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184-132
0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 11,2016 TO: Jim Regg P.I.Supervisor neert 'S(zs 1I(0 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2G-16 FROM: Lou Grimaldi KUPARUK RIV UNIT 2G-16 Petroleum Inspector Src: Inspector Reviewed By:e P.I.Supry -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2G-16 API Well Number 50-029-21163-00-00 Inspector Name: Lou Grimaldi Permit Number: 184-132-0 Inspection Date: 5/10/2016 Insp Num: mitLG160510094959 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well, 2G-16 , Type Inj N-TVD 5982 - 1 Tubing 1750 - 1750 1750- 1750 - T PTD' 1841320 - Type Test SPT Test psi' 1500 IA 1700 . 2490 - 2415 - 2390- Interval f4YRTST P/F P OA 130 . 150 . i 150 - 150 . Notes: Well shut-in during test,advised AOGCC may require test once well is back on injection.Pumped.8 bbl's diesel,.8 bbl's returned.All required paperwork available on location.Good static test. SCANNED SEP 2 7 2016 Wednesday,May 11,2016 Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] ZI1 z- Sent: Wednesday, February 08, 2012 10:49 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: 2G -16 (PTD 184 -132) Report of suspect TxIA communication 2 -6 -12 Attachments: MIT KRU 2G -16 02- 07- 12.xls Jim, Guy, p 164-/3z- Initial diagnostics were conducted on Tuesday February 7. 2G -16 passed the tubingpackoff testing and MITIA but failed an IA drawdown test. The well will be shut in and freeze protected as soon as possible. Further diagnostics with slickline and /or eline will be scheduled as needed. Brent Rogers / KeIIy Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 St4IVIOW FEB (j .Z •oblem Well Supv , February 06, 2012 3:26 PM @alaska.gov'; 'guy.schwartz @alaska.gov' G -16 (PTD 184 -132) Report of suspect TxIA communication 2 -6 -12 Jim, Guy, Kuparuk injection well 2G -16 (PTD 184 -132) is being reported to have suspect TxIA communication due to frequent bleeds of the IA. Initial diagnostics are planned for tomorrow to include tubing packoff testing, an MITIA and potential IA DDT test if the MITIA passes. An update will be sent following those diagnostics and if the MITIA fails, the well will be SI and freeze protected while awaiting further diagnostics using slickline and /or eline. The well will be added to the monthly failed MIT report until further notice. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted to continue injection or repair as needed. Attached is the schematic and 90 day TIO plot. « File: 2G -16 90 day TIO plot.ppt » « File: 2G -16 schematic.pdf » Brent Rogers / KeIIy Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 Well Name 2G -16 Notes: Frequent bleeds Start Date 11:x � I 1 GI -132 Days 9 0 End Date 2/6:2012 Annular Communication Surveillance 4000 160 _ WHP IAP 3500 C►AP — 140 WHT 3000 120 2500 100 IJ — .Q 2000 I . 8 '0 1500 60 '4....„ 1000 40 500 20 0 0 Nov -11 Dec -11 Jan -12 Feb -12 • 1600 •DGI 1400 MG1 1200 ........PWt S1rVl e II ▪ 1000 ✓ aoo~ �BLPD d Q 600 400 200 0 Nov -11 Dec -11 Jan -12 Feb -12 Date ,„..,,, KUP 2G -16 ConocoPhillips Oi Well Attributes ax Angle & MD TD Inc Wellbore APWWI Field Name Well Status Incl ( °) MD (MB) Act Btm (RKB) tararoPMnp 500292116300 1 KUPARUK RIVER UNIT INJ 47.98 3,700.00 7,900.0 " "" Comment H2S (ppm) Date Annotation End Date KB-Ord (R) Rig Release Date ••• Well COnl9 - 2G -16, 111 2012 3 17:15 PM SSSV: TRDP Last WO: 40.98 10/24/1984 Schematic.Actual - Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: 7,605.0 6/30/2005 Rev Reason: FORMAT UPDATE ninam 1/1/2012 Aidng Strings ,_, Cuing Description String 0... Stdng ID... Top (ROB) Set Depth (f... Set Depth (TVD) ... String Wt.. String .. String Top Thrd I I CONDUCTOR 16 15.062 35.0 110.0 1100 62.50 H WELDED HANGER. 32 , Casing Description String 0... String ID ... Top )RKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd i " SURFACE 95/8 8.921 34.0 2,909.6 2,772.4 36.00 J - 55 BTC _ Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... S tring Top Thrd ' �. PRODUCTION 7 6.276 34.6 7,848.1 6,309.8 26.00 J -55 BTC Tub Str - -__ Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String . String Top Thrd TUBING 31/2 2.992 32.0 7,464.3 6,006.0 9.30 J.55 EUE8RD CONDUCCTORO, Completion Details Top Depth ala (ND) Top Intl NontL.. Top (8KB) IRKS) (1 Description Comment 10 11n) SAFETY VLV, Pr. 32.0 32.0 0.36 HANGER MCEVOY GEN II TUBING HANGER 3.500 1,671 1,871.6 1,867.5 14.23 SAFETY VLV Baker FVL SAFETY VALVE ***FLAPPER CHECK, VERIFIED SSSV IS 2.810 NOT LOCKED OUT BUT SIGNIFICANTLY RESTRICTED, UNABLE TO SET ISO SLEEVE per WSR 6/28/2007"* GAS LIFT 1111 1,623 6.6, 7,421.5 5,972.4 38.24 PBR BAKER PBR 2.810 sei 7,435.2 5,983.1 38.19 PACKER BAKER FHL PACKER 3.000 _ 7,452.3 5,996.5 38.14 NIPPLE CAMCO D NIPPLE 2.750 7,463.8 6,005.5 38,11 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 7450' during OTIS TEMP LOG 2.992 on 04/12/1985 SURFACE. - 34 -2,910 Perforations & Slots Shot OAS 3 1 : . Top (ND) Btm (11/D) Dees Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date ( Type Comment 7,542 7,556 6,067.2 6,078.2 A -5, 2G-16 9/30/1985 4.0 RPERF 0 degPh;2 1/8"DresserBarKo GAS LIFT, s,ste I. 7,545 7,546 6,069.6 6,070.4 A -5, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarderJumbalet 1 7,549 7,550 6,072.7 6,073.5 A -5, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet GAS LIFT, 7,550 7,552 6,073.5 6,075.1 A -5, 2G -16 11/3/1984 - 1.0 IPERF 9odegPh;4 "CarrierJumbolet 6,727 , 7,555 7,556 6,077.5 6,078.2 A -5, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet GAS LIFT. 7,565 7,605 6,085.3 6,116.8 A -5, A-4, 2G -16 9/30/1985 4.0 RPERF 0 degPh;2 1/8 "DresserBarKo 7.360 {. 7,577 7,578 6,094.8 6,095.6 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet 7,580 7,581 6,097.2 6,098.0 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet a 7,584 7,588 6,100.4 6,103.5 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrerJumboJet Peft, 7 .421 7,592 7,593 6,106.7 6,107.5 A-4, 20-16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet PACKER, 7,435 „ .. 7,593 7,394 6,107.5 5,951.3 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CartierJumboJet 7,597 7,598 6,110.6 6,111.4 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet NIPPLE, 7.452 i f 7,598 7,599 6,111.4 6,112.2 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet 1. 7,605 7,606 6,116.8 6,117.6 A -4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet SOS, 7,464 - 7,608 7,609 6,119.2 6,120.0 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet a 7,611 7,612 6,121.6 6,122.4 A-4, 2G -16 11/3/1984 1.0 IPERF 90degPh;4 "CarrierJumboJet Notes: General & Safety End Date Annotation 10/22/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, 7,545-7,546 RPERF, 7,642 -7,556 " IPERF, 7.549 -7,560 IPERF, 7,550.7,552 0 0 IPERF, _ 7.555.7.566 IPERF, 7,577.7,576 IPERF, 7.5667.561 RPERF, _ 7.565 -7,605 _.._...- IPERF, MN 7,5847,566 • IPERF, 7,692.7,593 \ IPERF, 7,593 IPERF, 7,597 -7,586 - IPERF, Mandrel Details ' 7,57 Top Depth Top Port ,, = (TVD) Incl OD Valve Latch Size TRO Run Stn Top (9KB) (MB) (`) Make Modoi (In) sery Type Type (in) (p Run Date Com... IPERF, 7,6057,606 1 1,923.0 1,917.1 15.66 MMH 3.5 x 1 1 GAS LIFT DMY BK2 0.000 0.0 11/4/1984 _ 2 3,860.2 3,414.1 46.43 MMH 3.5 x 1 1 GAS LIFT DMY BK2 0.000 0.0 11/4/1984 IPERF, 3 5,518.7 4,597.8 43.49 MMH 3.5 x 1 1 GAS LIFT DMY BK2 0.000 0.0 11/4/1984 7,6067,609 - - 4 6,726.6 5,464.0 45.84 MMH 3.5 x 1 1 GAS LIFT DMY BK2 0.000 0.0 11/4/1984 IPERF, _ 5 7,380.5 5,940.9 39.57 MMH 3.5 x 1 1 GAS LIFT DMY BK2 0.000 0.0 11/4/1984 7,611.7,612 - PRODUCTION, 357,646 . TD, 7,800 MEMORANDUM TO: Jim Regg ~7 P.I. Supervisor ~ ~~6~~~G"~'•~ ~, FRONT: John Crisp Petroleum Inspector State of Alaska • Alaska Oit and Gas Conservation Commission DATE: Wednesday, May 07, 2008 SliBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC ZG-16 KUPARUIC RIV U;vIT 2G-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~jr;~ 1~--- Comm Well Name: KUPARUK RN UNIT 2G-16 Insp Num: mit1Cr080~04094952 Rel Insp Num: API Well Number: so-o29-z ~ 163-00-0o Inspector Name: John Crisp Permit Number: t 84-(32-o Inspection Date: 5i2i2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 'zG I6 '.,Type Inj. w ' T'~ ' s9s3 J ; IA I loo 3030 2940 ~, z9zo _ _ ~ ~-- ~ - I ---- / ~ ~ I _..----- p T I8aI3zo ~TypeTest ! sPT i Test psi ~~ 3000 ~ OA azo ago a7o ~ ago - - _ _ __ Interval avxrsr p~F P ~ Tubing',. ~60o zboo zboo zboo NOteS: 2.5 bb('s pumped for test. (V11,~ .,~a--P-~,~~GL~~ILU~ - 1 ~Sr'L~~s,. ~,~~ M~~ ~ ~ 200£ Wednesday, May 07, 2008 Page I of I FW: 2G-16 (PTD 1841320} Rep~of suspect TxIA communication • Page 1 of 3 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Wednesday, March 26, 2008 3:38 PM ~~ ~ ~~~ ~ D~ To: 'NSK Well Integrity Proj' ~~ Cc: Maunder, Thomas E (DOA) Subject: RE: 2G-16 (PTD 1841320) Report of suspect TxIA communication Perry - Thank you for providing the mos# recent pressure data for KRU 2G-16, and for your assessment based on the review of historical pressure data and operating history. As discussed this morning, I__agree with keeping„_KRU 2G-16 on_ water injection. Since there was no indication of communication during the 2 weeks since water injection was restarted, ! do not think it necessary for CPAI to request administrative approval to continue injecting in the Weil. However, it would be prudent to add (at least temporarily) KRU 2G-16 to the monthly injector integrity report and keep track of rate, temp, choke, etc., changes that could influence IA pressure; we can revisit the need far this enhanced surveillance when you submit the integrity report in early May. Of course, any indication of pressure communication or feakage would trigger notification per the normal procedure. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~ ~p~ ~ ~ 7d~~ From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Wednesday, March 26, 2008 10:46 AM To: Regg, James B (DOA) Subject: FW: 2G-16 (PTD 1841320) Report of suspect TxIA communication From: NSK Well Integrity Proj Sent: Tuesday, March 25, 2008 11:22 AM To: 'Maunder, Thomas E (DOA)' Subject: FW: 2G-16 (PTD 1841320) Report of suspect TxIA communication Tom, Yesterday was the 14th day of injection since permission to inject for 14 days was granted by Jim. Enclosed is a current 90 day TIO plot. As you can see the wail has no indication of annular communication. I would Tike permission to leave the wail amine, injecting water. See below e-mails where passing MlT and draw down indicated no communication. The well was initially reported as suspect as it was bleed twice in a weeks time or Tess. 4've been going over the trend plots as far back as 6 months and its possible that the suspect IA pressure is related to injection rate changes. The trends are subtle, possibly because the seawater is only 60 F on average. It certainly doesn`t react as quickly as a high volume produced water injector and hysteresis might be responsible for suspecting T X IA. I feel that the well has integrity. I propose that we continue to inject and monifior. We will operate the wail in accordance with Ai0 2B and the appropriate regulations of 20 AAC 25. Please !et me know if our proposal is acceptable. Thanks in advance. 3/27/2008 FW: 2G-16 (PTD 1841320) Rep~of suspect TxIA communication Perry Klein Well Integrity Project Supervisor ConocoPhiliips Alaska, Enc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 For Problem Wells Supervisor From: NSK Problem Well Supv Sent: Monday, March 03, 2008 2:35 PM To: CPF2 Prod Engrs; CPF2 DS Lead Techs NSK Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 2G-16 (PTD 1841320) Report of suspect TxIA communication • Page 2 of 3 As per AOGCC, we have approval to place 2G-16 on injection for 14 days so that we can monitor fior AnnComm. Please resume injection at your earliest convenience. Martin From: Regg, James B (DOA} [mailto:jim.regg@alaska.gov] Sent: Monday, March 03, 2008 2:32 PM To: NSK Problem Well Supv Subject: RE: 2G-16 (PTD 1841320) Report of suspect TxIA communication Your request to place KRU 2G-16 back on water injection is approved as proposed. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, February 25, 2008 8:51 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 2G-16 (PTD 1841320) Report of suspect TxIA communication Jim, I-lere is a follow up with the results of the initial diagnostics that were performed on 02115108. The tubing pack oft tests passed leading to believe the communication was not a result of the pack offs. The MITIA passed with the test data an the attached form. The IA was bled down for a drawdown test that also did not show signs of communication. The initial TEO prior to the lA being bled were 291011790/425. The lA was bled down to 1060 psi and was monitored on 02/18108 where the TIO was 2750111501350 and again on 02124108 where the TlO was 2675111751350. ConocoPhillips requests permission to place the well back on injection for a test period of 14 days in order to monitor for further signs of communication. At the end of the test period; follow up results will be submitted and the well will be evaluated for the next plan forward. «MIT KRU 2G-16 02-15-08.x1s» 3/27/2008 FW: 2G-16 (PTD 1841320) Rep~of suspect TxIA communication • Page 3 of 3 Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Friday, February 15, 2008 7:19 AM To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G-16 (PTD 1841320) Report of suspect TxIA communication Tom & Jim, Kuparuk water injector 2G-16 (PTD 1841320) was reported as having suspect TxIA communication. The IA repressures in about 6 days after being bled down. Immediate action taken will be to shut the well in and perform diagnostics which will include tubing packoff testing, a MITIA and an IA DD test if the MITIA passes. The TIO prior to the IA being bled was 2600/2100/450. ConocoPhillips will follow up with the results of the diagnostics and what the next intention will be. Attached is a schematic and a 90 day TIO plot. Please note that in December the operator misentered the OA pressure. Please let me know if you have any questions. «2G-16 schematic.pdf» «2G-16 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/27/2008 KRU 2G-16 PTD 184-132 • • FW: 2G-16 (PTD 1841320) R of suspect TxIA communication Page 1 of 2 J Regg, James B (DOA) From: Regg, James B (DOA) Sent: Monday, March 03, 2008 2:32 PM~~~~ '~~~a~0~ To: 'NSK Problem Well Supv' Subject: RE: 2G-16 (PTD 1841320) Report of suspect TxIA communication Your request to place KRU 2G-16 back on water injection is approved as proposed. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophiliips.com] Sent: Monday, February 25, 2008 8:51 AM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 2G-16 (PTD 1841320) Report of suspect TxIA communication Jim, Here is a follow up with the results of the initial diagnostics that were performed on 02{15!08. The tubing pack off tests passed leading to believe the communication was not a result of the pack offs. The MITIA passed with the test data on the attached form. The IA was bled down for a drawdown test that also did not show signs of communication. The initia! TIO prior to the IA being bled were 291011790/425. The IA was bled down to 1060 psi and was monitored on / 02118f08 where the T{O was 2750111501350 and again on 02124/08 where the Tl0 was 2675f1175I350. ConocoPhiliips requests permission to place the well back on injection for a test period of 14 days in arder to monitor for further signs of communication. At the end of the test period, follow up results will be submitted and the well will be evaluated for the next plan forward. «MIT KRU 2G-16 02-15-08.x1s» Brent Rogers Problem WeIIs Supervisor ConocoPhiltips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ~la+G'~1~~1,~{~ ~~R ~ Cb' 2U~C From: NSK Problem Well Supv Sent: Friday, February 15, 2008 7:19 AM To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G-16 (PTD 1841320) Report of suspect TxIA communication Tom & Jim, 3/3/2008 FW: 2G-16 (PTD 1841320) R -qf suspect TxIA communication Page 2 of 2 Kuparuk water injector 2G-16 (PT 1320) was reported as having suspect T~ommunication. The IA repressures in about 6 days after being bled down. Immediate action taken will be to shut the well in and perform diagnostics which will include tubing packoff testing, a MITIA and an IA DD test if the MITIA passes. The TIO prior to the IA being bled was 2600/2100/450. ConocoPhillips will follow up with the results of the diagnostics and what the next intention will be. Attached is a schematic and a 90 day TIO plot. Please note that in December the operator misentered the OA pressure. Please let me know if you have any questions. «2G-16 schematic.pdf» «2G-16 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 3/3/2008 KRU 2G-16 PTD 184-132 T/l/O Plot - 2G-16 25ao 2000 1500 a 1000 500 0 JO 150 a E a~ 100 0 t v 50 0 • 01-Dec-07 01-Jan-08 u~-rea-u~ Date i • 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. 2 ~3~p~~~ FIELD /UNIT /PAD: Kuparuk/ KRU/ 2G-16 DATE: 02/15/08 c ~r ~ OPERATOR REP: Colee-AES ~~ AOGCC REP: ~/ , i Packer De th Pretest Initial 15 Min. 30 Min. Well 2G-16 T pe Inj. N "TVD 5,983' uuing 2,910 2,900 2,900 2,900 Interval O P.T.D. 1841320 Type test P c Test si 1500 Casing 1,790 - 2,400 2,380 2,380 P/F P Notes: Diagnostic MITIA OA 425 400 400 400 Well T e Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. T e test Test psi Casing P/F Notes: OA Well T e In'. TVD Tubing Interval P.T.D. Ty e test Test si Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. T etest Test si Casing P/F Notes: OA TYPE INJ 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 2G-16 02-15-08.x1s f~f ~~ Conc~ccrAhil~i~s Ataska, inc. 2G-16 • KRU 2G-16 API ' 500292116300 Well T e: --- _ tNJ An le r~ TS: -- .iti ae ai 7aa1 _ SSSV T e: TRDP Ori Com letion: 10/24/1984 An le TD: 37 de 7900 ~ Annular Fluid: Last W/O: Rev Reason: TAG FILL, PULL VLV SSSV ~ Reference Lo Ref Lo Date: Last U date: 7/26/2005 (1872-1873, `~ -- Last Ta : 7605 TD: 7900 ftKB OD:3.500) Gas Lift andrel/Dummy Valve 1 (1923-1924, OD:5.313) Gas Lift andrel/Dummy Valve 2 (38603861, OD:5.313) Gas Lift andrel/Dummy Valve 3 (5519-5520, OD:5.313) Gas Lift andrel/Dummy Valve 4 (67276728, OD:5.313) Gas Lift andrel/Dummy Valve 5 (7380-7381, OD:5.313) PBR (7421-7422, OD:3.500) PKR (7435-7436, OD:6.151) NIP (7452-7453, OD:3.500) TUBING (0-7465, OD:3.500, ID:2.992) SOS (7464-7465, OD:3.500) Perf (7545-7545) Perf (7549-7549) Perf (7577-7577) Perf (7580-7580) Perf (7608-7608) ~ _ Last Ta Date. 6/30/2005 Max Hole Anq_ le. 48 deq_ ~ 3700 _ _ _ _ _ ~ 'Casing String -ALL STRINGS ' Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 110 110 62.50 H-40 SUR. CASING 9.625 0 2910 2773 36.00 J-55 ' PROD. CASING 7.000 0 7848 6310 26.00 J-55 ~ _ _ Tub_in Strin TUBING _ g ~ __ --- - - -- - ~ ze ~ Si Top f i Bottom _ - TVD - ~ Wt -- de I Thread Gra ,!~n ~~ ~ ,'_ ~ ~)7_ ~ ~ ~ ! t~ Eli I?I' _ . Perforations Summary _ __~ T Interval TVD Zone Status Ft SPF Date T e Comment 7542 - 7545 6067 - 6070 A-5 3 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo a 7545 - 7545 6070 - 6070 A-5 0 5 9/30/1985 RPERF 0 de Ph 2 1/8"DresserBarKo 7545 - 7549 6070 - 6073 A-5 4 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7549 - 7549 6073 - 6073 A-5 0 5 9/30/1985 RPERF 0 de Ph 2 1/8"DresserBarKo 7549 - 7550 6073 - 6074 A-5 1 4 9/30/1985 RPERF 0 de Ph 2 1/8"DresserBarKo 7550 - 7552 6074 - 6075 A-5 2 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo ' 7552 - 7555 6075 - 6077 A-5 3 4 9/30/1985 RPERF 0 de Ph;2 1!8"DresserBarKo 7555 - 7555 6077 - 6077 A-5 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo - 7555 - 7556 6077 - 6078 A-5 1 4 9/30/1985 RPERF 0 de Ph~2 1/8"DresserBarKo 7565 - 7577 6085 - 6095 A-5 A-4 12 4 9/30/1985 RPERF 0 de Ph 2 1!8"DresserBarKo '` 7577 - 7577 6095 - 6095 A-4 0 5 9/30/1985 RPERF 0 de Ph 2 1!8"DresserBarKo i 7577 - 7580 6095 - 6097 A-4 3 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7580 - 7580 6097 - 6097 A-4 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7580 - 7584 6097 - 6100 A-4 4 4 9/30/1985 RPERF 0 de Ph;2 118"DresserBarKo 7584 - 7588 6100 - 6104 A-4 4 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo ' 7588 - 7592 6104 - 6107 A-4 4 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7592 - 7592 6107 - 6107 A-4 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7592 - 7593 6107 - 6107 A-4 1 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7593 - 7593 6107 - 6107 A-4 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7593 - 7597 6107 - 6111 A-4 4 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7597 - 7597 6111 - 6111 A-4 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7597 - 7598 6111 - 6111 A-4 1 4 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7598 - 7598 6111 - 6111 A-4 0 5 9/30/1985 RPERF 0 de Ph;2 1/8"DresserBarKo 7598 - 7605 6111 - 6117 A-4 7 4 9/30/1985 RPERF 0 de Ph 2 1/8"DresserBarKo 7605 - 7605 6117 - 6117 A-4 0 1 11/3/1984 IPERF 90de Ph 4"CarrierJumboJet 7608 - 7608 6119 - 6119 A-4 0 1 11/3/1984 IPERF 90de Ph;4"CarrierJumboJet 7611 761.1, 6122-6122 A-4___ 0_ 1 11/3/1984_ _ _IPERF 90degPh;4"CarrierJumboJet _ Gas Lift MandrelsNalves _ _ -- St ' MD ND Man Mfr M an Type V Mfr V Type V OD Latch - Port TRU - - Date Run Vlv Cmnt 1 1923 1917 MMH 3.5x1 DMY 1.0 BK-2 0.000 0 11!4/1984 2 3860 3414 MMH 3.5x7 DMY 1.0 BK-2 0.000 0 11/4/1984 3 5519 4598 MMH 3.5x1 DMY 1.0 BK-2 0.000 0 11/4/1984 4 6727 5464 MMH 3.5x1 DMY 1.0 BK-2 0.000 0 11/4/1984 5 7380 5941 MMH 3.5x1 - . DMY 1.0 BK-2 0.000 0 11/4/1984 Other lugs, esp., etc.) -JEWELRY De th TVD T e Descri lion ID 1872 1868 SSSV Baker'FVL' 2.810 7421 5972 PBR Baker 2.810 7435 5983 PKR Baker'FHL' 3.000 7452 5997 NIP Camco'D' Ni le NO GO 2.750 ' 7464 6006 SOS Baker 2.992 7465 6007 TTL 2.992 v3 ,' ~I J . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ? f¡(?1t '-,¡5(ù7 DATE: Monday, May 21, 2007 SCBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 2G-16 KUPARUK RlV UNIT 2G-16 \'ti\~\Ô'Y FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprY.J!3fL..--- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2G-16 Insp Num: mltJCr070521110429 Rei Insp N urn: API Well Number: 50-029-21163-00-00 Permit Number: 184-132-0 Inspector Name: John Crisp Inspection Date: 5/19/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. ~~II_~~~6~pelnj. ¡w ! !"-~ 5983. .L~_~8~~~..1820·· --I.. 1820 , P.T.D 1841320 TypeTest i SPT i Test psi! 1500 j OA 100. 100 : 100 1 _..:.::..:.:::l~.__ .... .__~__~_ .__ _.. ~ Interval 4YRTST P/F /' P J&2-- Tubin~ i 2550 I 2550 I 60 Min. .- 110 I 1820 i _~--.--:... ._n~ 110 i 1840 I '1 2550 1. 2550 .j 255~_~.___ Notes: 8.3 bbl's pumped for test. Operator was not requested to test 1A with pressure higher than State required pressure. Due to amoumt of fluid pumped for test PI Supervisor will make Pass/fail determination. Water injection well trend charts WTe requesred from Operator for Supervisors review, no charts received @ this time. ¡..... SCANNED JUN 0 6 2007 Monday, May 21, 2007 Page 1 of I RE: 2G-16 (184-132) e e Subject: RE: 2G-16 (184-132) From: NSK Problem Well Supv <n1617@conocophillips.com> . . . Däte:.Wed, 08 Feb2006 18:30:28 -0900 ',<: :. To: Thomas Mau%~er <tdJt~~\Under@admin:stå~è.ak.ú~.:. .< ..~ Tom, Not much work has been done with this well. Attached is a work summary. Let me know if you need any more detail MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 ;:"". ·r·i¡".IA!I,,'.r.ÞIt::.~....'; . ,- C1VMU't]fl'tl&,tk Fl:. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, February 08, 2006 1:23 PM To: NSK Problem Well Supv Subject: 2G-16 (184-132) Marie, I just reviewed the 404 filed for the weld repair on the bradenhead threads. Looks like that issue has been resolved. I also looked at the well file and aside from a diagnostic MIT from about 2 years ago, there isn't anything in the file since a 404 filed May 25, 1994 regarding installing a injection valve. Is it possible to get a "high level" summary of the activity on the well since 1994. I am not sure if "high level" is the correct description for the summary. Jerry had pulled such a summary on several wells last year I believe. I understood that pulling such a report wasn't a lot of effort. So long as it isn't a hassle, could you pull such a report so we can make the file complete? Thanks in advance. Tom Maunder, PE AOGCC Content-Description: 2G-16 Work Summary 02-08-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 2/9/20067:43 AM 2G-16 Report Printed: 2/8/2006 Well History Daily Operations Report Date 1/29/20066:00 1/28/200616:00 1/26/20066:00 1/21/20066:00 1/20/20066:00 1/19/2006 6: 00 1/16/20067:00 1/11/20066:00 6/30/2005 6:00 6/29/2005 10:00 2/5/2004 12:00 e e Last 24hr Sum UNABLE TO SET FRAC SLEEVE @ 1872' RKB DUE TO RESTRICTION IN TBG @ SSSV. PULLED WRP @ 1815' ELM. UNABLE TO SET FRAC SLEEVE. IN PROGRESS. MITOA (POST BH WLD) -PASSED N2 PURGE FOR 3 PASS BH WELD AND TANKO HEAD REMOVAL BH WELD REPAIR PREP. PREP FOR BH WELD. DRILLED AND TAPPED CONDUCTOR. INSTALLED PURGE JEWELRY ON CONDUCTOR AND OA. BLED IA DOWN. FILLED OA FL TO 3' BELOW BH. 2.78" WRP PLUG SET AT 1815 FT. PLUG TAPPED- GOOD. CCL TO MIDDLE ELEMENT 12.8 FT, STOP DEPTH 1802.2 FT. BOTTOM NOT TAGGED. SSSV FLOW TUBE NOT COVERING FLAPPER. ATTEMPTED SET ISO SLEEVE. NO SUCCESS. CONFIRMED BAKER FVL NOT LOCKED OUT. SET ISO SLEEVE @ 1872' RKB. TAGGED @ 7605 RKB, EST. 3' FILL. MEASURED BHP @ 7577' RKB: 5103 PSI. PULLED SLEEVE @ 1872' RKB. [Pressure Data, SSSV Work, Tag] PULLED MCX INJ VALVE. ATTEMPTED DRIFT TBG, SET DOWN IN BAKER FVL SSSV. IN PROGRESS. MITIA - passed CPAI Rep Senden, Ty Brake, Jared Reilly, Evan Loveland, MJ Loveland, MJ Loveland, MJ ODell, Brian Fitzpatrick, Chuck Re: 2G-16, 2X-ll e e S~bject: Re: 2G-16,'à>r( <,",' \. <6'~ -\ ~ ~.. From: "NSK ProblertD¥clISupv" <ri1617@ppco.com> ' . .. .. Date: Fri, 25 Oct 2002-12:1:3:22 -0800 fp::: 1'torIflfauri~er<tom ~ rq~~~¥~@adB~taté1a.k. us> , 'L \ t'Y Ô ~ ':~;rr\ 1) ,,':: Tom: 2G-16 is a WAG well on gas injection. The current tubing pressure is 3500 psi, so there is 1000 psi differential. The bleed record shows about one bleed per month on the IA, which is nowhere near our problem frequency of 2 times per week. Under the operating criteria I inherited, up to 3000 psi is allowed on an MI injector on the IA. On water service this must be reduced to less than 2000 psi. maintains a goo etween the IA and OA. I s on the list to check out the packoffs. x month trend of the wellhea In is IA, white is OA, yellow is tublng . 1 (Embedded image moved to file: pic20485.pcx) Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <tom maunder@admin.staLe.ak.us> 10/25/2002 11:08 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Jim Regg <jim regg@admin.state.ak.us>, Mike Bill <mike bill@admin.state.ak.us> _._.___·.__.....·...._.._m._..................._m_._m.._ m.....m......................._.._._.....~_.._.._..._m....m..mmmm.m Subject: 2G-16, 2X-11 Jerry and Pete, I was just looking at Chuck's SSV reports for 2G and 2X pads. I'd appreciate your looking into the pressure history of the 2 wells I have noted. 2G-16 is a WAG well that according to the pressure values Chuck recorded shows an IA pressure of 2500 psi. That seems high to me. Is there any communication problem?? No "internal waiver is noted". On 2X-11 the IA and OA pressures are nearly equal. No "internal waiver is noted". Thanks in advance for looking into the history of these wells. Tom Maunder, PE AOGCC (See attached file: tom_maunder.vcf) Content-Type: application/octet-stream Content-Encoding: base64 ¿ r"'~~'\ \t.t.o\d 2/8/2006 11 :56 AM lof2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION e e FEB 0 7 2006 A1eska Oil & Gas Coos. Commission Anchorage REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. ShutdownD Perforate 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 184-1321 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21163-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 140' 2G-16 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7900' feet true vertical 6351' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 2770' 9-5/8" 2910' 2773' PROD. CASING 7708' 7" 7848' 6310' Perforation depth: Measured depth: 7542-7556',7565-7611' true vertical depth: 6067-6078',6085-6122' Tubing (size, grade, and measured depth) 3-1/2" , J-55, 7465' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'FHL' pkr= 7435' sssv= SSSV SSSV= 1872' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS 8Fl FEB 0 8 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation NA - well SI NA NA Subsequent to operation NA - well SI NA NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact MJ Loveland / Marie McConnell Printed Name Ma ie McConnell Title Problem Well Supervisor Signature ~~/Ø~æ?/ Phone 659-7224 Date /-1r¡-è6 Form 10-404 Revised 04/2004 O· · R···I G I f\' A L ,..,t ,J ¡ . " " Submit Original Only e 2G-16 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 1/16/2006 Set WRP plug in tubing @ 1815' to secure well for weld repair 1/21/2006 Removed top half of conductor Tanko head. Repaired Braiden head thread leak with 3 pass seal weld. 1/26/2006 MITOA to 1800 psi passed. See attached MITOA report for details. 1/28/2006 Pulled WRP in tbg at 1815'. " WELL NO.: MECHANICALeTEGRITY TEST CMIT) FORMe 2G-16 I DATE: 11-26-06 SWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITOA 1 i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 11800 1 psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel R d II W IIh d P b f d d . T t WELL TYPE: ecor a e ea ressures, e ore an urine¡ es. START TIME: 11 000 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T 1 PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING 100 100 100 100 T IA 50 50 50 50 PASS OA 0 1800 1740 1730 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING T IA / 9-5/8" OA /13-3/8" 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME:! PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA / 9-5/8" OA /13-3/8" 3 COMMENTS: rSC COMMENTS: * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. []] -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: ID. Sauvageau / B. Rogers cc: PWS 6/3/00 ~e¿q, 7-1 b I ó~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us ' ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. KRU 2G-16 02/05/04 Arend / Brake NA 0 P Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0 = Other (describe in notes) @CA~~E[ r[~ 1 ~ 200lJ, MIT Report Form Revised: 06/19/02 2004-0205_MIT _KRU_2G-16.xls ARCO Alaska, Inc. Post Office Box 100360 Anchorage, A~aska 99510-0360 ~i~efephor~e 907 276 May 23, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 2G-16 Variance (sssv) 2W-07 Repair Well (K valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (arch only) FTR052396 (w/o atch) RECEIVED MAY 2 5 1994 Alaska OJlf Gas Cons. Commission Anchorage AB3B-6003-93 ?4? ?t;()3 .... STATE OF ALASKA ALA,SKA OIL AND GAS CONSERVATION COMMk~.,ION REPORT OF SUNDRY WELL OPERATIONS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well_ Alter casing _ Repair well_ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance 1. Type of Request: 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 123' FNL, 87' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1210' FNL, 3651' FEL, Sec. 6, T10N, R9E, UM At effective depth At total depth 1267' FNL, 3901' FEL, Sec. 6, T10N, R9E, UM 79OO 6350 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 140.,, 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-16 9. Permit number 84-132 . ~,,z/,_ 10. APl number 5o-029-21163 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) feet Effective depth: measured 7 7 6 5 true vertical 6 2 4 2 feet Junk (measured) feet Casing Length Structural Conductor 1 1 0' Surface 2 8 7 6' Intermediate Production 7 8 1 4' Liner Perforation depth: measure 7542'-7556' true vertical 6067'-6078' Size 16" 9-5/8" 7" Cemented 202 Sx CS II 900 Sx Perm. E & 370 Sx Perm. C 400 Sx Class G & 250 Sx Perm. C , 7565'-7605', 7608', 7611' , 6085'-6117', 6119', 6122' Tubing (size, grade, and measured depth) 3 1/2", 9.3#/ft., J-55 with tail @ 7464' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 7435'; SSSV: Baker 'FVL' @ 1872' Measured depth 115' 2910' 7848' True vertical depth 115' 2765' 6310' RECEIVED 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MAY 2 5 1994 Alaska 0il & Gas Cons, Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 0 2119 0 2250 psi 0 1995 0 2250 psi Tubing Pressure 4050 psi 4050 psi 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Water Injector__ Oil ~ Gas ,, Suspended Service WAG INJECTOR 17. I hereby/~rtify that th~foregoing is true and correct to the best of my knowledge. S.i~ned Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY / TIME 1015 ./~ ~0 MDG _II~G DESCRIPTION OF WORK CONTRACTOR/KEY PERSON 14E5 - OPERATION AT REPORT TIME ~ COMPLETE [] INCOMPLETE FIELD EST: $ AFC/CC ~I O / I_5' ACCUMULATED COST LOG ENTRY PAGE 1 OF /%:0 155_5 ! CHECK THIs BLSOK IF SUM~AR~NTI~:'~ B~CK Repeal °F °F miles AR3B-7031 A~t~ska O~t & Gas Cons. Anchnrag¢, Wind Vel. Si e REMARKS CONTINUED: ACCUM. SERVICE COMPANY SCA # DAILY TOTAL , . ~. ~ .... TOTAL FIELD ESTIMATE ' A /~/¢ ¢0, /~_~ ¢¢ Kuparuk Well 2G-16 Status: WAG Injector API #: 50-029-2116300 ADL Lease: 25667 Permit #: 84-132 Surface Location: 123' FNL, 87' FEL, Sec 6, T10N, R9E, UM Top Kuparuk: 1210' FNL, 3651' FEL, Sec 6, T10N, R9E, UM TD Location: 1267' FNL, 3901' FEL, Sec 6, T10N, R9E, UM All Depths are MD-RKB (RKB= 32', Rig: Doyon 9) Pad Elev: 108' Tree: McEvoy Gen III 5000 psi I Casing and Tubing Detail: Size Weight Grade Depth.. 16" 62.5# H-40 110' 9-5/8" 36# J-55 2910' 7" 26g J-55 7848' 3.5" 9.3# J-55 7465' TT Tubing Jewelry: lem Twe DEI~ SSSV*-- B,4ax-FVL 2.81" 1872 PBR Ed~ 281" 7421' ~ B,4aII:HL 3111' 7435 1~ CanmD 2.7g' 745~ *NOTE: Locked out and Otis MCX w/5/8" orifice & BR Latch installed. Fish in Hole: · None Misc Data: Vol to Top Perf: Tbg Volume: 7" Csg Vol: 66 BBLs 0.0087 BBL/Ft 0.0383 BBL/Ft Hole Angle across Kuparuk: 38 deg. Max. Hole Angle: 48 deg. @ 3700' Notes: Fill tagged @ 7621' on 7/22/88 / Fill @ 7621' · ///////~ · -- PBTD: 7765' MD 6242' TVD L Gas Lift Mandrels: Stn Demh Mandrel 1 1923' MMH 2 3860' MMH 3 5519' MMH 4 6727' MMH 5 7380' MMH Last Change: 1985 ?? Arco Alaska, Inc Well History Dates: Spud: 10/16/84 Completion: 11/04/84 Frac (Fail): 3/23/85 Waterflood: 11/16/85 WAG: 3/09/87 Valve Port 1" DV 1" DV 1" DV 1" DV 1" DV RECEIVED MAY 2_5 ]994 /~iaska, Oil & Gas Cons. Commission Anchorage Perforations: Interval Zone Ft 7542-7556' A5 14 7565-7605' A4 40 4 7608' A3 1 1 90° 761¥ A3 1 1 90° SPF Phase 4 0° 0° Perfed A: 11/04/84 Dresser 4" Guns Reperfed: 9/30/85 Dresser 2-1/8" Gun Revised:. 05/23/94 By: CLP ( ARCa Alaska, Inc. Post Office Box i 00360 Anchorage, Alaska 995HI-036C Telephone 907 27S 12-15 ( ~~ ~~ April 20, 1 994 \~ '/; '?X Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. Well 2G-16 Action Variance (SSSV) If you have any questions, please call me at 263-4241. Sincerely, rðW P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments FTR042095 (w/o atch) RECE\VED APR. 2 2. 1994 Alaska Oil & Gas Cons. Commission Anchorage AFi3B-6003-93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance X Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Ipc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 123' FNL, 87' FEL, Sec. 6, T10N, R9E, UM At top of productive interval 1210' FNL, 3651' FEL, Sec. 6, T10N, RgE, UM At effective depth At total depth 1267' FNL, 3901' FEL, Sec. 6, T10N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 79OO 6350 feet Plugs (measured) feet RKB 140 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2G-16 9. Permit number 84-132 10. APl number 50-029-21 163 11. Field/Pool Kuparuk River Field/Oil Pool Effective depth: measured 7 7 6 5 true vertical 6242 feet Junk (measured) feet Casing Length Structural Conductor 1 1 0' Surface 2 8 7 6' Intermediate Production 7 81 4' Liner Perforation depth: measure 7542'-7556', true vertical 6067'-6078', Size 16" 9 -5/8" 7" 7565'-7605', 6085'-6117', Cemented 202 Sx CS II 900 Sx Perm. E & 370 Sx Perm. C 400 Sx Class G & 250 Sx Perm. C 7608', 761 1' 6119', 6122' Tubing (size, grade, and measured depth) 3 1/2", 9.3#/ft., J-55 with tail @ 7464' Packers and SSSV (type and measured depth) PKR: Baker 'FHL' @ 7435'; SSSV: Baker 'FVL' @ 1872' Measured depth 115' 2910' True vertical depth 115' 2765' 7848' 6310' RECEIVED /~,PR 2 2 1994 0il & Gas Cons. Commission 6nr. hnrana 13. Attachments Description summary of proposal X Detailed operation program _ Install sub-surface, spring controlled safety valve in a WAG injection well. 14. Estimated date for commencing operation 15. Status of well classification as: APRIL 1994 Oil Gas 16. If proposal was verbally approved Name of approver Date approved Service WAG INJECTOR B(~'~"~k-~¥~h Suspended __ 17. I hereby/~ertify that th,eI foregoing, is.true and correct to the best of my knowledge. Signed '~~ Z,~/~~ Title Senior En,cjineeer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test I Location clearance I Mechanical Integrity Test _ Subsequent form require 10-~ IApproval, No. , Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signect By David W. Johnston Commissioner Date ,(//,.7,, .~--,/ Y '~' SUBMI'"'T IN TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 2G-16 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to install a downhole, spring-controlled, injection valve in Injection Well 2G-16. This injection valve will act as a one-way check valve allowing downward injection of water and gas, while preventing upward flow of the injected fluid. The injection valve is capable of preventing uncontrolled upward flow by automatically closing if such an event should occur. This valve does not require a hydraulic control line from the surface to the subsurface valve. Its fail-safe design as normally-closed provides the same level of protection. The sub-surface safety valve (SSSV) in Kuparuk Well 2G-16 has failed closure tests and has a control line that can not hold pressure. The suspected leak was discovered on 4/6/94 and attempts to fix the problem have been unsuccessful. Installation of the injection valve would alleviate the problem. Attachment 2 shows a schematic of the proposed injection valve. RECEIVED Gas Cons. C0rnmission Al~ch0ra§e Attachment 2 Injection Valve Schematic TOP SUB ORIFICE ~SPRING DE SEAT Otis MC Injection Valve SEAT INSERT FLAPPER VALVE AND SPRING ASSEMBLY ARCO Alaska, Inc. Post Office bye. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 16, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field- on the Well Action Date Performed 1L-1 Convers 1L-7 Convers 1Q-2 Convers 1Q-7 Convers 1Q-11 Convers 1Q-13 Convers 2B-5 Convers 2B-9 Convers 2C-1 Convers 2C-3 Convers 2C-6 Convers 2C-8 Convers 2D-2 Convers 2D-7 Convers 2D-11 Convers 2D-14 Convers 2F-1 Convers 2F-2 Convers 2F-1 3 Convers 2F-1 4 Convers 2G-3 Convers 2G-3 Convers 2G-5 Convers 2G-7 Convers 2G-10 Convers 2~-12 Convers 2G-16 Convers 2U-3 Convers 2U-4 Convers 2U-7 Convers 2U-16 Convers 2W-2 Convers 2W-4 Convers on on on on on on on on on · on on on · on on on on · on · on on on on on on · on on on · on · on · on o on · on · on · on 11/18/85 11/18/85 11/17/85 11/17/85 11/17/85 11/17185 11/23/85 11/23/85 11119185 11/19/85 11119185 11/19/85 11120185 11120185 11120185 11120185 11121185 11/21/85 11121185 11121185 11/lq185 11/lq/85 11114185 11114185 11/lq/85 11114185 11114185 11/16/85 RECEIVED 11/16185 11/16/85 11/16/85 11/15/8~k~ 0il & 1 1 / 2 2 / 8 5 ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichlieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 4. Location of Well SURFACE LOCATI ON' T10N, RgE, UM 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 84-132 3. Address 8. APl Number P. O. BOX 100:360, ANCHORAGE, ALASKA 99510 50- 029-21163 123' FNL , 87' FEL, SEC. 6, 5. Elevation in feet (indicate KB, DF, etc.) 1 40' (RKB) 12. I 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name KUPARUK R I VER UN I T 10. WeLl Number 2G-1 6 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 November 14, 1985 Kuparuk well 2G-16 was converted from a producer to a water injector well as part of the full field waterflood conversion effort. Water is being injected into sand. the "A" 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~./~,.,~ ~--C~.~, Tit~e_ KUPARUK Date The space below for Commission use OPERAT IONS COORD I NATOR Conditions of APproval, if any: 12118185 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 ARCO Alaska, Inc. Post Office Be )360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed on the 2C-2 Perforate 9/28/85 2G-13 Reperforate 9/28/85 2G-14 Reperforate 9/28/85 2G-15 Reperforate 9/30/85 2G-16 Reperforate 9/30/85 If you have any questions, please call T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) me at 263-4212. ARCO Alaska, Inc. is a Subsidiary of AllantlcRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Na~Op?'t°*r S~uu t~ KA I NC 7. Permit No. · · 8q.-132 3. Address 8. APl Number P. O. BOX 100360, ANCHORAGE, ALASKA 99510 50- 029-21163 4. Location of Well SURFACE LOCATION- 123' FNL, 87' FEL, SEC. 6, T10N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 140' (RKB) 12. I 6 . Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 2G-16 11. Field and Pool KUPARUK RIVER FI ELD KUPARUK RIVER OIL POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] 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 September 30, 1985, the "A" sands of Kuparuk well 2G-16 were reperforated for production. After testing the lubricator to 3000 psi, the well was shot with a wireline conveyed gun. Interval (MD). 7542'-7556' (4 SPF) 7565'-7605' KEC_FtVED Alaska 0il & Gas C0ns~ C0[~lhTll$sJori ~nchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use KU PARU K Title OPEP~ATi ONS COORD i NATOR Conditions of Approval, if any: Date 10/9/85 Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 23, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive · Anchorage, AK 99501 Dear Mr. Chatterton: Attached is our notice of intention to perforate Kuparuk field wells 2G-13, 2G-14, 2G-15 and 2G-16. If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD:ps:File Attachment (In Triplicate) RECEIVED sEP2 198, Alaska Oil & Gas Cons. Commission Anchorage &C]/'~t"t AI~eU~ Inr le q _(:;i,hqil~i~rv (lf AllantlcRichfieldComJ~any STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL)~( OTHER [] 2. Name of Operator ARCO Alaska, ][nc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 123' FNL, 87' FEL, Sec. 6, TION, R9E, UM 6. Lease Designation and Serial No. ADL 25667 ALK 2588 5. Elevat~.~n f[~6iPd, ic~S,lDoF4?tc.) 7. Permit No. 84-132 8. APl Number 5o- 029-21163 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2G-16 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 2G-16 be perforated for production. Procedures call for the well to be perforated with a wireline conveyed gun under a lubricator. Proposed Intervals (MD)' 7544-7558' (4 SPF) 7566-7611' ANTICIPATED START DATE' 9/25/85 Alaska 0il & Gas C~w,.~ Cti~,,n~s:~u,~ Ancl~ora!;~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~~ ~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/23/85 . Conditions of Approval, if any: Approved by COMMISSIONER ~pproved Co~py ~eturne~d ..... By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office L._,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 September 20, 1985 Mr. L. C. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Street Anchorage, AK 99501 Dear L. C. Smith: Per our conversation on September 4, 1985, ARCO Alaska, Inc. proposes to convert 110 production wells to water injection to implement fullfield waterflood of the Kuparuk River Unit. As discussed a single "blanket" sundry notice (form 10-403) has been completed for all well proposed to be converted to water injection. Individual subsequent sundry notices will be filed when the actual well conversions occur. As stated in form 10-403, well conversion to water injection will occur in two primary stages. The first stage will convert approximately four wells per drillsite to achieve a nine-spot pattern. First stage conversions are expected to be completed by approximately 10/15/85, prior to waterflood startup. The second stage of conversions will convert approximately four additional wells per drillsite to achieve a line drive pattern. Second stage conversions are expected to be completed mid-December to January 1986. I would like to express my thanks and appreciation to the Commission in working with ARCO Alaska, Inc. in this area. If you have any questions please call me at 263-4212. Sincerely, T. M. Drumm Kuparuk Operations Coordinator cc: J.F. Beatl TMD:ps:013 RECEIVED S E P 0 0,~ ~ ,3~s Cons. Commission Ar~cho,~a~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany - 6 - 7 - 8 2D- 2 - 4 - 5 - 7 -10 -11 -14 -16 - 2E-10 -12 -13 -14 2F- 1 - 2 - 3 - 4 -13 -14 -15 -16 2G- 1 - 3 - 5 - 7 -10 -12 -16 2U- 3 - 4 - 7 -11 -14 -16 2V- 2 - 4 - 5 - 6 - 7 - 8 2W- 2 - 4 - 5 - 8 - 9 MARK:0092 100 96 95 84-152 151 126 143 101 99 159 161 84-230 211 196 197 83-183 188 187 190 156 159 172 177 84-118 139 80 85~ 106 128 132 85- 6 7 2O 40 84-247 249 83-161 165 176 179 180 186 85- 16 12 84-191 212 219 20979 20970 20974. 029-21177 21176 21157 21169 21135 21134 21183 21185 029-21246 21227 21213 21214 029-21058 21063 21062 21065 21032 21035 21048 21052 029-21150 21165 21119 21124 21140 21159 21163 029-21269 21270 21283 21303 21262 21264 029-21037 21041 21051 21054 21055 21061 029-21279 21275 21208 21228 21235 25653 25658 25658 25657 25656 25644 25643 25655 25644 25655 25642 2580 12/15/85 '! 10/15/85 " 12/15/85 2579 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 2584 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 2584 12/15/85 " 12/15/85 " 12/15/85 " 12/15/85 2583 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 12/15/85 " 10/15/85 " 10/15/85 2582 12/15/85 " 10/15/85 " 10/15/85 " 12/15/85 " 10/15/85 " 12/15/85 " 10/15/85 2575 10/15/85 " 12/15/85 " 10/15/85 2574 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 2575 10/15/85 " 10/15/85 " 12/15/85 2581 10/15/85 " 12/15/85 2573 10/15/85 " 12/15/85 " 12/15/85 " ~/15/85 r, .ECEIV STATE OF ALASKA ALASK/~ .... 'L AND GAS CONSERVATION Cr~'~MISSION SUNDRY NOTICES AND REPORT ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, AnChorage, Alaska 4. Location of Well N/A 99510 5. Elevation in feet (indicate KB, DF, etc.) N/A 12. 7. Permit No. see attached 8. APl Number 5o- see attached 9. Unit or Lease Name Kuparuk River 10. Well Number see attached 6. Lease Designation and Serial No. see attached Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF' 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool (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 X~ 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). Pursuant to form 10-403, it is proposed that the attached list oil^producing wells in the Kuparuk River 'Field be converted to water injection. The conversion will occur in two stages. The first conversion_ to a nine-spot pattern will occur approximately 10/15/85. The second conversion to a line drive pattern will occur approximately 12/15/85. Injection will be into the A and C sands. sE? 2 o 19" 5 AJaSKB 0il & Gas Cons. commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ::~, /~&~-~--~ ~,~z,z--~''~,~-~"-~ Title Kuparuk Operations Coordinator Date The space below for Commission use 9/18/85 Conditions of Approval, i~ any: Approved by Form 10-403 Rev. 7-1-80 Approved Copy By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, Inc Post Offi' 3ox 100360 Anchorage? Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-05-85 - TRANSMITTAL NO:5332A **CONTINUATION ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECOKDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TR3LNSMITTED RECEIPT AND SEQUENCE OF 2G-9,'"' PBU 2G-9 ~ PBU 2G-ii'"' PBU 2G-16--'~SBtiP 2h-l~ PBU 2h-lJ PBU 2U-l'' 'C' SAND PBU 2U-1-~ END 'C' SAND PBU 2W-7 -'f 'C' .S~D PBU 2W-7 / 'C' SAND PBU 2W-7.~ 'C' S~D P~U 2X-ll/~' PBU 2X-ll/ 'C' SAND PBU 2X-11 / 'C' SAND PBU 3C-5 -~ BhP & M1SC. 3C-7/ BHP & MISC. 3C-8 / BHP & MISC. 3C-9~-' BHP & MISC. 3C-!0 fBHP & MISC. HERE%~ITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RETURN ONE SIGNED COPY OF THIS TRANShITTAL. EVENTS FRC~ ~ELL SERVICE ~EPO~TS/PRESSURE DATA 08-22-85 & ~I$C. 08-21-85 08-19-85 0~-19-85 08-25-85 08-24-85 08-23-85 08-24-85 08-17-85 08-23-85 08-22-85 08-24-85 0~-25-85 0S-2b-85 08-29-85 08-30-85 08-31-85 08-09-85 08-10-85 KU PARUK WEL 3C-12/ STATIC 3C-10~- STATIC 3C-9 /- STATIC 2Z-16-- 2Z-15 '- STATIC 2Z-14.~ STATIC 2Z-13"' STATIC 2X-4'~ PBU 2X-4~' PBU 2U-l'~ 2A- 13-~' STATIC IR-10 "~ STATIC IR-9 / STATIC L PRESSURE REPORT ENVELOPE FACES: 'A' SAND 07-24-85 'A' SAND 08-10-85 'A" SAND 08-09-85 07-21-85 'A' SAND 07-17-85 07-20-85 'A' SAND 07-17-85 08-12-85 08-13-85 08-24-85 08-25-85 'A' SAND ~8-15-85 'A' SAND 0~-14-85 CAMC 0 OTIS OTIS OTIS OTIS OTIS OTIS CA/,]CO CAMCO OTIS CAMCO CAI~lCO CAMCO ~ECEIPT ACKNO%~LEDGED: ~PAE* B. CURRIER CHEVRON* % & M* DISTRIBUTION: DRILLING ~. PASnE~ L. JOHNSTON EXXON ~OB I L* PHILLIPS OIL* NSK CLERK J. RATSMELL* DATE: ",-,..:. -: .- '-:.'-.'.':, . · STATE OF ALASKA*" · SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Post Offi 3ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DAT ~.': 09-05-85 TRkNSHITTAL NO: 5332 FJ~TURN TO: TRANSMITTED kECEIPT AND SEQUENCE OF ARCO ALASKA, INC. KUPARUK_ OPERJ%TIONS ENGINEERING RECORDS CLEkK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 HEREWITH ARE THE FOLLOWING ITEMS. RETURN~ ONL SIGNED COPY EVENTS PRESSURE DATA OF THIS 1H-3 "' PBU 03-07-8 5 2A-I"' 'C' SAND PBU 08-03-85 2B-12,'" 'C' SAND PBU 08-01-85 2C-U 'A' SAND PBU 08-16-85 2V-2 ' 'A' SAND PBU 07-27-85 2V-5 '~ 'A' SAND PBU 06-25-85 PLEASE ACKNOWLEDGE TRANSMITTAL · SEi':UENCE OF EVENTS FROM WELL SERVICE lA-8 ~ bBHP & [qISC. 0 lA-5 PBU '& MISC. lA-3'~''' PBU lA-3--- PBU lb-2-~ 'C' SAND Pi~U lb-2-" 'C' SAND PBU lb-5 / STATIC TEMP.LOG 1E-21'~_. RUN BHP & MISC. 1F-5 PBU 'A' & 'C' bAND (ISLTD) 1F-5 / PBU 1G-15-~' 'C' SAND PBU 1G-15"- 'A' 5AND PBU & MISC. 1G-15/ 'C' SAND PBU 1R-10,-'~BHP & MISC. 1P,-9/ BHP & MIbC. 1R-12 ? Blip & MISC. 2A-1/ 'C' SAND PBU 2A-1'/ 'A' SAND BHP 2A-1-'~ 'C' SAND PBU 2A-13.,- BHP & MISC. 2B-13~ 'A' SAND BHP 2B-13'" 'C' SAND PBU 2B-13~ DATA FROM BHP SURVEY 2D-13~ 'C' ~AND PbU 2C- 8" PBU 2G-16" PBb 2G-16/ PBU RLCEIPT ACKNOWLEDGIiD: BPAE D~ILLING B. CURRIER L. JOHN~JTON CHEVRON £'~UI3IL D & M NbK CLERK REPORTS/PRESSURE 8-22-85 08-14-85 08-12-~5 08-11-85 08-05-~5 08-06-85 0~-15-~5 08-03-85 U8-18-~5 08-17-85 08-10-85 0~-06-85 08-09-85 0~-15-~5 08-15-85 0~-19-85 08-04-85 0~-04-85 08-03-85 0~-25-85 08-02-85 08-02-85 08-03-85 08-01-85 08-17-85 08-17-85 08-1~-85 BUTION: W. PAStiER EXXON DATA PHILLIPS OIL J. k~TP2,~ELL *PLEASE NOTE--DISTRIB- UTION CONTINU~JD ON . ,. NEXT PAGE. /~, DATE: ~"~ ~ ~"~/ SOhiO UNION " < (.'l ,/, r, K TULIN/VAULT "',: ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc Post Office x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 09-09-85 TP, ANS~ITTAL NO: 5337 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK A?O-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 /~ TRkNSMZTTED hEfLEWI'~'~ ARE THE FOLL~ING IT~v~S. ~EA~E ACKNOWLLDGE RECEIPT AND R3~TURN ONE SIGNED COPY OF THIS TRANSMITTAL. lA-3 ~'- 8/11/85 1G-15 / 8/.9-10/85 1Y-8 -/ 8/8/85 1Y-12j 8/11/85 2G-16 / 8/17/~5 2U-1 -.--' 8/23/85 PBU "C" $~.~DS PBU "C" SANDS FLO%~ING PRESSURE GRADIENT "A" & "C" SDS FLO~ING PRESbURE GRADIENT "A" & "C" SDS FLOWING PR~.'SSUkE ~RADI~:NT & PB0 PBU "C" SANDS RECEIPT ACKNO;~LEDGED: BPAE* B. CURkIER CHEVRON* D & H* DRILLING L. JOHNSTON MOBIL* NSK CLERK DIbT~iOUTION: ~. PAShER EXXON PHILLIPS OIL* J. RATHMELL* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanbcRichfieldCompany ARCO Alaska, Inc .... Post Office Box J360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 10, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Well Completion Reports Dear Mr. Chatterton: Enclosed are Well Completion Reports for the following wells: 2C-16 2D-10 2D-13 2G-16 1Q-8 2U-6 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L41 Enclosures RECEIVED Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany :. ..... STATE OF ALASKA .... ALASKA ..AND GAS CONSERVATION C(- ,vllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,. 1. Status of Well Classification of Service Well OIL E~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .... ,,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-1:~2 "~; Address 8. APl Number P. 0. Box 100:~60, Anchorage, AK 99510 50- 029-2116:~ ,, 4. Location of well at surface 9. Unit or Lease Name 12:~' FNL, 87' FEL, Sec.6, T10N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1210' FNL, :~651' FEL, Sec.6, T10N, RgE, UM 2G-16 At Total Depth 11. Field and Pool 1267' FNL, :~901' FEL, Sec.6, T10N, RgE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River Oil Pool 140' RKB ADL 25667 ALK 2588 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/17/84 10/22/84 11/04/84 N/A feet MSLI 1 , , , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7900'MD,6350'TVD 7765'MD,6242'TVD YES [] NO []I 1872 feet MD 1500' (Approx) 22. T~pe Electric or Other Logs Run DIL/SFL/GR/SP, FDC/CNL/Cal, Gyro, CBL 23. CASING, LINER AND CEMENTING RECORD ..... SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5~ H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" ~6.0~ J-55 Surf 2910' 12-1/4" 900 sx Permafrost E & ~70 sx Permafrost C 7" 26.0¢ J-55 Surf 7848' 8-1/2" 400 sx Class G & 250 s~ Permafrost 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) 7611 ' 7592' 7549' ~-1/2" 7464' 74~5' 7608' 7589' 7545' w/1 spf, 90~ phasing 7605' 7588' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7598' 7584' - 7580' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7597' 7577' See attached Adde~dum dated 5/2/85. 7593' 7552' - 7551' 27. N/A PRODUCTION TEST Date First Production ~ Method of Operation (Flowing, gas lift, etc.) I ,,i '~ate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 GRUg/WC27 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME ' GEOL©GIC M/~R:KERS TRUE VERT. DEPTH Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand MEAS. DEPTH 7480' 7486' 7532' 7689' 6017' 6022' 6058' 6182' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Date 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". ADDENDUM WELL: 10/29/84 3/25/85 4/03/85 2G-16 RU SOS, rn CBL & gyro. Att to frac well. Pmp total of 178 bbls gelled diesel. Abort frac due to high treating pressures. Flowed well after acid breakdn. Pmp'd 148 bbls gelled diesel in 3 stages. "A" sand frac gradient 0.75. Drilling ~uperintendent ~ '~ ~,~ ~-,"-~.~ Date Alaska Oit & Gas [;,~:m.~,~:.,~,,,~,,~.'~'"~"'"~":"'?m~ ADDENDUM WELL: 10/29/84 3/25/85 2G-16 ,RU SOS, rn CBL & gyro. Att to frac well. Pmp total of 178 bbls gelled diesel. Abort frac due to high treating pressures. Drilling ~uperintendent RECEIVED MAy 0 ~ ~985 Alaska Oil & ~as Con~ AnChorage' Commiasio~ ARCO Alaska, Inc, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 D A 'T' E: 0.5 -(') 7 -- ~ 5 TF;~AN,~'MIT'f'AI_ NO:5~ 78 F~I'ZT[JF<N TO: AI:~CO AI..A,~I<A, INC, ATTN: RECOF(D3 CLERI< A'f'O-11 tSB I::'.O. BOX 100360 ANCHORAGE, Al< 995i0 ~~~ TI:~AN3'MITTE~) i..IEI:~ENII'H ARE 'ri.il: I:=OI...I..ONINC~ ITEM,S', I:'L. EA~'I: ACKNOWLEDGE RECEIF'T AND RETURN ONE SIGNED COF'Y OF' TI'ii,? 'FF~AN3'HIT'FAL, F:' I N A L F:' R I N'T'S CBL.' $/3CI'iI_UMBEIRG E:F~ iE-iS'-< i0'"'30-84 RUN ~:~i 7300-789U 2 C - i ~ '""" 02 - 05 -' 8 .':'5 1:~ [J lq .,,. ...... ,'_~ .:)':" .>': .... ~'~ 0 -' "'? ~. ''~ 6 ,-."~ :.::C-t 4 ~.~- 02-06-85 RLJN :,",:2 3800-6030 2C--t 5 ~ 02'-08--~.'~ F;~[Ji'~I :11:t '5450-7f 2(") ::!(.",-'t 6 ~ 02-08-85 RLJN ¢:t 'i"t 75-"8'280 IX' "I:' ::.!G-I 6 ~ t 0-27-84 RtJN :,"'t .~o..>0-7'?,~>6 '2L.I.-t 5 ~'"// 02-'t 0-8.5 RUN :ll:t 6400--6985 · '.'..!W'-9 "'"" 01-0t-85 RLJN ~:t '.:~;700"7'i'86 "~W-'J t ~ O1 "0''>''°~': F<I. JN '"'t ':>S66-6640 2. W-1 :,..N,'" Ot-.0'2-85; I:~:UN :=:t 2640-797t ':~W-- t 6~ Om-Oi -85 RUN .... t 43° .. ,:~ 6 - 6982 ">X-J 4,,'" I t -.i 7-84 RUN .... t .4[5<26-7(374 · ~.. I:(ECE I F'T ACK NOWi...F'"I>GFI>: .... : ......... ii':i: ::: :i: i:i': i:i [i :i: :: ::i i:i 7 ............ B F'A [.:: ~ D F;.' 2:1 t.. :1: H (:;. -.- B I... W. F:' A ,? I-1E R B, C U R,r-;,' I E R L, J,3 I-.1N 3' T 0 N E X X 0 N. C H E: V R 0 N M 0 B ]'I F' H I I..I... I F:',S' (:) l L I> a M .x. N 3' I< '.::: L 1::: 1:;,' 1< '-' BI .... J, R A'f'l"l M 1:: L. L DATE: S 0 H I O / S E: U N :[ t3 :' ~ · x-I<. 7'U - I N/VA U L.'['-F I L_M ARCO Alaska, Inc. Post Office : 100360 Anchorage, ,.,aska 99510-0360 Telephone 907 276 1215 7'0' ARCO AI..A.?:-'I< A, l Nr_'. ATTN' RECORD.~ CL_ERK A '1" 0 --- 1 t t ~7 f': P.O, BOX 100.360 Ai',!C..HORA~E, Al< 99""~ i" is:.: A 1.~ ,'].' ?'i I .... ,-n ,,EI,'ITH ARE T t,:: ..... I'iE~::'. ..... ... ~' F:'l._.r.: A ~.'r-: ":'EcEIr"T AND F:,'I:.:"r'LIF,:N ONE .?I(.;i'..!t---D COF'Y r"nllENr"E OF F'¢Ei',~I-:? ' F:' 1... U I D I D 4 / 2 / 85 F'IIMF'_ gELLED L,.IATER. BATCH FRAC 4/t4/°'~, ,._, F'BL! 4/6-7/05 FLUID ID 4/6/85 .~ T~'-.~TICBF1F' -4/t,/°~',..,_. ':'/8 "':" 4/3-_,, '- V ," 5 : ..... 'I._ £LIR EY 4/5/,0 · FLOWING ~,,--I F' 4/2/85 i..- ..;. ~ :1. '7 F:'AG[: 2 0F' A C I'.; i'.,! C)L,.J 1... I::: D G E "ECEI F:'T ACK U.O!.4LEPGED ' D I ,::.. T R l B U T t 0 i'4 · L.L.,"]i-,.!G W. F'A2'HER J Ln.. !-I U. £ '¥ 0 H E X X 0 iq MO2-IL F' I-! ]: 1.. !_..,"[. F' ~ OIL CLERK J, RATFIMELL ARCO Alaska. Inc. is a Subsidiary of AtlantlcRichfieldCompany RECE/t.,'ED A]~ka Oil & Oas Cons. O'mmi;Won~ DAlE .......... U N I 0 N K . T I~L Z I,~/V A U L_ T ARCO Alaska, inc.~-- · Post Offir tx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 !:? A/'.,! ,'? H .'[ T 'T .r..;; ;!) iE CIE I .,":' T A i'-..! ..r.., !;;; [;.! U l:..-. N C: E 0 F' T F;' A ix~,'.T H .~ T' T' A I... i'.,! 0 .... ' t .:~. .... P A (.'; IZ 2 0 F' E \,; E N 'i" 5' ' i y'"".4 FI...U ;r. D ]:D 4/2/85 / E- 'i 6 F' LI ~-!F'. 5 E L I... E D W A T Ii..'. R B A'T C H F.' IR A (.'; 4 / i 4 / in .... 8 F'BIt .... , o-;/8.,' ~L.G .... ~ 6 F I.. U ]; ..P.., l D 4 ! 6 ,./8 ..~-, C-- "'-", ,':¢'T A T I C: BHF' .¢../6/8~:.,, 2, ~-.-2. F' r"' U,... 'I/~-~'~,~''*-~o~, ¢%?.~.----~,_. ~,,'I.. el Ir-;'VFY FLOW:rNc BHP ::: t.J Fi: F:: :i: F:.: iR · /R 0 i',.! ? ]1 ,'."? T R iF. B U T I C) i'-4: Lt ~.:,~ ..r,, .-., ..... .~ ,"! E:, E ;4 X 0 N F'H ]:!...L..TF..:"~ O..L..T J, RATHi'IEI...L ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldOompany ...- , ARCO Alaska, Inc. Post Office r_,,.,x 100'360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215. r.~ T'T"N ' F;: E C 0 F;: I) .,? C L. IZ F: I'( A'TO-.-1 ~ i''-' ~:' F', O, ir.~OX 'i 00360 A N C 1--I 0 R'A G r:- ,-"~ I( A' .... ..... · ...--.--_;. i (.) i ...... t..l . ._ - .... ,-,~.I,:F.{ ]:T-I-.I FiF~'F: -I"HE' F FILl F.: E- T U F:N r9 iJ. I!? ,iF :!: ~. i,! C ri:, C 0 F' Y £ C l.l L. (..I ~ i ? E' i';: (.~ F: F:: , C Y 13 E. q L 00 K D :[ L,,'-3' F L-- E¥ F: F D [?.'Ci":~ L- G R RAW Fit, Cv:C lq L - g R - F'O F.: O D]:IL/~tFL-GR EDC/CNL-GR-RAW FDC/CNL-G R-- F' r3 R 0. F;tUN ,:~:i 27,i RUN ~:i ,'2 ........ .- RUN .., -- ~' ,::., 0 ..; RUN I' -' .-2 ,.., I ~.~ L., _/ F:L!N ~i ?">~-~'r~ -?":,"~:' . i3,,'h '1" E ' ' ' ARCO Alaska, Inc. Post Office i~.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 25, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2G-16 Dear Mr. Chatterton: Enclosed is an addendum to the 2G-16 Well History to include with the Well Completion Report, dated 12/13/84. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU6/L53 Enclosure RECEIVED MAyo 1 1985 Alaska O~t & Cas Cons. Anchora!le Comml~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, In Post Office r~o× 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 December 14, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2G-16 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. I have not received the portion of the 2G-16 well history covering the completion details. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU3/L08 Enclosures RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ,--- ~-- STATE OF ALASKA ' - ALASK. _ AND GAS CONSERVATION ~, ivllSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-132 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21163 4." Location of well at surface 9. Unit or Lease Name 123' FNL, 87' FEL, Sec.6, T10N, R9E, UM Kuparuk River Unit At Top Producing Interval ~ L©C/~Ti~,~'~'~-~ ~ 10. Well Number 1210' FNL, 3651' FEL, Sec.6, T10N, R9E, UM -:x~Fl~,~ 2G-16 At Total Depth iSurf'- ~ 11. Field and Pool 1267' FNL, 3901' FEL, Sec.6, T10N, R9E, UM i[%H._~i Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 140' RKB ADL 25667 ALK 2588 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore I 16. No. of Completions 1 0/17/84 10/22/84 11/04/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 7900'MD,6350'TVD 7765'HD,6242'TVD YES [] NO []I 1872 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/SP, FDC/CNL/Cal, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 24" 202 sx Cold Set II 9-5/8" 36.0# J-55 Surf 2910' 12-1/4" 900 sx Permafrost E & ~'~70 sx Permafrost C 7" 26.0# J-55 Surf 7848' 8-1/2" 400 sx Class G & 250 s~ Permafrost 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) 7611' 7592' 7549' 3-1/2" 7464' 7435' 7608' 7589' 7545' w/1 spf, 90° phasing 7605' 7588' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7598' 7584' - 7580' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7597 ' 7577 ' N/A 7593' 7552' - 7551' 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I I Date of Test Hours Tested PRODUCTION FOF~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I "~i'ow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE R[CEiVED Alaska 0il & Gas Cons. Anchorage Form 10-407 GRU3/WC02 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand M EAS. DEPTH 7480' 7486' 7532' 7689' TRUE VERT. DEPTH 6017' 6022' 6058' 6182' FORMATION TES'~S Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS W~ll FH$~_ory~ Oyr_nscop~ .c~,,rvc'y (? cnpi~s) 32. I hereby certify that the foregoing is true and correct tO the best of my knowledge Associate Engineer 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 1~-~7 AtlanticRichfieldCompany '~' Daily Well History-Initial Report Instructions: Prepare and submit the "Initial Raiment" on the first Wednesday after a well is spudded or workovar operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. Districtm]_aska county or Parish Field Lease or Unit Kuparuk River Auth. or W.O. no, Tit e AFE 901113 I State North Slope Borough Alaska I Well no. ADL 25667 2G-16 Drilling Doyen #9 API 50-029-21163 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate I Spudded Date and depth as of 8:00 a.m. 10/17/84 10/18/84 10/19/84 Complete record for each day reported 10/17/84 Hour 0530 hrs A,R.Co's W,I. Prior status it a W.O, 16" @ 110' 150', (40'), Drlg Wt. 9.2, PV 21, YP 43, PH 8.5, WL 13.4, Sol 5 Accept rig @ 0100 hrs, 10/17/84. NU diverter sys. 0530 hrs, 10/17/84. Drl 12¼" hole to 150' 56.24% Spud well @ 16" @ 110' 2355', (2205'), Drlg Wt. 9.8, PV 24, YP 32, PH 8.5, WL 11.6, Sol lO Drl, DD & surv 12¼" hole to 2355'. 1445', Assumed vertical 1728', 9.3°, S76.9W, 1727.07 TVD, 22.86 VS, 5.20S, 22.35W 2111', 19.7°, S71.5W, 2096.69 TVD, 121.41VS, 29.20S, 118.17W 9-5/8" @ 2910' 2934', (579'), Prep to Tst BOP Wt. 9.4, PV 16, YP 12, PH 8.0, WL 10, Sol 8 Drld 2355'-2934', CBU, pmp pill. POH to 1300, circ hi vis sweep. C&C hole for csg, POH, LD BHA. RIH w/73 jts 9-5/8" 36# J-55 HFERW BTC csg, set w/FS @ 2910', FC @ 2827' Rn 11 B&W KK-4 centralizers. Howco pmp 5 bbl H20, tst cmt In to 3000 psi, ok. Mix & pmp 30 bbl Sepiolite @ 10.9 ppg, 6-1/2 BPM. Mix & pmp 900 sx (316 bbl) PF "E" @ 12.3 ppg, 8-1/2 BPM. Mix & pmp 3V0 sx (63 bbl) PF "C" @ 15.6 ppg, 5 BPM. Pmp 5 bbl H20. Switch to rig pump @ 10 BPM. Lost rtns for ±20 bbl. Had cmt rtns w/105 bbl displ; i10 bbls of cmt rtns to pit. Bmpd plug w/2150 stks w/1500 psi. CIP @ 2312 hrs 10/18/84. ND riser & 20" Hydril. RU cmt In, rn 1", do 50 sx PF "C" top job. MU starting hd, NU BOP. PU tst jt, set tst plug, prep to tst BOP. 2285'MD 23.5° S72.0W 2258.47'TVD 185.46'VS 49.26 S 179.00W 2601'MD 33.5° S74.5W 2356.18'TVD 336.21'VS 92.71 S 323.38W 2893'MD 45.8° S78.5W 2761.01'TVD 521.95'VS 136.21S 504.56W 10/20/84 9-5/8" @ 2910' thru 7850', (4916'), Drlg .10/22/84 Wt. 10, PV 13, YP 13, PH 9.5, WL 5.6, Sol Ii Tst BOPE. PU BHA, RIH to FC, circ, tst csg to 1500 psi; OK. Drl plugs & FC; no hard cmt below FC. Wsh'd to FS w/o finding hard cmt, CBU. DO FS, CO to 2934', drl to 2944', CBU. Conduct formation tst to 12.0 EMW. Displ spud mud in hole, drl 2944'-3058', POH. MU NaviDrl Mach II, RIH, drl & surv to 7850 . 3150 , 47.6°, S78.5W, 2937.27 TVD, 707.78 VS, 173.50S, 687.84W 3684 , 47.7°, S77.7W, 3298.18 TVD, 1100.92 VS, 277.60S, 1067.40W 3967 , 46.0e, S65.0W, 3491.73 TVD, 1307.37 VS, 343.63S, 1263.03W 5252 , 43.3°, $68.0W, 4406.06 TVD, 2206.77 VS, 695.20S, 2094.46W 6415 , 46.3°, S74.7W, 5260.13 TVD, 2995.56 VS, 925.80S, 2848.92W o 7360 ~ 39.7 , S74.5W~ 5944.79 TVD~ 3645.84 VS~ ll01.00S~ 3475.75W Theaboveiscorrect 7652', 37.5°, S77.4W, 6172.99 TVD, 3827.58 VS, 1145.23S, 3652.47W 10/30/84 Dr±lling Super±ntendent ;iiil:Pn°i°'mcl~:dr~P~asr8a~i~an~udaai;~edic~:r°inbUlti0'~ ~ C Et V E D AR3B-459-1-B ~aska 0il & Gas Cons. g;o~,~mJssion Anchorage Number all dally well history forms consecutively as they are prepared for each well. Pag~ no. ARCO Oil and Gas Company,~.,'~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District County or Parish State Alaska North Slope Borough Lease or Unit Kuparuk River ADL 25667 Field Alaska Well no. 20-16 Date and deptll as of 8:00 a.m. 10/23/84 10/24/84 Complete record for each day while drilling or workover in progress 9-5/8" @ 2910' 7900', (50'), C&C hole f/csg Wt. 10, PV 9, YP 8, PH 9.5, WL 6.4, Sol 11 Drl 7850'-7900', CBU, 15 std short trip, C&C hole f/logs, POH. RU Schl, RIH w/DIL/SFL/GR/SP/FDC/CNL/CAL, hit bridge @ 4974' RIH to TD, rn'g logs. (DIL/SFL/GR/SP f/7884'-2914'; FDC/CNL f/7865'-7250'.) POOH, RD Schl. RIH, rm & wsh 7632'-7900', CBU, LD 7 jts, short trip to 6400'. Rm & wsh last 7 jts to TD, C&C hole f/csg. 7" @ 7848' 7765' PBTD, Inj't mud dn 7" x 9-5/8" ann 10.3 NaC1/NaBr in csg C&C hole f/csg, POH, LD DP & BHA. RIH w/7" csg, rn 197 jts, 7", 26#, J-55 HF-ERW BTC csg + mrkr jt. RU cmt head & circ hole. Pmp 5 bbls wtr, tst cml in to 3000 psi; OK. M&P 65 bbls Sepiolite spacer @ 11.0 ppg/4 BPM. Drop btm plug. M&P 400 sx Cl "G" w/l% CFR-2, 5% KCl & .3% Halad-24 @ 15.8 ppg/6 BPM. Drop top plug, pmp 5 bbl wtr & 292 bbl 10.3 ppg NaC1/NaBr. Bump plug w/3000 psi. CIP @ 2300 hrs, 10/23/84. Held press f/15 min. Ck flts; held OK. RD cmt head, ND BOP, set slips, jet out top 120' csg. Instl tbg head, tst flange & pack-off to 3000 psi. WOC. Inj drl mud dn 7" x 9-5/8" ann. (FC @ 7765', FS @ 7848'). RECEIVED Alaska Oil & Gas Cons. Commission Ap, chorage Signature ~ For form pre~"~r~tion and distrib,l~i~-n see Procedures Manual Section ~0, Drilling, Pages 86 and 87 JDate 10/30/8~it'e Drilling Superintendent AR3B-459-2-B Number all daily well history forms consecutively Page no as hey are prepared for each well, ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "F!!~al. I~~t't'' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold "Final Report" shou d be submitted a ~;~ell Operat OhS are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report com~ end representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish Slate Alaska L .... North Slope Borough Al::ka Field or Unit no. Kuparuk River ADL 25667 2G-16 Auth. or W.O. no. T I e AFE 901113 Drilling Doyon #9 API 50-029-21163 Operator ARCO Alaska, Inc. A.R.Co. W.~.56.24% Iaband°nmentlc°st~Otal centernUmberprior°fof wellSthistO pluggingwell(active and°r reactive) on this Spudded or W.O. begun Date IHour Prior status if a W.O. Spudded 10/17/84 / 0530 hrs Date and depth as of 8:00 a.m. 10/30/84 Complete record for each day reported 7" @ 7848' 7765' PBTD, 7900' TD, WO prod compl 10.3 NaCl/NaBr in csg Fin injecting mud and 200 bbls fresh water down 7" X 9-5/8" annulus. RU Howco. Downsqueeze w/250 sx permafrost "C" and 56½ bbls arctic pack. CIP @ 0845. Prep to move to 2E pad. RR @ 1015 hrs, 10/24/84. Old TD Released rig 1015 hrs New TO 7900' 10/24/84 RECEIVED Alaska Oil & Gas Cons. gommission Anchorage PB Depth 7765' PBTD Kind of rig Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Resen/oir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, spa X length Choke size T.P. C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signature .,~ I Date I For form preparation anc~istribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 10/30/84 Title Drilling Superintendent AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each we . Page no. 3 DlvlllO~ of AtlantlcRIchfleldCompsny $ UB-$ URFA CE DIRECTIONAL SURVEY n-~ UIDANCE F~ ONTINUOUS r-~ OOL Company Well Name Field/Location , ATLANTIC RICHFIELD COMPANY 2G-16 (123' FNL~ 87,' FEL~ S6~ TION~ R9E~ UM) KUPARUK, NORTH St. OPE~ ALASKA Job Reference No. 69691 Logged By: PEPPEL Date ,. NOV- 26-1984 Computed By: STEVENS Fr~,h INC. K,~C I ,~! I< F. t4: ~.PCFt AI, ASKA, TNC. 15,~'IF, h;P[)f,ATE:f~ %/AI.(iFS r) E P T P I.) A 'f F: 1 cc - N i! 'U - f,14 10¢ , 9.0(1. 300, nO 40n , 500,00 600. oO 700. ~00, 900. O0 t-r!.k t,,VEN 10o Vb, F[' 1000, L 1 O0, OC L3OO.OU t 400, nO t60~.nu 1700. no [~On,O0 [nO0,O0 ~OOt%, f~O 7100.oo 2200. O0 ~ 40 ,"., 250n. ~70n. OO 2000.00 F F E'[' f) K (] / 1 PAGE DATE OF SURVFY! 28-0C'['-84 KELLY RuSHTr4C F'bFVATION: ~]NGT N FiE:R: PEPPEI[, OF [¢EASI~kEb (; NFCTA~GIILAK CF~iiRD T N a, TF:5 [1'¥ Nr)RTH/S[ItJTH F:A,ST/WEST 00 F E Fi 't' F' [':F: 7' r~. 0(, O.()0 0.00 N 0,O0 -0,0'-~ 0,80 0,16 S 0,15 -0,.52 0,07 1,07 S 0,8~ -n,R3 0.17 1,~5 S i,51 -0.07 O,Ug 2,82 S 1,94 -O.O9 0,12 3.66 S 2,23 -o.q() 0.10 4,44 S 2.39 -0,~3 0,,19 5,1.6 S 2,55 -1.3~ t),O& 5,46 S 3,23 -?,R() t,), :j 0 5,27 S ~,66 9CC9,9~ ,u"~q.q5 0 47 ~,.: %'1 46 I~ -4,2t, (3, 1099.94 q59,04 0 42 1 l°~.g~ lr~5o,q~S 0 3! H ~o 32 F -6,'~o O, 1209,93 1154,03 ~) 3n r~ 3;S 56 F -7.09 O, 1']49097 1950.o2 O 22 ~' 31 20 F -7.67 O, ]499,97 t'~bq,O2 () 23 ~,'47 ~ W -7,96 1, 1 bO9.2'7 1 SSO. 27 1 !7o'1.'/7 1657.77 11 5! S ~4 q 1894,9& 1754,06 lb 1 19c)(~,~ iRSO.q,{ 1'1 4R $ f~2 11 9; 217~.'2f~ '2034.7~ PI 3n ~, 72 54 W 7271.54 21.31.54 2o 1 S 73 34 W 2361.9n 222!.q0 ?n ,14 S 7~ 24 w ~449.77 2~U~,7"1 ~0 q F, 75 l'~ W 2534,b2 2~94,62 3:{ 4~ ~ 76 12 W ?t)lS.b7 24'1[,q'1 ~'7 1~ S 7'1 14 W 2'765,{,~ 7624,65 45 t2 g 79 15 W 140,00 FT HORTZ, DiST FEET 0,00 1.~5 2,46 3,42 4,29 5,04 5, '16 ~,~4 7.03 4% ~,7;~ S 6.02 F 7,06 31 3,U2 S 7,00 F 7,97 O? 2,96 S '1,64 Fi b,20 21 2,19 S ~,17 F ~.45 28 l'bf) S B,b8 E 8,73 7~ 1.08 S 8,73 F 8,79 75 1,In S 5.57 £ 5,6R e5 1.~1 S 5.02 W 5,34 40 6,~1 $ 45.3] W 45.84 10 11,06 S 73,05 3'2 1'7,06 S 104 ~! 66 2'1.32 S 138:10 98 38.34 S 175,06 06 50,13 S :,1 6.22 37 62,t) 1 $ 262.26 04 75.08 S 313,51 7~ 8.9,0] S 370,20 q9 102,45 S 432.32 4n 115.81 S 409.7~ ~1 129,15 S 571,76 20 142.0'/ $ 644,5~ 31 156.54 S 717,24 25 173,17 S '7R9,01 27 194.34 S 659,42 ~3 217.7~ S 929.67 1~ 241.47 S 999,95 12 265,30 S 1~70,26 34 2o0.21 ~ 1140.00 ~4 31') ~)~ S 1206,88 73,8R lOb,ltl 140,78 179,21 221.95 269,b] 3~2.5~ 38U,76 444,24 512,9g [)EPARTUHE AZI MU'tH DEG Id 0 0 E :5 43 22 g S 40 57 E $ 37 39 g $ 34 27 g S 31 19 E 828 17 g S 26 !5 g S 30 35 E S 41 26 E 851 48 E fi 61 24 E $ 68 51 E $ 74 58 E $ 79 25 E S 82 56 E ,5 7R 48 g $ 70 8 W 5 80 11 ~ S 81 27 W S 81 23 w $ UO 45 w $ 78 48 w $ 77 38 W S 76 ~b w S 76 34 W S 76 25 W 5 76 28 W $ 76 40 w 5 76 57 W SRO.t6 S 77 16 w 66o.13 S 77 31 w 734,17 S 77 41 w ~n'/,To S 77 37 w 8Hl,l? 5 77 15 W 954,H4 S 76 48 W O2~,oq S 76 25 W ~02.~ S 76 4 W 1176.J6 S 75 43 w 248.34 S 75 I 1 w Cf'):.iPlITA'I:/OI.~ UAl'I<: iO-~'UV-~4 ADCO AI~ASKA, 2G-.1~ TNC. AI, ASKA D A E I,~!'I'FI~,POI,ATt<r', VAI U~<5 l:r)R ~,~Vt<l~ 100 FEE'i' UF V t< P T l C n t<P '1.' 400o,nO 3509,?q 33bO. 4!00.00 351a0,03 4?On.r)O 3650.72 351o. 430(',, f)(; 4400,no 3702,~? 4'~00,0(~ !864,14 3724. 4600,0() t93b,'t~ 379~. 4700.0(2 4000,O0 407~. 17 4qOO.OU 4149.0$ 4aug. 72 44 52 g 6g il w 1450,68 75 44 41 $ 6~ I1 W 1529,91 t)2 44 35 5 6~ 13 W 1600,01 t4 44 Il $ 68 10 t~ 1670.04 48 44 31 $ ~8 11 W 1739,q6 78 44 2fl $ 68 14 W 1.~oq.q] 17 44 24 ~ ~.~ 16 W 1. fl70.gl 6b 44 20 S h~.~ 26 W lq44,60 PAGE 2 Ti< [iW SI)RVFY: 78-0C:r-84 LhY BI..ISHI't,iC FbF. VATION: 140,00 FI' NC;INFER: PEPPEI, 0 E P T H bO00. O0 a271 ,.)0 .lnb!, 5100.O(.) 42o3.17 415't. 5700,o0 4365,39 4725, 5300.00 44]7,94 4297, b6(}O,O0 4655,b2 4515. 570N,OU 4729,44 45H0, 5gUO,OO a879.46 4'73~, 30 44 10 S 6b 34 w 201o...9'3 17 4.½ 5] S 6R 54 w 2naH.6b 39 43 4! g 69 25 W 2157,74 3~) 43 q{ S 71 47 W 2295,4t 7b .~3 23 .q 71 54 W 2]64,43 44 .12 ~ $ 72 3q W 250n.~7 q7 al 2! S 73 ~ W 4'b aC 5~ $ 7.1 .11 w bOUO,OU 4955,U6 ~?()O.oO 6300.00 516~,05 6400,00 6500.0(~ %306.27 6&00, (){: 437b. 6700.n1_) 5444,26 O~OO,Ou 5514.10 6900,0(') It L A R 0 LI T h COORDINATES MORIZ, DgPARTURE EAST/WEST DIST, AZIMUTH FEET FEF'r DEG ~IN 1.3] 348.13 $ !272,92 0.83 375.tt0 $ 1338,49 0'b5 402,013 S 1~04.18 0,15 428,20 S 146~,57 0.22 454,28 $ 1534,76 0..47 480,34 S 1599 93 0,!? b06.37 $ !664~99 0.03 532,3o S t730,10 0,15 55fl,J.~ S 1795,14 0,17 5~4,14 .,~ 1860,14 O,IP 609,bg S 1975,05 (.),t)O 034,97 S 19~9,~3 ,).17 059,53 S 2054.49 U,7a b~3,47 S 2119,01 0.4o 70U,03 S ?184.,10 (),hq 727,.13 S 2249,75 1,0o 748,02 S 2314,8~ 0,34 '169,10 S 7379,15 0,37 807,50 S ?b05,70 t,34 B?b.t'~q S 756~,57 1,47 b44,26 $ 7ot4,74 0,'14 862,81 S 2703.22 (),34 881,60 S 2772,2? o.a2 9o0.01 S 2h41,70 u.20 919, 14 S 2911,b5 0.47 9S7,34 S 3051 45 U,t)P 97b.48 S 31~(.)~b8 0,~7 ~o2,8R S 31~9,31 1.%~ lO10,12 S 32~7.13 1,uq 1C77.14 S 3.J23,71 1,74 104.:1,9.1 .q 3~R9,17 1,40 !O59,.~1 S 3452.90 t,4~ 1075,1° S 3515,40 U.'!9 1103.08 .q 0,84 ll~n,t>l S ~b05,41 0.on 113(),21 S ~7~,t.b7 O,()n 1143.'7H S 3813.94 1.~19.67 ~ 74 42 W 139(i) 24 S 74 19 W 1.i60:60 S 74 1 ~ t53U.04 S 73 45 W 1.600,58 S 73 30 w 1670,48 $ 73 17 W 1740,29 S 7~ 5 W ~810,16 S 72 53 w ~879,97 $ 7~ 43 W ~949,70 S 7~ 33 W w 201.9,29 5 72 25 W w 2157:'16 6 72 12 w w 222~;51 S 72 7 ~ W 2295,~7 $ 72 5 w w 2364,4] 5 72 4 W W 2432,97 $ 7~ 4 W W 250U,38 $ 72 5 W W 2567,04 S 72 b W W ~b32,On $ 72 8 ~ 2008,03 8 72 10 , 2'160,70 $ 72 13 w 2837,57 S 72 17 ~ 2909,02 S 72 21 ~ 79~1,00 $ 72 24 w 3053,46 5 72 28 w 3125,92 $ 72 31 ~ ~1~,10 5 72 34 ~ .1269,b9 $ 72 38 ~ 3340,29 $ 72 42 ~ 3410.16 $ 72 46 ~ 3478,80 S 72 49 ~ 3546,30 S 72 52 W 3b12,00 S 72 56 w 367b,13 S 72 59 ~ .1738,41 $ 73 3 ~ 3'799,76 S 73 7 ~ 3860,42 ~ 7~ 11 ~ 3971.09 ~ 73 14 ~ 39Rl,'lfi S 73 18 ~ D k, lP '1' ~ 1_') ~ t-' T ~ D b: P T i) A'I'F: lq-i',ii~V-;i4 t-::Vi<~; 1C0<.~ t/F:le, SFC 1:: .lnt; S t?.:v ~;ll 1 ~FF:T Di,dqllO0 0 . 45 3,10 0,ql '1,33 ~),1~ 3,34 1,5~ -4 . '1 ?, ~ fi 5t.~3.~7 1~19,t~ 201. q.23 269R,nl 3400,R4 PACE I')A'FK t.;F' SL. tFvF~.'. 2B-(JCT-~4 K~;I,UY n, bSHT~,tG FL, FVA'I'TON= 140,00 FT f,, F: ~. $ U R AFCTA,"! O, 11, 129, 348, 1010. E 13 D k.. P T <,.; IJ b .~ h COLiRDTi'4ATEc. o HORIZ, f' E [< T F E f 'r DE, PARTLIRE AZIMUTH DEG ~IN N 0 0 g $ 51 48 g $ 81 23 w S 77 16 w fi 74 42 ~ S 72 10 w $ 72 46 w KIIPAIRllK J HTFkPi,I,i~,Tt~D VAI,uF2 ['(IR hVEI'! 1.()fl '1 R b F DEPTH I)F~T.h VERT]Ct~I, bEVIATIP,,'.,' ATI~UTt~ q40.05 IO40.o6 I 140, n7 I 1-! t.,, on 1240.o7 124C.o0 1340.0'1 134U,00 1440,o~ lq4o,un 1540.n6 lb4C..O0 1640.30 !04(),0n 1741 ,71 1R43,79 1~40,On [)AT~; OF SUR~,Et: 28-0C'1'-B4 K~/I,[,¥ BUSHING FbEVAI'ION: 14U,O0 FT Er'J(;IkF~.R: PEPP15I, 5 E C T [ r': 0 . 0 (, O -n.27 -0.9(.! .-N.Oq -n.85 -0 , q 1. -1, 1 P.U(;LF(; i~ FC!"A N (;ti i, A I~' SkVER[T¥ [')E~/1 O0 FL;F'i~ C 0 d R D 1 tq A T E 5 EAST/WESt FI:lET 0.o0 t),uO .N 0.00 t),O1 0,00 N 0,00 0,07 0.49 S 0,44 0.15 1.39 S 1.15 0,()7 2,30 S 1,69 0,07 3,16 S 2,07 0.13 3,98 S 2,31 0,17 4,'/4 S 2,~4 1,07 5, .t 't S 3,77 -3.41 0.1~ b,Oq -4.7q u,4A 4.40 -S. Ri.. 0,!6 3,44 -7,34 0,17 1,93 -7.85 0.12 1,3q -7.52 3,1~ O,9g -! ,&(; 3.77 1,22 11 .4~ .t,97 2,5° 3! ,44 3.23 4,BR b7.C;8 3, .~, 3 [~.92 8o.1(, 3,54 13,5n 124.70 1 .O1 22,05 164.6t'. 2.57 34..,t7 ?10.77 J.13 4'1.2o ?h~.l .~ 3.15 61,.17 ~ZS.1~ 4,10 7~.54 ~9~.4 I. 3. t3 q3, Ih 4 B*;. R t-, ~,()7 1! 1,0o %90.53 u. Sg 130,.10 69q.al 0. ,i la 150.o3 ,c.. ~lOn.'t9 2. 12 174.j7 S O17.~ 0.52 20o,~6 S 1027.q7 O.ln 242,2~ S ll.t~,P5 2.44 277,9~ S lPqR.~2 2.34 318,8% 134R.O2 2.()0 .j~0,44 1440.a3 0,71 .~oB.o7 1%47.ql 0.20 434.90 1646,2q 0,50 471 5.24 t),47 7,2P 7.86 b,35 8,23 2.08 .31,48 51,b5 ~9,30 123,70 1.61,94 205,77 256,80 J17.01 3~8.b5 474.81 57~.56 '1o3.36 h07,37 10O2.1q 1107.15 12Ob.j6 !394.28 ~4Rb.27 1577,~3 HOKIZ, PIST. FEET 0,00 O0 2,86 3,'17 4,60 5,33 b. O0 6,61 DEPARTURE AZIMUTH DEG ~IN N 0 0 E N 90 0 E $ 42 17 g $ 39 42 E $ 36 21 E S 33 14 E 830 4 g $ 27 13 E $ 26 45 E :5 34 49 E 703,02 8 77 37 W 812,20 $ 77 36 w 920.92 $ 77 0 ~ lU31.05 $ 76 24 ~ 1141.50 ~ 75 54 . !24'1.';R S 75 11 ~ 1350,24 b 74 tl ~ 1449,9q S 74 3 ~ lb4~.be S 7~ 41 ~ 58,34 S 81 12 W 90,32 S 81. 24 W 125,70 5 70 32 W 165,57 ~ 77 59 ~ 2!1.11 $ 77 4 , 263.90 S 76 ]b ~ 37b,12 S 76 25 ~ 399,b6 $ 76 31 ~ 4~7,bl S 76 50 W bg3,o~ $ 77 17 ~ 7.~1 S 45 49 g 7,82 S 55 47 g 8,05 S 64 43 E 8,29 S 71 19 g 8.57 $ 76 58 E 8,81. S 80 5b g 8,29 S 83 8 g 2,41 S 59 29 E 11,53 6 77 2 W 31,85 S 81 14 W AI;'Cfl ^i.0A~KA, TiOC. 2C.' 10 NORTH ~T:I]PIC, AhASKA t nA'r~: ()F SL, RVE~: 28-OCT-84 K~I,,bY B[JSh[NG F[,EV~I,~ION~ 140,00 FT IN'I'F:I~PLi[,ATI:~D VAI,tiF,& t'¢)~ hVEN I ()O F't:.;Er !iF SIJB-~EA DEPTH IEA~511RFt_,, V~ii?J,C'AI, Vt<P'I~TC, Ab DEVTATII'~ A?.I&~IITt~, 4606o'~4 4746,~5 4o40,U0 4R86,~1 4140,0n 5026 5164~P~ 4340,u0 4?On,nu 43 44 5307.~5 444O.U~ q ~()~,oO 43 29 5~41.01 4540.Qo 44t)o. Ou 43 5578.&5 4640.Un 4500.00 43 5 5714.~5 47a(),00 46()o.n0 a2 4 5847,93 484(,.0o 4700.0() 40 54 7381.26 594o.,uo bR()O. 0(; t9 ~6 7500,41 604(). un bqon.n(} t7 5q '1~36,05 614U.0~ f, nun. O(~ t7 26 7701.95 f124d. ()c, t, lOO.aU '~7 26 7R87.01 ~34d,UO r, 2oO. 0(~ ~'1 26 7qO0.O0 6349.00 f. St.)q. 6 (~ 37 26 I, F'G M T N Vk, PTTCt~I, D;I(;!~EG k[~';CTANG!.ILAk COUROI~ATES HORIZ, DEPARTURE 5ECTJ.,ON SEVERITY ~uARTti/Sf)UTH EAST/WEST DIS't, AZIMUTH FF'ET T~EC/1()0 FEET FEFT F~;ET DEG ~tN S A~ ll W 1744.4U S a8 tr-, w & 6~ 24 !'* 1°40,19 $ 6~ .t~ w 2o37.~5 $ ~9 17 W 2133.50 S 69 57 w 222~.46 S. 71 56 w 2t23.7~ S 72 ) W 241fl.36 S 72 41 w Y. 7j 2~ w 0,13 U. !4 O,lq (), 15 U, 42 O, HO 0.15 1.11 0.71 (~, 06 50U.02.. S 1.669,11. w 1144,71 $ 73 4 w 544,48 S 1760,39 W 1842,07 8 72 4~ W 580.67 S 1~51.37 w 1940,30 fi 72 35 w b1~,3~ S 1941,95 W P03'7,40 5 72 23 W 650,98 S 2031,78 W 2133,5~ 6 7~ 14 W 684,14 S ~1~(),85 W ~2P~ 47 6 7~ 7 W 71~.83 S 2211,11 W 2323,79 S 72 5 W 744.14 S 7301.03 W ~418,37 ~ 7~ 4 ~ 77!,95 S ~3~a.28 ~ 2509.94 S 7~ 5 ~ 7Q7,85 S 2472~96 W ~598.48 S 7~ 7 ~ S 7~ 56 W 2684.~4 S 74 4~ W 27'tg.07 S 74 44 W 28B0.12 $ 74 4? W 2083,62 $ 74 4g W 3088.~7 ~ 75 g W 3193.51 ,~ 7b 45 W 3295 Iq S 75 56 W 357~.95 2,05 0,55 U, bO 0.5'~ 0,~2 1.25 0,93 0,~7 872,05 S 2555,91 w 26R4,85 .5 72 10 W t~47.4g S 9046,62 W 2779.00 :5 72 14 w 874'00 S 2744,36 W 2880 17 5 7~ 20 w 901,33 S 2844,31 w 2983:71 S 72 25 W 9~9.08 S P945,97 W ~0~9.00 S 7~ 29 , 95~.2~ S 3047,17 w 3193.6~ ~ 72 34 W 981.92 S 3145.94 W 3295,~2 S 7~ 39 w 1006,26 S ~241.97 W 3394,55 5 7~ 45 W 1079.74 S 3333.~1 W 3489.22 S 7~ 50 W !051.9Q S 34~1.23 W 3579,32 S 7~ 54 , S 77 3 w S 77 6 w 3820.90 $ 71 ~ W ~97.09 ,% 77 5 w 3073.37 g 7 'l 5 W ]080. (),37 (.), 95 (~, f) 0 t). Of" 0. U 0 !072,32 S 3503.87 w 3664.23 $ 72 59 W 1.0q0.o4 S 3581.82 W 3744,10 5 73 3 w 11. o'/'9R S 3657,56 w 3tt?l.6g 5 73 8 w 1125.04 S 3732.1~ W 38o8 O0 5 73 13 W 1142.14 S ]800.'IR w 3974:4~ S 73 17 w !143,7a S 3813.94 W 3981,76 S 73 18 w PAGE 6 DAT~: [.}r SURVF¥: K~jLI,Y PLtSHING E:LEVATION: 140,,00 FT SUR~'AC~ LOCATION AT TgD RFCT~NGII~AR COORDINATES ~P[)~ K~ SUB-SkA NL)R'~F!/$[jI.J~H EAET/WE~T 3564 17 w 3567 77 w 3595 36 ~ 3688 90 w 3733 93 ~ 3813 94 ~ ~ARKFR MEASiJP El', F) El P ~l' t4 PAGE 7 KI<[,bY P, USHTN¢; EbEVATION: 140.00 FT t<NGINELR: P FPP i-ii., 1.23' $ FKI, RFCT , AN(.; TH/ LOCATION AT KC b, TION, RgE UM ULAR COORDXNATK~ SO!~TH EAST/WEST 6067,8 t 61~2,07 {~242.42 t~'~ 49.60 587~.82 5~81.55 5917.81 6102.47 6209,60 10 10 lO 11 11 11 86, 87 93 ~ 43. 59 S 3564 42 S 3567 76 $ 3595 14 $ 3688 45 S 3733 78 $ 3813 77 w 36 w 9O w 93 ~ 94 w SOHLUMB£ROE ARCO ALASKA, INC. 20-16 KUPARUK NORTH SLOPE, ALASKA OCTOBER 28, 1984 Trw PLOT FROM OCT DATA dOB REFERENCE 69891- WELL' 2G-16 __ -~ SURFACE LOCATION' __3' FNL, 87' FEL, S6, TION, R9E, .4 VERTICAL PROJECTION -4ooo -~coo -~coo - ~oco o c ~ooo _*%o 3ooo _ _ ...... 14nnn ' ......... rm.. ~ ??00 ..................... ' PROJECTION ON VEF~TICAL PLANE OF AZIMUTH 2S2 SCALED I74 'v'ERT;C~L DEPTHS '-',O~'Z SCALE : ;/ 1000 WELL' 2G-16 ~ SURFACE LOCATION' _..3' FNL, 87' FEL, S6, TION, R9E, .,q HORIZONTAL PROJECTION SCALE : l/!OOO IN/FT -i00o -2000 -aO00 -4000 -SOCC -6000 SOUTH -7000 , I ~ J I I I,[ ,' i ' -7000 -6000 -6000 -4000 -3000 -2000 wEST - 1 ooo , E~ST ~, , 1 (.. ... \.. .. ~ . suggestéð' .i:o.rm to be inserted in each "!tl.VC" well folder to d1(~ck for titœly ccmpliance with Our regulations. .. A/(ctJ I<~-t-M.~ "l G - / .t, O¡:erator I \'1 . Narre and Numl:er . Reports and Materials to be received by: I';¡ :"I)l/-ð>~ Date Ro::tuired Date Received Rer.arks Canpletion Rep:>rt Yes , . Well History Yes .'k'~ ~ .. _Sanples Mud Log Registered Survey Plat 7-1 ðl'( ðl<. 6~ Core Chips Core Description Inclination Survey (; ---- (}' , Directional SUrvey /J--/ - () Yes -g~ Digitized Data e~ ð .~ -I .,/"'-- .- ~- ARCO Alaska, Post Office 360 Anchorage, .~aska 99510 Telephone 907 277 5637 Date: 11/19/84 Transmittal No: 4858 TO: ARCO ALASKA, !NC. ATTN: Records Clerk ATO-1!15B P.O. Box 100360 chorage, AK 99510 ///~ransmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS TAPES/Schlumberger 1L-15 10/23/S4 t~n 1 2G-16 10/22/S4 " 3470 - 6694 #69652 2899 - 7897.5 ,~-~9653 /cat Receipt Acknowledged: DISTRIBUTION B. Currier Drilling W. Pasher BPAE Geology Chevron Mobil Phillips Sohio Phillips Oil Union D & M NSK Ops. J. Rathmell Well Files (' ARCO Alaska, Int;. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 21, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Monthly Reports Dear Mr. Chatterton: ( c£e- ~~ -1C.\ ~~ ß ~ ø ~ Enclosed are the Monthly State Reports for the following wells: 2G-14 2G-15 2G-16 2E-16 lL-l lL-16 lL-15 2W-5 2D-3 2D-2 2D-l ä~~: ;¡;:r. v;twin' Area Drilling Engineer JBK/SH/tw- HILL/05 Enclosures ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRlchfleldCompany 2X-16 2X-15 2X-14 WSP #2 RECEIVED NC)V 2 6 19 Alaska Oil & 84 Gas Cons AnChorage. Commission STATE OF ALASKA ALASK,-, OiL AND GAS CONSERVATION ~J~v~MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well D(lX Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 84-132 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21163 4. Location of Well atsurface 123' FNL, 87' FEL, Sec. 6, T10N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) 140' RKB, PAD 104' 6. Lease Designation and Serial No. ADL 25667 ALK 2588 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 26-16 11· Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of October , 19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0530 hrs, 10/17/84. Drld 12-1/4" hole to 2934'. Ran, crated & tested 9-5/8" csg. Performed 50 sxs PF "C" top job. Drld 8-1/2" hole to 7900'TD as of 10/22/84. Ran logs. Ran, cmtd & tstd 7" csg. Performed Arctic pack w/250 sxs Permafrost "C" + 56-1/2 bbls Arctic pack. Secured well + RR @ 1015 hfs, 10/24/84. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 9-5/8", 36#, J-55 HF-ERW BTC csg w/shoe ~ 2910'. Cmtd w/900 sxs PF "E" + 370 sxs PF "C". 7" 26# J-55 HF-ERW BTC csg w/shoe ~ 7848' Cmtd w/400 sxs Class "G" 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SFL/GR/SP f/7884' - 2914' FDC/CNL f/7865' - 7250' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '.~~~f~-~' TIT E Area Dril ling Enginee_r DATE SIGNED L /v z // / ~. v ,'-- ............... / / NOTE--Re~ort-- ol~/thV/~rm is required for each calendar month, regardless of the status of operations, and must be filed ir(' duplicate with the Alaska Oil and G~s Conservt~,~n Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H I LL/MR25 Submit in duDlicate MEMORANDUM Sta e of Alaska TO: THRU: ALASKA OIL AND GAS CO~]SERVATION COb~ISSIOI] C. re, ton DATE: ~.~'~.2~ ,.~. ;. //' FILE NO: Lonnie C. Smith Co.is s ioner TELEPHONE NO: October 23, 1984 D.41.40 FROM: Doug Amos ~ Petroleum Inspector SU BJ ECT: Witness BOP Test at ARCO's Kup 2G-16 well, Sec. 6, T10N,R9E,UM, Permit No. 84-132, Doyon Rig No. 9. Wednesday, October 1~7, 1984: I traveled this date from J~chorage ~~h~e--~he BOP test at AP. CO's Kup 2G-16 Well. Thursday, O_c.tpber 18~ .... !984: The BOP test was delayed due to h-~-~[sUaliy- SI°w--d~fI~-~ the surface hole. Frida~f__,_October 19, 1984: The BOP test commenced at 5:30 am and ~ ~~e~-d~-~t 7':0~0~-~. There were no failures and I filled out an AOGCC BOPE test report which is attached. In summary, I witnessed the successful BOP test at ARCO's Kup 2G-16 Well. Attachment 02-00IA(Rev. 10/79) O&G #4 4/80 ST ~ 5: 50 4', Y]1 I STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location: Sec ~ T/D/v RqG H ÚIM, Drilling Contractor DðYON R. ig # q /0/ Jq /54- I I Well ku:p, Z6ï w I~ Representative C, 12 o5S Pe rmi t # 84 - / :3 Z. <"I 0/3 Casing Set @ -Z q 0 q I ft. Representativp .15;/1 1l4o/Z/V1/::JN Date Inspector Operator Vou Cí Arvt OS A Reo kuP) 2(1 -It:, Well Location, General IJK ACCUMULATOR SYSTEM ~ \'lell Sign cK Full Charge Pressure -;(?)(")O psig General Housekeeping 01( Pressure After Closure \í £1 (ì psig Reserve pit /')/<" 200 ps ig Above Precharge Attained~ min ~8 sec Rig /1 k Full Charge Pressure Attained: Î- min-Msec N2 ZøOn '2 -¿.¿¡ j J Z-Š{(){Q,. "2-5(0) -z..t>Oð>S ig 6k I Controls: Master (J~ Remote (!Jf<.. Blinds switch cover Yf3'S BOPE Stack Tes t Pres sure Kellv and Floor Safety Valves Annular Preventer vr'l J 9{) Òo Upper Kelly vY I Test Pressure 5 CJc:J (/ I I - Pipe Rams i/IJ<Lv( Z 3 I f)& () Lowe r Kelly tVl Test Pressure I " . Blind Rams v( / II Ball Type ~ ¡ Test Pressure f f .. Choke Line Valves (1~i- l! Ins ide BOP 0 I Tes t Pres sure l ~ H.C.R. Valve V\ I I! Choke Manifold I Test Pressure (I ,v..Y yJ Kill Line Valves 16 j: 4 II No. Valves /5 vr '" Check Valve 0 II No. flanges 3'2..- Adjustable Chokes ! Hydrauically operated choke I Test Results: Failures . :MIJ Á) ¡:::; Test Time I hrs. 3D Repair or Replacement of failed equipment. to be made within Inspector/Commission office notified. days and /1/ II 1/1 III 1/ ./1 Remarks: Distribution orig. - AO&GCC' cc - Operator cc - Supervisor Inspector D&t...A. c) / ~{)1-- July 31, 1984 Mr. J. B. Kewin Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2G- 16 ARCO Alaska, Inc. Pe~it No. 84-132 Sur. Loc. 123'FNq_,, 87'FEL, Sec. 6, T10N, RgE, UM. Btm~ho!e Loc. 1389'F~L, 104]'F~L, Sec. 6, T10N, R9E, I~. Dear Mr. Kewin. Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log informatiom, shall be submitted on all' logs for copying except experimental logs' velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Artzc!e 7 and the regulations promulgated there, under (Title 18, Alaska Administrativ~ Code, Chapter 70) and bv the Federal Water Pollution Control Act, as amended. Prior ~o commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. Jeffrey B. k=win Kuparuk River Unit 2G-16 -2- July 31, 1984 equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witnes~ present. V~f~_t ru ly ~9urs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY O~ER OF nE COM24ISSION Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box Anchorage~ Alaska 99510-0360 Telephone 907 276 1215 July 18, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 2G-16 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 2G-16, along with a $100 application fee ' ° Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat o A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment Since we estimate spudding this well on September 12, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, J. B. Kew~i~ Area Drilling Engineer JBK/JG:tw GRU8/L56 Ati~achments RECEIVED J U L 2 5 1984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -" ALASKA OiL AND GAS CONSERVATION CO~,,MlSSlON PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL FXIX REDRILL [] DEEPEN [] lb. Type of well 2. Name of operator AR60 Alaska, Inc. 3. Address Po 0. Box 100360, Anchorage, Alaska 99510 EXPLORATORY [] DEVELOPMENT OIL I~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC SINGLE ZONE MULTIPLE ZONE [] 9. Unit or lease na~e Kuparuk River 4. Location of well at surface 123' FNL, 87' FEL, Sec.6, TION, R9E, UM . At top of proposed producing interval 1294' FNL, 1334' FWL, Sec.6, TION, R9E, UM At total depth 1389' FNL, 1041' FWL, Sec.6, TION, R9E, UN 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 140', PAD 104' ADL 25667 ALK 2588 12. Bond information (see 20 AAC 25.025) I-ederal Insurance Company Type Statewide Surety and/or number #8088-26-27 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distance and direction from nearest town 30 mi, NW of Deadhorse 16. Proposed depth (MD & TVD) 7946' MD, 6347' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 1410 feet. 21 14. Distance to nearest property or lease line miles 1 23 feet 17. Number of acres in lease feet 2501 20. Anticipated pressures MAXIMUM HOLE ANGLE 4,5 o (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed 2G-15wel160' @ surface feet 18. Approximate spud date 09/12/84 2758 3167 psig@__._8_0 ° L Surface psig@ 6205__ft. TD (TVD) Hole Casing Weight 62.5# 36.0# 26. O# 22. Describe proposed program: CASING AND LINER Grade Coupling H-40 / We]~ J-55 HF]ERW BTC[ Length SETTING DEPTH MD TOP TVD 80 36' I 36' 2860 35' I 35' I I 33' 33' I 7913 MD BOTTOM TVD 116~ 116' 2895' 2750' 7946'1 6347' I QUANTITY OF CEMENT (include stage data) ± 200 cf 800 SX Permafrost E & 370 sx Permafrost C 300 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7946' MD (6347' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure is 2758 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 2000 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 2G-16 will be 60' away from 2G-15 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. The well will be completed by the workover rig using 3-½" · 23. I hereby certify that the foregoing is true and correct to the best of my knowledge ¢~.,//~ j//~ r,,,,~?~ Area Drilling Engineer SIGNED ( . ~. __ _~.~,~,).,.. TITLE Thespace~elow/or~o'~---- e /' DATE Samples required []YES ~.NO Permit number Form 10-401 Mud log required []YES [~LNO ! Directional Survey required I APl number [~YES []NO I 50-- ~'L.~ Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE July 3] , 1 984. by order of the Commission Submit in triplicate Permit to Dril 1 2G-16 9.2#/ft~J-55)BTC)tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. RECEIVED JUL2 5 19B~ Alaska Oil & Gas Cons. Commission Anchorage commission I' ANNULA~ PR£¥~NTER BLIND · ~ $PI°L . PIP~ ~ ~ 2 DIAGRAM ~1 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 2000 psi casing head 3. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 13-5/8" - 5000 psi pipe rams 6. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 12-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams 9. 12-5/8" -.5000 psi annular ACCUMULATOR CAPACITY TEST '1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON NADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTW THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND VAL~v~S U1)S~ O1~ CHO}~]~S. DON'~'T T~ST AGAINST CLOS~.D CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 e. ~~'PP~SSbI~ DOWN$~~ OF CHOI~ ISOLATION ~/ALV]~S: TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD.VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9.OPEN TOP SE-F OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSi WITH KOOMEY PUMP. 15. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. RECEIVED JUL 2 5 I~B~ Al~.sk~ Oil & Gas Cons. Commission Surface Diverter System 1. 16"-2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" X 20" 2000 psi double studded adapter. 4. 20" 2000 psi drilling spool w/10" side outlets. 5. 10" ball valves, hydraulically actuated, w/tO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annular preventer. 20" bell nipple. i i Maintenance & Operation 1, Upon initial installation close annular preventer and verify Ghat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 1 6" Conductor RECEIVED JUL 2 5 19B& Alaska Oil & Gas Cons. Gomrnission Anchorsge ARCO Alaska, Inc. Post Office ~,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 5, 1984 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 2G Pad Wells 5-16 Dear Elaine' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU8/L26 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ~ 49th .6 ,? ,,8 DY. 20 I HEREBY CERTIFY THAT I AM P£OPERLY REGI STERF~ AND L1CF-NSED TO PRACTICE LA~D SURVEYING IN THE STATE OF- A LA SKA AND TI-lAY TH 1 S P LAY REPRES~TS A SURVEY. MADE UNDER MY DIRECT SUPERVISION AND T~AT ALL DETAILS ARE COZt SCT As oF:_ - A 5276- $ 't LOCATED 5. Y-5944195.0~ %- 50,8929,92 236 FWL l- ~08929.90 236 ~L 7. Y-~94407~.12 Z- 508930.00 236 ~L 5. Y-5944~ 1 Z35 ~L t. AT- 70-15-31.5000 LONG- 149-55-40.162 607 FSL LAT- 70-15-30.9115 LONG- ! 49-55-40. l $5 547 FSL LAT= ?0- ~5-~0,3204 487 FSL LiT- 70-15- 29.72~1 LONG,. ] 49-55-4~. ~ 88 427 i~L LOCATE) IM $£CTIOI 5,TI 9. Y-)943465.24 X- 50B969.91 273 FWL la. Y-~943405,{0 Z- 5os9~.75 272 ~L I I. Y-59433~5.24 ~- 50~969.92 272 ~L 12. Y-59432~5.17 ~- 50SS~.S4 LAT- ?0-15-24.32t$ LONG- 149-55-39,024 IZ3 FNL L.AT- 70-15- 23,7297 bONO,- 149-55- 39,031 183 FNL LiT- 70-15-23. t409 LONC-, 149-55-39.025 243 LAT- 70-15-22.5500 1.,O~O- 272 FW.L 303 FNL LOCATED IR SECTIOI 6.TION,RgE, U.M. I5. Y-59432<~5.15 LAT- 70-15-22.5542 X- 50B609.92 LONO-149-55-49,504 14, Y-~943MS.!5 LA?- 70-15-23,1441 X-508~.g0 I,,ON0-14~-55-4~.50:1 88 FE~ 243 FNL ~5. Y-594S405.25 X- 50S609.95 t,ONG,,l'l~55-qg.q~0 \ ~- - ' -- 6. Y-5943.465.22 LAT- 70-15-24.3252 %i 508609.93 LONG- 149-55-49.491 JUL ARGO Alaska, Inc. Kuperuk Proj~t North Slope Drilli D,S. 2,0 CONDUCTORS 5' 16 AS- BUILT 6,2.04 /' Company ~u Lease & Well No. /¿ ¡¿ ~. t- ~ - /~ CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee ~ ?-1Æ:J'1 (2) Loc ~, ~", 'j. 1.f";~ 2 thru 8) 2. 3. 4. 5. 6. 7. JlJfI 7-~'-H''I 8. (8) (3) Admin ~ )--¡.r-t"l 9. ~ 11) 10. If.¡¡1f 7-~-Zr 11. (10 and 11) (4) Casg )lð/I 7-~-<¡1 12. (12 thru 20) 13. 14. 15. 16. 17. 18. 19. 20. <----- (5);BOPE~7~':"fr (21 thru 24) (6) Add: III II ?-~-8Y rev: 12/08/83 6.CKLT ê- t:j 0 t-3 ::I:Z HO ~t-3 ~~ >H nt-3 t%jt%j H Z ~C"",'",',","!,'~",'", ..,~ YES NO REMARKS 1. Is the permit fee attached Is well to be-located in a defined pool............................. Is well located proper distance from property line .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................. ~ C~n permit be approved before ten-day wait ..........................~ Does operator have a bond in force .................................. ~ --- Is a conservation order needed ...................................... ~ Is administrative approval needed ................................... --- Is conductor string provided .........................................110 --- Is enough cement used to circulate on conductor and surface......... ¡/ðH --- Will cement tie in surface and intermediate or production strings ... ,7lllI Wi,ll cement, cover," all,' known productiv,e, ho,rizons" .. .,. ..",. ., .. .., ........ ,I," --- Will surface casing protect fresh water zones ......................., --- Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore. . . . . . . . . . . .. --..:... 1ftiI. Is old wellbore aþandonment procedure included on 10-403 ............ , ' --- ,R,I} # Is adequate well bore separation proposed....................... . . .. lIiif SEE.. /? E:.MI -RI< ~ 21. 'Is ,a diverte,rsys}t:.em ",req1:l1red",.."..,....,. :.."..'.'...'.'.'. ,.;,."...:. ..... ..:...;..,.;"~"~ 22. Are necessary diagrams of diverter and BOP equipment attached ...... .,11411 --- 23. Does BOPE have suf~icient pressure rating - Test to ~1I1J7> ',' psig . .1flíI--- 24.. Does the choke man1fold comply w/API RP-53 (Feb. 78).................. --- AfOrSUBMI1/E'D .,,,./" 25. Additional requirements . . .. . . . . . . . . . . eo . . . . . . . .'. . . . . . . . . . . . . . . . . . . .'. . --- liÆl:f. Additional Remarks: /A) É J..'-. :;.6 -lklAl/l..l... ÇE ~/)/ FROM ~/;-/~ F/l /)/'1 s V ÆP~E Tl> J/f/ð" rv [)¡ r¡t£REIJR E t1Jb 0 TilE/( (!)..OSJi5. 1/)£)..).. ßL>R.ES ÐowN#ðLt:." INITIAL GEO. UNIT ON/OFF POOL CLAS S STATUS AREA NO. SHORE t{~Q'óu t?tAJ . -0 ,1) I,ù 11(1,6 Ijl\) 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 APPENDIXl No special'effort has been made to chronologically organize this category of information. ~ ,-' . (0"., , ,'" ',,', ,> /',.-¡, ~ , ~ , , " ,', " ,t. $". UNIT TYPE CATE SIZE CDOE " .~ " " " , "',, ,,' t ' / '" ";t6t,' ,;,,",,: ; :',; '/,:,'~~r ¡{¡ "'/'<; ~:' ::;'t~:~\ ;,; ,:~~ ';, 6"~¥~ ~,:0 ,:'; ;},'\;,~' " " " ,,6,', " ""',, ... '" .. "'. 7'11' " "i" " . ,"< ' " " , , " w.~~\. . , " , ' .' '/\. " , ' , , , , /¡' ~ " " , ", ~, , (, ,I,,' , ,~ , " '" ~ -'" " ,~ f ,,' '" ,. , " ( .. -. --. -- -- _... -- '-- -- ~ -~ - ", ~ - ~ :. . , 'I' . or II' ,- 11" .. ~ ~"1" .. ,,.,... ."..- .... -.. -,. "" '!I' ' .". " ~, 'I' 'r ~. 'f" ..." , "'"" - 1" '" 'or ,'" ",- ~ '" "'" .",.. :; 'D'EPT 1.9326 - 399,.. 2500 -399.251,J0 " ~ , -999.2500 DEPT 3~OC.:~f)QC 5J::~_U r- 5.1055 ILj :5",7617 !LM 5.3008 , ^' . ~ -" - "" ,- r ~ ." '" "" .. '" ... " _. *", --.. ~ .... "... -,- "!\""'..' ","M "'"~ 1"" -,. or- r ..- ..,..,' --- ",-- -.. -- .,..." r- .--. 'ß"EPT SP RHD,B NPHI 3100.000fJ SFLtI - :3 4 1 . 7 5 CO.;; R - :1 9 .~ ,.. .2~.o Q D RHO - 99 '1'..25!J 0 NC Nl SFLU JEPT SP RH03 ;j~:;e:~::: , 2393.rJOQO SF,-U '-306.5000 SR -~91.2500 ;J R:-i 0 ,~,~~ ~1,~2,~,P,Q ", N"C,~~,L,: " , 5.6,2'89 Il'O 61.3125 G'R -:- '~ 93. 2 5 £Hi l~ R,A,¡ -'999,. '2,500 FtNL ItM CALI RNRA , ~.O541 -999.2500 -999.2500 9.4922 -'999.2500 -99'1.2500 ,~, ';¡,;:;' ):::,:;;,:~<?<~ :~;:r~;~,;~"q:",,' TI 114 êAL'I ~NQA zaoo.oooo -999,.2500 -999...2500 , , "" , "r.' ~ REEL TRA!LER ** ......." . 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