PPOT -OC — passed 1/3/2013 CMIT TxIA — scheduled during pre -rig well work Well Type: Injector Estimated Start Date: February 23, 2013 Production Engineers: David Lagerlef / Dana Glessner Workover Engineer: Jonathan Coberly (265 -1013 / Jonathan.Coberly @conocophillips.com) Proposed Pre -Rig Work: Slickline 1. RU SL. RIH and lockout TRDP -1A -SSA (2.812" ID) safety valve at 1,801' RKB. POOH. 2. RIH w/ dual Panex gauges and get updated Kuparuk C -Sand SBHP. POOH. 3. RIH and set CA -2 plug in `D' Nipple (2.75" ID) at 8,182' RKB. POOH. 4. CMIT TxIA 3,000 psi. 5. RIH and set catcher on top of CA -2 plug at 8,182' RKB. POOH. 6. RIH and pull DV from GLM #1 at 8,060' RKB. Leave open. RD SL. E -Line 1. RU E -Line. RIH w/ string shot to 8,085' RKB. Fire string shot. POOH. 2. RIH w/ 2.5" OD standard sized RCT to 8,085' RKB. Cut tubing. POOH. RD E -Line. Other 1. Set BPV within 24 hours prior to rig arrival. Proposed Procedure: 1. MIRU. 2. Pull BPV. Reverse circulate seawater. Monitor the well for a minimum of 30 minutes. If still seeing pressure, weight up and repeat circulation using new kill weight fluid. 3. Install BPV. Pressure test the BPV. ND tree. 4. Install blanking plug. NU BOPE. Function and PT BOP rams and choke manifold to 250/3,500 psi, PT, annular to 250/3,500 psi. 5. RU to pull tubing. Pull the blanking plug and BPV. Verify that the well is static. 6. MU landing joint, BOLDS, and pull tubing hanger to the floor. If the lift threads look damaged or landing joint is unavailable, use a spear to pull the tubing hanger. 7. Reverse circulate seawater. Monitor to ensure there is no flow. • • 8. TOOH laying down the tubing. On TOOH, set storm packer at —100' RKB with tubing hanging below. Bleed the OA pressure to 0 psi. Pressure up the IA. Bleed the IA pressure to 0 psi. ND BOPE. 9. ND tubing head using Hydratight tensioners. Replace the IC packoffs. Pressure test packoffs to 250/5,000 psi. NU new 5M casing head. NU BOPE and test to 3,500 psi. POOH laying down the tubing and storm packer. 10. Cleanout the 7" production casing to the cut tubing with casing scraper assembly. Circulate seawater. POOH laying down drill pipe. 11. RU E -line. MU caliper and gyro logging tools. Log the 7" production casing to surface. RD E -line. 12. RIH with overshot/packer assembly and new 5 ' /2" casing to tubing stub. Spot corrosion inhibited seawater followed by gelled diesel at the end of the 5 'h" production casing. Set the packer. Bleed casing pressure to 0 psi. Pressure test the 5 '/2" x 7" annulus to 1,500 psi. Bleed the annulus pressure to 0 psi. 13. Set the 5 ' /2" casing in temporary slips. Set a 5 'h" RBP at —50' RKB. Release from the RBP and pressure test the casing to 1,500 psi. Drawdown to 0 psi. POOH. 14. ND BOPE. Pull casing in tension. Remove excess casing. Install 5 ' /2" casing packoffs. Pressure test packoffs to 250/5,000 psi. NU new 5M tubing head and BOPE. Pressure test BOPE to 250/3,500 psi. 15. RIH and retrieve RBP. 16. Single in with the tubing string. Engage seal assembly. Space out tubing and MU new tubing hanger. 17. Swap the well over to corrosion inhibited seawater. Land the tubing hanger. RILDS. 18. With the annulus open, pressure test 3 'h" tubing to 3,000 psi for 15 min. Monitor annulus for returns. Bleed down pressure in tubing to 2,500 psi. While holding 2,500 psi on tubing, pressure test the IA to 3,500 psi for 30 minutes and record casing pressure test on chart recorder. 19. Bleed IA to 0 psi. Bleed tubing to 0 psi. Shear the SOV. Monitor well for a minimum of 30 minutes. Pull landing joint. Set two way check valve. Test two way check valve to 1,000 psi from below. 20. ND BOP stack, NU 5M psi tree. Pressure test tree and tubing hanger packoffs to 250/5,000 psi. Pull two way check valve. 21. Reverse circulate diesel to freeze protect to 2,000' TVD. Jumper the tubing and IA to allow diesel to equalize. Set BPV. 22. RDMO. Proposed Post -Rig Work: 1. Pull BPV. 2. RU Slickline: a. RIH and pull the SOV from GLM #1 and replace w/ a DV. POOH. b. Pull ball and rod on RHC plug at `X' Nipple. c. Pull RHC plug in `X' Nipple d. Pull catcher set on CA -2 plug at 8,182' RKB e. Pull CA -2 plug set in `D' Nipple (2.75" ID) at 8,182' RKB 3. Reset the well houses and flow lines. 4. Turn well over to Operations. . • ConocoPhillipS Well: 1C-10 2013 RWO PROPOSED COMPLETION API: 500292086500 Conductor: PTD: 182 -193 20 ", 92.0 #, H -40 to 99' RKB A] Wellhead: FMC Gen II NIP Surface Casing: X -mas Tree: 3 -1/8 ", 5M psi 10 -3/4 ", 45.5 #, K -55 to 2,567' RKB Lift Threads: 3 1/2" BPV: 3 1/2" Intermediate Casing: 7", 26.0 #, K -55 to 8,977' RKB Proposed 3 Completion • Production Casing: • Tubing, 3 -1/2 ", 9.3 ppf, L -80, 5 -1/2 ", 23.0 #, L -80 to XXXX' RKB IBTM SCC • 2.875" ID 'DS' Nipple Perforations: • CAMCO GLM MD Zone • 3 -1/2" Seal Assembly 8,278' - 8,304' Kuparuk C • 3-1/2" x 7" Premier Packer 8,308' - 8,344' Kuparuk C • 2.813" ID 'DS' Nipple • Poor - Boy Overshot - 2.875" ID 'DS' Nipple set at -500' RKB \ / Directional: 41— SBE set at X,XXX' RKB Max Incline: 57.8° @ 4100' Max Dogleg: 8.7° @ 4850' A 4— Premier Packer set at X,XXX' RKB NIP 4— 2.813" ID 'DS' Nipple i 4— Poor -Boy Overshot ••■•■ 4— SBR set at 8,110' RKB Nil 4_- HCL Permanent Packer set at 8,135' RKB I 4— 2.75" OD 'D' Nipple set at 8,182' RKB .4. . Fill at: 8,332' RKB Last Updated: 16- Jan -13 TD: 8,977' RKB Updated by: JRC b KUP • • 1C -10 # ConocoF-hilli Well Attributes Max Angle & MD TO Alaska, Inc. Wellbore API /UWI Field Name Well Status Inc! ( MD (ftKB) Act Btm (ftKB) .,,:phis 500292086500 KUPARUK RIVER UNIT INJ 57.82 4,100.00 8,976.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -• —SSSV: TRDP Last WO: 3/24/1990 41.00 11/29/1982 Well Config: g 1780.14.15 AM Schematic - Actual 11 8 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 8,332.0 3/16/2007 Rev Reason: MANDREL LATCH ORIENTATION ninam 8/17/2011 — — Casing Strings j Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... Str ng ... String Top Thrd CONDUCTOR 20 18.940 34.0 99.0 99.0 92.00 H-40 WELDED HANGER, 31 i Casing Description String 0... String ID ... Top (a8C8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd , 11 SURFACE 103/4 9.794 34.4 2567.0 2,283.9 45.50 K -55 Casing Description Siring 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd r PRODUCTION 7 6.276 32.3 8,976.9 7,095.6 26.00 K -55 BTC 9.625x7" Strings Tubing gs Tubing Tubing trin String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING WO 31/2 2.992 30.7 8,135.5 6,345.5 9.30 J -55 DSS -HT - Completion Details Top Depth II Nomi... (TVD) Top Intl Comment ID (in) T op MKS) (ftKB) ( °) Item Description 30.7 30.7 0.88 HANGER FMC GEN II TUBING HANGER 3.500 1 e 1,801.4 1,696.0 35.91 SAFETY VLV CAMCO TRDP -1ASSA SAFETY VALVE 2.812 8,110.4 6,323.3 27.31 SBR Overshot OTIS SBR OVERSHOT 4 8,134.51 6,344.7 27.16 SLICKSTICK 3.813 Tubing Description String 0... String ID ... Top (ftKB) Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING Original I 31/2 I 2.992 I 8,135.6 I Set 8,199.4 I 6,402.4 I 9.30 I J -55 , BTC Completion Details Top Depth CONDUCTOR, (TVD) Top Inc! Nomi... 34-99 I Top (ftKB) (ftKB) (') Item Description Comment ID (in) 8,135.6 6,345.6 27.16 PACKER OTIS HCL PERMANENT PACKER 4.000 8,182.0 6,386.9 26.88 NIPPLE CAMCO D NIPPLE NO GO 2.750 Perforations & Slots Shot .i ___ -- Top (TVD) Btm (TVD) Dens SAFETY VLV, ( oLa 1,801 Top (WKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh— Oh— Type Comment - 8,278 8,304 6,472.7 6,496.0 C-4, 1G10 1/12/1983 4.0 IPERF 8,308 8,344 6,499.6 6,531.7 C-, C -3, C -2, 1/12/1983 4.0 IPERF 1C -10 Notes: General & Safety End Date Annotation SURFACE, 4/1/1990 NOTE: Well was waked-over 4/90; aadized 5/90 34-2,567 11/16/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS ,0 0 8,080 ^4 SBR Overshot, 1 8,110 J Li PACKER.8.138 NIPPLE. 8,182 IPERF. 1111 ItE SEM 8,278 -8.304 IPERF, II 8,308.8,344 R Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) 1 ° ) Make Model (in) Sere Typo Type (in) (psi) Run Date Com... 1 8,059.7 6,278.3 27.82 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 3/24/1990 12:30 FISH, 8,744 TD, 8,978 PRODUCTION 9 825x7', • 32 -8,977 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim DATE:Friday,June 01,2012 P.I.Supervisor c-11 6l/(/(v SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-10 FROM: Bob Noble KUPARUK RIV UNIT IC-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .,eg--- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Bob Noble Permit Number: 182-193-0 Inspection Date: 5/19/2012 Insp Num: mitRCN120522064244 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-10 - Type Inj W 'TVD 6345 - IA 540 600 - 600 600 PTD I 1821930 - Type Testi SPT'Test psi 1800 , 1 OA 600 2010- 1940 1930 ' Interval L QVAR P/F P ' Tubing 1390 j 1390 1390 1390 Notes: IA x OA,MIT-OA /j; 2(.i O3(v SCANNED MAR 13 NM Friday,June 01,2012 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE:Friday,June 01,2012 Jim Regg P.I.Supervisor J£2 1l � 7� SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-10 FROM: Bob Noble KUPARUK RIV UNIT 1C-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .1g2— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1C-10 API Well Number 50-029-20865-00-00 Inspector Name: Bob Noble Permit Number: 182-193-0 Inspection Date: 5/19/2012 Insp Num: mitRCN120522062217 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-io ' Type Inj W'TVD 6345 -j IA 660 3310 - 3180 3150 PTD 1821930 Type Test SPT Test psi 3000 OA 640 690 , 700 700 , Interval IREQVAR ;P/F P Tubing 1390 . 1390 _ 1390 1390 , Notes: IA x OA,MIT-1A (51;52; 2P,03(, SCANNED MAR 13 2014 Friday,June 01,2012 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 25, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Bottom Hole Presure S urvey: 1 C -10 Run Date: 8/13/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C-10 \UI V Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 20865 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 20865 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com / (1/ Date: a I. S.�"o� j Signed: V ` l ,IS')‘- 1 93 III • (PS WELL LOG TRANSMITTAL lo. PRGAcrivE DIAgfosnc SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 °. : 004 4= ,, t; ', 1 Z U E' a (907) 659 -5102 ass RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : RECEIVED ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road AUG 1 9 2011 Suite C Anchorage, AK 99518 ON & Gas Cons. Commlesbn Fax: (907) 245 -8952 Anchorage 7 ,... .,--___ 1 Caliper Report 13-Aug-11 1 C-10 1 Report / CD 50-029-20865-00 ( 2) Caliper Report 11- Aug -11 1 E -11 1 Report / CD 50 -029- 20787 -00 Signed : Date : - X`4 ( I Print Name: V.L. w u.- CS I., lc., ,d PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -8952 E -MAIL : PDSANCHORAGE(WMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Dishibution\ TransmittalSheets \Conocophillips_Transmikdocx IS 1 1 1 • • 1 Multi- Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1C -10 Log Date: August 13, 2011 Field: Kuparuk River Unit I Log No. : 10258360 ZX70 State: Alaska Run No.: 1 API No.: 50- 029 - 20865 -00 Pipet Desc.: 3.5" 9.3 Ib. J -55 DSS -HT / BTC Top Log Intvll.: Surface I Pipet Use: Tubing Bot. Log Intv11.: 8,203 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection I COMMENTS : This caliper data is correlated to the GLM at 8,060' per the tubing tally dated 22- Mar -1990. U This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage during operations to evaluate RWO potential for repairing the production casing. The caliper recordings indicate the majority of the 3.5" tubing logged appears to be in good condition with U respect to corrosive and mechanical damage. Wall penetrations from 20% to 25% wall thickness are recorded in only six of the 306 joints logged. Recorded damage appears as pitting, lines of pits, and general corrosion. No significant areas of cross - sectional wall loss are recorded. Although the caliper recordings indicate scattered light deposits throughout the log interval, no significant I.D. restrictions are recorded. I The summary report is an interpretation of data provided by Halliburton Energy Services. 1 MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting ( 25 %) Jt. 248 @ 6,665 Ft. (MD) I Line of Pits ( 24%) Jt. 159 @ 4,308 Ft. (MD) Isolated Pitting ( 21%) Jt. 62 @ 1,713 Ft. (MD) Corrosion ( 20 %) Jt. 270 @ 7,248 Ft. (MD) Line of Shallow Pits ( 20 %) Jt. 279 @ 7,487 Ft. (MD) I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: I No significant areas of cross - sectional wall loss (> 10 %) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: 1 Although deposits are recorded throughout the log interval, no significant I.D. restrictions are recorded. I Mandrel Orientation 1C 10 ConocoPhillips Alaska, Inc. Kuparuk August 13, 2011 Joint No. Tool Deviation Mandrel No. Latch Orientation I 300.2 28 1 12:30 I Field Engineer: P. Juday /J. Conrad Analyst: M. Lawrence Witness: B. Boehme ProActive Diagnostic Services, Irr. P.O. Box 1. Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com I Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 a 1 • • Correlation of Recorded Damage to Borehole Profile III Pipe 1 3.5 in. (38.1' - 8202.81 Well: 1C-10 Field: Kuparuk I Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: August 13, 2011 1 I ■ Approx. Tool Deviation IN Approx. Borehole Profile 1 1 — 38 ii 25 705 1 1 50 1383 75 a l 2060 I 1 1 00 il 2733 I 125 3387 sil 150 4 4047 E ; 175 4718 - E c Z 200 5379 s I c a 0 225 6040 1 250 6705 MB 275 3 7367 1 GLM 1 300 8028 302.4 8203 1 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 1 Bottom of Survey = 302.4 1 1 • • 1 PDS Report Overview ti . Body Region Analysis 1 Well: 1C -10 Survey Date: August 13, 2011 Field: Kuparuk Tool Type: UW XR 24 No. 10000429 I Company: ConocoPhillips Alaska, Inc. Country: USA Tool Size: 1.69 No. of Fingers: 24 Analyst: M. Lawrence Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 3.5 in. 9.3 ppf 9.3 ppf J -55 DSS-HT 2.992 in. 3.5 in. 6.0 in. 6.0 in. 3.5 in. J -55 BTC 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 Penetration(% wall) Damage Profile (% wall) 400 NMI Penetration body lm Metal loss body ---- 0 50 100 300 ? 200 --- _ 1 100 iii-- 49 AI 1 0 to 20 to 40 to over 20% 40% 85% 85% 99 1 I Number of joints analysed (total = 306) 300 6 0 0 r4 A 1 149 -,1 Damage Configuration ( body) 1 40 j a 1 30 199 4 __, 1 20 10 249 = -3 I 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 1 GLM 1 (12:30) Number of joints damaged (total = 40) 39 1 0 0 0 Bottom of Survey = 302.4 1 1 1 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 I Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 38 0 0.02 9 2 2.95 ■� 1.1 65 0 0.03 10 5 2.95 Pup 1.2 80 0 0.02 7 2 2.96 Pup 2 87 0 0.03 12 4 2.95 ■ I 3 114 0 0.03 11 3 2.94 4 139 0 0.02 7 2 2.94 5 167 0 0.02 8 2 2.93 6 193 0 0.02 7 2 2.96 I 7 220 0 0.03 11 2 2.92 Lt. Deposits. ■ 8 245 0 0.03 10 3 2.93 ■ 9 273 0 0.02 9 2 2.96 • 1 0 301 0 0.04 15 4 2.92 Line of Shallow Pits. Lt. Deposits. • I 11 328 0 0.03 10 2 2.95 ■ 12 353 0 0.02 9 2 2.94 • ■ 13 379 0 0.03 12 2 2.93 Lt. Deposits. • 14 407 0 0.02 9 2 2.93 Lt. Deposits. • 15 435 0 0.03 11 2 2.93 Lt. Deposits. I 16 463 0 0.02 9 3 2.93 Lt. Deposits. 17 490 0 0.02 8 2 2.93 Lt. Deposits. 18 516 0 0.02 9 3 2.96 19 544 0 0.04 17 4 2.93 Shallow Pitting. Lt. Deposits. • I 20 569 0 0.03 11 2 2.95 21 597 0 0.02 7 2 2.96 22 623 0 0.03 11 2 2.92 Lt. Deposits. ■ 23 651 0 0.02 9 3 2.93 I 24 678 0 0.02 9 2 2.94 25 705 0 0.02 8 2 2.94 26 732 0 0.03 11 3 2.95 ■ 27 761 0 0.03 12 2 2.93 Shallow Pitting. ■ I 28 788 0 0.03 11 3 2.93 Lt. Deposits. • 29 816 0 0.03 10 1 2.94 30 841 0 0.02 8 2 2.95 31 869 0 0.02 7 3 2.92 Lt. Deposits. 32 896 0 0.02 9 2 2.96 I 33 924 0 0.02 9 2 2.96 34 953 0 0.04 14 2 2.92 Shallow Pitting. Lt. Deposits. • 35 980 0 0.02 9 3 2.93 Lt. Deposits. 36 1008 0 0.02 9 4 2.98 I 37 1037 0 0.02 9 3 2.90 Lt. Deposits. 38 1064 0 0.02 7 2 2.94 39 1091 0 0.02 9 5 2.92 Lt. Deposits. 40 1118 0 0.03 11 3 2.95 I 41 1144 0 0.02 7 2 2.91 Lt. Deposits. 42 1170 0 0.02 7 2 2.94 43 1198 0 0.02 9 2 2.93 44 1222 0 0.03 10 3 2.93 Lt. Deposits. 45 1248 0 0.02 7 2 2.93 Lt. Deposits. I 46 1276 0 0.02 7 2 2.96 47 1304 0 0.03 11 2 2.97 48 1330 0 0.01 6 2 2.93 ' Penetrat Metal Loss ion Body Page 1 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 Body WaII: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 49 1356 () 0.02 7 2 2.97 50 1383 0 0.02 7 2 2.94 51 1411 0 0.03 1 1 2 2.94 52 1439 0 0.02 9 2 2.94 I 53 1463 0 0.02 7 2 2.93 54 1491 0 0.02 7 3 2.94 55 1519 0 0.02 7 2 2.94 56 1546 0.03 0.05 20 5 2.96 Shallow Pitting. I 57 1566 0 0.03 10 3 2.94 58 1594 0 0.02 8 2 2.96 59 1621 0 0.02 7 2 2.94 60 1644 0 0.02 9 2 2.93 I 61 1668 0 0.03 11 2 2.93 U. Deposits. 62 1694 0 0.05 21 2 2.92 Isolated Pitting. Lt. Deposits. 63 1719 0 0.02 7 2 2.93 64 1744 0.03 0.04 15 2 2.94 Line of Shallow Pits. 65 1771 0 0.02 8 2 2.94 I 65.1 1800 0 0 0 0 2.82 SSSV 66 1821 0 0.02 9 2 2.93 Lt. Deposits. 67 1847 0 0.02 7 2 2.95 68 1875 0 0.02 9 3 2.91 Lt. Deposits. I 69 1895 0 0.02 7 2 2.93 Lt. Deposits. 70 1923 0 0.03 13 2 2.89 Line of Shallow Pits. Lt. Deposits. 71 1950 0 0.03 11 2 2.93 Lt. Deposits. 72 1977 0 0.03 11 1 2.96 I 73 2005 0 0.03 11 2 2.93 Lt. Deposits. 74 2033 0 0.02 9 2 2.95 75 2060 0 0.02 9 2 2.96 76 2088 0 0.02 7 4 2.95 77 2115 0 0.02 7 2 2.91 Lt. Deposits. 78 2143 0 0.02 7 2 2.94 79 2168 0 0.02 7 2 2.93 Lt. Deposits. 80 2195 0 0.02 7 2 2.93 81 2220 0 0.03 10 2 2.92 Lt. Deposits. I 82 2247 83 2275 0 0.02 8 2 2.95 0 0.02 7 2 2.96 84 2300 0 0.02 7 2 2.96 85 2328 0 0.02 9 2 2.93 Lt. Deposits. I 86 2355 0 0.02 9 2 2.92 Lt. Deposits. 87 2384 0 0.02 9 2 2.92 Lt Deposits. 88 2410 0 0.02 7 2 2.94 89 2438 0 0.02 8 2 2.92 Lt. Deposits. 90 2466 0 0.02 9 2 2.92 Lt. Deposits. 91 2493 0 0.03 11 2 2.92 Lt. Deposits. 92 2520 0 0.01 6 2 2.93 93 2547 0 0.02 7 2 2.92 U. Deposits. I 94 2572 0.03 10 3 2.93 Lt. Deposits. 95 2600 0 0.02 9 2 2.93 Lt. Deposits. 96 2627 0 0.03 10 3 2.93 97 2650 0 0.02 7 3 2.93 Lt. Deposits. I Penetration Metal Loss Body Page 2 1 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 1 Joint Jt. Depth Peen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 98 2677 99 2705 0 0.01 6 2 2.93 Lt. Deposits. 0 0.02 9 2 2.93 100 2733 0 0.02 9 3 2.95 101 2761 0 0.02 7 1 2.93 I 102 2789 0 0.02 7 2 2.92 Lt. Deposits. 103 2813 0 0.02 7 2 2.93 Lt. Deposits. 104 2839 0 0.02 7 2 2.93 Lt. Deposits. 105 2866 0 0.02 7 2 2.93 I 106 2893 0 0.02 7 2 2.93 107 2920 0 0.02 7 2 2.96 108 2946 0 0.03 1 1 2 2.90 Lt. Deposits. 109 2974 0 0.02 9 2 2.91 Lt. Deposits. I 110 3000 () 0.01 6 2 2.94 111 3027 0 0.02 7 2 2.94 112 3053 0 0.01 6 2 2.93 113 3079 0 0.02 6 2 2.93 Lt. Deposits. 114 3104 0 0.03 13 5 2.90 Line of Shallow Pits. Lt. Deposits. I 115 3132 0 0.03 13 2 2.91 Shallow Pitting. I. t. Deposits. 116 3150 0 0.02 7 2 2.92 Lt. Deposits. 117 3176 0 0.02 8 2 2.93 Lt. Deposits. 118 3203 0 0.02 7 2 2.93 Lt. Deposits. I 119 3231 0 0.02 8 �1 2.92 Lt. Deposits. 120 3257 0 0.02 8 ■ 2.92 Lt. Deposits. 121 3283 0 0.01 6 2 2.96 122 3308 0 0.02 7 2 2.92 Lt. Deposits, I 123 3336 () 0.02 7 2 2.93 124 3363 0 0.03 12 ; 2.95 Shallow Pitting. 125 3387 0 0.02 9 2 2.92 Lt. Deposits. 126 3414 0 0.02 9 2 2.96 127 3443 0 0.02 9 2 2.95 I 128 3471 0 0.02 7 2 2.96 129 3495 0 0.02 7 2 2.94 130 3521 0 0.02 6 2 2.95 131 3544 0 0.02 7 2 2.93 I 132 3570 0 0.02 8 2 2.92 Lt. Deposits. 133 3597 0 0.02 7 2 2.93 Lt. Deposits. 134 3623 0 0.04 14 2 2.93 Shallow Pitting. 135 3646 0 0.02 8 2 2.94 I 136 3673 0 0.01 6 2 2.93 Lt. Deposits. 137 3700 0 0.02 7 2 2.95 138 3725 0 0.03 11 2 2.95 139 3753 0 0.01 6 1 2.96 I 140 3780 0 0.02 9 2 2.92 Lt. Deposits. 141 3805 0 0.02 6 2 2.93 142 3831 0 0.02 9 3 2.93 Lt. Deposits. 143 3858 0 0.01 6 2 2.93 144 3885 0 0.02 6 2 2.94 I 145 3911 0 0.02 7 2 2.94 146 3940 0 0.02 7 2 2.93 147 3967 0 0.03 11 2 2.96 I Prat Meta Loss ion Body Page 3 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 148 3994 0 0.02 7 2 2.92 Lt. Deposits. 149 4020 0 0.02 2.95 150 4047 0 0.02 6 2 2.93 151 4074 0 0.02 8 2 2.94 I 152 4103 0 0.02 6 2 2.95 153 4129 0 0.02 6 2 2.92 Lt. Deposits. 154 4157 0 0.03 11 2 2.96 155 4183 0 0.03 11 2 2.92 Lt. Deposits. I 156 4208 0 0.03 13 2 2.93 Shallow Pitting. 157 4236 0 0.02 9 3 2.93 158 4262 0 0.02 9 2 2.93 159 4289 0 0.06 24 4 2.93 Line of Pits. I 160 4315 0 0.02 9 2 2.92 Lt. Deposits. 161 4341 0 0.02 9 2 2.91 Lt. Deposits. 162 4366 0 0.02 9 2 2.93 Lt. Deposits. 163 4393 0 0.02 9 3 2.92 Lt. Deposits. 164 4421 0 0.02 9 2 2.93 Lt. Deposits. I 165 4449 0.02 7 2 2.95 166 4477 0.02 6 3 2.91 Lt. Deposits. 167 4503 i 0.02 9 3 2.93 Lt. Deposits. 168 4530 0 0.02 9 2 2.93 169 4557 0 0.02 9 2 2.92 Lt. Deposits. 170 4585 0 0.02 '' 2.92 Lt. Deposits. 171 4612 0 0.02 9 2.92 Lt. Deposits. 172 4639 0 0.03 12 _ 2.93 Shallow Pitting. Lt. Deposits. I 173 4667 0 0.03 11 , 2 2.93 174 4690 0 0.02 7 2 2.92 Lt. Deposits. 175 4718 0 0.01 6 2 2.92 Lt. Deposits. 176 4745 0 0.02 6 3 2.92 Lt. Deposits. I 177 4771 0 0.02 9 4 2.92 Lt. Deposits. 178 4797 0 0.02 7 3 2.93 Lt. Deposits. 179 4824 0 0.02 7 2 2.93 180 4852 0 0.02 7 2 2.96 181 4878 0 0.04 16 2 2.94 Shallow Pitting. I 182 4903 0 0.01 6 2 2.93 Lt. Deposits. 183 4929 0 0.02 7 2 2.94 184 4957 0 0.02 6 2 2.92 Lt. Deposits. 185 4984 0 0.02 7 2 2.92 Lt. Deposits. I 186 5009 , 0 0.02 9 3 2.93 Lt. Deposits. 187 5036 0 0.03 11 1 2.97 188 5062 0 0.02 2.92 Lt. Deposits. 189 5088 0 0.03 10 2.93 Lt. Deposits. I 190 5116 0 0.02 7 2.94 191 5143 0 0.02 2.92 Lt. Deposits. 192 5168 0 0.02 2.92 Lt. Deposits. 193 5195 0 0.03 I it 4 2.97 194 5221 0 0.02 9 2 2.92 Lt. Deposits. I 195 5247 0 0.03 10 2 2.92 Lt. Deposits. 196 5273 0 0.03 11 2 2.92 Lt. Deposits. 197 5301 0 0.01 6 2 2.92 Lt. Deposits. Peno Body Metal Loss n Body Page 4 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1 C -10 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 Joint Jt. Depth I'en. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) 0 / (Ins.) 0 50 100 1 198 5327 199 5352 0 0.02 7 2 2.95 t) 0.02 9 2 2.94 200 5379 0 0.03 12 3 2.94 201 5405 , 0 0.02 8 2 2.92 Lt. Deposits. I 202 5434 0 0.01 6 2 2.94 203 5460 0 0.02 7 2 2.93 204 5485 0 0.03 11 .3 2.92 Lt. Deposits. 205 5513 0 0.02 8 2 2.92 Lt. Deposits. I 206 5539 0 0.02 7 2 2.94 207 5568 0 0.02 7 2 2.96 208 5594 0 0.03 10 2 2.96 209 5616 0 0.04 15 3 2.91 Line of Shallow Pits. Lt. Deposits. I 210 5643 0 0.02 8 3 2.92 Lt. Deposits. 211 5671 0 0.02 9 2 2.94 212 5698 0 0.02 9 3 2.95 213 5720 0 0.03 10 3 2.92 Lt. Deposits. 214 5747 0 0.03 12 3 2.95 Shallow Pitting. I 215 5775 0 0.02 9 2 2.93 216 5803 0 0.02 8 2 2.92 Lt. Deposits. 217 5827 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. 218 5854 0 0.02 7 2 2.93 Lt. Deposits. I 219 5881 220 5909 0 0.03 13 4 2.91 Shallow Pitting. Lt. Deposits. 0 0.02 8 2 2.92 Lt. Deposits. 221 5934 0 0.02 7 , 3 2.96 ! 222 5962 0 0.03 10 2 2.96 I 223 5984 0 0.03 12 2 2.95 Shallow Pitting. 224 6012 0 0.02 8 2 2.92 Lt. Deposits. 225 6040 0 0.02 7 2 2.91 Lt. Deposits. 226 6068 0 0.02 7 2 2.96 I 227 6093 0 0.03 10 2 2.96 228 6122 0 0.02 7 2 2.92 Lt. Deposits. 229 6146 0 0.02 9 2 2.94 230 6174 0 0.02 9 2 2.94 231 6195 0 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. I 232 6224 0 0.02 7 2 2.94 233 6251 0 0.02 8 2 2.92 Lt. Deposits. 234 6277 0 0.02 9 3 2.91 Lt. Deposits. 235 6303 0 0.03 11 3 2.96 I 236 6326 237 6351 0 0.02 7 2 2.92 Lt. Deposits. 0.04 14 1 2.93 Shallow Pitting. Lt. Deposits. 238 6378 0 0.02 9 2 2.92 Lt. Deposits. 239 6405 0 0.02 9 2 2.95 I 240 6433 0 0.04 16 3 2.94 Shallow Pitting. 241 6456 0 0.02 8 2 2.93 242 6485 0 0.02 9 3 2.92 Lt. Deposits. 243 6512 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. 244 6539 0 0.02 8 3 2.94 I 245 6566 246 6594 0 0.02 9 2 2.95 0 0.02 8 2 2.94 247 6621 0 0.02 9 2 2.92 Lt. Deposits. I Prat Meta l Loss ion Body Page 5 1 1 • • I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 248 6649 0 0.06 25 2 2.93 Isolated Pitting. • 249 6677 0 0.03 12 2 2.92 Lt. Deposits. ■ 250 6705 0 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. ■ 251 6733 0 0.02 9 3 2.92 Lt. Deposits. ■ I 252 6761 0 0.03 11 2 2.92 Lt. Deposits. ■ 253 6789 0 0.04 15 2 2.92 Shallow Pitting. Lt. Deposits. m 254 6816 0 0.02 7 2 2.91 Lt. Deposits. 255 6843 0 0.02 9 2 2.93 IN I 256 6868 _ 0 0.02 9 1 2.91 Lt. Deposits. 257 6895 0 0.02 9 2 2.92 Lt. Deposits. 258 6921 0 0.04 14 2 2.93 Shallow Pitting. Lt. Deposits. 259 6948 0 0.02 7 2 2.92 Lt. Deposits. I 260 6976 0 0.02 8 2 2.92 Lt. Deposits. 261 6999 0 0.02 7 2 2.95 262 7025 (3 0.05 19 2 2.92 Shallow Pitting. Lt. Deposits. 263 7051 0 0.02 9 2 2.86 Lt. Deposits. ■ I 264 7080 0 0.02 9 2 2.91 Lt. Deposits. ■ 265 7107 0 0.03 11 2 2.88 I.t. Deposits. 266 7133 0 0.02 7 2 2.93 Lt. Deposits. 2 267 7160 0 0.03 11 2 2.92 Lt. Deposits. ■ 268 7187 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. I 269 7213 270 7238 0 0.02 7 2 2.93 Lt. Deposits. 0 0.05 21 1i) 2.83 Corrosion. Lt. Deposits. 271 7260 0 0.03 10 2 2.92 Lt. Deposits. Ni 272 7287 0 0.03 11 2 2.89 Lt. Deposits. ■ I 273 7314 0 0.03 11 2 2.92 Lt. Deposits. 274 7342 0 0.02 7 2 2.91 Lt. Deposits. 275 7367 0 0.02 9 2 2.92 Lt. Deposits. 276 7395 0 0.02 9 2 2.94 ■ I 277 7425 (1 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. 278 7451 0 0.02 9 2 2.92 Lt. Deposits. 279 7478 0 0.05 20 3 2.88 Line of Shallow Pits. Lt. Deposits. IN 280 7504 0 0.02 9 2 2.94 • 281 7532 0 0.02 9 4 2.95 ■ 282 7559 0 0.03 10 5 2.91 Lt. Deposits. 283 7584 0 0.02 9 3 2.95 284 7612 0 0.03 11 2 2.91 Lt. Deposits. 285 7640 0 0.02 7 2 2.92 Lt. Deposits. 286 7665 0 0.03 11 2 2.94 NI 7691 0 0.02 9 2 2.91 Lt. Deposits. ■ 288 7719 0 0.02 9 2 2.96 ■ 289 7747 0 0.03 13 2 2.95 Shallow Pitting. ■ I 290 7776 0 0.03 13 2 2.90 Shallow Pitting. Lt. Deposits. ■ 291 7804 0 0.04 18 2 2.84 Shallow Pitting. Lt. Deposits. • ■ 292 7825 0 0.03 10 3 2.92 Lt. Deposits. ■ 293 7853 0 0.03 11 2 2.91 Lt. Deposits. ■ I 294 7881 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. IN 7909 0 0.04 14 3 2.94 Shallow Pitting. 296 7934 ( ) 0.02 9 2 2.92 Lt. Deposits. 297 7957 0 0.03 11 2 2.90 Lt. Deposits. I Penetration Bo Metal Loss Body Page 6 1 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf J -55 BTC Well: 1C-10 I Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: August 13, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) 0 /0 (Ins.) 0 50 100 I 298 7983 U 0.02 9 2 2.81 Deposits. 299 8009 0 0.02 9 3 2.91 Lt. Deposits. 300 8028 0 0.04 14 1 2.86 Shallow Pitting. Lt. Deposits. I 300.1 8054 0 0.01 6 1 2.96 Pup 300.2 8060 0 0 0 0 2.89 GLM 1 (Latch @ 12:30) 301 8070 0 0.01 6 1 2.92 Lt. Deposits. II 301.1 8102 0 0 0 0 2.92 Otis SBR Overshot 301.2 8117 0 0 0 0 2.80 Slickstick I 301.3 8140 0 0 0 0 3.84 Otis HCL Permanent Packer 302 8156 0 0.02 7 2.96 II 302.1 8187 0 0 0 0 2.74 D Nipple 302.2 8190 0 0.02 7 2 2.94 Pup • I 302.3 8198 0 0 0 0 2.73 Undocumented Jewelry 302.4 8203 0 0 0 0 1.48 EOL Penetration Body I Metal Loss Body 1 1 1 1 1 1 1 1 Page 7 1 1 1 • • 1 PDS Report Cross Sections 1 Well: 1C -10 Survey Date: August 13, 2011 Field: Kuparuk Tool Type: UW XR 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf J -55 DSS -HT Analyst: M. Lawrence 1 1 Cross Section for Joint 248 at depth 6665.409 ft Tool speed = 58 I Nominal ID = 2.992 Nominal OD = 3.5 _ Remaining wall area = 98% // Tool deviation = 39° 1 1 I \ 1 ----) 1 1 Finger = 19 Penetration = 0.063 in. Isolated Pitting 25% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 11\4-7)S, PDS Report Cross Sections 1 Well: 1C -10 Survey Date: August 13, 2011 Field: Kuparuk Tool Type: UW XR 24 No. 10000429 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 1 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf J -55 DSS-HT Analyst: M. Lawrence 1 1 Cross Section for Joint 159 at depth 4308.359 ft Tool speed = 58 I Nominal ID = 2.992 Nominal OD = 3.5 __ Remaining wall area = 96% Tool deviation = 55° V / 7 \ N i , 1 1 1 1 0 1 1 1 Finger = 21 Penetration = 0.062 in. Line of Pits 24% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 I ., e, � --- - N. \ KUP 1 C-10 ConocoPhillips f ° '\ Attributes gle & MD TD 'Vverhon Apl'U'WI nell Name 'Well Statue I hcl i°7 MD(ft!. I el Act eke 1t1/ •loa`n' 0,... 500292086500 ( KUPARUK RIVER UNIT I INJ 57.82 4,100.0 8,976. I ••• .. .... ,. ern `. tu¢ceil;mla C. Comment Fal1S H28 (ppmi 'Cab I, Annotation B4 Leta Ii B•i3rd (TFt Rig Rebate TRDP Last I 32M7990� 41.01 112911 Annotation ((t1/Bi Bitl Annotation La It Mod B' 0M Deb Last Tag: 8,332n 3/161/007 Rev Reason: FORMAT UPDATE Imoshm 5/1201 • Casing Strings •:t Ong C6ealpton Ottng OD.. string 10... Top i0 B) Set Depth it... Set Opal (TJDM... String VA.. 19019... String Top T N °. NGEP. 31 ' CONDUCTOR 20 18.940 34.0 99.0 99.0 92.00 H WELDED I Ca ling Da mrlptlon String 00... String 10... Top(ttt. 81 Set Depth a.. Set Depth (TYO). Siring Wt.. Sting... Siring Top 711 SURFACE 10374 9.794 34.3 2,567.0 2,283.9 45.50 K •0.10g DeecriptIOn String 013.. Sang D._ Top CPI, Bi Set Lepel it..' Set Dept (ToU1 String 'Wt.. String... Sting Top 111 PRODUCTION 7 6.276 32.3 8,976.9 7,095.6 26.00 K-55 BTC 9.625x7' Tubing Strings 1001118 [e wipe on String 00_ String D... Tap itte Et■ set Geptl it.. Set Depth iT.Di_. t '*L. ftng _ String Top n •, 1 1 1'.1 r 7 n n l l L 111 I TUBING WO 3 12 2.992 30.7 8,135.5 6,345.5 letting 8.30 I J-55 000 -H Completion Details Top rept) I Top (To Top MI ( Oi '1/81 (tte e) {•I DM 00.009ton Comment 10 MI 30.7 303 0.88 HANGER FMC GEN II TUBING HANGER 3500 1,801.4 1,696.0 35.91 SAF ETY VLV CAMCO TRDP- 1A- S SA SAFETY VALVE Haml... 2.812 • 8,110.4 6,323.3 27.31 SBR Overshot OTIS SBR OVERSHOT 4750 8,134.5 6,3443 27.16 SLICKSTICK 3.813 I ming Oa ortptan sting ati_IS09.9D._(Top(MMKIn Iaet Eeptn it_Iset riptr iT,Di_. I Stne WL. i ttnng_. String Ta TUBING Original 31/2 2 II 8,135.6 8,199.4 6, 402.4 9.30 /55 Completion Details Top Dept, coNOUC1n B, ti Top (T,0i Top MI 11001._ 3H itt1 BI i1PB' i °i Item Ceemipton Com meet IDiin, I 8,1352 6,345.6 27.16 PACKER OTIS HCL PERMANENT PACKER 4.000 8,182.0 6,386.9 2628 NIPPLE CAMCO D NIPPLE NO GO 2.750 Perforations 8 Sots Edit Shot atn Top (13 Bin (TVD) Dena I , rErvvr:. To MY in ittH',61 tt4Bl =one - I,wl Top Men) 4 8,278.0 8,304.0 6,472.7 6,496.0 C-4, 1C-10 DIM 11_ { To 10 1/12(1983 4.0 IPERF 8,308.0 0,3442 6,489.6 6,531.7 C -, C-3, Cy 1/12/1903 4.0 IPERF Comment 1C-10 Notes: General & Safety Edit I Bt0 Debi Mno9ton cu P rrc E, 4/1 /1990 NOTE: Well was worked-over 4/90; ooidl2ed 5 11/162010 NOTE: Mew Schematic w /PJaska Schematic9.0 1 G,., LIFT 8,aa 1 000 Oten0Bl, 8.110 I PAC/AP, 8,136 CI I NIPP LE, 8,1112 "RI 1 E PEPI. = 1 .,40.0.V.; IPEPi, 1 8, 1 ! OL 8,1.. Mandrel Details Jena Sin /191/0 Top Depth POD I Top ITVDi Top 00 Lath - 9111 T nun S) ittI/ Srcl( °I wee 110011 1101 1.ro 'Va1 e6TDB P410 (111 (Pan RUI Oab o)m... r no 0,0.070 1 8,059.7 6,2782 2722 CAM... MMG-2 112 GAS LIFT DMY RK 0.000 0.03/24/1990 9F OTnN • • 6. 1D-106 — Single casing well. MITIA failed 7/16/2010. Well last injected 6/2010. Comments on the sheet indicate you have located the deep leak. 5. 1C -133 — Single casing well. MITIA failed 5/21/2010. Well last injected 5/2010. --o- 4. 1 C -10 — AA 2B.036 issued 8/25/2008. 1. 55 From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. I also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 0 • ConocoPhillips Well 1C-10 Injection Data • Water Injection 0 Gas Injection I 4000 3500 - 3000 .2 2500 - a • 2000 • , � •M ! z • • 1500 - • 1000 - 500 - 0. 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Injection Rate, bwpd or mscfpd Date of Water Gas Injected Tubing IA Pressure OA Pressure Injection Injected (mscfpd) Pressure (psi) (psi) (bwpd) (psi) 31- Dec -10 3465 0 2168 457 437 30- Dec -10 3079 0 2061 440 422 29- Dec -10 3443 0 2153 418 399 28- Dec -10 3481 0 2161 436 417 27- Dec -10 3315 0 2110 431 411 26- Dec -10 3324 0 2131 444 425 25- Dec -10 3183 0 2101 462 442 24- Dec -10 3179 0 2097 443 424 23- Dec -10 3290 0 2127 519 500 22- Dec -10 3412 0 2167 600 581 21- Dec -10 3339 0 2152 490 471 20- Dec -10 3245 0 2116 439 420 19- Dec -10 3262 0 2119 455 437 18- Dec -10 3183 0 2095 455 437 17- Dec -10 3290 0 2123 496 478 16- Dec -10 3331 0 2133 492 474 15- Dec -10 3211 0 2093 516 498 14- Dec -10 3243 0 2099 499 479 13- Dec -10 3415 0 2143 469 450 12- Dec -10 3335 0 2110 485 465 11- Dec -10 2611 0 1913 446 428 10- Dec -10 1793 0 1703 442 425 9- Dec -10 2312 0 1837 439 421 8- Dec -10 2496 0 1875 479 463 7- Dec -10 2838 0 1978 476 457 6- Dec -10 3368 0 2109 487 468 5- Dec -10 3497 0 2144 484 466 • • 4- Dec -10 3491 0 2143 601 584 3- Dec -10 3538 0 2158 569 552 2- Dec -10 3558 0 2158 562 543 1- Dec -10 3583 0 2160 477 461 30- Nov -10 3586 0 2154 550 520 29- Nov -10 3619 0 2162 550 520 28- Nov -10 3691 0 2183 488 471 27- Nov -10 3671 0 2179 511 494 26- Nov -10 3682 0 2180 531 514 25- Nov -10 3731 0 2190 570 552 24- Nov -10 3757 0 2194 602 584 23- Nov -10 3578 0 2173 602 584 22- Nov -10 2948 0 1950 537 519 21- Nov -10 3722 0 2160 545 526 20- Nov -10 2999 0 1954 513 50 19- Nov -10 2716 0 1876 520 50 18- Nov -10 2841 0 1907 555 538 17- Nov -10 2824 0 1899 610 594 16- Nov -10 3785 0 2172 703 681 15- Nov -10 3839 0 2189 696 678 14- Nov -10 3941 0 2214 715 695 13- Nov -10 3918 0 2201 728 708 12- Nov -10 3968 0 2211 734 715 11- Nov -10 3945 0 2196 755 739 10- Nov -10 3991 0 2204 727 710 9- Nov -10 3910 0 2168 691 674 8- Nov -10 3694 0 2098 649 632 7- Nov -10 1534 0 2083 587 570 6- Nov -10 3641 0 2134 695 681 5- Nov -10 3755 0 2101 719 701 4- Nov -10 3922 0 2148 719 699 3- Nov -10 4000 0 2167 762 743 2- Nov -10 3833 0 2115 872 856 1- Nov -10 3666 0 2072 914 896 31- Oct -10 3818 0 2108 914 896 30- Oct -10 3411 0 1998 696 677 29- Oct -10 3210 0 1936 659 643 28- Oct -10 3264 0 1949 564 548 27- Oct -10 2998 0 1873 538 523 26- Oct -10 2999 0 1867 653 639 25- Oct -10 2988 0 1867 672 657 24- Oct -10 3056 0 1884 658 640 23- Oct -10 2943 0 1848 617 601 22- Oct -10 3073 0 1871 408 391 21- Oct -10 1260 0 1339 544 530 20- Oct -10 2812 0 1891 566 553 19- Oct -10 2799 0 1881 561 545 18- Oct -10 2453 0 1796 599 581 17- Oct -10 3074 0 1939 614 600 16- Oct -10 3096 0 1941 411 397 15- Oct -10 2534 0 1795 389 375 14- Oct -10 3231 0 1963 354 341 • • 13- Oct -10 2077 0 1686 359 346 12- Oct -10 2345 0 1754 395 381 11- Oct -10 2822 0 1867 470 461 10- Oct -10 2685 0 1850 578 566 9- Oct -10 3769 0 2141 630 595 8- Oct -10 3947 0 2191 575 563 7- Oct -10 3999 0 2203 648 621 6- Oct -10 3932 0 2185 643 623 5- Oct -10 3815 0 2150 615 602 4- Oct -10 3793 0 2139 592 582 3- Oct -10 3585 0 2088 530 518 2- Oct -10 3399 0 2029 597 589 • • ConocoPhillips Well 1C-10 Injection Data • Tbg Psi IA Psi A OA Psi 4000 3500 3000 - 2500 Q • ••••• . w• . ••• . • •••••••• • •""MaM+l .••.••.• •d. �. a 2000 - • • « •• . ft .. « • ..,• • ; • 1500 - • • 1000 - 500 0 09/10 10/10 11/10 12/10 01/11 Date \ J PTD: 182 -193 Reason: AIO 2B.036 for IAxOA Communication issued 8/25/08 Witnessed MITIA /MITOA passed on 05/21/10 AIO 2B.036 requires report of monthly bleeds for all annuli No pressure bleeds occurred within the last month. • • E~~~~IED ConacoPhillips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: :~u~ ~ ~~ ~o~a ~iasica ~ i~ Gat Gatt9t. Gission Anch,rage ,. ~~ 3 1~ , ~ti Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 1A. 1C.1E PAD Well Name API # 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 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1G01 50029205260000 1801280 SF Na 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" Na 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6!2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1G10 50029208650000 1821930 37'6" 8.00 8" 11/25!2007 6.8 7/68010 1E-02 50029204720000 1800500 21" n/a 21" Na 1.7 7178010 1 E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 717/2010 1 E-06 50029204930000 1800780 12" Na 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" Na 5" Na 2.6 7!18010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/78010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7!18010 1E-19 50029209050000 1830170 1" n/a 1" Na 1.7 7/78010 1E-21 50029208920000 1830020 3" n/a 3" Na 2.6 7!18010 1E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/78010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/88010 1E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/88010 Page 1 of 3 Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Monday, July 05, 2010 1:07 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj; NSK Fieldwide Operations Supt; Bradley, Stephen D; CPF1 &2 Ops Supt; CPF3 Ops & DOT Pipelines Supt; Cawvey, Von Subject: RE: ANSI 1500 Flanges Attachments: Page from ASME B31.4.pdf; Page from ASME B16.5.pdf; 1 C- 121.jpg; 1C-119.jpg Jim, Please see below in blue for the ConocoPhillips response. Let me know if you have any additional questions. MJ Loveland MOOED JA 2 re' Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659 -7043 Cell (907) 943 -1687 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, June 25, 2010 2:17 PM To: NSK Well Integrity Proj; NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e.g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing presssure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). 10-25 and 1 C -27 are Kuparuk WAG wells currently on MI injection cycles. The tubing injection pressure is approximately 3800 psi, however, the highest allowable working pressure for the inner annulus on a well of this style of well is 3000 psi which is well below the ANSI rated working pressure of 3705 psi. Tubing by inner annulus communication is not allowed on an MI injection well. For the unplanned instances that it does happen, the pressure is bled upon discovery. With the exception of 2 wells, 30 -12 and 3Q -15 which have API 5000# flanges, ConocoPhillips does not initiate an MITIA pressure tests above 3600 psi. 1/3/2011 • Page 2 of 3 Additionally based upon your inquiry Operations elected to proactively replace the the ANSI 1500 flanges on 1C- 25 and 1 C -27 with API 5000# flanges during our investigation. We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. CPAI does not operate equipment outside of safe engineering limits. This includes the use of ANSI 1500# flanges. CPAI's policies and engineering standards with regard to design and test pressures are in accordance with Industry Standards, such as ASME /ANSI B16.5, ASME B31.3, ASME B31.4, etc. Similar to your reference to API's stance on 'rated working pressure', the ASME /ANSI standards consider the 'pressure rating' or 'internal design pressure' the maximum pressure the piping system is designed to withstand under normal operating 9 P p PP 9 Y 9 conditions. These standards vary to some degree, but each provides for test pressures in excess of the internal design pressure. Again, similar to your reference to API, test pressures should not be confused with the internal design pressure (rating). The ANSI 1500# flanges have a rated pressure of 3,705 psig up to 100 °F and ASME /ANSI B16.5 allows a hydro test of up to 1.5 times the rated pressure. The ANSI 1500# flanges are therefore allowed to be subjected to test pressures up to 5,557 psig. See blue underlined section of ASME 616.5- 2003 which is attached. The ASME standards also provide for variations from normal operations, to account for things like surge, short - term operational events, etc. These allowances differ depending on the code used and other factors, but do acknowledge and provide for short -term pressure excursions. For example: The ASME B31.4 piping code allows a variation from normal operations of up to 10% over the piping system design pressure as long as adequate controls are in place to limit the pressure. Applying this allowance to our ANSI 1500# flanges, this overpressure allowance will allow a maximum abnormal pressure event of 4,075 psig. See blue underlined sections of ASME B31.4 -2006 which is attached. In summary, the ANSI 1500# flanges have a rated pressure of 3705 psig. Under normal operating conditions the IA flanges will be subjected to pressures well below 3000 psig. MITIA test pressures for these wells should not exceed 3600 psig, which is below the rated pressure, even though ASME /ANSI B16.5 would allow significantly higher test pressures (up to 5,557 psig). In the event of TxIA communication, administrative controls are in place to detect this condition and to respond accordingly in order to limit IA pressures below 3000 psig. In the unlikely event these controls fail to keep the IA from equalizing with the injection tubing pressure, the flanges could be subjected to injection tubing pressures of up to 3900 psig (^'5% above rated pressure) for a short period of time. However, this represents a multiple failure scenario and even then the pressure excursion would be well within the limits allowed by the ASME /ANSI standards. Other deficiencies noted during the KRU 1 C -pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1C-10, 1C-15) The stud bolt / nut engagement on 1C-10 and 1C-15 tubing spools have been added to the DHD work list and have been given a priority for repair. - KRU 1C-119 and 1 C -121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. Wells 1C-119 and 1C-121 had surface casing patch repairs completed in 2006. The conductor casings were intentionally left short of the mandrel hangers to allow access for cement and sealant. The conductor annulus of each well is cemented to surface and topped with corrosion inhibiting sealant. The surface casing is not centered in either conductor casing and both wells lean about 2 degrees which gives the appearance of a sideways bind. However, both wells and well lines are well supported with the flow line jacks that were recently adjusted as seen in the attached photos. - KRU 1C-174 was observed to have orifice meter wrapped in absorbant and an oily waste bag; use and condition of the orifice meter here needs to be explained. Heavy duty plastic bags are commonly used as a temporary "poor boy" insulation method to capture heat and to keep the metering from freezing. The oily waste bag on the 1C-174 was for such purpose. The meter was functioning normally during the inspection and is still functioning normally. A more permanent insulation system is 1/3/2011 Page 3 of 3 being evaluated. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 1/3/2011 i • AWE B31.4 -2006 PIPELINE TRANSPORTATION SYSTEMS FOR LIQUID HYDROCARBONS AND OTHER LIQUIDS 401.8 Relative Movement of Connected Components 402.2.4 Ratings - Allowance for Variations From Nor - The effect of relative movement of connected compo mat Operations. Surge pressures in a liquid pipeline rents shall be taken into account in design of piping are produced by a change in the velocity of the moving and pipe supporting elements. stream that results from shutting down of a pump sta- of a v alve or blockage lion or pumping unit closing , e of I p p g g the moving stream. 402 DESIGN CRITERIA Surge pressure attenuates (decreases in intensity) as it moves away from its point of origin. 402.1 General Surge calculations shall be made, and adequate con - Paragraph 402 pertains to ratings, stress criteria, trols and protective equipment shall be provided, so design allowances, and minimum design values; and that the level of pressure rise due to surges and other formulates the permissible variations to these factors variations from normal operations shall not exceed the used in the design of piping systems within the scope internal design pressure at any point in the piping sys- of this Code. lem a� nd equipment by more than 10°i°. The design requirements of this Code are adequate 402.2.5 Ratings - Considerations for Different Pres- for public safety under conditions usually encountered sure Conditions. When two lines that operate at differ - in piping systems within the scope of this Code, includ- ent pressure conditions are connected, the valve ing lines within villages, towns, cities, and industrial segregating the twa lines shall be rated for the more areas. However, the design engineer shall provide rea- severe service condition. When a line is connected to a sonable protection to prevent damage to the pipeline piece of equipment which operates at a higher pressure from unusual external conditions which may be encoun- condition than that of the line, the valve segregating the tered in river crossings, inland coastal water areas, line from the equipment shall be rated for at least the bridges, areas of heavy traffic, long self suppa operating condition of the equipment. The piping unstable ground, vibration, weight of special attach- between the more severe conditions and the valve shall meets, or forces resulting from abnormal thermal condi- be designed to withstand the operating conditions of lions. Some of the protective measures which the d esig n the equipment or piping to which it is connected. engineer may provide are encasing with steel pipe of larger diameter, adding concrete protective coating, 402.3 Allowable Stresses and Other Stress Limits increasing the wall thickness, lowering the line to a 402.3.1 Allowable Stress Values greater depth, or indicating the presence of the line with (n) The allowable stress value S to be used for design (06) additional markers. calculations in para. 404.1.2 for new pipe of known speci- 402.2 Pressure--Temperature Ratings for Piping fication shall be established as follows: Components S= F x E x specified minimum 402.2.1 Components Having Specific Ratings. yield strength of the pipe, psi (MPa) Within the metal temperature limits of -20 °F ( -30 °C) where to 250 °F (120 °C), pressure ratings for components shall E = weld joint factor (see para. 402,4.3 and conform to those stated for 100 °F (40 °C) in material Table 402.4.3) standards listed in Table 423.1. The nonmetallic trim, F = design factor based on nominal wall thickness. packing, seals, and gaskets shall be made of materials In setting design factor, due consideration has which are not injuriously affected by the fluid in the been g iven to and allowance has been made piping system and shall be capable of withstanding the for the underthickness tolerance and maximum pressures and temperatures to which they will be sub- allowable depth of imperfections provided for jetted in service. Low temperatures due to pressure in the specifications approved by the Code. The reduction situations, such as blow downs and other value of F used in this Code shall be not greater events, shall be considered when designing carbon diox- than 0.72. ide pipelines. 402,2.2 Ratings - Components Not Having Specific Table 402.3.1(a) is a tabulation of examples of allai+ able stresses for reference use in trans Ratings. Piping components not having established transportation piping pressure ratings may be qualified for use as specified systems within the scope of this Code, for F = 0.72. in pass. 404.7 and 423.1(b). (b) The allowable stress value S to be used for design calculations in para. 404.1.2 for used (reclaimed) pipe 402.2.3 Normal Operating Conditions. For normal of known specification shall be in accordance with (a) operation the maximum steady state operating pressure above and limitations in para. 405.2.1(b). shall not exceed the internal design pressure and pres- (c) The allowable stress value S to be used for design sure ratings for the components used. calculations in para. 404.1.2 for new or used (reclaimed) 8 .. . G'pyript AS'- E Intern atm,' Efored.d°y IHS underFarrse vrtn AS!.1e Ucenstt.LOC 12-An? 1 AKS919200112. UserrH .Mod 010 re100d 04 fnAOrtr g Wrolled ; 04 w'7Icense tam IHS Not lo-: Resa4. 0?11200l 0a 1.:07:'.*2 MDT • I ASME B16.5 -2003 PIPE FLANGES AND FLANGED FITTINGS 1.9 Denotation 2.3.2 Mixed Flanged Joints. If the two flanges in a 1 1.9.1 Pressure Rating Designation. Class, followed M flanged joint do not have the same pressure- temperature rating, the rating of the joint at any temperature is the a dimensionless number, is the designation for pressure- lower of the two flange ratings at that temperature. temperature ratings as follows: Class 150 300 400 600 900 1500 2500 2 . 4 Rating Temperature 1.9.2 Size. NPS, followed by a dimensionless nun The temperature shown for a corresponding pressure bet, is the designation for nominal flange or flange fitting rating is the temperature of the pressure containing shell size. NPS is related to the reference nominal dietrteier, of the component. In general, this temperature is the DN, used in international rating corresponding to a temperature other than that ational standards, The relationship same as that of the contained fluid. Use of a pressure DN is, , use typically, as follows: of the contained fluid is the responsibility of the user, NPS DN subject to the requirements of applicable codes and regu 15 lations. For any temperature below -29 °C (- 20 °F), the 3/4 20 rating shall be no greater than the rating shown for 1 25 -29°C (- 20 °F). See also paras. 2.5.3 and 5.1.2. 1 32 1 40 2.5 Temperature Considerations 2 50 2 65 2.5.1 General. Use of flanged joints at either high or 3 80 low temperatures shall take into consideration the risk 4 100 of joint leakage due to forces and moments developed in the connected piping or equipment. Provisions in GENERAL NOTE: For NPS> 4, the related DN is DN = 25 (NI'S). paras. 2.5.2 and 2.5.3 are included as advisory with the aim of lessening these risks. 2 PRESSURE - TEMPERATURE RATINGS 2.5.2 High Temperature. Application at temperatures in the creep range will result in decreasing bolt loads 2.1 General c flanges, bolts, and gaskets takes place. a. relaxation of flan e. a g P Pressure- temperature ratings are maximum allowable Flanged joints subjected to thermal gradients may like- working gage pressures in bar units at the temperatures wise be subject to decreasing bolt loads. Decreased bolt joint to sustain loads diminish the capacity of the flanged j in degrees Celsius shown in Tables 2-1.1 through 2 -3.17 $ j for the applicable material and class designation. Tables loads effectively without leakage. At temperatures F2 -1.1 through F2 -3.17 of Annex F list pressure - tempera- above 200 °C (400 °F) for Class 150 and above 400 °C ture ratings using psi units for pressure at the tempera- (750 °F) for other class designations, flanged joints may ture in degrees Fahrenheit. For intermediate develop leakage problems unless care is taken to avoid temperatures, linear interpolation is permitted. Interpo- imposing severe external loads, severe thermal gradi- lation between class designations is not permitted. ents, or both. 2.2 Flanged Joints 2.5.3 Low Temperature. Some of the materials listed in Tables 1A and 1B, notably some carbon steels, may A flanged joint is composed of separate and indepen- undergo a decrease in ductility when used at low tem- dent, although inter - related components: the flanges, the peratures to such an extent as to be unable to safely gasket, and the bolting, which are assembled by another resist shock loading, sudden changes of stress, or high influence, the assembler. Proper controls must be exer- stress concentration. Some codes or regulations may cised in the selection and application for all these ele- require impact testing for applications even where tem- ments to attain a joint that has acceptable leak tightness. peratures are higher than -29 °C (- 20 °F). When such Special techniques, such as controlled bolt tightening requirements apply, it is the responsibility of the user are described in ASME PCC -1. to ensure these requirements are communicated to the manufacturer prior to the time of purchase. 2.3 Ratings of Flanged Joints 2.3.1 Basis. Pressure- temperature ratings apply to 2.6 System Hydrostatic Testing flanged joints that conform to the limitations on bolting Flanged joints and flanged fittings may be subjected in para. 5.3 and on gaskets in para. 5.4, which are made to system hydrostatic tests at a pressure of 1.5 times the up in accordance with good practice for alignment and 38 °C (100 r rounded off to the next higher 1 Tar assembly (see para. 2.2). Use of these ratings for flanged (25 psi) increment. Testing at any higher pressure is joints not conforming to these limitations is the responsi- the responsibility of the user, taking into account the bility of the user. requirements of the applicable code or regulation. 2 c6pyrot AWE' irdtma::.n81 Pro.nded by IHS under Irmose w5h ASV E Li_rosee•LO: 12-Anth, g., 5919205112. Vser01341g, Rood No reproduct n or ne'n°rkng Perrnoed rollout k oroo torn HS S,l fx Re,''e. 03'182001 12 52 5'32 Page 1 of 1 Regg, James B (DOA) • • __ ____ _ _ _ __ _ _ _ From: Regg, James B (DOA) ~ b~z,51 10 Sent: Friday, June 25, 2010 2:17 PM ~~ 1 ~~/~~,{, (C-t C~ To: NSK Well Integrity Proj; NSK Problem Well Supv p~ -~z- ~t3 Cc: DOA AOGCC Prudhoe Bay; Maunder, Thomas E (DOA) Subject: ANSI 1500 Flanges Inspectors have been finding ANSI 1500 flanges installed on the IA of some wells when out to witness MITs. The rated working pressure for these flanges is 3700psi. If I understand the situation correctly, the ANSI 1500 flange is installed on the IA and would either be directly exposed to test pressure approaching the rated working pressure, or could be exposed to excessive injection pressures in the case of TxIA communication (e.g., high injection pressures on gas injectors or via thermal expansion). During witnessed MITs in late May 2010, ANSI 1500 fllanges were found on West Sak gas injectors KRU 1C-25 and 1C-27. In both occurances, CPAI was advised these are deficiencies. API defines the rated working pressure of equipment to be the maximum internal pressure that the equipment is designed to contain or control, and further notes that rated working pressure should not be confused with testing pressure (I read that to say it is inappropriate to justify operating equipment at pressure exceeding rated work pressure just because it was tested to the higher pressure). Exceeding the rated working pressure represents an inappropriate risk to field personnel attending to the wells. Inspectors have not been able to field verify if ANSI 1500 flanges have been hydrotested to proposed higher test pressure, and even if the flange was tested, we question how you would account for the history (exposure to extreme temps, harsh chemicals, corrosive fluids, etc.). We are interested in understanding CPAI's safe operating practices regarding ANSI 1500 flanges. We are also interested in reviewing any CPAI test policy that allows for the pressure rating of equipment to be exceeded. Other deficiencies noted during the KRU 1 C-pad inspections in late May: - Two instances of tree flange adapters made up to tubing spool without full engagement of the nuts on the studs (1 C-10, 1 C-15) - KRU 1 C-119 and 1 C-121 were noted to have mandrel hangers off seat from conductor casing; WAG injection lines were hanging from tree without support, placing the casings in a sideways bind. - KRU 1 C-174 was observed to have orifice meter wrapped in absorbant and an oily waste bag; use and condition of the orifice meter here needs to be explained. Please address these items. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 ~~h M,~! ~ if ~ 6/25/2010 MEMORANDUM • State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg ~ .~(zs~lo P.I. Supervisor FROM: john Crisp Petroleum Inspector DATE: Wednesday, June 09, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-10 KUPARUK RIV UNIT 1C-]0 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv `ua~--- Comm Well Name: KUPARUK RIV UNIT 1C-10 API Well Number: 50-029-20865-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523163209 Permit Number: 182-193-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ ]c-lo Type Inj. w~ TVD ~ ~-- 6sas 'I IA 6so z7zo 26zo ~ zs9o - P.T.D 1821930 TypeTest SPT I TCSt pSl 1586 / OA ~ 560 560 580 580 - Interval REQvAR p/F' P ~ Tubing 1957 ~ 1959 1949 1957 ~- __ NOtes: First MIT; test pressure too low per AIO 28.036, refer to mitJCR100523163729. MITIA per AIO 28.036.3.3 bbls pumped for test. Tree adapter flange to to mg spoo oes not ave engagemant on studs & nuts. Operator Reps made aware of deficiency. lUl~p.~ ~ Wednesday, June 09, 2010 Page 1 of 1 • MEMORANDUM Toy Jim Regg P.I. Supervisor l ~ ~r~s' (Q FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 09, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-10 KUPARUK RIV UNIT 1C-10 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv ~~' Comm Well Name: KUPARUK RIV UNIT 1C-10 API Well Number: 50-029-20865-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523163729 Permit Number: 182-193-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T lc-lo ~ Type Inj. W ~ TVD 6345 -I~- 420 347s 3360. 33s0 '~ ~- ~-- P.T.D~1821930 TypeTest SPT~TCSt psl 1s86 OA 438 638 6s6 i 67s Interval REQyAR P/F P ~ Tubing ~ 19s7 196a 1961 19s9 NOteS: Retested; initial test was not done to max anticipated ini. pressure per AIO 2B.036. MITIA per AIO 2B.036. 4.5 bbls pumped for test. Tree adap erer flange to tubing spool studs & nuts are not fully engaged. Operator Reps made aware of deficiency. ~~~v Wednesday, June 09, 2010 Page 1 of 1 • MEMORANDUM To: Jim Regg P.I. Supervisor ~~~~( 6I2~I ~G FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-10 KtJPARUK RIV UNIT IC-]0 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~.~- Comm Well Name: KUPARUK RIV UNIT iC-10 API Well Number: 50-029-20865-00-00 Inspector Name: John Crisp Insp Num: mitJCr100523164526 Permit Number: 182-193-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weil 1c-1oType Inj. ~W TVD 6345 ~ IA 415 463 482 j 494 P.T.D 1821930 p t ~ SPT 'I'8St psl ~ 1586 Q~-600 1820 /I 1790 ~ 1780 Interval REQvAR p/F P / Tubing ~ 19ss 9 ~ ~ 19s6 _ 19so -- Notes: MITOA per AIO 2B.036. 1 bbl pumped for test. Tree flange adapter to tubing spool does not have full engagement on studs & nuts. Operator Reps made aware of deficiency Tuesday, May 25, 2010 Page 1 of 1 • ! ! y { SARAN PALIN, GOVERNOR �T�+ �p ALASKA OIL AND GA�S 333 W 7th AVENUE SUITE 100 CONSERVATION COMMISSION ANCHORAGE ALASKA 99501 -3539 PHONE :9071279 -1433 FAX . 4507} 276.7542. ADMINISTRATIVE APPROVAL 28.036 Ms. NU Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. stANINF ? I A r•' 2 ?Oil P.O. Box 100360 Anchorage, AK 99510 -0360 RE: KRU 1C-10 (PTD 1821930) Request for Administrative Approval Dear Ms. Loveland: In accordance with Rule 9 of Area Injection Order (AIO) 028.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. The request to continue miscible gas injection is denied. Kuparuk River Unit (KRU) 1C -10 exhibits pressure communication between the production and surface casings (outer annulus or OA). All positive pressure tests performed on the well's inner annulus (IA), OA, and wellhead seals have passed since communication was first identified and reported in February 2008. The Commission finds that CPAI does not intend to perform repairs at this time. deferring until the location of pressure communication can be determined. Reported results of CPAI's diagnostic procedures and wellhead pressure trend plots indicate that KRU 1C-10 exhibits at least two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1C -10 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily: 2. CPAI shall submit to the AOGCC a monthly report of well pressures. injection rates, and pressure bleeds for all annuli: 3. CPAI shall perform an MIT -IA every 2 years to 1.2 times the maximum anticipated injection pressure: 4. CPAI shall perform an MIT -OA every 2 years to 1800 psi: A1O 213.032 • 0 August 25. 2008 Page 2 of2 5. CPAI shall limit IA pressure to 2000 psi and OA pressure to 1500 psi; 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; - 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. and 8. The MIT anniversary date is July 9, 2008. DONE at Anchorage. Alaska and dated August 25. 2008. 0 r" - )41' i 1 l Daniel T. Seamount, Jr. Cathy ► . Foerster Jo 1 K�'orma Chair Commissioner Commissioner RECONSIDERATION AND API'IAL NOTICE As provided in AS 31.05.080(a), within 20 daps alter written notice of the entry of this order or decision. or such further time as the Commission grants Fitt good cause shown_ a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. lithe notice was nailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within IO days alter it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial_ this order or decision and the denial of reconsideration are FINAL. and may be appealed to superior court. The appeal ,M1UST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes. the order or decision denying reconsideration. UNLESS the denial is by inaction. in which case the appeal NI UST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration. this order or decision does 001 become final. Rather. the order or decision on reconsideration will be the FINAL order or decision of the Commission. and it may be appealed to superior court. That appeal \IUS'1' he tiled within 33 days after the date on which the Commission nails, OR 30 days if the Commission otherwise distributes. the order or decision on reconsideration. As provided in AS 31.05.080(6) " it]he questions reviewed on appeal are limited to the questions presented to the. Commission by the application for reconsideration."' In computing a period of time above. the date of the event or default after which the designated period begins to run is not included in the period: the last day of the period is included. unless it lalls on a weekend or state holiday. in which event the period tons until 5:00 p.m. 011 the next day that does not fall 00 a weekend or state holiday. 4h>, OIL Fit . 1.' .,.: ' ,:- .. :\.1.:1- • • Regg, James B (DOA) P~ +`82-L9~ From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Sunday, August 03, 2008 6:49 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Subject: Emailing: MIT KRU 1 C-10 07-09-08.x1s ~~~ ~' k'~~~ Attachments: MIT KRU 1C-10 07-09-08.x1s I -~,~ MIT KRU 1C-10 07-09-08.x1s (21... «MIT KRU 1C-10 07-09-08.x1s» Please find the Attached MIT IA and MIT OA that were completed in preparation for an AA application. The AA application was mailed 8/3/08. Please let me know if your have any questions about the data. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 ~1~~' AEG 2008 1 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: ConocoPhillipsAlaska, Inc. ~~ c~ {a~i]`~ FIELD /UNIT /PAD: ~~ Kuparuk /KRU / 1C-10 DATE: 07/09/08 OPERATOR REP: Bates !Phillips - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-10 Type Inj. W TVD 6,346' Tubing 1,925 1,950 1,950 1,950 Interval O P.T.D. 1821930 Type test P Test psi 1586.5 Casing 890 3,000 2,950 2,910 P/F P Notes: Diagnostic MITIA for AA application OA 870 900 900 900 45 min T/i/0=1950/2900/900 Well 1C-10 Type Inj. W TVD 6,346' Tubing 1,950 1,950 1,950 1,950 Interval O P.T.D. 1821930 Type test P Test psi 1586.5 Casing 1,000 1,000 1,050 1,050 P/F P Notes: Diagnostic MITOA for AA application OA 900 1800 1800 1800 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 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting 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 1C-10 07-09-08.x1s • 0 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 Y ;? W t August 2, 2008 .Ale r U� 0 5 2 00 t4 Clap _.F, rw i s Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 JO2� Dear Mr. Maunder: ConocoPhillips Alaska, Inc. presents the attached proposal as per AIO 2B, Rule 9, to apply for Administrative Approval to allow well 1C -10 (PTD 182 -193) to remain in water or MI injection service with inner annulus by outer annulus communication. If you need additional information, please contact Perry Klein or me at 659 -7043 or Brent Rogers / Martin Walters at 659 -7224. Sincerely, z , ./ MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Attachments • • Conoco Phillips Alaska, Inc. Kuparuk Well 1C -10 (PTD 1821930) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 1C -10. Well History and Status Kuparuk River Unit well 1C -10 (PTD 1821930) was originally completed in November 1982 as an injection well. 1C -10 was reported to the Commission on 02/19/08 as showing sign of IAxOA communication. All positive pressure diagnostics (MITIA, MITOA, and packoff testing) continue to pass integrity testing however, the attached TIO trend shows definite IAxOA tracking albeit below 1000 psi. There is no recordable leak rate therefore it is unknown if the communication is buttress tread leaks down hole or a pack off leak in the well head. The most recent diagnostic tests conducted on 07/09/08 are as follows; a passing MITIA to 3000 psi and a passing MITOA to 1800 psi. See the attached MIT form for additional details. ConocoPhillips intends to pursue repairs if the leak worsens enough to be detectable and located. However, until the leak is detectable, ConocoPhillips requests an AA for water and MI injection service which will allow the OA to equalize with the IA. For consistency with other IAxOA AA's we request an OA do not exceed pressure of 1500 psi. Barrier and Hazard Evaluation Tubing: The 3.5" 9.3 lb J -55 tubing has integrity to at least the top packer at 8136' RKB based on passing MITIAs and TIO trends. Production casing: The 7" 26 lb K -55 production casing has integrity from the formation and injection pressure based on passing MITIAs and TIO trends. The internal yield pressure rating of the casing is 4980 psi. Surface casing: The surface casing and cement shoe have integrity based on passing MITOAs @ 1800 psi. The 10 -3/4" 45.5# K -55 surface casing has an internal yield pressure rating of 3580 psi. Primary barrier: The primary barrier to prevent a release from the well and provide zonal isolation is the tubing. Secondary barrier: The production casing is the secondary barrier in the event of a release. Tertiary barrier: The surface casing will provide a third barrier in the event of a release. A 1500 psi OA pressure is allowed for consistency with other IAxOA AA's. Monitoring: Each well is monitored daily for wellhead pressure changes. Should additional leaks develop in the completion it will be noted during the daily monitoring process. Any deviations from approved MAOP annular pressures require investigation and corrective action, up to and including a shut -in of the well. NSK Well Integrity 08/02/08 • • Additional Repair Plan ConocoPhillips intends to pursue additional diagnostics and repair options. If a successful repair is achieved the AA will be cancelled. Proposed Operating and Monitoring Plan 1. Water and MI injection service allowed; 2. Perform 2 -year MITIA to maximum injection pressure; 3. Perform 2 -year MITOA @ 1800 psi to verify integrity of production and surface casings to OA cement shoe; 4. IA pressure is not to exceed 2000 psi, OA pressure is not to exceed 1500 psi; 5. Well will be placed on the Monthly injector Report to the AOGCC. 6. Shut -in the well should injection rates and pressures indicate further problems and provide appropriate notification to the AOGCC. • NSK Well Integrity 08/02/08 2 CHOKE FTP FTT !AP OAP T /1/0 Plot -1 C -10 2000 _ 1500 100 — "` 1 _- E a. Fii a = 2, -100 a 1000 = Y r\._ i 2 __________., I\ i 1 , \ 1 500 _ it r- 1..r I 01- Jun -08 01- Jul -08 01- Aug -08 Date • • 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: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 1C-10 DATE: 07/09/08 OPERATOR REP: Bates / Phillips - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C -10 Type Inj. W TVD 6,346' Tubing 1,925 1,950 1,950 1,950 Interval 0 P.T.D. 1821930 Type test P Test psi_ 1586.5 Casing 890 3,000 2,950 2,910 P/F P Notes: Diagnostic MITIA for AA application OA 870 900_ 900 900 45 min T /I /0= 1950/2900/900 _ Well 1C -10 Type Inj. W TVD 6,346' Tubing 1,950 1,950 1,950 1,950 Interval 0 P.T.D. _1821930 Type test P Test psi 1586.5 Casing 1,000 1,000 1,050 1,050 P/F P Notes: Diagnostic MITOA for AA application OA 900 1800 1800 1800 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) MIT Report Form BFL 11/27/07 MIT KRU 1C -10 07- 09- 08.xls • 10 1 KRU 1C-10 ConocoPhillips Alaska, Inc. API: 1 500292086500 Well Type: INJ Angle W TS: 27 deg 8276 SSSV Type: TRDP Orig Completion: 11/29/1982 Angle p TD: 28 deg C ) 9002 Annular Fluid: Last W /O: 3/24/1990 Rev Reason: ADD PERF DATES Reference Log: Ref Log Date: Last Update: 7/8/2007 Last Tag: 8332' TD: 9002 ftKB SSSV Last Ta Date: 3/16/2007 Max Hole An le: 58 d 4100 (1801 - 1802, Zlsing L 00.3.500) Description Size Top Bottom TVD Wt Grade Thread (UBBIN9 r C 20.000 0 99 99 92.00 H -40 00:3.500, SURFACE 10.750 _ 0 _ 2567 2284 45.50 K -55 1112.992) PRODUCTION 7.000 0 8976 7095 26.00 K -55 'RODUUCnON String _ TUBING (0 Size Top Bottom _ TVD Wt Grade Thread 00:7.000, 3.500 0 8199 6402 9.30 J -55 DSS -HT Wt:26.00) forations Summ Interval _ TVD Zone Status Ft SPF Date Type Comment 8278 - 8304 6473 - 6496 C -4 26 4 1/12/1983 IPERF Gas lift 8308 - 8344 6500 - 6532 C- 4,C -3,C -2 36 4 1/12/1983 IPERF 3ndrel /Dummy I .- S Lift __ Valtie 1 St MD TVD Man Mir Man Type . V Mir - T V T V OD Lat Port TRO ' D Run VIv (8060 -8061, Date Cmnt 00:5.750) 1 8060 6279 Camco MMG - DMY 1.5 RK 0.000 0 3/24/1990 Depth ype Description ___ -- ID 1801 1696 SSSV Camco TRDP -1A -SSA 2.813 8110 6323 SBR Otis 4 SBR 8136 6346 PKR Otis'HCL' Perm. 4.000 (8110 - 8111, 8182 6387 NIP Camco 'D' Nipple NO GO 2,750 OD:3.500) _ A,F 8199 6402 SOS Vann €* ;= 8199 6402 TTL 2.992 Fish - FISH Depth Description Comment 8744 Vann Gun Left in Hole after initial Perf. General Notes - - -- -- — — PKR Date Note (8136 - 8137, 4/1/1990 NOTE: Well was worked -over 4/90; acidized 5/90 00:6.156) NIP (8182800 00:3.5500) SOS (8199-8200, 00:3.500) TTL (8199 -8200, OD:3.500) Perf (8278-8304) Perf (8308 -8344) Vann Gun — — (8744 -8890, 00:4.000) ,.p 03/20/07 Schlumbergel' /1.. 11 . l {)j---' NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth SCANNED APR 0 3 2007 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~1AF( ;~: 2, 2001 Field: Kuparuk U Ie... /75 d -/Cj3 Well Job# Log Description Date BL Color CD 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1 C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1 A-12 11638832 SBHP SURVEY 03/08/07 1 1E-20 11638833 GLS 03/09/07 1 1E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1 E-117 11626471 INJECTION PROFILE 03/14/07 1 1 Q-09 11638839 INJECTION PROFILE 03/16/07 1 3S-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1 C-1 0 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1H-21 11638842 GLS 03/19/07 1 1 D-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 I Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ì6' . . Kuparuk Injection Well Reporting Page 1 of 1 Re , James B DOA • 9J ~ ) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, February 19, 2008 1:34 PM ~~~~ ~'t~ ~~~ To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk Injection Well Reporting Jim, Per our phone conversation, here is a list of injection wells that we are in the process of pursuing AA's for A102B. Each of these wells have been waivered under ConocoPhillips Well Operating Guidelines and reported to the State as a group on a spreadsheet in June 2007. They also may have been reported individually at the time of the waiver or in the first group report submitted 10/08/03. Up until this time ConocoPhillips has assumed that we had implied AOGCC consent to continue water injection in each well in its current condition. The purpose of this email is to ensure that we do indeed have consent for water injection and to notify the State that AA applications are in progress. 1A-12 - 181-178 - IAxOA communication 2V-02 - 183-161 -Minor IAxOA communication 3N-12 - 186-079 -Slow TXIA •'~;~,~~~~~;; ~~~ Q 20~~ 3N-13 - 186-081.- Slow TxIA a1C-10 - 182-193 - IAxOA communication ~ Wells 1A-12, 2V-02, 3N-12, and 1C-10 were added to the Monthly injector report this month. 3N-13 is already on the report. Please let me know if you have any questions or if additional reporting or action (other than the AA applications) is required. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/13/2008 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg -p I· P.I. Supervisor "IteN '5 tCd 0 Y DATE: Tuesday, May 09,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC !C-W KUPARUK RIV UNIT lC-lO :;'Ã& .·~·ta.t.J .. :.a"i~~' l'·O FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv."rtSlZ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-IO API Well Number 50-029-20865-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060508180844 Permit Number: 182- I 93-0 Inspection Date: 5/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well : 1C-10 IT I" I -~ I I ype nJ. i wI TVD I 6346 IA 540 I 1560 1550 1550 I OA I i P.T. : 1821930 iTypeTest i SPT i Test psi , 15865 i 380 i 380 I 380 390 I ì I ..L -- Interval 4YRTST P/F P Tubing I 2141 2143 ! 2143 2143 I L i ! Notes 1.9 bbls diesel pumped, I well house inspected; no exceptions noted. Waivered: IA x OA communication. .;",..·.··1('" ~ ~.~4i'¡r::::_·_..."¡-_\.·.... . f.... 11.: ..r\.~..1 :. c r- r c-· ~V{f'tJJ~C\]~jq, 'Ìoi?V .~ ~ J ¿JUb Tuesday, May 09, 2006 Page I of I I e e ConocoPhillips Alaska, Inc. KRU 1 C-1 0 1C-10 API: 500292086500 Well Type: INJ Angle (â) TS: 27 deg (â) 8276 SSSV Type: TRDP Orig 11/29/1982 Angle @ TD: 28 deg @ 9002 ComDletion: Annular Fluid: Last W/O: 3/24/1990 Rev Reason: TAG FILL sssv I Reference Loa: Ref Loa Date: Last UDdate: 10/17/2004 (1801-1802, Last Taa: 8340 TD: 9002 ftKB 00:3.500) Last Tag Date: 10/15/2004 Max Hole 58 deg @ 4100 TUBING Angle: (0-8199, Casing String - ALL STRINGS 00:3.500, 10:2.992) DescriPtion Size TOD Bottom TVD Wt Grade Thread 'ROOUCTlON CONDUCTOR 20.000 0 99 99 92.00 H-40 (0-8976, SURFACE 10.750 0 2567 2284 45.50 K-55 00:7.000, PRODUCTION 7.000 0 8976 7095 26.00 K-55 Wt:26.00) Tubina Strine - TUBING Size I Top 1 Bottom I TVD I Wt I Grade I Thread Gas Lift .t 3.500 I 0 I 8199 ! 6402 I 9.30 I J-55 I DSS-HT ¡ndrel/Oummy Perforations Summary Valve 1 Interval I TVD 1 Zone I Status I Ft 1 SPF I Date I TYDe I Comment (8080-8061, 00:5.750) 8278 - 8304 I 6473 - 6496 I C-4 I ODen I 26 I 4 I I I 8308 - 8344 1 6500 - 6532 C-4,C-3,C-2 ODen I 36 I 4 1 I I Gas Lift MandrelsNalves St I MD I TVD I Man Man Type I V Mfr I V Type I V OD I Latch I Port I TRO Date I Vlv Mfr Run Cmnt SBR 1 I 8060 1 62791 Cameo I MMG-2 I I DMY I 1.5 I RK 10.000 I 0 13/24/19901 (8110-8111, 00:3.500) Other (I lugs, equip., etc.) - JEWELRY . Ðepth TVD Type Description ID 1801 1696 SSSV Cameo TRDP-1A-SSA 2,813 8110 6323 SBR Otis 4.750 8136 6346 PKR Otis 'HCL' Perm. 4.000 8182 6387 NIP Cameo 'D' Nipple NO GO 2.750 I PKR 8199 6402 50S Vann 2.992 (8136-8137, 8199 6402 TTL 2.992 I 00:6.156) Fish - FISH Depth I Description I Comment 8744 I Vann Gun ! Left in Hole after initial Perf. General Notes Date I Note NIP 4/1/1990 I Well was worked-over 4/90; acidized 5/90 (8182-8183, [] 00:3.500) SOS (8199-8200, 00:3.500) TTL (8199-8200, 00:3.500) - , Perf - - (8278-8304) - - - - - - - - - - - - Perf = = (8308-8344 ) - f--- - f-- - f-- - f-- - f--- - f--- - I f-- Vann Gun (8744-8890, 00:4.000) -~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor r,.~)\ Chairman DATE: June 16, 2002 THRU: Tom Maunder P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Phillips 1 C Pad KRU Kuparuk Packer Depth Pretest Initial 15 Min. 30 Min, WellJ 1C-05 I Typelnj.! F I T.V.D. I 6267 J Tubing J 2000 I 2000 J 2000 ] 2000 I lntervall 4 P.T.D.I 181-005 ITypetestl P I Testpsil 1567 1CasingI 1050I 2050I 2000I 2000I P/FI -P Notes: we,,I~c-qo I Typelnj. I F I T.V.D.i~ I Tubing 1~9oo I~oo I~oo I,~oo I,nterva, I 4 P.T.D.I 182-193 ITypetestl P I Testpsil 1587 ICasi.gI 900 I 20251 19751 19501 P/F I P Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Well! P.T.D.I Notes: IType I nj. Type test Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Phillips 1C Pad in the Kuparuk River Field and witnessed the routine 4-Year MIT on wells lC-05 and lC- 10. The pretest tubing and casing pressures were observed and found to be stable. The standard annulus pressure test was then performed with both wells demonstrating good mechanical integrity. M.I.T.'s performed: _2 Attachments: Number of Failures: 0 Total Time during tests: 2 hour cc: MIT report form 5/12/00 L.G. MIT KRU 1C Pad 6-16-02 CS.xIs 6/20/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 97 feet 3. ,Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 ser~___x Kuparuk Unit 4. Location of well at surface 8. Well number 1469' FNL, 4603' FEL, Sec. 12, T11N, R10E, UM (asp's561681, 5968763) lC-10 ,At top of productive interval 9. Permit number / approval number 926' FNL, 1159' FWL, Sec. 13, T11N, RIOE, UM 182-193/ ,At effective depth 10. APl number 50-029-20865 At total depth 11. Field / Pool 1251' FNL, 4125' FEL, Sec. 13, T11 N, R10E, UM (asp's 562204, 5963705) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9002 feet Plugs (measured) true vertical 7118 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 99' 20" 246 sx AS II 99' 99' _ . SURFACE .......... 2~7~)~ .... 10r3Z4"_ .9eOs~JF~.d. &2Se~zP_F C ........ 2567'.. 2284'. PRODUCTION 8879' 7' 878 sx Class G & 250 sx PFC 8976' 7095' Tubing (size, grade, and measured depth) ........................ !:! ............ i:::-_- .......... ---'-:::-::-:~::-:::::~ .............................. ~ ................................... · ................ - ......... :-::-:' ........................................................... ::: :~,~.a u~ ~,~ ~Gas Cons. Commission - · ....................................... -.: :'.::- .... :.:: ~rlc~.0~a,~..~: i:~:~:~:~:~:~.~:::-': ....... · ........... : :: :-:-: c-:-:-:-:--.;.;-;-;-; ;.; :-: :-:-:-:':-'-;-; T;';-;-;-: ;-;;; i-; :-:':-:-:-:-:-: :':':':::: :-:-:-:-:-: :':-: :':':':': :'i;; :': :-:':':':':':':':':';'; ;';;;::: ':':':':':': ;':';;; :': :':':: -: :':;;:: :':'. :'-':'- :':' 13. Stimulation or cement squeeze summary ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ================================================================= ::::::_ ::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::: ::: ::.::: ::: ::::: ::...:/ ..-...-........== _ ..._..-............-..,............ ...... ....._....._....... ....... . ...-......-. _...... ..... .......... · ............... ::::::::::::::::::::::::::::::::::: ===================== :-:::...:.:.:::: ::: .-..: .. .:.., .... ...... :.. ...... .: ..... :.. ...... . . ..:: .:: .:. - , :.. :.:::;.: ..:..: .::::.::.:: :.:.::.::::.: Treatment description including volumes used and final pressure i!!~ii~i!~!!~!i!~i:i~i;i;iiii!!!!i~i!!~i~!:iii:i~!~:;~i~!~i.!:i~!~i!i!:i~.~:~i.~j~:~?~ i::']:i'i:i. ?:.i:i:/::i:i:i:i:!i::: 14. Representative Daily Average Produotion or Injection Data OiFBbl ..................................................... G~=M_.~ ........................... w..a.!e_r=B.b! ............. ........................ : .......... :.:.:.: ........ :.::.::. :....:....:.:.:.:.::.:.:..:.: _.. :.:.:+ ::.::-::.:....::.:.:. :-.. .... :.....:. :... ................. . . ,.. .......... .,..:.. -. ..... :.:..,:. :.:.:.:..:,: 15. Attachments Copies of Logs and Surveys run __ 17. I hereby certify that bhe foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed ~""~~-'~~ Title Production Engineering'Supervisor Date ~ · Jeff A. Spencer Prepared by Robert C rh~tensen 659-7535 Form 10-404 Rev 06/15/88 ORIGINAL JAN 9 2002 SUBMIT IN DUPLICATE 1C-10 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/6/01 J Commenced WAG EOR Injection J I I I ! STATE Of ALASKA -"'/~-~-~' · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well X ot h e r __ 2. Name of Operator ARCO Al~,ska. 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 1471' FNL, 674' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 926' FNL, 1159' FWL, Sec. 13, T11N, R10E, UM At effective depth At total depth 1254' FNL, 1156' FWL, Sec. 13, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 9 0 0 2' feet 71 1 7' feet Plugs (measured) 6. Datum elevation (DF or KB) 97' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1C-10 9. Permit number/approval number 82-193/90-090 10. APl number 50-029-20865 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 8 8 9 0' true vertical 7018' feet feet Junk (measured) 8722' VANN GUNS Casing Length Structural 6 5' Conductor Surface 2 5 3 7' Intermediate Production 9 7 3 6' Liner Perforation depth: measured 8278'-8304', true vertical 6472'-6495', Size 20" I 0-3/4" 7" Cemented 246 sx AS II 990 sx Fondu & 250 sx Permafrost C 878 sx Class G & 250 sx Permafrost C 8308'-8344' 6499'-6531' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 DSS TBG W/ TAIL Packers and SSSV (type and measured depth) @ 8195' Otis "HCL" Pkr @ 8136', Camco "TRDP-1A" SSSV @ 2081' 13. Stimulation or cement squeeze summary Intervals treated (measured) M~sured depth True vertical depth 96'md 96'tvd 2568'md 2284'tvd 8977'md 7095'tvd Treatment description including volumes used and final pressure 14. Reoresentative Dailv Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 05/1 Title Area Drilling Engineer SUBMIT IN DUPLICATE ARCO Oil anu Gas Company Well History - Initial Report - Daily Inabuctiona: Prepare and submit the "lnlUii RII~IT' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to SPudding a~ould be summarized on the form giving inclusive dates only. District Field ARCO AT.~SY~I~ ZNC. I C, ounty, parish or borough NORTH SLOPE ILease or Unit KUPARUK RIVER I ADL: 25650 ALK: 468 ! r Title Auth. or W.O. no. IState AK IWell no. KRU lC-~0 Operator IARCO W.I. I 55.8533 SpuddedACCEPT°r W.O. begun IDate 03/16/90 [Hour IPrior status if a W.O. Date and depth as of 8:00 a.m. 03/16/90 ( TD: 0 PB: 8891 SUPV: GB 03/17/90 ( TD: 0 PB: 8891 SUPV:GB 03/18/90 ( TD: 0 PB: 8891 SUPV: GB 03/19/90 ( ~I:): 0 PB: 8891 SUPV: GB 1) 2) 4) 03/20/90 (5) TD: 0 PB: 8891 SUPV: GB Complete record for each day reported NORDIC #1 W O TOOLS MW: -0.0 NU UPPER FLANGE ON TREE,FILL PIT WITH MUD,RU LUBRICATOR, PULL BPV, BPV TOOL FAIL W O ANOTHER BPV TOOL. · DAILY:S18,691 CUM:$18,691 ETD:SO EFC:$18,691 RD SLICKLINE UNIT MW:12.6 LSND PULL BPV, RU SLICKLINE, TEST LUBR., RIH AND PULL A2 PRONG~ POH, RIH AND PULL A2 PLUG, POH, RD SLICKLINE, PUMP 117 BBLS WATER, FOLLOWED BY 12.2 PPG MUD, MONITOR WELL, SITP 420, WGT MUD IN PITS TO 12.6 PPG, RU SLICKLINE, RIH W/A2 PLUG, STOPPED AT SSSV, POH, RIH W/ 2.8" GR TO D NIPPLE, POH, RIH W/ PLUG, UNABLE TO SET PLUG, POH, RD SLICKLINE UNIT DAILY=S41,879 CUM:$60,570 ETD:S60,570 EFC:$0 CIRC. & COND MUD MW:12.6 LSND RD SLICKLINE, SET BPV, ND TREE, SET TEST PLUG, BLED GAS OFF 7"X10-3/4" ANNULUS NU BOPE, TEST BOPE TO 3000 PSI, PULL TEST PLUG, PULL BPV, BOLDS, PU & PULL TBG FROM SBR, LD TBG HGR, CIRC & COND MOD DAILY=S28,147 CUM:$88,717 ETD:S88,717 EFC:$0 POH LD TBG MW: 12.6 LSND .'/.:~i:CoNT. CIRC. & COND HUD, PUMP DRY JOB, POH LD TBG, CIRC & ~:_~.~COND MUD, CONT. POH LD TBGv CIRC & COND MUD, CONT. POH LD ~D~ZLY=$54,809 CUM:$143,526 ETD:S143,526 EFC:$0 NU BOP STACK/FLOW NIPPLE MW:12.6 LSND CONT. POH LD TBG, RU & R~H W/ RBP ON 3-1/2" DP, SET RBP AT 7999, TEST CSG TO 2500 PSI - OK, RELEASE FROM RBP, POH 2 STANDS, PU STORM PKR, RIH, SET PKR AT 51', TEST PKR TO 500 PSI, RELEASE FROM PKR, POH, BLED GAS OFF 10-3/4" ANNULUS, BOLDS, LATCH INTO 9-5/8" PACKOFF, PULLED PACKOFF APART, ND BOPE, RETRIEVE REMAINDER OF PACKOFF, INSTALL NEW PACKOFF, NU WELLHEAD AND TEST TO 3000 PSI, NU BOPE/FLOW NIPPLE DAILY:S34,280 CUM:$177,806 ETD:S177,806 EFC:$0 RaH W/ 3-1/2" COMPLETION MW:12.6 LSND CONT. NU FLOW NIPPLE, SET WB, RaH & RETRIEVE STORM PKR, POH, RaH, CIRC, RELEASE RBP, POH, RU & RIH W/ 3-1/2" COMPLETION ASSEMBLY DAILY:S43,798 CUM:$221,604 ~TD;$ZZi,604 RFC:SO The above is/~. ct For form preparetio.l~"a~l ~]istributlon, ~ see Procedures M~nual.,/Section 10 Drilling, Pages 86 ~,"87. Date // / Title AR3B-459-1-D Number all daily well history forms consecutively ~ no. las they are prepared for each we . IPage I ARCO Oil and ,.,as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show tormation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District ARCO ALASKA INC. ~County or Parish I NORTH SLOPE Field ILease or Unit KUPARUK RIVER ADL: 25650 ALK: 468 Date and deptll Complete record for ~ach day willie drilling or workover in progress as of 8:00 a.m. NORDIC #1 7 IStale AK JWell no. KRU 19-10 03/22/90 ( TD: 0 PS: 8891 SUPV: GB 03/23/90 ( TD: 0 PB: 8891 SUPV: GB The above is/orrect S i g n at u r e ~/,.~......,~...~,_ ~ For form preparation,a~:l distribution ~ see Procedures Man[~alJSection 10, Drilling, Pages 86 anl~87 LAND TUBING MW: 12.6 LSND RIH WITH 3.5" COMP. ASSY,NU FMC WELLHEAD, TRY TO LAND AND SPACE OUT TUBING. DAILY: $50,448 CUM: $272,052 ETD: $272,052 EFC: $0 MW: 0.0 diesel LAND TUBING, ND BOPE, NU TREE, TEST ANNULUS,DISP W/ DIESEL, RU OTIS TO RETRIEVE LOCK OPEN SLEEVE. DAILY:SO CUM:$272,052 ETD~$0 EFC:$272,052 RECEIVED APR 2 5 1990 AlaSk 011 & ommMiofl Date / / Title AR3B-459-2-B JNumber all daily well history forms conseculively JPage no. as they are prepared lot each well. I ARCO Oi, ,~nd 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. "F|rlal 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 reporling the entire operation if space is available. J Accounting cost center code District [State ARCO ALASKA INC. AK County or Parish NORTH SLOPE JLease or Unit KUPARUK RIVER I ADL: 25650 ALK: 468 Title Well no. KRU lq-10 Auth. or W.O. no. Operator I A.R.Co. W.I. ARCO J 55. 8533 Spudded or W.O. begun ~Oate ACCEPT I 03/16/90 Date and depth as of 8:00 a.m. 03/24/90 ( TD: 0 PB: 8891 SUPV: GB Complete record for each day reporled NORDIC #1 9) Iota! number of wells (active or inactive) on this Dst center prior to plugging and bandonment o! this well our l Prior Stalus if a W.O. I Did TD I New TD I Released rig I Date I Classifications (oil, gas, etc.) RELEASE RIG MW: 6.8 diesel FINISH SETTING DV IN GLM @ 8060' MD. POH RD OTIS. TEST 7"X3-1/2" ANN. TEST OK, TEST TBG & ~SSV, OKAY, RELEASE RIG @ RECEIVED APR 2 § 1990 1600 3/23/90. DAILY:S27,044 CUM:$299,096 ETD:S299,096 EFC:$0 7n~ll~hJ ~lJJ Idl~ll~JlJe do, ,,o Anchorage Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test IGas per day Pump size, ~PM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Eflective date corrected The above ~:orrect For form preparati~a~d distribution, AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no. Dlvl~/on of AtlantlcRIchfleldCompany AL' ':A OILAND GAS CONSERVATION COMK ',ON FOR SUNDRY APPROVALS APPLICATION 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well X Plugging _ Change approved program_ Pull tubing ~ 2. Name of Operator 99510 5. Type of Well: Development .X__ Exploratory _ Stratigraphic _ Service ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 1471' FNL, 674' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 926' FNL, 1159' FWL, Sec. 13, T11N, R10E, UM At effective depth At total depth 1254' FNL, 1156' FWL, Sec. 13, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical 9002 7117 Operation Shutdown _ Re-enter suspended well_ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) 8890 7018 Effective depth: measured true vertical 97' RKB 7. Unit or Property name Kuparuk River Unit Casing Length Size Structural Conductor 6 5' 2 0" Surface 2 5 6 8 I 0 - 3 / 4" Intermediate Production 8 9 7 7' 7" Liner Perforation depth: measured 8278'-8304', true vertical 6472'-6495', 8. Well number 10-1Q 9. Permit number 82-1c,);~ 10. APl number 50-029-20865 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool feet Plugs (measured) None feet Tubing (size, grade, and measured depth feet Junk (measured) None feet Cemented Measured depth 246 Sx AS II 65' 990 Sx Fondu & 256 8' 250 Sx Permafrost C 878 Sx Class G & 8 9 7 7' 250 Sx Permafrost C 8308'-8344' 6499'-6531' 3-1/2", 9.3#, J-55 DSS tbg w/ tail @ 8195' Packers and SSSV (type and measured depth) Otis HCL pkr @ 8136', Camco TRDP SSSV @ 2081' 13. Attachments Description summary of proposal X Detailed operation program _ Proposed workover will repair leaking wellhead packoffs. 14. Estimated date for commencing operation 115. Status of well classification as: March 1990 I Oil ~ Gas _ 16.If proposal was verbally approved Name of approver Date approved Service .~ _-¢___~"-~,~, 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'~,~J~. ~. ~(_~-~.~ Title /~eA-~::~ ~-I~Kt~,~ ~-',ffr FOR OOMMISSlON USE ONLY Approved by the order of the Commission Form 10-403 Rev 06/15/88 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test )~5''~' Subsequent form require -\ ORIGhNAL o,,.~'~-~ BY Commissioner Approved Copy .Retu~'ned True vertical depth 65' 2284' 7095' BOP sketch Suspended _ Date SUBMIT IN TRIPLICATE KUPARUK RIVER UNIT 1C-10 Workover Procedure SUMMARY Kuparuk Well 1C-10 will be worked over to repair a wellhead leak in the 9-5/8" packoff seals. The well is on...ga.s~ with good tubing integrity. However, there is a small leak from the inner annulus to the outer annulus which has been diagnosed as being located in the 9-5/8" casing head packoffs. The leak is very small and the well will pass a MIT (Mechanical Integrity Test). The workover will eliminate the communication and allow the well to continue gas injection. PROCEDURE 1. . = . . . . . 10. 11. 12. 13. 14. MIRU Nordic #1. Displace tubing and annulus with 12.6 ppg mud. Set BPV, ND tree, NU BOPs. Pull BPV and test BOPs. Pull 3-1/2" tubing above permanent packer. RIH and set RBP at _+7000'. Pressure test casing. ND BOPs. Replace 9-5/8" casing head packoffs. (Wellhead is 9-5/8" X 13-3/8" with crossovers for 7" casing and 10-3/4" casing) NU BOPs. Retrieve RBP. Rerun tubing and locate back into permanent packer. ND BOPs, NU tree. Reverse circulate diesel to displace mud from annulus and tubing. Set BPV. RD, release rig. Pull BPV. 11" 5000 PSI BOP STACK I I 5 ! 1C-10 1. 13-3/8" CASING HEAD 13.625" - 5000 PSI FLANGE 2. TUBING HEAD 13.625" - 5000 PSI X 13.625" - 5000 psi 3. CROSSOVER SPOOL 13.625" - 5000 PSI X 11" - 5000 PSI 4. 11" - 5000 PSI BLIND RAMS 5. 11" - 5000 PSI PIPE RAMS 6. 11" 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 2. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 6. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 7. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 8. OPEN PiPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. 9. CLOSE BLIND RAMS AND TESTTO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 1 0. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 1 1 . TEST STANDPIPE VALVES TO 3000 PSI. 1 2. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 1 4. SIGN AND SEND TO DRILMNG SUPERVISOR. 1 5. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. · NORDIC · SRE 9/89 KUPARUK WELL 1C-10GI APl ~ 50029~ SPUD OATE: ORIGINAL RKB: ADL LEASE: 25650 PERMIT 11115/82 COMPLETION DATE: 11/29/82 WORKOVER SURFACE LOCATION: 1471.FNL,674.FWt.,SEC12,T11N,R1 TOP OF KUPARUK: 926-FN1.,1159-FWL,SEC13,T11N,R1 TO LOCATION: 1254-FN1.,1156-F'WI.,$EC13,T11N,R1 A1 cbp~ am M0-RK8 t= top ol 97 TUBING SPOOL: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH ~ 92~ H-,ID 99 10.7~ 45.5~ K-55 2567 7" 26~ K-5~ 897~ 8.S" g.3~ J-56-OS~ 819~ UNER DETAIL~ SIZE WEIGHT GRADE TOP BTM ,ii TUBING JEWELRY ITEM TYPE IO DEPTH ~SR OTIS 8111 PKA OTIS HOL 81~8 NC)GO ~ O ~T~ 81~ ~ VANN 81M WELLTYPE: L STN DATE: PAD ELEVATION: 61 GAS LIFT and FLOW INFORMATION VALVE DEPTH MANDREL SIZE 807~ CAMCO GL PERFORATION DATA INTERVAl. ZONE FT SPF PHA~E 82'/'8-4304 28 4 90 82-193 COMME POF SIZ H MISC. DATA DESCRIPTION VANN GUN 145.541.ON~ · OEPTH 8744 REVISION DATE: ARCO Alaska. Inc. .- '. '-: 'z ~- ,£.--L:: 9~-f; ':,: -; ".ct,._ ~'-'- 277 5537 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 .. ~ransmitted herewith are the following items. Please acknowledge receipt ~and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco 1C-5 " " 4/13/84 " lC-6 Gas Disp. 5/16/84 Otis 1C-7 PBU 4/20~21 Camco 1C-9C~---~Falloff Test 4/29/84 " 1C-lO~.~-~_" " 5/06/84 " 1D-1 Static BHP 4/19/84 " 1D-5 Falloff Test 4/29/84 Otis 1E-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 '" 2F-i3 " " 5/14/84 Ot%s 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat ~eceipt Acknowledged: B. Adams D & M Camco DISTRIBUTION F.G. Baker P. Baxter BPAE Dr il 1 ing Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union Chevron NS'K Operations R&D Well ~iles STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-193 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50-029-20865 4. Location of Well SURFACE LOCATION' 1471' SEC. 12, T11N, R10E, UH FNL, 674' FWL, BOTTOM HOLE LOCATION' 1826' FNL, 1384' FWL, SEC. 13, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 97 ' (KB) I ADL 25650 12. 9, Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1C-10 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On December 26, 1982, Kuparuk River Unit Well 1C-10 was stimulated with 61 bbls of 12% HCl through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 3000 psig and the maximum tubing pressure was 1300 psig. 240 MCF of nitrogen were injected via the coiled tubing to aid in cleanup. The well would not flow to surface following the treatment. 1C-10 was converted to a gas injection well on January 1, 1983. 14. I hereby certify, that the~foregoing is true and correct to the best of my knowledge. Signed Title OPERAT IONS The space below for Commission use COORDINATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL · . TO: Wi'lliam Van Allen FROM: DATE' ~--//---~- ~ WELL NAME' ', D. W. Bose/Shelby J. Matthews Transmitted herewith are the following' PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE,~ :' ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/3!I · P O. BOX 360 ANCHORAGE, AK. 99510 ~,RCO AlaSka, Inc; Post Office £ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January' 13, 1983 Mr. C. V. Chatterton commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are monthly reports for December on these drill sites: 1-24 13-14 1G-7 2~1'1 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for: 1-22 13-13 1-23 14-6 6-24 lC-1 7-15 1C-IOGI 12-20 1E-25 13-6 The survey for 2-22 'needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and 1C-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28:1 lm Attachments ARCO Alaska, Inc. is a subsidiary of AllanticRichfleldCompany - " ""- STATE OF ALASKA ~.-.~, ALASKA.-.,..L AND GAS CONSERVATION C( ,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE I~ Gas Injection 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-193 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20865 4. Location of well at surface 9. Unit or Lease Name 1471' FNL, 674' FWL, Sec. 12, T11N, R10E, UN ~,'$I Kuparuk River Unit At Top Producing Interval ~V~:,,rf~Dc~' ~ ,~ lO. Well Number 926' FNL, 1159' FWL, Sec. 13, T11N, R10E, UM jSurf ~- 1C-10GI At Total Depth~, 'JB.~.~ '11. Field and Pool 1254' FNL, 1156' FWL, Sec. 13, TllN, RJ(~E-UM~ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.)16.Lease Designation and Serial No. Kuparuk River 0i 1 Pool 97' RKBI ADL 25650, ALK 468 -12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/15/82 11/25/82 11/29/82I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 121. Thickness of Permafrost 9002'MD,7117'TVD 8890'MD,7018'TVD YES [] NO [] 2080 feet MDI 1650' (approx) 22. Type Electric or Other Logs Run D IL/FDC/CNL/SFL/Cal/GR, CBL/VDL/GR/CCL, Gyro/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 65' 30" 246 sx AS II 10-3/4" 45.5# K-55 Surf 2568' 13-1/2" 990 sx Fondu & 250 sx Permafrost C 7" 26.0# K-55 Surf 8977' 8-1/2" 878 sx Class G & 250 sx ~ermafrost C 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) 8278' - 8304 ' ,j ,n ~' '/ 3-1/2" 8199' 8135 ' 8308' - 8344' w/4 spf \~ 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED ,., N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) / Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD II~ I Flow Tubing Casing:Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska Oil & Gas Cons Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC4 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS TRUE VERT. DEPTH Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 8278' 8408' 8542' 8651' 6472' 6588' 6708' 6805 ' 30. FORMATION TESTS Include interval tested, pressure da~a, all fluids recovered and g,avi~y, GOR,and time of each phase. N/A 31. LIST OF ATTACHMENTS Drilling History., Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed J Title Sr. Drilling EngineerDate INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Fnrm I N_SIN? 1C-IOGI DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1330 hrs, 11/15/82. Drld 13-1/2" hole to 2585'. Ran 62 jts 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe @ 2568'. Cmtd 10-3/4" csg w/990 sx Fondu & 250 sx Permafrost C. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld cmt. Tstd csg to 1500 psi - ok. Drld 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-1/2" hole to 8787'. Ran DIL/FDC/CNL/SFL/SP/Cal/GR f/8787'-2567'. Cont. drlg 8-1/2" hole to 9002' TD (11/25/82). Ran 213 jts 7", 26#/ft, K-55, BTC, csg w/shoe @ 8977'. Cmtd 7" csg w/878 sx Class G. Disp well to NaC1. Ran Gyro/CCL f/8890'-surf. PBTD = 8890'. .Tstd csg_to 1500 psi - ok. Ran CBL/VDL/GR/CCL f/8890'-8000'. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx Permafrost C, & 106 bbls Arctic Pack. Ran 3-1/2" completion assy w/tail @ 8199', SSSV @ 2080', & pkr @ 8135'. Ran CCL/GR. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp tbg w/diesel. Tstd 7" x 10-3/4" ann to 1000 psi - ok. Perf'd 8278'-8304' & 8308'-8344' w/4 spf. Flowed well. SI well. Dropped ball and released Vann guns. Closed SSSV. Set BPV. Secured well & r. eleased rig @ 1330 hrs, 11/29/82. JG-11m 12/10/82 GRU1/DH9 JAN Alaska Oit & Gas Cons. Commission Ancho[ag~ ~ 1 C- 10GI (SEC 12 T11N R~E) COMPUTATION DATE BOSS GYROSCOPIC SURVEY KUPARUK ~. NOVEMBER 2~, 1~82 dOB NUMBER BOSS-1~134 TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ME(' JRED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL 200 1.99.98 102..98 , 0 56 S 16. 0 W 0.27 2.13 S 1.08 W 2.01 300 299..97 202.97 0 48 S .9.8.9 W 0.16 3.61 S 1.43 W . 3.46 700 6.9.9.01 602.01 8 45 $ 0,89 W 4.32 25.21 S 1.64 W 24. !74 750 748 28 651 28 10 41 ~ I 6~ W 3 8~ ~' .... ~.66 S 1 84 W 33.33 ~~~: .~ : .,;,~h.:h~ ~~,~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i '~ 0 t ~ , t "~ ~ ................................................................. :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::~i!]~i~hH~H~h':~ ..... :~/!~H~i/~hH~Hh[~':5'::"':'"~:~~~}: '""'~::'"'?"::~ ::~::~: ~ ~::' ~ .... ~ ................. ~ ~'::~ .... [:~::: ~ ~ ~:::~: ~ ............... ~:: 1000 989.78 8~2.78 18 35 S 9,69 E 3.21 97.25 S 2.66 E ~7.07 1100 1083 56 98~. 56 '~'~ -' · ~z 3 ~; 15.6~ E 4.03 131.05 S 10.43 E 131.45 1~ 11~ ~ 1~~ '3~ I ~. ~ t ~ ~ ' ~ ~,': ~ zo ~ ~ c. ~,~ .-,,~, ~ ~ ~?~'% T;i~~;~;:: ::~;~:;;:;::~:":~E '~:~ ~:: ~:~:~::~:~:::~:~;~;~::~:::::~:~:::;~:~ ........... ============================ ........ ~ ............. ~:~:.:::~ ............................. ~:~ ........... ~::~:::::~ .................................. ~.~..~..~. ~..:...~ ............................. ~.~. ........ . .... . p .... ~ .......................... ~, ~ .~ ................................ ...... .~: : : ::::::::: ::::::, : . .. :: ::::;,::::::::::: .:: :, :. ;::::: , :: :::::::::: : :::, ::. :::::~:: :::::::::::::::::::::::::: ,:::::::,:.:~ : :::::::::::::::::::: ::::: :: ,::::::~ ::::: ::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::: ,::,,,::.,~,,::: ~ ~ :.:.~::~:: :'~::~::~ ':~"~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: '.'::. :: ': :. :':~ ~Z:~:'~:: :::::::::::::::::::::::::::::::::::::::::::::::: :':~:"~ ~:::::.::"~::::':~:~:~:' ~ ~ ~ :. ~ ::::::::::::::::::::::::::::::::::::::::::::::::: ~ ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~::~:'..:~'::: :.¥. ~:: ~::~::~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::?::.::?:?:L.~ :::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: ::~':~:::: ~::~ ~ ~ :: :: ~ :: ~ :: :: ~ ~ :: ~ ::~ :: ::~?:~?. ~ ::?: ~ ::~::?:::~::?~ ~::::~ ::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::: ,:~::t?¥ ?,?:?.:.~: ?: :~ ~ ~ ~'~':'_~'.:,:.~:.~:.::t~t~:,~':~:.~[:::~::'.~:. ~: ~~:~ ::::::::::::::::::::: ::~ ',:: :::~ :.?: :/. :.:: tt~: ~'~::: ~?,?:'::. ~ ~?:::~?:': ~:::.~:: ?::::: ~:::,~ ?:::::~t::::~ :::::::,::~: :::::::::::::::::::::::: ~::~?::,~ :::: ~ ~:.:, ?::, :::::::::::::::::::::::: :,:::: ::::::::::::::::::::::::::::::::::::::::::::: ~'::,::~::.~ ?,:::: ~:::,::',~:, ~::::~:: ::~ ::~?::~?: ::?: ~?: ::?: ::~::::::~?:~ ~ ::~::~?:?:~i::~:: ::~ ~::~ ::?:~::?::: :: ~ ::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::: ~:,~ ~ ~ ::::::~ ========================================================= ~:.:: ?:~:,?:~ ~ ~?:?~::~ ~ ~ ::~?:?:?,?:?.~ ::?:~ :.?: ?,?:~?:??:~ ?.:: ~:,:,::~:: ~t~? :': %: ~:.::~::'f ::~::~:, ::~ ::?~ ~?: :,~::~ ::~::~::~ ::~?:~ :: :: 1550 1485.71 1388.71 30 38 S O. 30 W 3.40 329.14 S 40.43 E 331.49 1600 1528 54 1431 54 31 '"~ .... . . ~o. S 0.10 E 1.71 354.94 ~ 40.3~ E 357.17 ::~,: '~ ':: ,' :~:~:~: :: :::~'?::~.:L ,:: x :~:~::,:: ~:.: ,~: .:::: m ~:: x ::~: x ~:~:..:~.,~: :.:.:~km :~::::::h<...~:~ m:: m ::~, ~::: m m~:::,, x~::::: ::~:: ::~fi:: :~::::: ::::., :~:. ,:::::::::: :::::::~:~:::. ~:::::::::::,.: ::: 4: ,..::. ,~ ::::: x..:::::::::~ ::::::::::::::: ::: ~:~::,, 4:.:.:: :: :::::::::::::::::::::: :~ ~::: .............. ~:: ~. ~ ~' ....... : ............ ~ ...... ~, ..... .:~:~,::::,~::,::: .......... ,::~.:,. ~,:~,:::~,: .......... :::: ....... :::~ ........ :::,:::~, ,:,, ..,::::::::::::;:::~:,~::::::~:::~,,-,:::::~p ,,:::::, ::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: 1900 1774.92 1677.92 37 55 S 9.69 E ~.66 ~25.2~. ~ ~1.~°° E 527.7~". 2000 1853.11 1756.11 39 11 $ 9.69 E 1.25 586.69 S 61.72 E 58~Z~,..?~:::~ 'T~ ' ~ - ,D "~ .... ~ ~ ~ · ,- - , ,-. ~ ~ ~ ~'7~;~:.::':::%~?:::'~ ........ ~' ...................... o~0 ................. 1.8~1..-~7 ............. 1.7.~4...~7 ........... ~....~~. . ~. ~ ~,, ..37: ... & .~. - - ............. .... ........ .,.. ......... ~........~ ........... ,, . ~ .................... ~ ..................................................... , ............................................ t~ ~.:...~ ........................... ~~....~ ................................... . ................... ~.~'~. . . , ~:: , .:: ,~::,:: .~ ~ .:: :.~,~...,: ~:x ,::~ :,,.,,::..~.. :,..: ......... :,,,.,::,,:.,;.,..,.,,:,,:,.,:,,,,.,,,. ........ :,,,,,,: ........ :,,:::,,:,,,::m,.,,.,,::::,~::~:.,,.::,.,,,:::::,,,,,,::,::,,,:::,::,:::,::::, ,,,,~::::::::,.::,:,,,,:: ,,,::.:,,,. :, ,: ............ ,,,,,,,,,,: ....... :~&~:,,:: :, ,,, ............... ,,, , ..~ .. ,~ ~ .,,,.. ~ ~. ~.,.. .,,.,.., ..... ,, ..... ,,.,.,.,~ ,,,,,.,,,.,,,.,.,, ..... ~,.,,,..,,,,,,~.,,.,,.~. ,,,,,.,. ........ ,.,,.,,,,,.,,., ........ ,,.,,,,,.,, .... ,,. ,,,,. ,,,,,,,,.,,,,,,,, ................ ...,....,. .... .. ....... . ......................................................... . ........ ,,,,. ...... ...,..,..,..,.,,,,,.....,,,,,.,,,,,,.,,,,.,,, ........ · ' I ] ~ - ~ ~ ............ ~ .......... ' ............................. ~ ...... I 0 0 0 , :l:lC-lOOI (SEC 12 TIXN RiOE) COMPUTATION DATE BOSS GYROSCOPIC SURVEY <UPARUK NOVEMBER 29'., 19'82 dOB NUMBER BOSS-1,6134 ALASk..;:A ............. ~E~ ._v. l:ll 1'~I.4TK!I% £LEU = ~7 O0 ~'r ~E{ .IRED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY ~ECTANUULA~ COORDINATES VERTICAL DEP.~H .................. DE~H .............OEP.TH ........ DEG M~N .... F!~R~ n~/:~nr~ Nn~Th/~nilTN Cn~T/uF;.ST ................ SEC~I 2400 2159'.40 2062.40 40 54 S 7.30 E 3.40 841.13 S ~7.77 E 846. 2500 2234.17 2137.17 42 18 S 7.6~ E 1,42 ~06.~6 S 106.44 E ~12.~7 ............... 2600 ............ 23.OZ.,.Z8 ........ 2210...28 .............. _4~.5~ ~; I 1. lA ~ ~3.R7 97:~.7A R 1 l~_~n F 7oP .:; ,.: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :'.~:.~:~::::~ ~,:: ~:::: ~:~. ~ ~:[:.:: ::: :" ?~ ::~.:~ ~:~: ~: ~:.: ~ nv~ :~: ?.~ ::: ::~: ::: ~.: '::: ~:: :~ ~:: R :7:: ~; ~: :~ ~:~ '.::::::~':~ :~ :.::::::~:.: ::'::.::~'::~ ::':~ ::::~ :~ ~ ~':'.::::: :.~ ~::~::: ::::~ .::: :::::: :~: :~: ::~:~ :::::: ~::~ ~: ~:.::~ ::::::::::::::::::::: ~::~::~:::::: ::::::~::: ~ :~ ::::~:.~::~: ~:::::~ :::::::::::::::::::::::: ~::~::::~::~[: ~?:~::::~ ::~:: ~ .:~::~:~:: ~ ~ ~ ~ ~:: ~::~ ~ ::~ :::::~ ~:::~: ::~::~ ::::::~ ::~: ~:.:: ~ ~ ~:: ::~ ~::~:::: ::~:::~::~:: ~ ::~ ::~ ::~::::::~ ::~ ::~:~::?:::: ::::~:: ~::~ ~::: ~ ~:::~:::~:::: ~.:~::~ ':~ :~ :::: [.:::::::i::~ ::'::~.:: :.::: :~ :~:::~:~: ~ :::: :::~'] :]. ~.: ::5: :~ ::'::; ?' :?~?::::'~:,~': ':::~:: ~ :':: :::~ :" ~?L?. ?:~'~'?~ :'~':::: :'::'. ::~'?i::'~i'F'.??:'~.'?::?~'::'[??:'?~?:'~ ~'?T???~'[?~':.~'',~::~?[~?~:::2~:~:, ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ...:.. ..... : ~ ~ ~ O, 05 ....· ....... 71:~',.:0~ ..... ' ...................... ~.~ ................ 8 .................... ~ .......... 8:~ ...... ~ .................................... [:::::::~D ..................... ' ..... ':m,:::::~.:., ..... ' ........................ ~:.. ~ ...... ' ...... ::::' ..... ': ,* ~ ] .......... '~ ., ....... :,', ', ~ ::' o':' ............. : ...... :' : .............. .::::~ ......... ~'::::' .......... ::"':'::::::'"": ......................................... ' ..................... : .......................... ' .....................................................................................................................................: ........................................ 3600 3011,16 2914.16 49 21 S 8.10 E 1,60 1674.31 S: 231.26 E 1688. 3700 3075.02 29'78.02 51 15 S 7.6~ E 1,91 1750.51 S 241,83 E 176~.5~ : ':: : ' :::: · ' ':: : ".' , . ':': :::":: .:'~:' "'.'. :~: ':,': :' , :::::::::::::::::::::::::::::::::::::::::: ::::::..::::~::::..::::::::::~:::~~:.......~~>:~::~..~:~:::~::..:~..::....:..~::: ,:,'.:'.:.'.,'.,'.,, :,'.,.:::,:::~:'~:~:.,~,,:~, ,::::,~:~K::::::::h:,,:;.~.~,S~~ ::::::::::::::::::::::::::::: ' : :: ::':":: ~:::~,:' ::::: ~' ":: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::,]b::H~H~H~]::: ~ ]] ::: : :::::,.:::: :::::::::::::::::::::: ~::::::??~:::::::::::::::::::::::::~'~:::~`~::~:::~::~::::~::~H~::h~ ':'": ::': : ~ ~1 : ': ::::: "~ *~ :: ~ .:: :::::: ",':.: i ~. :: :l~i~: :::.:::::,,::::::: ~::::::::':. ::::::::::::::::::::: :::::::::: ..::::::::: '::::: ::::::::::::::::::::::::::::::::::::: ==================================== :::: .,, .,....,::,.~ ...,,.j~f .............. :::.,,:.:, ,,,,:::: '::..:' ,:":::::' ============================================================================================ ::::: ::,::,::,: .: :::::::: .. ::: :,.;,:: ..:.: ::.: ::. :::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::: ::'::~:~f::::::: ::~ :::: :;:::: : :: : ::: :::~:~: .:.: ~:~:~:~:::: :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: : ::::::::::::::: ~ :::::::::::::::::::::::::::::::::::::::::::::::: ::':"::::::::::::: ~ ~ ' :":: ' :" "'~"~l~f~': '::':: ' :::::: ~i" ' :: ~ ::::::::::::::::::::::: ~:" :: ::':::: 4050 3279.57 3182.57 57 36 S 3.50 E 2.14 2032.67 S 271.12 E 2049.21 41 O0 3306.28 3209'. 28 57 49' S 3.10 E O. 80 2074.87 S 273.55 E 20'~ 1. ~.:::.' :: ': :::: :' ~' ' :: .: ]~:: :: . ~::'~ ] '.::~::' ~ ::.:~ :::':::::',:-.:::: ::::~:.::::~::::::.::~?::]:~:::~:~:::~i~j:~::~:~:~::::::::::..h..::::~]~.~:~:~h:~:~:::H:~:~:~..~:~:~:~:H~i~:~:~:~:~::~:~:~:~:~..::::~:~::..:::::~:::..v.::::::::~.~~:~ ,~:~,:~:~:::~:~:~:~:: 4..,00 ~ :~' ,J416.50 ~ ~ :,~:. GO ~:~.::~:::~,~:~::~:~:~5~:~::::~.~ !~?.~:::~:~:',,~?.~::~:~:~:~:~:L~,O,,~,,~'~:~?,~:~ ........... ~:~,~: .................. ~::,,,.I~,.~ ......................... ~:~,~,',,,,~,,~ ........... ~:~,,~:~:~',~:::~:~ .................. ~ ............................. ::.:. :: : : ~ ~ :' ~. -~ ~:::::. : ~ ~. : ~::::: :::: :::::~ . '::: : :::::::: ~ .... ~ ............. ... ..... . .. ....... .,: ....... .. ~ ~ ~ ::,:::~, ::::: ....... ~ .: : .-. ~,:., : ~ ~ ~ ~ : : :,: ................. .: ~:::,.:,:: :,:: :~ ...... :.,,,: ............................. ::: ,~ : ".,-':'~::~!-'~ ~i~.~......~:....-.~::~...~.~-.-~i~i~..~i~....--~....~-~.-~..:~-...--~..~-.-..~--.~.~.~i~i~ 4600 357~6.62 34'P9.62 49 40 S 2.10 W 2.70 2481.28 S 277.56 E 24~6.41 4700 3663.31 3566.31 46 3? S 2.80 W 3.05 2555.71 S 274.3~ E 2570.21 475Q ::: /-, 9' F: _ 'P 4 :q/-,A1_ 5'4 ~4 49 ,:: 9 '~A IJ '~ ,~7 ':'~t ~ ~' .)7-~ 7c~ ~ oz.r,~ z~, ~,..,-... ~ ....... :..~: ,., ,....:.: ........ : ....... ~ ~,.~ ~, .:.,: .............. ~.:.~.~, .~.I.:, ~.:.......,.:.~--~:..?. , ~ .~ ........... ~..-~.:..~, ~-.~.~~.~ . ~ ~ : ., ; - ~ ..~ ~ ~ ~ - ~ Al~l~:O ':'ALASKA,--~NC ~ ' '" ':' ' #1C-lOGI (SEC 12 Tl lN RiOE) COMPUTATION DATE BOSS GYROSCOPIC SURVEY KUPARUK NOVEMBER 29, 1982 JOB NUMBER BOSS-16134 TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL M~ JRED VERT I CAL VERT I CAL INCL I NAT I ON DIRECT I ON SEVERITY RECTANGULAR COORD I NATES VERTICAL ~E~H ....................... DEP_Y~ ............... DERYH ................. DEG ....~I.N.-~~EE~S ........... [~G/!.CU) .............. ~Q. RTH,f.~OU.YH .................. E~Y..~..~E~.~ .......................................... ~SE~]T!.E~ I 4~50 3849.98 3752.98 40 6 S 12.80 E 2.86 2720.42 S 285. ~4 E 2735.28 5000 3887.58 37~0.58 42 19 S 13.50 E 4.53 2752.50 S 2~3.44 E 27~7. ~2 ::::::::::::: :::::~ '::.:..::.: ,~ ~ : :~. i.":~+~ :: ~:~:[::::~::~:~ .::' ~:~::::~:.: :,:::::~:~:~.~, ::.. ...:. :'~. :..::: :::'..'.::.:: ::::::::::::::::::::::::::::::::::::::::: :: :::::::::::::::::::::: ...... ~:: ::: :.~':::': :~: '.~; [~:::: :: [[~?'".: '.::~': .... [;:: .... ~ ~'~"~V'""::.".:: "'~ ~: : ::::::::::::::::::::::::::::::::: ~: :.??~.: 1~0:: ~c,:::: ~.~:~:: ::..[~ ~.6:~:~ ::~.0:: ~?~ ~i:~ ~ ~: ~: ~:~::.~ ~ ~ :~::: :'~::: ,:5...~::~:?: ,~ ::~ :~:~ ::i :~: :? ~ ::~.~:~,'.~::~:: :, :.~:~ 4 ~.: :: :. ~ :,~: ~?.~:: :.::$~:~:~:~:~;:~.:~ ~:~?!~0:~:.~: ~:?::?::.,?:::~??~?:~:~??:?: 5300 4103.34 4006. :34 44 19 S 5.19 E 0.40 2959.20 S 318.24 E 297~. 04 5400 4175.06 4078.06 44 2 S 5.37, E 0.31 3028.59 S 324. ~8 E 3045.73 ............ ~.;7'~ :=:A~7. A7 ~ :~:~_gq~q ~ :-q~_ ~q :::::::::::::::::::::::::::::::::::::::::::::/:[lTw"...~%~:5~,~i~ll~lh~:~.:~s¢~.?"::::~:'.:?';'.:::.".:l~i:.~::~ ii ~ :::::::::::::::::::::::::: :::::::' ::' ":::::" ::::::::::::::::::::::::::::'" .~x:::....¥."..:: :h:::::::: 5900 4538.52 4441 · 52 42 27 S 5.80 E O. 35 3370.28 S 358.17 E 338~. 06 6000 4612.84 4515.84 41 32 S 5.67 E 0.72 3436.85 S 364.88 E 3455.77 ~,Y& - ~-~ ,. ~. ~ ,~, - ~ - .-~.~ .- ~ .~, ~ ~' ~ .~.~.- .-, : ..... ;: :2~ ~:[~:~:: .: : :a ~: :~ .... ~ : , .... ;..~ ..... :.,;,;,:,:,,:,:,,:,:,:....:,:.:.:..:,,:,,:,.,,,:,:,.~:,,,..:,~ ........ ,::: ?. i :: '.., -. ~=:.'...:: =- ~:==:._::;;~====~=::::.': .:, .~ ::..~ =:~ :.: ::: :.::: :.:.: ~::~:..:..::.::: 0:= :.:~,.~ ................................ ~ ~ ~: :~"~:'~2 ~:':'~::~::~:.~:.~:~ ~ ~:'ti~~ ~::~ ~ ?:~ ~J~2 ~ ? 6500 4'~93.45 4E:S~6.45 39 20 S 5.89 E O. 31 3759.41 S 3'B7.2'~ E '3780.14 6600 5071.04 4'~74.04 38 53 S 5.60 E O. 49 3822.18 S 403.61 E 3843.22 ~55~..'?' ?: ~F:~¢.~?.~¢'~:~?'.)..... ............ :..x.:.x.:.:.:.~ ...:.:...:..:.:~ ..... :::::: ,....::'.:..~¥:::.:::::::.:¥::::::;x:::. ~..::. ;:'.'.: ~::..:::::::::::x::'.:.:: 71 O0 5464.56 5:367.56 36 1 '~ S 6.50 E 1.32 4128.7:3 S 437.07 E 4151.57 7200 5545.61 5448.61 35 23 S 6.1~ E 0.~6' 4186.~5 S 443.55 E 4210.14 ~..::' ::: ~ ;.. ,~ ' :::..: : :~:::.: .(:- - :,:~ ~::~: :~,~ ..: ::::' :~ ~,~'..::,:: :~:~:::~ ~?~u ~ ~;[?~? ~::~?: :~:~?:.:?:~?:?:::~?f.~ ?::'.~:'-:~'~ ~'?:?::::'?,~': :::::::::::::::::::::::::::::::::::::::::::::::::::::::: '::-'?' :::?::.~'~ " :Y :: :: ~ :: :: ': : " :::::::::::::::::::::::::::::::::::::::::::::: ] :: : · . . . =';'" ¥= zs~;==~:?:?=: ?::?s=.?~=;ss :.z,~ :: =?s~?~57 [ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: . / ........................ .......:..:.... 0 0 0 #IC-IOGI (SEC 12 TllN RIOE) COMPUTATION DATE BOSS GYROSCOPIC SURVEY KUPARUK NOVEMBER 29, 1982 dOB NUMBER BOSS-16134 TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ME URED VERT I CAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL -~Er2 z T n~ 7700 5964.50 5867.50 30 58 S 4.80 E 1.16 4458·56 S 469.00 E 4482·.94 7800 6050 · 57 55)53.57 30 13 S 4,30 E O. 79 4509· 2'.~ S 473.04 E 4533.83 "" '-.' 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Ac? xI.R.~g_ (')~ ~ ,8.7/-,_ .~/-. ~ .8,~:"4 ~ 8250 6446.78 6349.78 26 28 S 1 . 0 E 1 . 15 4722.05 S 485.19 E 4746.78 8300 6491.50 6394.50 26 41 S 1.10 E 0,43 4744.43 S 485.60 E 4769.09 ~.~00 ~.SSP..,.81 ................ ~88.~ ....................... ~.& ....... ~ .................. .S.:...:, ................. ~..~,,~E ............... ,:.. ............ ¢..~.9:Z .................... ,:~..~..,::~:~?.::..:~ ~n* ~/' ; a~~ ~' :,i~ :ii ',,,::.:',:'":'~':i::::::::::::,:i:i~,,ii':?:" ?~ <":,: ':": '"'::;~ ,:' ~,, :'::':::::=:::i?:~i:::i::i:~??:~: :?:::::::::~: :': ,::.,,,,:,:,:: ::?.,::,,,?:~:::,, iii:::::: :::::::::~=:::~:i::i:::i:i?=,i~,,~?;:,i?::.?,,,:?:i:?:::i¢:::: ~ :: ::::~=,,,,,,::~?,:~:,.?::::?:~,?,,,,,,,:,:::~: ! :~: ~::~ ~ ~ ~ ~ ~ ~:~ ::~ ::~:~:~ ~ ~0o,:.:?:?::??;::?~:~:~:~::.:~.... ................ ..:..::::: .~.~.~...::~ :.~ ........................................ :.~_. ............. = _ :. ........................ := ............... : ~.._..., ..... , ................................................... _.,=..~._ ........................ , .......... ... ~ ..:..~ =...., ~:~:~:~:~:~::~?~:~:::~?:~:.~:?:~?:~::~(~:¢~::~ 8800 6937.87 6840.87 27 16 S 2.89 W 1 . 18 4969.62 S 487.23 E 4993.43 8850 6982.25 6885.25 27 35 S 3.30 W 0.74 4992.62 S 485.98 E 5016.20 ¢~0~1 7A'-/A ~. ~.0'-~0 ~. 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"..,',' .... :, ,: :'~:,:,:.::: :,:,:,:'::: :: ::: ::::: :: :"':::' ' ~', ;>'~': '", ' :,:,, ' ....... -~,w:'., ~, :'"": ::::: :'": :'"::: ::::::::::::::::::::::::::::::::::::: ,:,:,:,:,:,, '' ....... ,..,, ,,, ,. , :,,,,. :., ,:: :,,,,,,,:, v ,., ::::: :.,,,,,.::: :::::::::::::::::::::::::::::::::::::: ,:, .. ,,... ,.,.,...,, ,, ,,,, ,, .... : : :.., .:,,-,:..,..,: :., .,: :::: :,... :, . ,:::::::::: ......... :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ............ ::::::::::::::::::::::::::::::::::::::::::::::::::: ......... : ...... :. ,:.:,:,:,:,~,,: ::::::::::::::.,,+:.::,:::::::::::::,.,:: .::~:::::::::::::;~:: ......... : ....... :,:, .:,::,:.:,:::..,,::::::::::::,,~::,,::::;:::::::::::::::::,.::,,:::~:::,,:,:: ................ :~~::::::::::::::::::.'::;'.::::.':::::::::::''::::::::::::::::::::':~.':~:::':4~:::::':~:':'::~: .................... :.,:,:.:.:+.,:.:.:.::,:,:.:,,,::.:::.~:~:::: ::::::::~:;.::::,::::::, >:,..,.,.:, ::" :::::::::::::::::::::::::::: ¥::+'.",? :::~:::::::::::,,:::::::::,. ,,:.., ::::,,::::~.: ' ':'4:: : :: :::,. ,,:::::::::,,.,,.::;::~.,. ,.:::::, :, : ,. ,, : ...?-,:,,:::::::::::::::::::, :,, ,.:. ::~,,::,,:., :,. v, ~ ::, :, , : ,, ,,,.:: ,:: ::::::::::::::::::::::: ~.:,, ,:~ · , J:~: :,::: : :: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::.::: ::: :~::::::::: ::::::::::::::::::::::::::::::::::::::::: ::~: ::: ::::::?:::::::::::::::::::::::::::::::::::::::::::::::::::::: : :.:: ~: ::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: : ~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :~:~:~: ::: :: ::::::~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: HORIZONTAL DISPLACEMENT = 5085.7:/ FEET AT SOUTH 5 DEG. 26 MIN. EAST AT HD = 9002 ~~e~-~~..-' -" ':: ~ : .... ': '~'' :' ::::::::::::::::::::::::::::: "~: ':; :::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~ . ._. .__.___.__..__..__~ __._ _~.n, ~ ..... ~,~v~ ~ ~IC-IOGI (SEC 12 TllN RIOE) COHPUT~TION DATE <UPARUK NOVEMBER 2~, 1982 dOB NUMBER BOSS- 1 ~.1,.'~ k."~/I U ~1 I~U T kl~: ~l ' "' '" .... "'" ''"' "'"'~11'. k111 V~I . · ~k'"'"f I .~'~ W Vlt k~kgl 6YVV g kk g ~'l IEk~VVlTk~ &'kl g I I (' TRUE SUB-SEA TOTAL ^,:.m iBc'r, t JC"DT T PA1 UI:'C, TT PAl PI='I"TA~F~I II AD Pni"'i~rl :' ::':':' ' ' :"" :::'::" :::::':::::::: :' ::;':: """:"":" ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::" '"'~: '"'::" :::::: ' ::::::::::::::":'""':'"'"' ":'-" "::':::"'::'H "':"'""': ....... ::.::::::..:::::::: 1000 989 · 78 892 · 78 97.25 S 2 · 66 E 2000 1853.11 1756 · 11 586.6'2 S 61.72 E il!ili!iii:'.i!iiiiiii":"::'::i;'~":!':":::.ii!ihh iii::ilF~: ........... ~:'iiii:'' !'""'iiii!!iii!:iilE!!!~: :'" '"'.:'""i:i i:" '?'"'ii!iEiiEE!ii! ':'" ':'":::'"'":::'"":: ..... :""q E !ii .... i:'i:i"i ...... ~'::' :::::::::::::::::: .: : ' :::::::: :::;:'.:::. ;;' .u::::~ :::::::::::::::::.. ::.': . :. ::::::q:. "::::::::::::::::::::::::::::::: ;:.' ... '. ::.:.:: .~::::: :::::::::::::::::::::::::::: :.. ::';::" '" ":::: ::::::::::::::::::::::::::: ........ ..... ,~l~~~ ~ ~ ~ w~, ~' · ~ g~'~ ~ ~ ~ ~ ~ ~ 7000 5384.6'.~ 8000 6224.73 5287.69 4068...o5 S 430.37 E 6127· 73 4607.37 S 479.69 E :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 10.22 10.22 146 · 89 136 · 67 ii ilii i i iili iiii : iiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiii iii iil!iiiii 1615.31 228. 1775.27 159. ~6 100~ ~1 1Et~ ....... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ,0 0 0 ~lC-IOGI (SEC 12 Tl lNRIOE) COMPUTATION DATE ~UPARUK NOVEMBER 29, 1982 dOB NUMBER BOSS- ~i^~,'~ i ....................................................................... · ..................................................................................................................... .,. ............................. ~LLY~::,.~.~U~H.I.~::::.:~.~.[ :'/7 .97. O0 0. O0 197 197. O0 100. O0 ~x..~?.7 2'.97. O0 200 ~ O0 ~97 697, O0 600. O0 ( TRUE SUB-SEA TOTAL MEA~U...REI) _VER.T!CAL VERTICAL RECTANGULAR COORn INATEa MI~-TVII V~'RT I ~':al 0,63 S 0.40 W 0.01 0.01 2.08 S 1.07 W 0.02 0.01 3.57 S 1.~2 W 0.(3~ O_Ol 24.~0 S I.~3 W 0.~7 0.70 799 797. O0 700. O0 43.76 S 1.95 N 2.7& 1.79 ~' ....... :X~~~.~}~:~a~:~:~i~.~?~i~ii~?.i~i?:~i~ii~i~:i~f:i?.~:.a:~:~i}~a~.~i:~?~i~i~?~i~i~i~i~ii~i~i~ii~::~i~:~i~i~i~ii~i?~i~ii~ii~i~i~ii~i~i~i~i~i~:~i~i{~ii~?~ii~iii~i~i~iii~i~i~i~ii~iii~i~i~i~i~:~i~?.~i~ii~i~iii~iii~i~iii~ii~i~i~i~i~iii~ii~iiii~i~i~i~i~i~i~ 1334 12~7.00 1200.00 225.17 S 2~.ee E 37.16 10.71 1447 1397.00 1300.00 278.13 S 37,88 E 50.~2 13.4~ ,© 0 0 ¢., ~lC-lOGI (SEC 12 TllN RIOE) COMPUTATION BATE KUPARUK NOVEMBER 2~. 1~82 dOB NUMBER B055-1~134 ~/~A~'~ ~'~1 i~ ~U~l~ ~, ~tJ -- o~ ~ ~ ( TRUE SUB-SEA TOTAL I~EASURED VERT I C'AL UI::'RT I CAL R~P~TANAI. AR nnnRn T N~,T[R Mn-Tun ' u~R'r T ~-~ 2 ! 137 ! 997. O0 ! 900. O0 706. ! 0 S 74.20 E ! 90.45 30. 2317 2097. O0 2000. O0 788.42 S 89.05 E 220.84 30. · 2z~49 :21 ~7. oo ? ~ ?~? O('} t'}O i:17~_ AA .q 1 n..l,..,, o.=i P' ?.~?_ A.~ , .,.. _ ~T '~' .'., · '. ,.' ......... ' ". ........... '::'"' :::::::::::::::::::::::::: ::S:::;: .:,:i: :::::::::::::::::::::::: :::::::::::::::::::::::::::::: ?::~: :~::.,~...':: ~::::: ::::::::::::::::::::::::: :::: :::::: ~::::?.,:::. ,;:, , ::~::::~: ::: ;:~:::: :: ::::::::: :::::::::::::~ ~:~::::~:'::':~"~":i~'~<'2' :"~':':~'~~:,~+~?,~v~:~,' ~2~Z~~.~:::::::::::::::::::::::::::::::::::::::::::::::::::: ~::'':'~ ........................ ' ............. : .................. ~'"'"::~ ~:~::~:::::"::,:,':~:'"' = .......... : ..... : .......... ~i .......................... ~ ~ ~::' ......... ::::::"'::'"': :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:~::~::i~::~:::::::::::::::::::::::::::~i::?:~?:i::i~i:~ !ii!L! ~ ::~2!!::~:?:"'!::'::,:::':':'::/~i!!~!!~ii~ih!F"::'.i::::'?i::':':::]! ?ii:!:::i:~ii!~::::?:iiiii!::!::::!::i!::!i?:~ii~ ?' :::,'"!::: ~::"F':::'~'::~i!iii~i!!!ii]i!i!:i::~i:ii::" :!" !~": ':::::" ~::~::::::.~::::::::::::::::::::::::~.~:!.~i~.~:~ii~!~.~?.i:iiiii~.~ ii]!i!:iiilh:ii:::i::::::::' ':"::: ::::::::"'::" :::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:~:~:::':~'~85~:~:~?~:~: ~,9~:~:~ :~:: ~ :~1~:~.~::~i~:.~ .................................... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .................. ~::::~:::::::~:I~:~D?,~:::t.?.~ 2997 2597. O0 2500. O0 1241,43 S 166.95 E 400.22 38. 3137 2697. O0 2600. O0 1338.27 S 182.78 E 440.33 40. ~i~::~::?~ ~:~,~:~?:~, ~ :,::~ :. ::~:i?.~:~::~','~:~:.":~', ::~ ::?:?~::~:..?~:~.:..::~:;i~::.i.::i.i.?:::~i~:~:i.::~:~::~:~¥~:~.?~ ::' ?,:~:.~','.:~::' i ~ i i~ i i~::~i?:ii::~i::?.::::,~*::*: ?;'F:,*':;?:,?~*'~'~'i';?~?;P?;';F~'P;P;P; ~ : ,.,,:~ :, ~::,, :,,,.,...,.~::,~:.,,,.:~ ~ ~ ~:,~ .............. ;.. ::,,..,::,~ ~ ~ ~??~::..::,,,, .,,:::::. ...... ::::.:,,,,.: ............ .,.,..~ 3901 3197. O0 31 O0. O0 1909.80 S 261.06 E 704.59 66. 4082 3297. O0 3200. O0 2060, 14 S 272.75 E 785.58 80. 47A~ ~q:~7_ AA '~fR'~D . 971 ~ A~ ~ ............ :::: ::: ::::::: :::: :. :::: ,, ::, .:- ,:L:::::: ::~: ;: :~: ::: :: :~,:,:.:~::~:). :~, :,. :::::: ::~:,;:?,,,:: :::::::::::::: ;::; ::,,, .:: :, ,: ,:,x: :7',::: ;::: ::':':;~::'"':: ~t:;:::::: ::: :::~:::::~:::~: :::::::::::::: ::.v,,.::~, ,.,,,, ,,.,,,,, ::: ::: ,,.: :,,,,,.,,:::: ::...,,. :::::::;: ::: :: :::::::::: ::..,.,,,:.:,,,,,:: ,.,,,::: ::: ::.,. ,,.,::..,. ::::: :: :,,., ..::: ::::: :::::::::::::::::::::::::: :::: :::::: ::,, ,, ::.,., :~, ,,:::::: ::,,:: .:. #1C-IOGI (SEC 12 TllN RIOE) COMPUTATION DATE KUPARUK NOVEMBER 29, 1982 dOB NUMBER BOSS-16134 TRUE SUB-SEA TOTAL. 5012 38~7. O0 3800. O0 2760.84 S 295.44 E 1115.74 31 . 37 5150 39~7. O0 3900. O0 2854.85 S 308.59 E 1153.70 37. 5291 ~097. O0 4000. O0 2953.03 g ~ 17. A~ ~ 1 ::~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: "~? }~ ~ ::~ ~::~::::~::::::::::::~F':.F"/"~::~?:~::'"'"~F '~:~::::~::::~::~::fi~fi ~:::.. :~i~::::::~: ::~i ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: "~' '~?:~?,',: .:~h, ,~ ~i::~::~::::~::::~::~ ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~?~:0~?,~:~:~:~":. :,,,.~',:~'~ :', ...................... ~ ,, .':~: .......................',':' .......... ".:'.' ................................................. ' ................................................... ~ ....~ ................................ :' "~":~ -' ....... : .......................................................... 5843 44~7. O0 4400.00 3332.41 S 354.34 E 134~. 68 36.62 5~78 45~7. O0 4500. O0 3422.8~ S 3~3.48 E 1381.84 35.1 ~112 ~~0 4&O0. O0 351 o. 73 ~ 372. ~2 E 14 ~ 5_ ~3 :'~:~. ~ ....................................................... :~h:E:~Hh:::h:: ?,: :~:" ":' '?': m::'.:::~: :h: ::i:)h:: :':~ ?: ": '?: ~:' H:: ~:' ':::' :::::::::::::::::::::::: ::'"': :~; :?" ':::" "::~::~:~:~ ?'"~:'.~:" ":~E~H~HHE~H~HHE~ ~" '::T ::"~:"" :' ':'"::::: ~' ":" '" :::: :~" '":: :~:~: :~:~:~::H~H~HHHH~ :'"'"':'?"~:'"'"': H H F": H :'"H h H" ' ' ' ::::::::::::::::::::::::::: :: 6633 50~7:O0 5000. O0 3843.02 S 405.66 E 1536.3& 28.77 6761 5197. O0 5100. O0 3922.79 S 414.36 E 1564.57 28.22 ~':~::~':::~::~i]::~:,:.~t:? : :::' ';~::'.~L~:.~/::::: t~ '~ ~,.. ~. ?~?~"':.":]~:~::~':::'::.::::?,::::~'~:" :': ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ?." "~::~::~i '"~' ::::~::::" '~::~::~::~::::~?' '?.~'::~ ': ~ ': ~ ?: :: ? ~' :: :: :: :: ~ :: ::::::::::::::::::::::::::::::::::::::::: ? ":~ '.~::'*~::~::~ '~, :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::": ':~:::~:,L.,.,::::. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ......... ........... '::~:~5~:~0.. ............... 550 _ ~ ~ _ ......................... . ~,. ..... '~..: .,z ...... ~. . . :..=-- .-: .... ~ ..................... :.='- ~:: - -- = .... I~ lC- 1013 ! ( SEC 12 T 1 1N R IOE) COMPUTAT ! ON DATE <UPARUK NOVEMBER 29· 1982 JOB NUMBER ~LASKA ....... I'II ~l~I I I Ii~i~ ~I ~'~k~'~.---~ I ~i~I ~ ~ I i.-~iI .i. YV I ~Ii~i J ~1 ~i~II~II ~il~l--1 ~JIiiII I ~ I .................................................. I'RUE SUB-SEA TOTAL 7502 57'~7. O0 5700. O0 4354.06 S 459.85 E 1705.35 19.12 7L,20 5897. O0 5800. O0 4417.52 $ 465.47 E 1723.93 18.58 5..-90 ]. O0 4 8,-0 ~ ~' 1Z~o. ~ ~ ~ o~ 81 ~4 6397. O0 6300. O0 46~7.09 S 484.4~ E 1797.30 12.43 8306 6497. O0 6.400. O0 4747.19 S 485. &5 E 1809.16 11.86 0418 &597.00 &5~]O,O0 4797,~5 ~ ........... 48&~&~ !~L~ ..... ,~ o~ ::::i:::::::::::::::::?:::::::~.~::::::::::::::::::::::::::~:::::":::~:::::::::::::::::::::::::::~:7~:~:::~::::~:~::::::~::::::::::::::?:::::::::?:~:~:~::~:~:::::::~:~::::::::::::::::::::~:~:~:~::8::::::~:~::~::::~::::::::::::::::::::::::::::~::::::~::::::::::::::::::::::::::::::::::::::j::::::::::::i:::~::j::~::j:~::::: ::::::::::::::::::::::::::::::::::::::::::::::::: ::J::::J:::J :::::::::::::::::::::::::::::::::::::::::::::::::::::: ~( ........ ~7~. .:~:~ ......................... :::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~ ............. . ..... : ............. :::::::::::: :: ::::~:::'"'~':::~:?:::~,,.....~:~ ...................................... :~ :::::::::::::::: :: :~::~:::~::~::~:~:~::~::::::~::~:::::~:~:::~:~:~:::::;~::~::::~::::~:::::~::~:::::~:::::::~:~:~:~:::::~:::j::~:~:::~:::::~:~::::::~:::~::~:~::::::~::~::::::~:::::::::::::::j:~:::::::::::::~::::~::::::::::::::~:~::::~::::~;::::::::~::::~:~:~:::~::::::::::::~:::::~:::~:i:~::~::::~::~:::::::~:::::::::z.~.~ ....... :386~. 6997. O0 ~?~00. O0 5000.31 S 485.54 E 18~.'P. 64 12.61 8979 7097. O0 7000. O0 5052.48 S 482.53 E 1882.48 12.84 ~]'~'~' ': "3 ~ ~, " ~ ' ," ,~ -", ,~,~,= ~ -~ =.:'=':: :: ~CAEuULAT::: ~' ' "":'::' ' :~ ..... I ON:~: PRO~EDURE~' ?' .... :,'~::: ~: 'U~E'::: A ::::::::::::: ::?:::::::?::::::: ::'.:~.I NEAR'~ :~..! NTE:RFOEA~.I ON:~::~:~:~:"::~ ............ ::: :::: ?::: : ::::: ':''':''?'': ::: ........ ~::A:?:::::: ~: ¥:???::: :??:::: ':::'::::::''EB'?:?::?: ............................. :::::::::?::::::::::: ............................................................................................................................ ::::::::::: ::::: :?:: ::::::: ?: :: :.:, ,:,::::. :::: :::, :::....,.,,:: :.,. ,: : :" .,:::~.,,, ::::, ..:::.:.,.. ,,,:: ...... ,,.., ,::,,: .:: , ,:., ....... ...:::::,, :.,,,, .:::.::,,, ::.,.::,.,.;::::~ ..,,.,. ::,:: ,,,:~,.:~:,, ~::::~:::~::::::::~:::::::::::::::::::::::::::::::::::::::::::::::~:?.:..::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::?.x:~::::::..:::~m..::::::::::..::: .C?', © 0 ~L~.O ALAS~: INC._ #1C-IOGI (SEC 12 Tl lN RIOE) KUPARUK .. ~PERRY-~LIN WELL.~.URVEY IN~,, COMPUTATION DATE NOVEMBER 2'~, 1982 dOB NUMBER BOSS-16134 TRUE SUB-SEA TOTAL I~E~UEED .......... 2d.E R..T.I C' dIL_..__V E ~T_ I. E;~ L ...... F:flS. C..-IL~I~I~LiALC. fiIDRE~I~IAT.. _F. ~;-" -- .............................................................................................................................................................................................................................................................................................. 8408 6587.'.~6 6490.96 47.92.99 S 486.53 E BASE UPPER SAND 8542 6707.69 6610.69 4853.13 S 488, 12 E TOP LOWER SAND 8~.1 680 A. ',~ 4, ......... 6.7..~ Z.., 9~4 ....................... ,,4~RO 2,, 35,,,,S .......... ASEb,~3- ~S~~~...D,. .................................................................................................. ,.-. ................................ ,':'..:' ,:. ' ,.:i:: :: ;; .......... ' ~ x:':i:' :::': :::":: : ii!!:: :!i]] ::ii: !:i ;":':::":!:' ::' :' :: i~:i :i! ii ii:i!: ,: .~::?:i~!i~i::~>:?.:::~::i~::x~x.::..:i::~...:::::x..:x~`i:::~::~:~x~x~:~:..~'~::~:~x:::~:~:~.~:!:!::!:~i:!:!~!:?~?`~:::!.~:!:!x~..~:~:!j!:i..~::~:~::!:!~`i::!~i:i:~!:!:i:i:!:::!:~:::i::xi:~:~::~p:::xx::~:::x::::x:~::~::::: ................... ::,,,.,...: ....... ::.::': .................... :::,x ...... :::::: r , .© © 0 STRAT I GRAPH I C SUMMARY DERIVED USING D IL DEPTHS AND SPERRY SUN SURVEY DATA { SEC 12 T11N RIOE ..... ~ ' , ~. ......... ~ ~ .................. . ..... ~ ...................... ~ .... SURVEY DEPTH 8850 6982.25 6885.25 4992.62S 485.98E PBTD 8890 7017.70 ~920.70 5011.11S 484.91E '.:]::: I!'I :::?i: ..; ' j 'ill!ii:::! . :'i;L 'i ,Iii !i'I:: ': i: ..... ::i:::" ::: iiiiIi:' i: I:::':!iiF ..... iii:.ili~..,i:,.::?,:ii!;,i.,::i.i,' ....... ...~:.....~....~.::!~..~:::i::~:..`.~.:F.~!~.:....~i~....i.......::~.~:P:~i!iii!ii!ii!iiiii~iiii!!~i!!~ii!i!i;i~!ii!!iii~i!~!;i~iiiii~!i!~i~!iii~i!!i~iiiii!ii~ii:k.!..:::::~:~: DATA CALCULATION AND INTERPOLATION BY RADIUS OF CURVATURE KELLY BUSHING ELEV. = .97.00 FT,. T~UE NORTH Surface Location ARCO Alaska, /nc. Our Boss Gyroscopic Survey Job No. Boss-16134 Well: #lC-10GI (SEC12 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: November 27, 1982 Operator: Tom McGuire Scale: 1" = 1000' 1000, ~00~ 00' :0. O0 O0 oo 9002 l_6ooo, oo HORIZONTAL PROJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. Boss-16134 Well: ~lC-10GI (SEC12 TllN R10E) Kuparuk Field North Slope, Alaska Survey Date: November 27, 1982 Operator: Tom Mc~uire Scale: 1'' = 2000' 4000.00 - 6000.00 5085.79' @ S5° 26'E 9002 8000.00 2oEo. oo 40~0.00 VEBTICRL 60~0.00 PROJECTION Suggested form to be inserted in each "Active" well folder to ckeck for timely compliance with our regulations. ' OPe?ator, Wel'l ~ame and Number and Materials to be received by: /'~--~_~~ Reports Date Required Date Received Remarks · . . .. Cc~p letion Report Yes / --' / ~~-'~ ~ '~''.~ Well History Yes _Samples ..... ._, ~re ~ips - Core ~scription . Registered ~ey Plat .. , Inclination S~ey Dire~i°nal ~oY Drill St~ Test Ro~s ~~~. ~: , ~~ ~ /~ , - Pr~u~ion T~t Re~s ~s R~. Yes KUPARUK ENG~ING TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted her~cith are the following: /'//~ A~.~I~iED: ~ PI.FASE RETURN Rt~/EIPT TO: Al:03 ALASKA, INC. Alaska 0il ~ 8as Cons. commission A~: ~~ L, JO~S~ - ~A/311 P, O, ~X 360 Anchorage ~0~, ~. 99510 ARCO Alaska, Inc.. Post Office Bo), Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager December 17, 1982 Chat Ch State o Oil and 3001 Po Anchora atterton f A1 aska Gas Conservation Commission rcupine Drive ge, Alaska 99504 Dear Chat' Attached are notices of our intent to stimulate Kuparuk well 1C-9 and 1C-10 with acid through coiled tubing. As you know, these wells were recently drilled to be used as additional gas injection wells. During our planned cleanup period for the wells, we have identified reservoir damage that we feel can be removed through acid stimula- tion. Removal of the damage is necessary to ensure maximum gas injection capacity for the wells. Also attached is a notice of our intent to pull a dummy gas .lift valve in well 1B-11 'to allow gas injection into the upper Kuparuk sands in this well. This will increase the well's injection capacity. Please have you~ secretary call me at 263-4528 when the · notices are approved so that I can send a courier over to pick them up. Kuparuk Operations Coordinator RLS/b Attachments xc' H. C. Vickers E. A. Simonsen L. M. Sellers ARCO Alaska. Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO--.,dlSSlON SUNDRY NO'T C S AND R PORTS ON DRILLING WELL 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 4. Location of Well SURFACE LOCATION' 1471' FNL, 674~ SEC. 12, T11N, R10E, UM COMPLETED WELL ,.~ OTHER [] ' '~'/~Pw~':~,~ 7. Permit No. ~/, 82-193 ~, ~ 8. APl Number : 99 U. ,,'~ -so-029-20855 F~L~% %; KUPARUK R~VER UNiT ~ (~ 10. Well Number ';~/~r,. 1C-10 ' . BOTTOM HOLE LOCATION' 1826 ' FNL, 1384' FWL,":~2 11. Field and Pool SEC. 13, T11N, R10E, UM KUPARUK RIVER FIELD 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KUPARUK R I VER 01 L 97 ' (KB) ADL 25650 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 ]K] 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). ARCO Alaska, Inc. proposes to stimulate the Kuparuk Sands in Kuparuk River Unit well 1C-10 to remove probable skin damage. This we11 was drilled as a gas injection well, and our plans were to initially produce the well to help clean up the wellbore. · To date, .all attempts to flow the well have been unsuccessful. Due to similarities to we1] lC-9, which does flow, but exhibits only a 50% flow efficiency, we feel that an acid treatment on 1C-10 will improve the wel. l's flow capabilities,- as well as maximize Its gas injection capacity. Prior to acidizing the well, nf'trogen will be injected via coiled tubing into the wellbore to provide 1 irt to allow the well to produce and cleanup for a short time. The treatment will consist of 2-562 gals of 12% HC1 with mud and 'silt remover additlves. The coiled tubing unit BOP~s will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be .1 imited- to 4000 pslg and the tubing pressure wil 1 be 1 imited to 1500 psig. Following the acid treatment, nitrogen wfll be injected through the coiled tubing and aid the cleanup. During cleanup the well will be produced to . tanks on location. Fol lowing the cleanup the well will be produced to CPF1. The well will be converted to a gas injector after producing for several days. Expected start date' December 22~ 1982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK Izd~7 Signed'~-~/::]-~-~C ,~' ~ Title OPERATIONS, COORDTNATOR Date The space 4ow for Commission use Conditions of Approval, if any: Subsequent Work. Reporte~[ /~-.~ro,,~d Copy ~.,., ~ ~u ~ No./~--~ Dat~ · A, pp r-~ v,'.,-i b'¢. ............................... : ........... ............ ................. Submi[ "lntenoons"-in Triplicate Form 10-4U3 and "Subsequent Reports" in Duplicate Rev. 7-1-80 , TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.WASE NOTE: BL - BLUELINE, S - SEPIA, F - FII~4, T - TAPE: RECEIPT ACKNfNNT.~3ED: PLWASE RETURN RECEIPT TO: ARCO ALASKA, INC. ATrN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AK. 99510 w .. DEC .... Alaska Oil & Gas Cons. Oom~nissio~ ~chorage - Post Office B 160 Anchorage, A~,,'T~ka 99510 Telephone 907 277 5637 December 9, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine. Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for November on these drill sites- 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 Also enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4- 13-15 WSW-5 18-10 WS.24. 1F-7 WSW-6 WSW-7 WSW-8 The su.rvey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV' JG' sm Attachments GRU1/L3 ARCO Alaska. Inc, is a subsidiary of AllanlicRichfieldCompany STATE OF ALASKA ALASKA~,_.~L AND GAS CONSERVATION C ,Q..~,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling wel~([~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-193 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20865 4. Location of Well atsurface 1471' FNL, 674' FWL, S~c. 12, T11N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 97' RKB 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1C-IOGI 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. ADL 25650 ALK 468 Kuparuk River Oil Pool For the Month of November ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1330 hfs, 11/15/82. Drld 13-1/2" hole to 2585'; ran, cmtd & tstd 10-3/4" csg. Drld 8-1/2" hole to 8787'; ran logs. Cont. drlg to 9002' TD; ran, cmtd & tstd 7" & csg. Ran 3-1/2" completion assy. Perf'd well. Secured well & released rig @ 1330 hrs, 11/29/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 65'. Cmtd w/246 sx AS II. 10-3/4",45.5#/ft,K-55,BTC csg w/shoe ~ 2568'. Cmtd w/990 sx Fondu & 250 sx Permafrost C. 7", 26.0#/ft, K-55, BTC csg w/shoe ~ 8977'. Cmtd w/878 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/FDC/CNL/SFL/SP/Cal/GR f/8787'-2567' CBL/VDL/GR/CCL f/8890'-8000' Gyro/CCL f/8890'-surface 6. DST data, perforating data, shows of H2S, miscellaneous data N/A DEC i 5 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ._ ....... _ _ I E Senior Drilling Engineer E .... SIGNED T TL .................. DAT NOTE--Rep~/~' or'his fern is~equired for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Ga~/l~onservation C' -ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU 1/NR 1 0 Submit in duplicate 1C-IOGI DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1330 hrs, 11/15/82. Drld 13-1/2" hole to 2585'. Ran 62 jts 10-3/4", 45.5 #/ft, K-55, BTC csg w/shoe @ 2568'. Cmtd 10-3/4" csg w/990 sx Fondu & 250 sx Permafrost C. ND Hydril & diverter. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Drld cmt. Tstd csg to 1500 psi - ok. Drld 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-1/2" hole to 8787'. Ran DIL/FDC/CNL/SFL/SP/Cal/GR f/8787'-2567'. Cont. drlg 8-1/2" hole to 9002' TD (11/25/82). Ran 213 jts 7", 26#/ft, K-55, BTC, csg w/shoe @ 8977'. Cmtd 7" csg w/878 sx Class G. Disp well to NaC1. Ran Gyro/CCL f/8890'-surf. PBTD = 8890'. Tstd csg to 1500 psi - ok. Ran CBL/VDL/GR/CCL f/8890'-8000'. Arctic packed 7" x 10-3/4" ann w/300 bbls H20, 250 sx Permafrost C, & 106 bbls Arctic Pack. Ran 3-1/2" completion assy w/tail @ 8199', SSSV @ 2080', & pkr @ 8135'. Ran CCL/GR. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp tbg w/diesel. Tstd 7" x 10-3/4" ann to 1000 psi - ok. Perf'd 8278' -8304' & 8308' -8344' w/4 spf. F1 owed well. SI well. Dropped ball. Closed SSSV. Set BPV. Secured well & released rig @ 1330 hrs, 11/29/82. JG:llm 12/10/82 GRU1/DH9 DEC i 5 L '82 AlaSka Oil & Gas Corr. ' ~ .~. COmmission An,,.ora~ja TO: William VanAlen D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.WASE NOTE: BL- BLUELINE, S - SEPIA, F- FIL~ T~~-TAP~E PC - PHOTOCOPY ~~~E RETtTRNACKNC~U.~Px~RD: R~CE~ TO: ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O. BOX 360 ANCHORAGE, AKo 99510 MEMORANDUM Sta e of Alaska TO: Thru: Lonnie C. Sm~ ~n ... Commi ssion~ r FROM: Edgar W. SiPple, Jr Petroleum Inspector ALASKA ~-IL A~D GAS CONSERVATION COMMISSION /~t~r//j. DATE: N O vein be r 22, 1982 C. V ton Chai(.~h"-" FILE NO: 10 8/H TELEPHONE NO: SUBJECT: Witness BOPE Test at ARCO's Kuparuk 1C-10GI Doyon Rig No. 9 Sec. 12, TllN, Ri0E, UM Permit No. 82-193 Thursd~¥~ November %8, 1982 - I arrived at ARCO's Kuparuk 'ic-10Gi, D0~h:-Rig N~,-9, -The d. rilling rig was in the process of running casing. The BOPE test commenced at 11:30 p.m. and was concluded at 5:00 a.m. on November 19, 1982. There was one failure, the Graylock clamp on the lower pipe ram and mud cross leaked. A new API ring ~as installed, and. it tested to 3000 psi. The A.O.G.C.C. BOPE test report is attached with this report. In sumn~ry, I witnessed the BOPE test at ARCO's Kuparuk 1-C10GI, Doyon Rig No. 9. Inspector TATE OF ALASKA ALASKA OIL & CAS CONSERVATI(;i-I CC~ffSSION B .0. P.E. Inspection ReL~prt Wet 1 / -- 2'- Location: Sec /~_ T//~J R l~ ~ M ~.~ Prillinq Contractor :~)~ ~ ~ Rig # Rep ti "-. ' ~ ~''' '- resenta VO Permit # &Z-- ! ?3 / ~ <V Casing Set @ ,J~-.~l ft. Representat ire location, Genera] Wel 1 Sign Cenera 1 Housekeeping Reserve pit Rig Ok BOPE Stack -~ .. . Annular Preventer Pi~e 'Rams- .- . Blind-Rams-~ . Choke.: Line '~ Valve H.C.R. Valve , ~ K~i 1 Line.~ Valves · CheCk. ,.Va iTM. Test Pres sure JOoo · ~J 0 o:.3 ~00o Test Results: Failures ' Repair or Replacement of failed equipment to be made within InSpeCtor/Cc~mti~sion office notified. ACC6~I!UIATOR SYS TE~ Pul 1 Charge Pres sure ~ OO ~ psig pressure After Closure /?~O psig Pump incr. clos. pres. 200 psig O..min~2_ sec. ~,~' rain ~"; sec. N?pPull Charge7 ® pressure~D. (93 Attainedj o ~ ~1~ ~ooo ~oo~ '?o~ psig 2 Controls: ~ster ["Jl/,,x~ ~_A,,m R_ _eJl~_ __t_e_ ~~-~ B 1 i n_d S__ swi td!._ .c_ .o v_e .r_ Kelly and Floor Safety Valves · Up~r Kelly. ~!~ Test pressure 3o ~ o Lower Kelly ~ ~ Test Pres sure _ BalI Type. 0~' Test Pressure /d~_ Pf/' Inside BOP o U Test Pressure Choke ~nifold Test Pressure~o No. Valves / g/ No. flanges. ~djustable Chokes / -- ~o, t., }~fdrauically operated choke [~ day s and 'm- · Distribution orig. - AO&CCC CC - Operator cc - Supervisor ARCO Alaska, Inc. Post Office Bo~lr360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 16, 19'82 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1C-10GI Permit Dear Mr. Chatterton' The 1C-10GI permit, dated November 10, 1982, incorrectly lists the surface location as' 1471' FNL, 6751' FWL, Sec. 12, TllN, R10E, UM The correct location is' 1471' FNL, 674' FWL, Sec. 12, TllN, R10F., UM Please revise your records to indicate this correction. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer CC' R. W. Crick, ANO 91.2 C. L. Crabtree, ANO 350 E. A. Simonsen, AFA 311 Doyon 9 Rig Supervisor 1C-10GI Well File RECEIYEO NOV [ ? ]982 Alaska Oil & Gas Cons. Comrnissioe ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCornpany ARCO Alaska, Inc. ,~'~ Post Office t' 360 Anchorage, /.w,aska 99510 Telephone 907 277 5637 November 10, 1982 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built LoCation Plat - 1C-9GI & ~1~ Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG:llm Enclosures ARCO Alaska, Inc. is a subsidiary ol AtlanlicRichfieldCompany i I II i I · I I I 12 LOCATED IN PROTRACTED SEC. 12, T. II N,~IOE,UMIAT MGR... · ~ " ~ , A'/),, i , ~C&LE' I · I HI · , D.$. I-C CONDUCTOR STAKE OUT LOCATIONS, I-C .9 Y'= 5968851.99 I- C-lO X · 561548,05 LAT. 70° 19':51.59;54' LON<~, 14~)° I;581 EN.L. ~ 542: £W.L, NOTES: I. ALL Y AND X COORDINATES ARE ALASKA STATE PLANE, ZONE 4. 2. DISTANCES FROM SECTION LINES ARE GEODETIC. X · 561680.92 LAT. 70° 19' 30.7107" r $. D.S. AND Y AND X COORDINATES ARE BASED ON MONUMENTS lC WEST 8~ lC EAST PER LHD.ASSOC. I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AI~~ LICENSED TO PRACTICE .LAND SURVEYINO IN THE STATEO, ALASKA, AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY MEt AND THAT ALL DETAILS ARE CORRECT AS OF NOVEMBER $, 1982:. 'ARCO Alaska, Inc. Kuperuk Project North Slope Drilling · D,$, I'¢ (}AS INdEcTION - wEL~s' I-C-9 & I-C:lO A8 BUILT LOCATIOn, , _'. ,.,;': ',or: :'. ;',0~ .... {',"'.; :",'. ~°'o ' !~ovember 10, 19~2 !~r. Jeffrey B. Kewin Senior Drillimg Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 ~> ~.~ver Unit 1C-] 0 G7 ,,e: Kuparuk ~ _ At, CO Alaska, Inc. Per,~nit No. 82-193 Sur I.oc. 1471' .... ' 6751'FWL, Sec ~2, __~, , · . ~ E_.On, .... Etmhole Loc 1826'FNL, 1384'~L, Sec 13, TITM, Dear ~-'~r. Kewin: Enclosed is the approved application = ~or peri, it to drill the above referenced well. If coring is conducted, a one cubic inch chip fron~ each foot of recovered core is required. Samples of '~ell cuttings and a mud log are not required· A continuous directional survey is required as per 2~ AAC 25.050(b)(5). If available, a tape containin~ the ~.igitlzed log information shall be submitted on all logs for copying except experimental logs, velocity surveys an¢] dip~eter surveys. ,any rivers in Alaska and their drainage systems have been classified as important for the spa%auing or migration of anadrom, ous fish. Operations in these areas are subject to A~, 16 05 870 and the ~ ~ ' * . . re~.u,ations promulgated thereunc~er (Title 5, Alaska Ad~ninistrative Code). Prior to co~encing operations you may be contacted by the Habitat Coordinator's Office, Depart~-.ent of Fish and Game. Pollution of any ~aters 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 am..:.ended. Prior to commencing operations you ~ay be contacted by a representagive of the Depart~ncnt of Environ~nental Conservation. To aid us in scheduling field ~ork, please notify ~his office 24 hours prior to commencing installation of the blowout Mr. Jeffrey B. Kuparuk River Unit 1C-lO GI -2- November 10, 1982 prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~aere a diverter system is required, please also notify this office 24 hours prior to cc~mencing equipment installation so that the Commission may witness testing before drilling below the 6hoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Ve~ry~ truly yours, c. v. Chatterton Chairman of ~Y DItD~F.8.0~ T~t~_~O~l~|~O~ Alaska Oil and Gas Con~erva'~iOn~o~ssion Enclosure cc: Department of Fish & Game, !{abitat Section w/o encl. Department of Environmental Conservation w/o encl. CVC..be Post Office B~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 8, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1C-iOGI Dear Mr. Chatterton: Enclosed are: o An application for Permit to a $100 application fee. o A proximity plat showing the nearby wellbores. Drill Kuparuk 1C-IOGI, along with subject wellbore's position to surface hole diverter system. BOP equipment. o A proximity analysis. o A diagram and description of the o A diagram and description of the Since we expect to spud this well on November I3, 1982, your earliest approval would be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kewin Senior Drilling Engineer JBK/JG:sm Enclosures GRU2/L38 ARCO Alaska. Inc is a st~bsidiary of AtlanlicRichfieldCompany STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CG.~,vllSSlON I ERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [~X STRATIGRAPHIC SINGLE ZONE I~IX MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 1471' FNL, 6751' FWL, Sec. 12, T11N, R10E, UN At top of proposed producing interval 1320' FNL, 1320' FWL, Sec. 13, T11N, R10E,UM At total depth 1826' FNL, 1384' FWL, Sec. 13, T11N, R10E, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 1C-10GI 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) 6.~erial no. 56'GL, 61' PAD, 97' RKB ADL 25650 ALK 468 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount .$500,000 15. Distance to nearest drilling or completed 1 C-3 wel~1781 ' TVD, 156 feet 18. Approximat9 spud date r. 11/13/82 ' 19. If deviated (see 20 AAC 25.050) 258/+ . psig@. 80° Surface psig@. 6432 ft. TD (TVD) 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 Miles NW Deadhorse miles 0'@5232'TVD(6710'MD) feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 9329' MD, 7095'TVD fe~t 2560 / KICK OFF POINTS00 feet. MAXIMUM HOLE ANGLE 44.3Z~20' Anticipated pressures I (see 20 AAC 25.035 (c) (2) 2969 21 ! Proposed Casing, Liner and Cementing Program i SETTING DEPTH QUANTITY OF CEMENT SIZE Hole Casing 4" - ' 2O" 3-1/2" 10-3/4" 8-1/2" 7" Weight 94.4# 45.5# 26# K-55 CASING AND LINER Grade Coupling H-40 Welded K-55 BTC BTC 22. Describe proposed program: Length MD TOP TVD 80' 36' I 36' 2523 ' 35' I 35 ' I 9296' 33' I 33' MD BOTTOM TVD ~ 115' I 2558' 12250' I 9329' 17095' I I (include stage data) 300 cf 1000sx ext. Perm. 250sx Perm. C. 1000sx Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field gas injection well to approx. 9329' MD, (7095'TVD). A 20", 2000 psi annular diverter will be installed on the 20" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2584 psig. Pressure calculations are based on 1C-7 reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.3#, J-55, DSS tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole~a~e.~y, valve will be installed and tested upon completion of the job. See attached proximity analysis. ~'C~/VL~ 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ~l~,ivOV~j 0 9 1982 SIGNED ~~. ~ TITLE Senior Dr i,/,~,,~er DATE ~-~-~ The space below for Commission use ~l~of~ ~ili8~i0~ APPROVED BY CONDITIONS OF APPROVAL Samples required Mud log required I DirectionaI Survey required APl number --~]NO I--lYES --~[O I '~I'-Y ES •NO 50-- 0 ?-. [-]YES Permit number Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS Form 10-401 GRU2/PD24 ~' // / Submit in triplicate November 1982 ,COMMISSIONER DATE -u, bv order of the Commission i ! I ~JAII'1' il'J I MI; !Mr1 Ii I I1,, ' Ii~I~IiliPlI!;FrlJ i I ! I ! :j=~- f~ J: I 1 I i i ''IIl ,I ~; "~ .~i .... : ' ' ' ii ii I lli! II J J j i I i il i J iNI/f, i i I Iii I I J I i J ! J '"="':' r""' """'"': '":-I ',T F? "" '"' "" """""'"''" '" ' i j .... F,' ~'qq-r I I I I I ! ~ i ! ! ! I I ; I i I I I J I I ! ! ' ! i ! !I ! I! !' I! ~i Jl!l IJii ii i IJli ilii Iii I 1 i ! ii I i il J i iii i i ' ' I I I J ~ I I l i I I i Jill ll'i i !l iii i Il I ~ J! i iJ 11 1 I! I I i I I I I I I iiii il I I II L I11 i ii ! I I I t I! !il ill 11 J '' I I i I I I i ! I iJll J! 1 ! !i illl i I1 i II I ! I !1t ' '1 ~r J J I I ~ I I .... i I ~lljI I I I ii J~tJ i Il [ ii I I, III ii! ~ ,i ~ i ~ ~ I J I I Jj J j I I [ Il iii', i I ~i I I J J ijj; j ' j ~ J I ' I lJ'i ! j j:jj 1 l! 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I i I ] i {, I i Ill I l il I { [I Il I ~Jll J til[ }il! : ~ iii{ i} I {1{ {] i J l il ~ i: I i { ii i{{l iJ [J ~ [l i ~ I 'ill Ill{ :, I { ! } ![ }iii '! .... i" ;-g~ , . .... i j j j j j j j J J I j j i {il J : ., J ~{i{ iii' ij ..,, , :. I~ t lJJ i J [ r l [ il { [lil !ill i { i T,~[,~:[~~ { j i { , i ~[ LS [lllill I Ii i · , [iii ~ J i [ , Ii }ill ill i [ J J ] Jill ~ ~ ~ i { { i J } J J ~ J { J I J J J J ~ i J J ' '- i-J]~ ~:: ': J ;j'J 1~ {' ',Il i I iii: j 11 { ~' il i" " "' '' ' {' ":: i: ,,l: , ;, :,ii iiit { I , , , [ i ' ,I J ~{J jjrJ ljjl I i {ill ~ill ,.J: I }l I Il )i.4i : t i J lii~ J,l Llll ~lii [1{1 II'{ I Il,iii F I J Il l ; {j :l { lili i~ il,I I'Jl fill ilJl il I I~l {I l[ i !Iii I Il jill jill ANALYSIS OF WELL PROXIMITY WELL 1C-IOGI NOTE: Refer to the attached proximity map. 1C-10GI/lC-3 The proposed Well 1C-iOGI will cross the existing Well 1C-3 by a distance of 156' at a measured depth of 1904'. This distance was calculated using the Gyro multi-shot survey on 1C-3 and the proposed course for 1C-IOGI. Well 1C-3 has an ellipse of uncertainty of 108' across its major axis at the depth at which the crossing occurs. 1C-iOGI will have an ellipse of uncer- tainty of 104' across its major axis at the depth of interest. The areas of uncertainty for the two wells will therefore not intersect. ARCO proposes that the following procedures be used to drill 1C-IOGI safely past the above crossing. 1. The 13-1/2" surface hole will be continuously surveyed to its total depth using a Teleco tool and single shot surveys. 2. Well lC-3 will be shut-in if calculations show that a crossing of 106' or less is to occur. This distance corresponds to the intersection of the areas of uncertainty. Upon shutting in, casing and tubing pressures would be monitored until a safe crossing is evident. 3. If calculations show that a crossing of 106' or less is to occur, a deflection assembly will be run. In addition to the above precautions, the on-site rig personnel and supervi- sors will continuously monitor all drilled. parameters as the interval ~f~.interest is 4/,~.~ o//~, 9 -~2" ANALYSIS OF WELL PROXIMITY (contd) A1 so, ARCO Alaska, Inc., proposes to drill Gas Injection Well 1C-IOGI on 160' spacing adjacent to existing 1C-9GI, as shown on the attached wellbore proximity plot. 1C-9GI is a vertical well and 1C-iOGI will be vertical to 500'. At 500' the area of uncertainty of both individual well surveys would be 4' in diameter. This is based upon typical field-observed accuracies for . the surveying tools utilized. Assuming a worst-case situation, the areas of uncertainty would not intersect or overlap one another. Further, after reaching 500', the subject well is directionally drilled at a diverging angle further widening the margin of safety. In light of the above, we feel we can safely drill Well 1C-IOGI and avoid proximity problems with the adjacent wellbore. JG'sm 11/08/82 GRU/AWP Surface. D ~.__~.,r~r System 1. 16" Bradenhead. 2. 16" x-20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/10" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open autc~ti- cally upon closure of annular.preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ,nipple. -o i® 16" Conductor Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular p~venter and blow air through diverter lines ~ery 12 hour: 3; ClOse annular p~venter in the event that gas or fluid flow to surface, is · det~ted. If necessary' n~nually-over~ ride and close ball valve to upwind diverter line. Do not. shut in well unde,r ~ ci rcu~nstances: RNNULRR . PREVENTOR 9 ' _ [_ BL I bid RRHS ,--- ' ) '- -Lq · . . PIPE RRMS ) ( R'ILLING SP6OOL .C J ) PiPE RRMS ) 3-5/8" 5000 PSI ~SRRA BOP STAr. '~.~ 2. 3. 4. 5~ e 16" Bradenhead 16" 2000 PSI x i0' 3,%3 FSI c~sing head 10" 3000 PSI tubing he~,d lO" 3000 PSI x 13'5/8" 5000 FSI .. adapter spool .:' 13-5/8" 5000 PSI pipe 13-5/8" 5000 PSI drilling spool w/choke and kill lin~ -_- .13-5/8" 5000 PSI pi~'~- _-.._-- -[.-.... .... 13-5/8" 5000 PSk bliad r~ -- - 13-5/8" 5000 PSI an~lar--. .. - _ A~h~TO~ ~I~ ~T ' ' ' - ~: ..... -~--. -- .- . - .~ : - :.. - .... = - ~:-~ .... :-' --':_~'~t- :.' ' ~ '~ FILL A~~TOR ~ER~I~ ~ P~P~ -' ~. '-"' ~'~ WITd HYDP~ULIC ~IO. - -. ~ ~T A~~T~ P~~ I~ ~ ~I .-- WI~ l:S~ PSI ~.~~ ~ Tr~ ~~R. ~S~YE TIHE Th~ C~E ~ L~ITS S~-~- ~GLY ~qO RECOPJ T~ T~ ~ P~ ~~ ' -- P~¢ OFF. . _ L~IT IS 45 SE~;~ ~I~ T~E ~ l~ PSI 13-5/3" EOP ST*,tC.< TF_.~ ~ILL BOP STAC~ A~¢ J'U,.-~[FOLD ~[TE ~?J=~C DIESEL. ~N SC~AS Iff ~E ~tU~ PR~~ ~O C~ ~ ~?~S ~jT ALL C~r~S TO 10 MI?~TES. B~ED TO ~0 ~[. PIPE ~. ~V~. T~ i P~H.,~ b~~ ,~,~FO~ Y~, IF ~, ~I~ TO ~0 PSI. - ' _ ~gt TOP S~ OF PiPE H[I~. B~ED TO Z~ PSI. ~I~ JOI~ ~(O ~ ~ OF B~O TO ,ZERO PSIs. ~ - T~ ~Y ~ ~ I~I~ P~ TEST [fIF~TI~ w~R. - _ - . - - - - - - ~TI~LY' OP~ ~ ~LY- '- - -:: -~-- ' Lease & Well CHECK LIST FOR NEW WELL PERMITS Comp any b ~'~ ITEM (1) Fee (2) Loc AP PROVE DATE / . ~ ....t ,~' ".-" ,!':~," (f thru 8) (3) Admin thru 11) (4) .Cmsg ~.~.~.. //-~-~9~__ (12 thru 20) (5) 'BOPE .~~ M-~-~?~_ (~1 thr~ ~ 1. Is the permit fee attached ......................................... 2. Is well to be located in a defined pool ............ ... 3. Is well located proper distance from property line .''..'°''''''.''' 4. Is well located proper distance from other wells ....... . . 5' Is sufficient undedicated acreage available in this P°°li!i!iiii'ilI 6. Is well to be deviated and is well bore plat included ........ 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait .............. o 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Does operator have a bond in force ................................. Is a conservation order needed ..................................... Is administrative approval needed .................................. YES NO Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an exis'ting wellbore ............. Is old wellbore abandonment procedure ~ncluded on 10-403 ............ Is adequate well bore Separation proposed ........................... Is a diverter system required .............. ......................... ~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) ............... '... REMARKS Additional requirements ............................................. ~ Geology: .Engineering Y.. LCS WVA ~-- J KT~Z.~RAD / / rev: 08/19/82 ' INITIAL GEo. UNIT oN/OFF POOL CLASS STATUS AREA 'NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. .To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ,. _ · .ci,:'~ .... 2 %(, ~ t;?r-!:,, ., L~ I... -- ~ ..... LJ h' ti L) (:/,,~ m. I. I L, D t..A i., .f. ,!. L, L:' C .a, b ,i. £ ,t~ L; 2. U o q: 0 , C 3 '1 -b 3.4 3 7 ~ 3 . 3 i ,.)5 8,5 t:'.'. 'i *~ 3 e,. o t ,5 .i: a2o i :5 .':~ S. (.: i3 ~..: C A t., ] L:~ R H i3 L:' .A l, .l.. t: I . 1 5 6 2 *"L:, vt 4Z 't ,B b, {,)~; U o <'<, . 3.5'~ ~ 29 b, '1%~)!.! 4. "j~..',,, . {'., ._.
